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The digital oilfield technology is typically associated with high level of field automation and instrumentation, as well as advanced petroleum engineering modelling. This paper discusses the application of digital oilfield to large brown fields based on real, but anonymous cases, where the level of instrumentation is low, production models might not be available, and the local expertise might be limited. In such situation, the principles of digital oilfield need to be adapted. This paper presents a staged implementation methodology, where the benefits and costs can be evaluated at every step of the project, allowing to build a system with the right amount of functionality and complexity. The first step focuses on improving data quality, even if the data is captured manually, through automated quality checks and raising awareness during the data capture process. The second step focuses on automating routine tasks, such as reporting, leading to efficiency improvement, but also increased accuracy and traceability of the reported figures. The third step focuses on developing a production monitoring platform, allowing to perform exception-based surveillance, particularly important for large fields, as well as providing a single point of access for different disciplines, hence acting as a collaborative environment. At last, the model-based more complex workflows are discussed, such as virtual metering, production optimization and short-term production forecasting. The main conclusion of this paper is that the Digital Oilfield can deliver value for brown fields, even if they are close to their life end. The relatively low cost of these solutions, and the immediate benefits they can provide makes it meaningful, even in a short-term perspective. A staged implementation lowers both the project risks and the required initial investment, while easing the adoption process by the users. The main differences with application to green fields is an increased focus on data quality improvement, and a lower focus on models and complex engineering workflows. The surveillance platform should also focus more intensively on exception based surveillance, allowing to pre-process large amounts of data, rather than providing extremely fine detail.
The digital oilfield technology is typically associated with high level of field automation and instrumentation, as well as advanced petroleum engineering modelling. This paper discusses the application of digital oilfield to large brown fields based on real, but anonymous cases, where the level of instrumentation is low, production models might not be available, and the local expertise might be limited. In such situation, the principles of digital oilfield need to be adapted. This paper presents a staged implementation methodology, where the benefits and costs can be evaluated at every step of the project, allowing to build a system with the right amount of functionality and complexity. The first step focuses on improving data quality, even if the data is captured manually, through automated quality checks and raising awareness during the data capture process. The second step focuses on automating routine tasks, such as reporting, leading to efficiency improvement, but also increased accuracy and traceability of the reported figures. The third step focuses on developing a production monitoring platform, allowing to perform exception-based surveillance, particularly important for large fields, as well as providing a single point of access for different disciplines, hence acting as a collaborative environment. At last, the model-based more complex workflows are discussed, such as virtual metering, production optimization and short-term production forecasting. The main conclusion of this paper is that the Digital Oilfield can deliver value for brown fields, even if they are close to their life end. The relatively low cost of these solutions, and the immediate benefits they can provide makes it meaningful, even in a short-term perspective. A staged implementation lowers both the project risks and the required initial investment, while easing the adoption process by the users. The main differences with application to green fields is an increased focus on data quality improvement, and a lower focus on models and complex engineering workflows. The surveillance platform should also focus more intensively on exception based surveillance, allowing to pre-process large amounts of data, rather than providing extremely fine detail.
Drilling a well is comprised of multiple activities which are linked to the well objectives and requirements set in the design phase. Some of the activities have short term impacts on the well such as logging a section etc., and some of the activities have long term impacts on the well such as cementing, wellbore accessibility etc. It is quite important to list the activities based on their impact on a well and rate them individually to get the overall impact on the objectives of a well by these activities. Conventionally a well quality score was reported 6-12 months after a well was completed. The quality cycle to improve the performance of a well became ineffective and irrelevant due to late reporting. The results of the activities of a completed well were so late that many wells had been drilled and completed during the reported period. First, this major flow turned the existing Well Quality KPIs into laggard KPIs, which were not contributing to enhancing the Quality of a delivered well. Second, the well quality score was distributed among four different categories where Well Integrity was an isolated category, and a well integrity issue has minimum impact on overall well quality scoring. Third, the scoring guidelines were very generic and were depended on the evaluator judgment. A lack of verification of the results was also evident during KPI reporting, which made the KPIs score skeptical and unreliable. Fourth a fixed scoring structure was used to evaluate all type of wells at the same scale. Such as the scoring of a complex well was treated the same manner as a scoring on a workover well. Last, some activities were ignored in the well quality scoring such as Coring Quality, minimum Well Integrity requirements etc. The overall score does not represent the actual picture of a well using existing Well Quality KPIs, which was impacting the overall project quality score. A new approach was adapted to capture the well quality score right after a well is delivered so that improvement ideas can be implemented in the current drilling wells in the execution phase and coming wells in the design phase without any delays. The quality cycle was improved resulting in shorter well duration with lesser well integrity issues. A new weightage system was introduced to capture all activities in a well, where these activities are evaluated individually. Scoring criteria for each activity is defined clearly. Based on deviation from the planned activity, the actual score is recorded accordingly by the user. Later these activities are verified by the end users, so verification is enhancing the trust as well the validity of a lesson learned. Users and end users are connected at an early stage after a well completed to capture the feedback. Improvements get quickly implemented as the quality cycle is short and quick. The new scoring method introduced a wide range of Well Integrity checks based on rigorous and clear guidelines, where failure to meet key well integrity policies can result in nulling the overall score of a well. New well quality scoring guidelines provide a clear and efficient approach to score the key performance indicators of a well at the right time. Consistency in scoring, timely reporting and right weightage for well quality scoring results in high quality well programs, application of fit-for purpose technologies and better knowledge transfer among team members.
ADNOC operates its onshore and offshore fields through its operating companies. In order to effectively govern and steer the operations, it is essential for ADNOC to monitor, track and measure key reservoir and production performance indicators efficiently on time. In this regard, ADNOC Upstream has established an integrated reservoir and production performance visualization environment that enables upstream departments to efficiently monitor the performance of onshore and offshore operations at different levels from the headquarter in a collaborative manner with the operating companies. The integrated visualization environment is built on four key components, the upstream data hub, visualization, process automation and data governance which forms the common foundation for various upstream projects, enabling multi-project collaboration, reporting integrity, common business data and KPI definitions. The datawall in Thamama Collaboration Center is powered by the integrated reservoir and production performance visualization dashboards configured on objective based themes such as Reservoir Management, Production Assurance, Business Plan Assurance and others required by different departments. The visualization capability is enabling engineers and managers in the upstream directorate, to monitor key reservoir and production performance information on a daily and periodic basis, and the solution facilitates collaborative review sessions with OPCO team either on a regular or adhoc manner and to initiate and track actions. The integrated visualization environment shall be continuously enhanced to add more themes based on business needs, and to carry out advanced data analytics to predict and forecast performance leveraging the established foundation. Business processes shall be streamline through automation of the performance measurement processes to achieve higher degree of digital transformation.
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