We don’t include a structure like the Eiffel Tower with separators, pumps, and compressors on the top observation platform in an onshore development plan. And yet, how many jacket platforms are there around the world? Production from an offshore Angola field has been decreasing because of subsea pressure declines amid water-cut increases and limited gas compressor capacity. The development process leading to the selection of high-boosting multiphase pumps is described. In maturing oil wells, oil production is often restricted as reservoir pressure depletes.
Unmanned minimum facility platforms are a reliable alternative to traditional wellhead platforms or subsea installations, and the technologies enabling simpler designs have evolved. Anadarko aims to maximize immediate short-cycle value through tiebacks and platform relocations in the Gulf of Mexico. This review of papers illustrates some of the innovative solutions used in the region. In maturing oil wells, oil production is often restricted as reservoir pressure depletes. Two case studies highlight the application of two-screw multiphase pump systems in to extend well life.
Aker Solutions and FSubsea have agreed to a joint venture, named FASTSubsea, to help operators increase oil recovery. Subsea pumps are used for gas/liquid separation, subsea compression, and subsea boosting. Solutions aiming at cost reductions are crucial to make subsea processing projects feasible. A cost- and complexity-reduction solution for the subsea electrical power supply is a critical consideration. In maturing oil wells, oil production is often restricted as reservoir pressure depletes.
Content of PetroWiki is intended for personal use only and to supplement, not replace, engineering judgment. SPE disclaims any and all liability for your use of such content. An artificial lift device that uses the flow of a power fluid through a nozzle to create a low pressure area that draws well fluids into the chamber and assists in lift the fluids to the surface.
Most hydraulic pumping systems operate in centralized field facilities (tank batteries, other lease-level facilities). Sometimes, however, only a few wells in a field are suitable for hydraulic pumping, or spacing considerations make the use of centralized facilities impractical. To address the limitations of the central battery system, single-well systems have been designed, . These have many of the same components as centralized facilities, but have been designed for efficient use by one, or sometimes two to three, wells. Several of the manufacturers of hydraulic pumping units offer packaged single-well systems that include all the control, metering, and pumping equipment necessary.
Surface facilities for hydraulic pumping systems include a pump at the surface to send the power fluid downhole, a gas, diesel or electric engine to drive the pump, and a system for storing, treating and delivering the power fluid (produced oil or water) for use by the downhole pump. Hydraulic pumping systems have evolved toward the use of relatively high pressures and low flow rates to reduce friction losses and to increase the lift capability and efficiency of the system. Surface operating pressures are generally between 2,000 and 4,000 psi, with the higher pressures used in deeper wells, and power-fluid rates may range from a few hundred to more than 3,000 B/D. While some surface multistage centrifugal pumps are rated to this pressure range, they are generally quite inefficient at the modest flow rates associated with single-well applications. Multistage centrifugals can be used effectively when multiple wells are pumped from a central location. The surface pump for a single well or for just a few wells must be a high-head and low-specific-speed pump.
The two basic types of installations are the "fixed"-pump and the "free"-pump design. In the fixed installation, the downhole pump is attached to the end of a tubing string and run into the well. Free-pump installations are designed to allow the downhole pump to be circulated into and out of the well inside the power-fluid string, or it can also be installed and retrieved by wireline operations. Figure 1.2-Free and fixed hydraulic downhole pumping installations. Figure 1.3-Free pump (pump in-and-out operation).
This page provides examples including calculations involved in the design and optimization of hydraulic pumping systems for artificial lift. Examples are included for both jet pumps and reciprocating hydraulic pump types. The following is an example of a design for a well using a jet pumping system. The design data must be carefully collected and is shown in Table 1. Because there are numerous possible combinations, and a design typically requires many iterations, current design methods utilize computer software programs.
Hydraulic pumping is a proven method of artificial lift -- adding energy to move the fluids to the surface after reservoir pressure is no longer sufficient to do so. The key component of a hydraulic pumping operation is the downhole pump. The two basic types of installations are the "fixed"-pump and the "free"-pump design. In the fixed installation, the downhole pump is attached to the end of a tubing string and run into the well. Free-pump installations are designed to allow the downhole pump to be circulated into and out of the well inside the power-fluid string, or it can also be installed and retrieved by wireline operations.