The new opportunities of gas in western project (PNOGO for its acronym in spanish) is looking for new technologies to improve the efficiency of the exploration and production of gas reserves, in order to assure start-up and operational continuity of Ana Maria Campos Petrochemical Complex located in Zulia state. In view of this, it became necessary to evaluate the feasibility of building wells using monobore completion technology especially in the B6 LL 370 reservoir located in Tia Juana Field, Lake Maracaibo. Designing a monobore completion involves the construction of a wellbore whose internal diameter of the completion string is the same size from top to bottom. This type of completion has shown that this technique is feasible for the production of gas due to has yielded excellent results worldwide. The premises used for the selection of this completion were based on a review of geological, geophysical, petrophysical and reservoir characteristics, as porosity, permeability, well location in the structure of the reservoir, fluid production risk, among other features. Furthermore, production analysis and economic evaluations stablishing the new completion design. During this project, two wells have been drilled with this type of completion in this field whose diameter production casing was 5-1/2". The results indicate an average gas production of 5.6 million standard cubic feet per day (MMscfd) compared to conventional wells whose output is 1.7 MMscfd in the same reservoir. The decrease in the construction cost and operating time was 30% and 28%, respectively. The results show that using the technique of monobore completion is feasible and economically viable in the construction of wells in the B6 LL 370 reservoir.
Since there are a lot of reservoirs of highly viscous heavy oil, whose extraction is a challenge for petroleum engineers in Venezuela, and also the significant gas shortage, which makes many of the gas injection projects in our reservoirs in the west of the country have been suspended are reasons why it has raised the need to explore alternative sources for the recovery of such highly viscous oil. Improved Recovery processes emerge as an alternative to increase hydrocarbon recovery, changing the characteristics of the fluids and the capillary forces acting on them. Enhanced recovery is mainly based on sophisticated techniques in operation, is usually costly, but very effective, therefore, the enhanced hydrocarbon recovery is defined as oil production, by injecting a fluid, in addition to displace oil, favorably modifies the oil recovery mechanisms. The techniques can be applied at any stage during the operation of the reservoir; in fact, there are formations which for its geological and petrophysical characteristics can only be exploited by Enhanced Recovery techniques. Several factors play a role in the selection of the most economically attractive alternative, these factors are: The rock type and characteristics that have the greatest influence on the pattern of exploitation is undoubtedly the porosity, permeability, reservoir fluid, and the last factor is the injection fluid to be introduced to the reservoir. The selection of the fluid to be injected either to maintain reservoir pressure, move, or modify the mobility of hydrocarbons, are carried out based on the analysis of the molecular interaction between the injected fluid and oil in a reserve.The present study shows the results of the Evaluation of Different Secondary Recovery Process in Reservoir BACH-01 to increase the recovery factor of the same; this reservoir is located on Lake Lagunillas Exploitation Unit. It was built a numerical simulation compositional model using the simulator STARS of CMG company, to represent the geometry and dynamics of the reservoir fluid flow, thereby validating the rock / fluid properties. Among the different methods studied is the CO 2 injection, the Alternating Steam Injection more Gas (IAV ϩ GAS), SAGP y VAPEX.
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