Conventional Artificial Lift for Horizontal Wells
GARP Lite Sump Design
GARP Lite Screened Sump Design
Two Step GARP Design
Big Bore GARP
The cost to install the equipment depends on numerous factors such as depth, casing size, and existing production equipment and facilities. The down-hole equipment costs for a GARP Lite installation can be as low as $20K. Call your GARP Services representative for a quote.
We design, provide the necessary parts, and will have a well site consultant on the location to assist in the installation process. We will also provide complimentary consultation after installation to ensure it is functioning properly. You maintain operations of the well. The operation of GARP is very similar to a standard rod pump and gas lift operation.
GARP will increase production from the wellbore, but only up to the limit of the down-hole pump. Therefore, the ability to separate out gas from the liquids often is over the capacity of the pump to lift the liquids from the well. Call a GARP Services representative for an analysis of your well. Every well is different. Send us your PI/IPR curve or historic production data (oil, water, gas) for each well and we will analyze the data to determine if GARP can help. We have seen rate increases up to 20 fold and reserve increases over 35% of the cumulative oil and gas produced to date.
GARP LITE SUMP Advantages
FULL GARP Advantages
Basically any well that has gas separation issues, solids issues, or has the pump installed high to the reservoir
There are three main designs with the ability to run GARP LITE (velocity string only) or FULL GARP (fluid injection) as follows:
GARP Lite SUMP – may be installed in casing sizes of 4-1/2” or larger
Two Step GARP Lite to Full GARP – may be installed in casing sizes of 4-1/2” or larger
Big Bore GARP – may be installed in casing sizes of 7” or larger
GARP contains two main methods which significantly increases the capacity of down-hole gas separation and also raise liquids from below the pump to above the pump.
Both methods increase the gas separation capacity dramatically over conventional down-hole gas separators by utilizing packer type separation system instead of a conventional tubing anchor/gas anchor system.
Both methods combine a sucker rod pump (or other applicable pump) with a concentric tubing arrangement to allow the pump to be placed in a “pump friendly environment” to keep operating costs low.
GARP increases production and reserves by lowering the flowing bottom hole pressure by either utilizing a short velocity string below the downhole pump to concentrate the reservoir energy to lift liquids or by the addition of low pressure and low volume gas lift to raise liquids from below the conventional artificial lift equipment. Hydraulic lift is also available if gas lift is not possible. Removal of these liquids (hydrocarbons and/or water) reduces back pressure on the reservoir and can accelerate production and also increase reserves and extend the life of wells and the associated lease(s). Inherent in the GARP design is a very efficient gas separator that allows wells with high GLRs to be artificially lifted where previous conventional systems have failed. Also GARP contains an efficient solids separation and containment system which lessens the risk of solids interfering with the pump or packer. The GARP designs provides other benefits as well such as paraffin elimination or reduction, a more efficient chemical placement system, and the ability to free stuck pumps with load water (an optional standing valve is required).
Liquid loading below conventional down-hole pumps (rod pumps & ESPs) is a major problem in wells with horizontal or deviated sections, high gas to liquid ratios (GLRs), deep reservoirs, or long perforated intervals. Operators generally prefer to install down-hole pumps in a well’s vertical section, above any perforations or deviations, to prevent high maintenance costs and inefficiencies resulting from frictional wear on tubulars, solids sticking the down-hole pumps, and gas interference in the pump. In many instances, the pump is placed many hundreds to thousands of feet above the reservoir. Since down-hole pumps cannot recover liquids that exist below them, liquids build up above the reservoir and causes significant back pressure, reducing or even ceasing the production, resulting in a lower eventual ultimate recovery (EUR) and premature abandonment of the well.
Other forms of artificial lift fair no better. The back pressure from gas lift operations will eventually over power the reservoir pressure in depletion drive reservoirs. Plunger lift and soap strings only operate in a narrow range of well conditions and do not effectively lower the bottom hole pressure. Jet pumps are difficult to operate, have environmental concerns with power fluid, and are very inefficient with low BHP and high GLR’s. Hydraulic piston pumps also have environmental issues with power fluid and are inefficient at high GLRs.