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Horizontal and multi-lateral wells allow oil and gas companies to maximise contact with reservoir quality rock in either a single reservoir or multiple reservoirs. However they do not, by themselves, guarantee optimum reservoir drainage. Premature water or gas breakthroughs frequently occur due to:Reservoir permeability heterogeneity,Variations in distance between the wellbore and the fluid contacts, particularly in compartmentalized reservoirs,Variations in reservoir pressure in different regions of the reservoir penetrated by the wellbore.Pressure drop along the completion's flow path due to friction ("heel-toe" effect). Many such well and reservoir management problems can be mitigated by installation of downhole flow control devices - "Active" Interval Control Valves (ICVs) and "Passive" Inflow Control Devices (ICDs). ICVs were initially employed for controlled, commingled production from multiple reservoirs; while ICDs were developed to counteract the "heel-toe" effect. The variety of reservoir applications for both technologies has proliferated so that their application areas now overlap. Appropriate selection between an ICV and an ICD completion can be both a complex and a time consuming process. This paper compares the functionality and applicability of the two technologies. Completion Design selection guidelines are developed based on multiple criteria drawn from reservoir, production, operation and economic factors. Reservoir engineering aspects, such as uncertainty management, formation heterogeneity, and the level of flexibility required by the development are analyzed. Production and completion characteristics, such as tubing size, the number of separately controllable completion zones, the installation of multiple laterals and the value of real time information were also investigated. This systematic analysis forms the basis of a screening tool to identify the optimum technology for each particular situation. This study provides a robust, comparative framework for both production technologists and reservoir engineers to select between passive and active flow control for optimised, advanced well completions. 1. Introduction Increasing well-reservoir contact has a number of potential advantages in terms of well productivity, drainage area, sweep efficiency and delayed water or gas breakthrough. However, such long, possibly multilateral, Maximum Reservoir Contact (MRC) wells bring not only advantages by replacing several conventional wells; but also present new challenges in terms of drilling and completion due to the increasing length and complexity of the well's exposure to the reservoir [58]. The situation with respect to reservoir management is less black and white. An MRC well improves the sweep efficiency and delays water or gas breakthrough by reducing the localized drawdown and distributing fluid flux over a greater wellbore area; but it will also present difficulties when reservoir drainage control is required.
Horizontal and multi-lateral wells allow oil and gas companies to maximise contact with reservoir quality rock in either a single reservoir or multiple reservoirs. However they do not, by themselves, guarantee optimum reservoir drainage. Premature water or gas breakthroughs frequently occur due to:Reservoir permeability heterogeneity,Variations in distance between the wellbore and the fluid contacts, particularly in compartmentalized reservoirs,Variations in reservoir pressure in different regions of the reservoir penetrated by the wellbore.Pressure drop along the completion's flow path due to friction ("heel-toe" effect). Many such well and reservoir management problems can be mitigated by installation of downhole flow control devices - "Active" Interval Control Valves (ICVs) and "Passive" Inflow Control Devices (ICDs). ICVs were initially employed for controlled, commingled production from multiple reservoirs; while ICDs were developed to counteract the "heel-toe" effect. The variety of reservoir applications for both technologies has proliferated so that their application areas now overlap. Appropriate selection between an ICV and an ICD completion can be both a complex and a time consuming process. This paper compares the functionality and applicability of the two technologies. Completion Design selection guidelines are developed based on multiple criteria drawn from reservoir, production, operation and economic factors. Reservoir engineering aspects, such as uncertainty management, formation heterogeneity, and the level of flexibility required by the development are analyzed. Production and completion characteristics, such as tubing size, the number of separately controllable completion zones, the installation of multiple laterals and the value of real time information were also investigated. This systematic analysis forms the basis of a screening tool to identify the optimum technology for each particular situation. This study provides a robust, comparative framework for both production technologists and reservoir engineers to select between passive and active flow control for optimised, advanced well completions. 1. Introduction Increasing well-reservoir contact has a number of potential advantages in terms of well productivity, drainage area, sweep efficiency and delayed water or gas breakthrough. However, such long, possibly multilateral, Maximum Reservoir Contact (MRC) wells bring not only advantages by replacing several conventional wells; but also present new challenges in terms of drilling and completion due to the increasing length and complexity of the well's exposure to the reservoir [58]. The situation with respect to reservoir management is less black and white. An MRC well improves the sweep efficiency and delays water or gas breakthrough by reducing the localized drawdown and distributing fluid flux over a greater wellbore area; but it will also present difficulties when reservoir drainage control is required.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper describes the equipment, function, and benefits of the innovative multilateral well completion installed in the Wytch Farm M-15 well operated by BP Amoco. This completion enables production from two different sections of an oil reservoir. Effectively, it is a multilateral well equipped with advanced completion functions much like two wells but without doubling the construction expense. This advanced completion included three hydraulic wireline-retrievable flowcontrol devices and an electric submersible pump (ESP). In addition, downhole electronic instruments provide monitoring of pressure, temperature, and flow.With the inflow-control valves successfully operating in this well, we further optimized production, including commingled production from both laterals.This completion set several firsts: one for the long length of its extended reach and another for the first surfacecontrolled flow device installed below an electric submersible pump (ESP). The team estimated that flow control would allow recovery of an additional 1 million bbl [158 900 m 3 ] of oil that otherwise would not have been economically recoverable.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe increased complexity of hydraulic and complex electrohydraulic flow-control systems, especially with multizone completions, substantially increases deployment risk. Until now it has not been possible to provide an infinitely variable flow-control system for multiple zones using only a single conduit from surface.The BP Wytch Farm F-22 well has an all-electric tubingretrievable flow-control device installed as the primary active downhole component in the intelligent completion system. This device integrates an electromechanical adjustable choke, multiple quartz pressure and/or temperature sensors, and a mass-flow sensor, all powered from the surface through one permanent downhole cable. Multiple flow-control devices can be run on the same cable to provide zonal control and monitoring. Each device is independently addressable, allowing the operator to adjust any zone in the well on command and react to potential reservoir uncertainties in real time. The presence of an electric pump cable near the permanent downhole cable at the Wytch Farm installation has demonstrated that the communication system working on a twisted pair cable is immune to noise. The fully electrical system can establish a secure link between multiple downhole sensing and flow-control components, the surface acquisition system, and remote control locations where reservoir engineers and production specialists can monitor and control well operations. Infinitely variable flow control coupled with real-time monitoring and data transmission will facilitate and accelerate the development of subsea, deepwater, and other hostile location wells by eliminating the need for surface or close infrastructure.
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