Much can be done to improve the Well Testing through effective use of minimal electronic instrumentation on the well head and the test separator. The purpose of this paper is to describe Shell tools and experiences using the resulting real time data to enable well test optimization and automation. 1.0 Introduction The purpose of well testing is to periodically determine oil, gas and water flows for accounting, reporting and surveillance purposes. Hydrocarbon allocation provides official reports of well and reservoir production for lease owners, petroleum revenue tax purposes and management reports as well as feeding into hydrocarbon reserve figures and reservoir simulations which are used for major field decisions e.g. where to drill the next out-step well. Surveillance is key to determining well and reservoir behaviour and ensuring optimal well productivity and integrity. Routine well testing is an established procedure. Wells are for the most part manually diverted to a gravity separator or multi-phase meter and oil, water and gas phases are measured discreetly. Tests are periodically conducted, for example once a month, or once a week. The duration of purge and test periods are usually fixed, for example 30 minutes to purge the test separator and eight hours to test the well. The manual well testing process is subject to error and uncertainty - the wrong well may be put on test, the wrong instrumentation may be used, the instrumentation range may be incorrect and instrumentation may be dysfunctional. After the well test is complete the final result may be good, bad or suspect, hence results are usually subject to a manual validation process. This begs a number of questions related to well test optimization and automation: The purpose of this paper is to discuss Shell E&P experiences and real time software applications relating to the above well test optimization and automation issues.

TX 75083-3836, U.S.A., fax 01-972-952-9435. Abstract This paper summarizes the findings of the SPE Forum held in September 2005 on "Making our Mature Fields Smarter".

TX 75083-3836, U.S.A., fax 01-972-952-9435. Abstract This paper summarizes the findings of the SPE Forum held in September 2005 on "Making our Mature Fields Smarter".

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractMuch can be done to improve the Well Testing through effective use of minimal electronic instrumentation on the well head and the test separator. The purpose of this paper is to describe Shell tools and experiences using the resulting real time data to enable well test optimization and automation.

Although the implementation of Smart Fields, or Digital Oil Fields is at last gaining momentum, many companies continue to place the measurement of benefits in the 'Too Difficult' category. It seems to make sense that the combined capability of a Smart Field should allow more value to be extracted from the field, but measuring value from a large programme of interdependent projects can be difficult. Attempts to allocate benefits to individual projects can be misleading and often results in double-accounting between different stakeholders, and some of the 'high value' benefits associated with additional recovery are difficult to quantify and are typically realised many years into the future.This paper addresses some of the tangible benefits that have been identified in ADCOs first Smart Field development, together with the expected benefits in implementing similar capabilities across the other assets. It explains how several different levels of wellhead instrumentation and control were evaluated to determine the level of smartness which generated the highest business value.The results of the assessment have been used to support the roll out of a corporate wide, integrated Smart Fields programme, covering well instrumentation and control, an upgrade to the telecoms infrastructure, analytical / visualisation applications and collaborative work environments.