TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe paper presents a new empirical correlation to predict the dewpoint pressure of gas-condensate fluids from readily available field data. The new correlation relates the dewpoint pressure of a gas-condensate fluid directly to its reservoir temperature, pseudoreduced pressure and temperature, primary separator gas-oil ratio, the primary separator pressure and temperature, and relative densities of separator gas and heptanes-plus fraction. The correlation was developed based on field and laboratory PVT analysis data of several gascondensate fluid samples representing different gas reservoirs in the Middle East. Additional data sets, not included in the development of this correlation, were used to validate the new model's accuracy. Based on the error statistical analysis results, the new model outperforms the existing correlations.
Multiphase boosting technology can provide a cost-effective option for developing remote and marginal oil field discoveries, by reviving dead oil wells and increasing the production from active wells. The implementation of the multiphase technology at the remote field is a new strategy to obtain increased production and flow assurance from the operator. This paper describes the implementation of a rotodynamic (helicon-axial) multiphase pumping (MPP) system at a remote, hilly-terrain onshore oil field in Saudi Arabia. The process conditions, the MPP package scope of supply, the MPP installation setup and operation will be discussed in detail. Introduction The water cut and gas fraction usually increase with field production over time. This problem can be aggravated if the multiphase well fluids, transported over long distance pipelines, cross hilly topography due to the added length of the pipelines, to production stations or process facilities. Therefore production reaches a stage where the field or part of the field becomes severely restricted and could lead to premature abandonment of many producing wells, unless remote multiphase pressure boosting is implemented to regain production. MPPs are capable of pumping multiphase flow streams with various combinations of oil, water, and gas without the need for separation. The MPP technology is mostly used to add energy to unprocessed fluids to be transported to processing facilities located downstream. The MPP can help reduce or eliminate the need for remote production infrastructure such as separation equipment and offshore platforms. This would lead to lower operating costs associated with the development of hydrocarbon reserves. Marginal fields located in hostile environments can also be developed more economically. In addition, MPPs can reduce the high-back pressure on producing wells, leading to increases in production and recoverable reserves. The selection of the suitable multiphase boosting system is generally based on a number of factors such as the economics and constraints imposed by a geographic location, specific field conditions and fluid properties. Some of the common constraints are available space and weight, in the case of offshore platforms. Power availability is another concern for marginal and unmanned satellite field developments.
New oil fields are hard to develop and mature oil fields are becoming more challenging and costly to operate. Advances in multiphase technologies have made significant impact on the way oil and gas companies managing and optimizing their upstream oil business. Multiphase technologies, including multiphase pumping, multiphase flow metering and compact separation systems, have been recognized to provide the critical need to alleviate production decline, optimize production operation, and reduce capital and operating costs. In this regard, Saudi Aramco has undertaken a number of new production related initiatives, developments and projects involving multiphase technologies that are deemed to provide advantages in achieving corporate goals and objectives. The company has invested and implemented significant new multiphase technologies with the goal of maximizing production and minimizing capital investment and operating costs. Multiphase Pumping (MPP) technology provides a cost effective option to develop remote and marginal oil field discoveries. MPP showed excellent performance during field test projects and resulted in significant incremental oil production. Applications of Multiphase Flow Metering (MPFM) technology has resulted in significant capital and operating cost savings. Continuous and real-time data has enhanced production and reservoir management, which led to improved total recovery. Compact Separation technology is another area Saudi Aramco is committed to pursue its field implementation. The technology has the potential to de-bottleneck existing facilities capacity limitation, and reduce facility cost for new oil and gas field developments. This paper will provide an overview of the multiphase technologies Saudi Aramco is considering for field applications. It will also discuss Saudi Aramco's experience and future potential applications. The applications discussed have either been implemented or are expected to be implemented in the near future. Introduction Water cut and gas fraction increase with field production over time. In addition, problems can be compounded by satellite fields located long distances from central processing facilities, and multiphase well fluids transported through pipelines crossing locations with hilly terrain. This is due to the added length of the pipelines transporting the well fluids to production stations or process facilities. There are also specific demands by the process systems in term of the optimum operating conditions. This is often dictated by the characteristics and the operating range of the capacity of the separators in terms of the gas flow rate capacity, the gas compression system and the amount of water they can process as water cut increases.
The inline separation technology has attracted the attention of oil and gas field operators due to the considerable weight, space and cost savings that can be achieved. In addition, the inline separation technology can play a major role in debottlenecking and upgrading the existing production facilities.Several gas wells are beginning to produce significant water. Older gas plant facilities were not designed to handle high water production. Compact inline separation technology has the potential of eliminating any water-related restriction on well production, and reducing the investment for upgrading existing conventional separators.A trial test of a skid-mounted inline separation technology (Deliquidizer) is being implemented at a wet gas remote header. The header has three flowing wet gas wells. The separated gas and liquid (water and condensate) streams will be monitored for flow rate and phase fractions using suitable multiphase flow meters. The separated gas will be flowed to the gas plant and separated liquids will be flowed in a separate flowline to the nearest oil processing facility. This will allow unrestricted flow of the gas wells without the need to upgrade the water handling facilities of the gas plant resulting in significant cost savings. This paper discusses the concept, objectives and benefits of inline separation technology application in Saudi Aramco wet gas field. The field trial test loop, process conditions, equipment specifications, and future applications of this technology within Saudi Aramco will also be discussed.
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