BSP: An evolution from Smart Wells to Smart Fields

Abstract

Abstract This paper discusses the "evolution" from Smart Well installations to the delivery of a fully integrated "Smart Field". Capabilities were first developed and tested in nearby fields before being applied in the Champion West field. Results and issues with the component Projects are discussed. The creation of a "Smart Field team" with representation from Petroleum Engineering, Well Engineering, IT, Control and Automation, Data Management/Application, Facility Engineering and Production Engineering is seen as a key enabler for a successful Smart Field development. Introduction Brunei offshore waters are known to be rich in oil accumulations. Not all of them are straightforward economic discoveries. In the case of Champion West (CW), the field was more or less accidentally discovered in 1975 by an out step development well from the Champion Main field, drilled for gas lift supply. Fortunately, the well discovered oil, a new field was discovered and the discovery well was renamed to Champion West -1. Through various appraisal campaigns, the complexity of the field became evident (very erratic charge in stacked (some 100) reservoirs in 10 fault blocks). Many field development plans (FDP) were drafted, but none of them executed because the oil development costs were too high (too many platforms and too many wells). Developing the CW oil and gas accumulations as a gas field only (i.e. forgoing the oil) was never acceptable to the Brunei regulator or Brunei Shell. An FDP was started in 1998 but execution was terminated after major drilling problems were encountered. The last FDP is being executed in a phased approach. The current FDP is different from previous plans in the fact that it relies ona novel well concept,smart well technology andextended reach drilling. Now only a single new platform and 20 wells from there are planned to develop the field. With this "smart" FDP, 15 years after discovery, the CW field became the largest undeveloped hydrocarbon resource in Brunei and will support Brunei's oil and gas production (340 mln Boe) for the next 20 years. Peak oil production is expected end-2006 to be around 50,000 barrel per day, some 20% of Brunei's export. Gas production will support LNG sales for many years. Vision Early on in the Project Lifecycle (1999), the vision was agreed to develop the CW field from the new platform as a "Smart Field" and it was selected as the first candidate for implementation of "Smart Well" systems. The plan was to develop the field as a fully integrated, remotely controlled and operated field where regular pressure, temperature, fluid and flow data is continuously gathered and immediately transmitted to end users for on line monitoring and control. Production allocation was to be automated and the data flow linked to well, reservoir and production models to ensure optimal well and reservoir management policies were adopted. A technology staircase was used for a stepwise approach to the introduction of smartness in the operator. This vision was widely advertised, supported by operator's management team and also adopted by Shell's central technology council. The project became a key demonstrator project for the Shell group for smart field developments and as such, receives great focus from its top management. Phased Staircase approach With this vision for the CW field formulated for a 2005 development, operator realized that a phased approach of the introduction of smart well and smart field technologies was the only way to success.–Phase 1- Introduction of smart well technology in 1999–2000.–Phase 2 Upgrade of an old facility to a new smart facility with remote control of surface Flow-Control-Valves (FCV) and Inflow-Control-Valves (ICV's) in 2003–2004.–Phase 3 - Installation of a new smart platform in 2005.