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• W2084260704 abstract "Abstract A reliable liquid rate estimation is critical for evaluation of well and pump performance in wells lifted using electric submersible pumps (ESPs). The estimation of reliable liquid rates is a challenging and complex task even in digital oilfields (DOFs), such as the integrated Kuwait Integrated Digital Field (KwIDF) project in the Sabriyah (SA) field in North Kuwait. The correct liquid rate estimation is necessary to identify the ESP operating point to extend the ESP run life, improve field uptime, and identify production optimization opportunities. Different methodologies have been adopted to provide the most reliable virtual liquid rate estimation:Real-time rate measurement.Virtual rate estimation based on well modeling using iterations of wellhead pressure (WHP) and pressure drop across the pump.Virtual rate estimation based on a well gradient plot using iterations of WHP, water cut (WC), and gas/oil ratio (GOR).Empirical correlation (tubing head pressure [THP] vs. liquid rate) based on measured data during surface multirate production testing. This paper describes the approach adopted in the KwIDF SA for the best estimation of the real-time liquid rate in each well. The daily production rate reconciliation approach used in the KwIDF SA field will be discussed as well. Using this approach, better well surveillance was made possible and an 18% increase in field uptime (equivalent to a 4% increase in production recovery) was achieved. In addition, more effective proactive analysisand a more stringent decision-making process were implemented. In conclusion, this innovative approach provided more value in terms of asset surveillance compared to that conventionally adopted within the industry. Introduction Oil companies sometimes struggle to obtain a produced liquid and oil volume measurement, which is a very important piece of information for reservoir and day-to-day well surveillance and optimization. In many cases, reservoir and well surveillance relies on monthly back allocation. This type of process creates a time gap between the event and problem identification. In some cases, problems are not identified for months. Currently, many systems are available that can provide both direct and indirect fluid rate measurements for produced liquid and oil rate evaluation, e.g., a multiphase flow meter [MPFM] combined with a WC meter. This paper describes the use of a combination of different solutions for accurate measurement of liquid and oil rate in real-time. It includes a MPFM, WC meter, and virtual measurement using well models in real time matched with the latest well surface production test available. The KwIDF SA project has developed a robust approach for estimating the real-time liquid rate and has implemented the use of a WC meter for real-time WC evaluation." @default.
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• W2084260704 date "2014-12-10" @default.
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• W2084260704 title "Innovative Integrated Approach for Real-Time Liquid Rate Estimation for ESP Wells Production Optimization and Field Production Reconciliation in the Sabriyah Digital Oil Field" @default.
• W2084260704 doi "https://doi.org/10.2523/iptc-18160-ms" @default.
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