The ultraviolet (UV) absorption spectra of several gasoline samples are measured using a compact static Fourier-transform (FT) spectrometer. The FT-UV spectrometer is constructed from crystalline quartz Wollaston prisms and polarizers fabricated from beta barium borate to form an interferogram in the spatial domain. The interferogram is recorded with a UV-sensitive detector array and Fourier transformed to yield spectra. Investigation using principal component analysis enables the identification of important gasoline properties such as origin.

In recent years advances in computing and control technology have enabled real time monitoring, surveillance and control of reservoir, well and process; Within the Exploration and Production (E&P) industry these technologies are increasingly being applied throughout all phases of oil and gas field development and production. Arguably least attention has been given to asset operations, where the rewards are actually harvested. "Smart" technologies can significantly increase value here, provided they are properly focused and implemented, and integrated into the facilities daily operations. The successful implementation of smart applications requires new ways of working and different skill sets of the operators and support engineers. This is a particular challenge in mature assets, where the operational style has become embedded through time. Fieldware Production Universe, "PU" is an application developed within the Royal Dutch Shell Group, ("Shell"). Real time signals from individual wells e.g. tubing head pressure, are processed by numerical "data driven" models to estimate three phase flow from individual wells. Total production from the facility is reconciled to individual wells using these estimates. These flow estimates change the traditional process of periodically routing a well's production to a test separator; individual well flow information is available all the time and tests are performed only when necessary to validate or update PU models. A more advanced version of PU, PU-RTO also allows the use of the models for real time production optimisation. To get from research to a fully implemented and sustainably used product is a lengthy and sometimes arduous task. Across the industry most operators can think of at least one system that has been "rolled out" but not been fully adopted and has "died" before it delivered it's full value. Reasons for failure are many, but often centre around support and delivery of true benefit to end users. This paper discusses Shell's experience with, PU, and it's application for real time production optimisation on the Nelson platform in the UK sector of the North Sea . The paper describes PU, how the applications were implemented, some of the challenges faced during the implementation and the changes that have had to be made, resulting in a PU becoming a sustainable part of the "way we do business". Introduction Shell Exploration & Production in Europe operates a wide range of assets from new greenfield developments through to 30 year old brownfield platforms. Technology continually advances and whilst new development may have the latest technology the business case for large investment on brownfield assets is not always clear cut. One such brownfield facility is the Nelson Platform, constructed in 1994 and entering Shell's portfolio in 2002 following the acquisition of Enterprise Oil. Situated 200 km North East of Aberdeen, Nelson wells produce approximately 6,000 m3 Oil and 450 kSm3 gas per day from 33 platform wells and two sub sea tiebacks, approximately 60% of gas production is used to power the platform. All wells produce from the same reservoir and have water cuts of between 10 and 95% with an average of 80%; the approximate Gas Oil ratio is 78 m3/m3. Production is assisted through gas lifting of all the wells. Platform operations staff operate a 14 day two shift system, many operations staff have worked on the platform from commissioning.

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Within the Exploration and Production (E&P) industry much focus has been on the application of "Smart" technologies. Deployment of these technologies has frequently focused on new field developments, where costs of installation and training of users are included in the overall field development cost. However within the Royal Dutch Shell group of Companies ("Shell") a significant volume of hydrocarbon production comes from mature assets, where the business case for such large investment is not always clear. The level of installed instrumentation and it’s condition on these platforms, whilst not impacting on the integrity of the asset, is not always optimal for the implementation of "Smart" technologies. Globally within Shell two programs, Well and Reservoir Management (WRM) and Smart Fields Foundation Mark I ("Mark I"), are being deployed to a number of assets. These programs focus on "fixing the basics" and deploying a minimum "foundation" level of smartness to support field management best practices. The successful implementation of Mark I requires new ways of working for all members of the asset; from offshore operators through to onshore petroleum engineering staff. Using a set of integrated applications and processes, it is only when these changes are fully embedded that the production and other benefits expected by the project are realised. The authors describe both the technical installation and subsequent implementation of Mark I on the Nelson platform in the central UK sector of the North Sea. The topics covered include; challenges in the installation project, changes to the way operations are executed in the asset, organisational changes and the development of a support structure to ensure the Mark I applications remain sustainable. The paper documents the benefits realised from an implementation that is focused on changes in peoples working practices with minimal capital investment.

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