Salym Petroleum Development N.V. (SPD) is a Joint Venture operating and developing the Salym group of oilfields in Western Siberia. The fields are artificially lifted, predominantly using variable speed drive ESP's for some 330 wells (Q1 2010). Pump controllers and well head instrumentation has been tied-into a SCADA/Historian system. The basic control system is being enhanced by progressively installing Shell's integrated Smart Fields* capability based on the combination of FieldWare* suite of real time software applications (for real time monitoring, surveillance and control), electronically linked to offline Integrated Production System Models and the Hydrocarbon Accounting System. In this application FieldWare consists of four modules: -Production Universe -real time oil, gas and water flows for all of the wells virtual flow measurement and for real time monitoring of ESP operating downhole parameters; -ESP -real time pump efficiency curves, reports, surveillance and remote control complemented by Mikon echometer fluid level measurement; -EOR -water injection optimization and real time water flows from source to injection, including real time monitoring of surface vessels levels, surface pumps and wells injection pressures and rates; -WellTest -well test optimization, enabling real time well test measurements screening, troubleshooting and automatic transfer of test data to the hydrocarbon accounting system.The purpose of this paper is to describe/quantify Smart Fields benefits seen so-far in terms of less operator travel and hazard exposure, reduced ESP interrupts, more stable operations and faster re-starts. Benefits quantification is facilitated by meaningful comparison of automated and yet-to-be automated parts of the field, including impact from the deployment of Smart field Technologies in Salym fields.

In Shell, asset professionals use advanced technologies and processes for field management and optimising production performance. Real time monitoring of wells and compressors has become the norm, delivering higher uptime and increased production. Asset teams use visual information on hundreds of wells and their facilities using a web-based portal. The wells and facilities with events or deviations, i.e. exceptions, are highlighted, enabling the staff to focus on fixing the critical wells and facilities. The information is brought together in Collaborative Work Environments with video connection to streamline the communication between field and office and speed up decision making. Shell has implemented these capabilities in a number of assets around the world, for example in Oman, Russia, Brunei, UK and Gulf of Mexico. The people side is a large part of the attention, during the implementation and for sustainability of the solutions. Awareness sessions, training, local ownership, feedback sessions, coaching and regular reviews are part of the embedding activities. The paper describes the capabilities and the benefits, and illustrates this with a field case from Salym in Russia. This includes the approach to change management and learning from both the project and the embedding phase. The benefits include HSE improvements (less travel exposure), increased production and reduced operating cost.

Salym Petroleum Development (SPD) has embarked on an ambitious Oil Field Management Improvement Program with as key objectives to:• Optimise Production (2.5% additional production through reduction of Locked-in-Potential and better reservoir pressure maintenance; unscheduled deferment less than 1% through reduction of ESP trips).• Increase Ultimate Recovery (Increase RF by 1%; platform for future EOR project; robust basis for infill drilling).• Reduce OPEX (increase ESP mean time between failure; contain chemical consumption costs; in field staff journies reduced by 10% /annum; less than 3 non-critical loss of integrity incidents per year).

Salym Petroleum Development (SPD) has embarked on an ambitious Oil Field Management Improvement Program with as key objectives to:• Optimise Production (2.5% additional production through reduction of Locked-in-Potential and better reservoir pressure maintenance; unscheduled deferment less than 1% through reduction of ESP trips).• Increase Ultimate Recovery (Increase RF by 1%; platform for future EOR project; robust basis for infill drilling).• Reduce OPEX (increase ESP mean time between failure; contain chemical consumption costs; in field staff journies reduced by 10% /annum; less than 3 non-critical loss of integrity incidents per year).