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Gas resources play a key role in nowadays energy supply and provide 24% of the diverse energy portfolio. Water encroachment is one of the main trapping mechanisms in gas reservoirs. It decreases recovery by reduction of reservoir life, limits productivity and efficiency of wells, and elevates safety risks in gas production. The lack of a comprehensive study about water production problems is the primary motivation for this study. Contrary to the serious concern over the standalone investigation of an actual water production case study, less concern is put to deal with the problem comprehensively through an investigation of all potential sources and mechanisms, required methods, and available techniques. This study presents the potential sources of the problem, methods to identify it, and approaches to address it. Firstly, possible sources are described. Secondly, the diagnostic techniques are expressed. Then, practical solutions used in actual cases to overcome problems are elaborated. The solutions include both well- and reservoir-oriented approaches. Finally, all proper strategies are summarized to tackle the water problems in gas fields. The current study comprehensively presents the available methods for water control problems in parallel with conceptual and qualitative comparison. The finding of this study can be very constructive for better understanding of water sources, available diagnostic tools, and solutions for controlling water production in gas reservoirs and, consequently, taking the best decision in real case studies before attempting many water shut-off approaches.
Gas resources play a key role in nowadays energy supply and provide 24% of the diverse energy portfolio. Water encroachment is one of the main trapping mechanisms in gas reservoirs. It decreases recovery by reduction of reservoir life, limits productivity and efficiency of wells, and elevates safety risks in gas production. The lack of a comprehensive study about water production problems is the primary motivation for this study. Contrary to the serious concern over the standalone investigation of an actual water production case study, less concern is put to deal with the problem comprehensively through an investigation of all potential sources and mechanisms, required methods, and available techniques. This study presents the potential sources of the problem, methods to identify it, and approaches to address it. Firstly, possible sources are described. Secondly, the diagnostic techniques are expressed. Then, practical solutions used in actual cases to overcome problems are elaborated. The solutions include both well- and reservoir-oriented approaches. Finally, all proper strategies are summarized to tackle the water problems in gas fields. The current study comprehensively presents the available methods for water control problems in parallel with conceptual and qualitative comparison. The finding of this study can be very constructive for better understanding of water sources, available diagnostic tools, and solutions for controlling water production in gas reservoirs and, consequently, taking the best decision in real case studies before attempting many water shut-off approaches.
fax 01-972-952-9435. AbstractMinimizing production of water from gas reservoirs is one of the main strategies for enhancing primary hydrocarbon production. Advances in intelligent well technology and simulation of reservoir-production system enable optimum inflow allocation of produced fluids by controlling perforations and valve settings. However, real-time optimum control of flow is still a challenge. To this end, we have developed an advanced method for optimization of production based on a feed-back optimum control concept. The method allows optimization of inflow-control-device operation in conjunction with strategic updating of reservoir-smart well model under uncertainty.In this work, we present a hybrid optimization method for improving optimum solutions. In this method, the response of production system to control variables is mathematically described by a high-order proxy model, which is developed using Response Surface Methodology (RSM) and Design of Experiments (DOE). The validity of this method was tested for the dynamic optimum control of gas and water coning observed in a physical two-dimensional layered bead-pack model with automatic inflow control valves. The valves were actuated by distributed flow or pressure sensors. Results showed that dynamic (time-dependent valve settings) and static (fixed valve setting) control exhibited advantages one over another, depending on operational conditions. It was also found that the heterogeneity of porous media strongly influenced the control effectiveness. Field implications are discussed.
It is widely agreed that gas reservoirs with a component of water drive should be produced at high rates to minimize the volume of gas which is trapped at high pressure by the advancing water (often termed 'outrunning the aquifer'). Yet high production rates are also associated with coning (in vertical wells) or cresting (in horizontal wells) of the encroaching water, leading to early water breakthrough. In vertical wells, the formation of an inverse gas cone means that high gas rates can be maintained post-breakthrough until almost the whole perforated interval is flowing water. However, in horizontal wells, water breakthrough is a serious threat to gas deliverability, because the inverse coning mechanism does not apply and the well rapidly loads with water. Consequently, it is not clear whether producing at high rates is the best strategy to maximize recovery in gas reservoirs developed using horizontal wells. We investigate the risk associated with producing horizontal wells at high rates by simulating gas recovery and aquifer response over a broad range of reservoir properties and production scenarios. We find that high rates always result in lower gas recovery unless the ratio of vertical to horizontal permeability is very low, in which case water cresting is suppressed. However, there are many instances where accelerating production recovers only slightly less gas over much shorter timescales, so may be economically favorable. Rate sensitivity increases in low permeability reservoirs with thin gas columns, because these conditions increase the tendency for water cresting, and decreases in reservoirs with strong aquifer support, since water breakthrough occurs regardless of the rate at which the well is produced. Our results can be used as a reference framework to rapidly assess gas production behavior and aquifer response within a wide range of field development scenarios. Introduction Horizontal and highly deviated wells are increasingly being used in gas field developments worldwide.1–5 Large-bore horizontal wells can deliver significantly higher gas production rates than conventional completions,2 reducing field development costs by allowing reserves to be targeted with fewer wells.4–6 However, realizing the potential of high-productivity gas wells requires an understanding of the subsurface risks to deliverability, to ensure sustained gas production, maximize profitability, and establish large-bore completions as an economically viable development option. A key subsurface risk in gas reservoirs with a component of water drive is early water breakthrough.3–5,7,8 In large-bore horizontal wells, early water breakthrough is a particularly serious threat to deliverability, because of the significant reduction in gas flow capacity associated with flowing entrained water to the surface.4,9–11 At best, substantial water production will require expensive processing facilities; at worst, it will effectively 'kill' the well.3–5,12 Based on material balance considerations, it is widely agreed that gas reservoirs with a component of water drive should be produced at high rates. This approach (often described as 'outrunning the aquifer') maximizes gas recovery by reducing the volume of gas which is trapped at high pressure by the advancing water.13–18 In this context, high productivity horizontal wells might be expected to make a positive contribution to gas recovery, because they can generally produce at much higher rates than vertical wells. However, material balance approaches assume that the gas-water contact (GWC) remains flat during production.13,14,16,18,20–22 Yet bottom-water drive gas reservoirs are associated with coning (in vertical wells) or cresting (in horizontal wells) of the GWC towards the well.7,23–28 Cresting occurs when viscous forces associated with pressure drawdown overcome gravity forces resulting from the density contrast between gas and water, causing a crest or cone of water to be drawn upwards towards the producing well 29 (Fig. 1). Water crest behavior has been described using analytical approaches to predict a 'critical rate' above which water breakthrough is expected,30,31 and time to water breakthrough.32,33 These approaches imply a sensitivity of gas recovery to production rate that conflicts with material balance techniques, as the severity of water cresting is increased with accelerated production, and therefore water breakthrough is expected earlier at higher rates. Water crest development also becomes more significant as the separation between the well and GWC is reduced, the horizontal reservoir permeability decreases, and the vertical permeability increases.29
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