Performance of Horizontal Wells In Gas Condensate Reservoirs: Hassi R'Mel,Algeria
- Boualem Marir (Sonatrach Inc.) | Tiab Djebbar
- Document ID
- Society of Petroleum Engineers
- SPE Russian Oil and Gas Technical Conference and Exhibition, 3-6 October, Moscow, Russia
- Publication Date
- Document Type
- Conference Paper
- 2006. Society of Petroleum Engineers
- 5.3.2 Multiphase Flow, 5.1 Reservoir Characterisation, 5.2 Reservoir Fluid Dynamics, 5.1.5 Geologic Modeling, 5.8.8 Gas-condensate reservoirs, 4.1.2 Separation and Treating, 5.5.8 History Matching, 5.1.1 Exploration, Development, Structural Geology, 5.3.1 Flow in Porous Media, 2.4.3 Sand/Solids Control, 5.2.1 Phase Behavior and PVT Measurements, 5.6.4 Drillstem/Well Testing, 5.6.8 Well Performance Monitoring, Inflow Performance, 4.1.5 Processing Equipment, 5.2.2 Fluid Modeling, Equations of State, 2 Well Completion
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Hassi R'Mel Field is one of the biggest gas-condensate fields in the world. The southern area of this field, Module 02, has been depleted by vertical wells since 1979.
Since 1981, water production has exceeded the allowed water limit. The salinity of the produced water is about 05 g/l, which is the maximum salinity allowed at the surface facilities. As a result, severe reservoir damage may have occurred. So the producing reservoir levels (C) were shut-in.
The primary objective of this study is to investigate the performance of horizontal wells in a Sector-Model, to predict their behavior versus water production, and condensate recovery.
To simulate the depletion processes, a compositional simulation is conducted to investigate the following phenomena in the case of horizontal and vertical wells: (a) Water influx effects, (b) Comparison of horizontal well drawdown pressure to that of vertical wells, and (c) The influence of the horizontal well length section and reservoir thickness on horizontal well productivity, and condensate recovery.
A reservoir characterization is made, and a 3-Parameter Peng-Robinson equation of state (3-PR-EOS) is established to characterize the reservoir fluids.
A 3-D Cartesian Sector Model was built for the zone of interest in order to predict the performance of horizontal wells and the different phenomena that can be present in retrograde gas-condensate reservoirs, and to analyze the most relevant reservoir parameters that affect horizontal wells performance.
The obtained results showed that the use of horizontal wells is a proven technology for reducing water influx problems and improving condensate recovery. The condensate production of a horizontal well compared with that of a conventional vertical well can be increased by a factor of 1.30, owing to less condensate accumulation in the region of the producing well.
Gas condensate reservoirs differ essentially in their behavior from conventional gas reservoirs, and the optimization of hydrocarbon recovery needs careful reservoir analysis, planning, and management.
At the time of discovery, gas condensates are often found as a single-phase gas in the reservoir. However, as the production is carried out, there is an isothermal pressure decline and as the bottomhole pressure in a flowing well falls below the dew-point of the fluid, a liquid hydrocarbon phase is formed.
Due to lower permeability to liquid and a high liquid-to-gas viscosity ratio, most of the condensed liquid in the reservoir is unrecoverable and constitutes the "condensate loss??. Condensate loss is one of the greatest economical concerns since the condensate contains valuable intermediate and heavier components of the original fluid now trapped in the reservoir.
The liquid keeps accumulating until the critical liquid saturation is reached. Once this liquid starts flowing, the flow of gas and liquid is subjected to the law of multiphase flow in porous media.
For single-phase reservoirs, whether oil reservoirs or gas reservoirs, it has been well established in the literature that horizontal wells present significant advantages over vertical wells. Higher gas rate and increased liquid recovery are the main advantages that horizontal wells can offer. In horizontal wells, drawdown pressure is three to four times lower than vertical wells for the same flow rate. Therefore, there is less condensate deposited near the horizontal wellbore. This affects favorably the productivity of a gas condensate reservoir, as less blockage will occur in the skin zone.
Gas condensate-related topics, such as well deliverability, well testing interpretation, gas-condensate inflow performance, and flow in reservoir in general, have been long-standing problems. From the literature, many studies have been conducted to predict the production behavior of a well in gas condensate reservoirs.
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