Search citation statements
Paper Sections
Citation Types
Year Published
Publication Types
Relationship
Authors
Journals
Oil and gas companies increasingly require environments that support real-time E&P business processes, where wellsite information, applications, and experts can be linked with operational managers and decision makers in one place so that daily operational parameters can be viewed and decisions executed. Most companies believe that making decisions in real time while leveraging global resources and infrastructure will help to improve their field productivity while reducing costs. Project team members are often collocated to ensure open communication and planning. However, since E&P activities often take place in remote and hostile parts of the world where it may not be possible or economical to deliver all the required resources and personnel, global operations with dispersed personnel frequently require such operations support centers to be "virtualized." Reliable and secure information flow is central to ensuring success in the contemporary oil field. In a previous paper, the authors outlined the significant challenges of process, networking, security, hardware, and software infrastructure encountered in creating and supporting these integrated operations centers. These challenges include the end-to-end IT infrastructure such as wellsite and field IT, the design of the work processes to be supported, and the business model for company implementation. This paper discusses some of the progress that has been made in meeting these challenges over the past year, with particular focus on the actual applications that support oilfield operations. Introduction Exploration and production companies are turning towards integrated operations centers as a means of gaining improvements in operations such as drilling and production, where access to real time data and analysis can lead to gains in productivity and efficiency. Operators and service companies have a range of strategic business activities that may be referred to as "real-time." These strategic businesses need global, sophisticated systems with many elements of infrastructure to carry those business applications.
Oil and gas companies increasingly require environments that support real-time E&P business processes, where wellsite information, applications, and experts can be linked with operational managers and decision makers in one place so that daily operational parameters can be viewed and decisions executed. Most companies believe that making decisions in real time while leveraging global resources and infrastructure will help to improve their field productivity while reducing costs. Project team members are often collocated to ensure open communication and planning. However, since E&P activities often take place in remote and hostile parts of the world where it may not be possible or economical to deliver all the required resources and personnel, global operations with dispersed personnel frequently require such operations support centers to be "virtualized." Reliable and secure information flow is central to ensuring success in the contemporary oil field. In a previous paper, the authors outlined the significant challenges of process, networking, security, hardware, and software infrastructure encountered in creating and supporting these integrated operations centers. These challenges include the end-to-end IT infrastructure such as wellsite and field IT, the design of the work processes to be supported, and the business model for company implementation. This paper discusses some of the progress that has been made in meeting these challenges over the past year, with particular focus on the actual applications that support oilfield operations. Introduction Exploration and production companies are turning towards integrated operations centers as a means of gaining improvements in operations such as drilling and production, where access to real time data and analysis can lead to gains in productivity and efficiency. Operators and service companies have a range of strategic business activities that may be referred to as "real-time." These strategic businesses need global, sophisticated systems with many elements of infrastructure to carry those business applications.
Accurate individual well production rates are essential to meet corporate production target plans, optimize reservoir performance and make reservoir management decisions that may require well intervention. Short of installing rate measurement devices on each well, a "back allocation" method is generally employed to assign well production rates, using multiplying factors based on well tests conducted the month before. Apart from the inherent errors, based on the assumption that the wells produce at the same rate throughout the month, the process is also not suited for real-time field management that requires production rates to be known much more frequently.This paper describes the implementation of a system that automates the calculation of individual well production rates using real-time pressure data from permanent sensors installed on the wells. The system, based on integrated physical models of the reservoir, well and surface network, has been successfully used to implement crude blend management in a large Saudi Arabian field, producing from three different reservoirs. The paper also describes how the system is used to automate the validation of well test measurements, allowing the engineers to focus their time on problem wells while ensuring that all wells are reviewed. In addition, field models are kept evergreen and can be utilized by different disciplines for production forecasts. Application of the system could result in significant cost savings, due to reduction in the requirements for physical metering of well production. The system also provides unique optimization opportunities, allowing the engineer to determine the optimum settings to maximize production or revenue. Other benefits include, faster resolution of production problems due to early problem detection, focus on exceptions rather than bulk and massive troubleshooting, and zero-latency applicationassisted decision making, all combining to bring real-time field management and optimization to the engineer's desktop.
Reservoir engineers operating in mature fields across the world struggle to get necessary reservoir data to make their exploitation plans more realistic. Pressure transients are the most effective way to understand the dynamic behavior of the reservoir. Loss of production and cost of acquiring data versus the benefits has always been a classical management dilemma. With the advent of digital oilfield technology, the pressure and hence the deterioration in well deliverability can be continuously and cost effectively monitored. This paper illustrates how real-time data can be used to make decisions on when to invest in pressure transient tests, and when a test is run, how to minimize the downtime. The case studies presented here are for wells on electrical submersible pumps in various types of reservoirs across Latin America.The paper briefly discusses the three pillars of digital oilfield; technology, processes and people and how they work together to achieve continuous reservoir and production optimization. Reservoir analysis for wells on electrical submersible pumps (ESP) is challenging due to the restrictions imposed by the downhole equipment. Our work presented here focuses on developing workflows and interpretation techniques for this unique environment.Having sensors downhole provides operators with an opportunity to get pressure drawdown and buildup data when the ESP starts and stops. For the wells we monitor, 10% of these unscheduled events provided much coveted reservoir information without having to stop the production intentionally. For the scheduled pressure transient events, the data acquisition rates were actively changed to ensure sufficient high quality data. Also, the length of the test was decided in real time to make sure that the test was long enough to meet the objectives but not too long to increase the cost without additional benefits. Thus with real-time technology we were able to overcome the shortcomings of traditional well testing and address the concerns of both engineers and the management. Case studies are presented where production enhancement opportunities were uncovered as a result of scheduled and unscheduled events on wells producing with ESPs. The results show that more than 70% of wells can benefit from stimulation, potentially increasing production up to 300%. To make proactive decisions and act on the recommendations generated from these production enhancement opportunities is still a challenge that needs to be addressed.For fields with large numbers of ESP wells, a time snap of reservoir properties could be periodically obtained to track changes in pressure, skin and permeability for real time optimization.
scite is a Brooklyn-based organization that helps researchers better discover and understand research articles through Smart Citations–citations that display the context of the citation and describe whether the article provides supporting or contrasting evidence. scite is used by students and researchers from around the world and is funded in part by the National Science Foundation and the National Institute on Drug Abuse of the National Institutes of Health.
hi@scite.ai
10624 S. Eastern Ave., Ste. A-614
Henderson, NV 89052, USA
Copyright © 2024 scite LLC. All rights reserved.
Made with 💙 for researchers
Part of the Research Solutions Family.