HOUSTON – Emerson has introduced a new version of its Dynamic Lift Optimization (DLO) software.
This is said to help producers to extract greater value from their assets and reduce field decline rates by ensuring a field or platform is producing at maximum efficiency, given current production constraints.
Use of the software, Emerson claims, can bring a typical site operating multiple wells a 10% improvement in production.
DLO dynamically adjusts lift gas flows or electric submersible pump (ESP) speed based on the most recent well test curves. Once configured, it optimally allocates available lifting power to the wells to maximize production, while at the same time adjusting to changing conditions such as wells coming on or off, or compressor trips.
Conventional gas lift adjustments, Emerson points out, are typically handled manually and infrequently, which can lead to missed opportunities and lower field performance.
The new DLO version facilitates cloud-based infrastructure, and its new graphical user interface is said to allow production engineers to safely and securely access critical field optimization data from any location with an internet connection.
In addition, the software now uses theOSIsoft PI System - a scalable open data infrastructure and historian that provides common data architecture from the plant floor to board level.
Oil producers can also pair the technology with Emerson’s integrated well testing solution to derive more frequent updates of well curves in order to ensure field production is continuously maximized.
The well test solution comprises a multi-port flow selector, a three-phase flow meter and a remote terminal unit delivered pre-engineered and fabricated on a skid, offering a greatly reduced footprint and weight compared to a traditional test separator and manifold.
Each skid can handle up to seven wells, cutting back on piping, valves, and vessels. The three-phase flow meter provides instantaneous readings for oil, gas and water from that well, eliminating the settling time required for a traditional test separator.
The well test schedule can be programmed in advance and can occur without manual intervention, so there is no need for an operator to manually line up valves.