The application of Multiphase Meters (MPM) over the past decade or so has, in the main, been in deployment of meters in small quantities (i.e. ones and twos) and there are few applications where MPM's have been deployed in bulk. Petrozuata in Venezuela is such an operation where 37 MPM's were deployed and have been in use for over 5 years. This paper describes the facility and the operations where MPM's have been selected, tested and implemented. The paper also describes the difficulties experienced and the operational results from the extensive use of such measurement techniques. Introduction Petrozuata is a joint venture Strategic Association owned by ConocoPhillips (50.1 percent) and Petróleos de Venezuela, S.A. (PDVSA), the national oil company of Venezuela (49.9 percent). The project is a fully integrated crude oil processing and petroleum business, located in the state of Anzoátegui, Venezuela. It began commercial operations on April 12, 2001, however Extra Heavy Crude Oil (EHCO) began flowing in mid 1998. Petrozuata's primary function is to produce EHCO from the Zuata region of the Orinoco Oil Belt; transport it to the Jose industrial complex on the north coast of Venezuela; upgrade it into 19 to 26.5 degree API synthetic crude; and market it along with 14 degree API gas oil and associated by products e.g. LPG, sulfur and petroleum coke. The Petrozuata "project" is now an operational oil producing business with over 5 years production experience. The Strategic Association has a 35-year operating life and will require the drilling of more than 750 wells with an estimated recovery of approximately 1.6 billion barrels of Extra Heavy Crude Oil (EHCO) during this period. This facility uses the ConocoPhillips' proprietary coking technology to upgrade heavy crude oil into lighter synthetic crude and has a nameplate capacity of 120,000 barrels per day (BOPD). At present, Petrozuata produces more than 125,000 BOPD of EHCO. The synthetic crude oil produced by Petrozuata is used as a feedstock for ConocoPhillips' Lake Charles, Louisiana, refinery and the Cardón refinery in Venezuela, operated by PDVSA. Since 1997, Petrozuata has drilled more than 260 wells (at present there are 195 active producers) in an area of 56,000 acres of the Zuata region with the expectancy of drilling a further 490 wells over the next 30 years in order to drain the reservoir. Wells are clustered around 37 production pads as shown in Figure 1. Conceptual engineering for the Petrozuata project was carried out in the early 1990's, and a substantial body of engineering was put forward for the use of multiphase technology for both pumping and measurement. Initial engineering required steam flood of the reservoir; however, this was later changed such that production is now based on the use of cold horizontal wells in unconsolidated sands with the extensive use of single and multi-laterals (1). Production is moved around the field via 11 off 2000 hp multi-phase pumps (MPP), with the EHCO diluted with naphtha. Within the field, the production is metered and allocated using 37 multi-phase meters (MPM), one located at each production pad as shown in Figure 2. The diluted crude is processed (degassed and dewatered) at a central processing facility, after which, it is fiscally metered and pumped to the upgrader via a 125 mile 36 inch pipeline.

During recent years, optimization of lifting methods has been applied in the oil industry in order to evaluate the effect on oil well production and establish a company's optimal investment policies. The higher costs of new artificial lif ting equipment and facilities for new fields have created the necesity to review the latest available technology of different lifting methods and specially that of the electrical submergible pump (ESP). Few studies in the area of heavy crude oil production optimization using ESP's as a lifting method have been published. This paper discusses the results of a pilot ESP project performed in ten wells in the Boscan field and analyses the performance of the equipment and its application range. This equipment was installed in completions at depths ranging from 7000 to 9000 feet, with a 10° API crude gravity and bottom-hole temperatures of 180°F. It was concluded that despite a reduction of the pump's efficiency, the ESP equipment does qualify as a good alternative lifting method for heavy oil production. It is also possible to obtain higher production rates. The results obtained in this project confirms that submergible pump is an alternative method for lifting heavy crude oil from relatively deep reservoirs.

Optimization of lifting methods has been used in the oil industry to study both the oil well production and to determine a company's optimal investment policies. The higher costs related with new facilities and artificial lift installations for new fields have created the necessity to review the latest technology available from different lifting methods, especially from the electrical submersible pump (ESP). Few studies ‘rave been published in the area of heavy crude oil production optimization using ESP's as a lifting method. This paper describes the results of a project performed in two different fields and will study the performance of the equipment and the related aplication range. The equipment studied was installed in completions to depths ranging from 6000 to 11000 feet, with crude gravities on the order of 15 to 21 °API and bottomhole temperatures above 180 °F. Some conclusions base shewn that the ESP equipment can perform in similar crudes with even lower °api's, despite a reduction in the pump's efficiency. Higher fluid production rates are also possible to achieve. This survey and supporting data will confirm the submersible pump to be an alternative method for lifting heavy crude oil from relatively deep reservoirs.

This paper will demonstrate the use of reeled (coiled) tubing applied to gas lift technology and will add another method to the growing list of service and production capabi 1 it i es now fac il itated by ree 1 ed tubing. By using reeled tubing to install conventional gas lift valves, production enhancement of many wells is possible without workovers or change of exi st i ng tubul ars. This paper will discuss the design parameters, components and actual field results of using reeled tubing to install gas lift valves.

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