Wells – Processes – With indicating – testing – measuring or locating
Reexamination Certificate
2001-05-24
2003-07-29
Bagnell, David (Department: 3672)
Wells
Processes
With indicating, testing, measuring or locating
C166S066700, C166S066000, C367S083000
Reexamination Certificate
active
06598675
ABSTRACT:
BACKGROUND
THE PRIOR ART
In certain wells that naturally produce very slowly, pumps are desirable. Pumps can increase the rate of production by pumping fluid faster than the well could otherwise push the fluid. Pumps, therefore, are desirable in many well situations. A drawback of the use of pumps however is that they generally have a limited life span (pumps generally have a life of about 80% shorter than other well components). Limited life span components necessitates frequent repair or replacement. In order to repair or replace a pump it must be withdrawn from the well. The activity requires that the well be opened. Thus, unless there is a means to close off the well or the well is killed dead, the removal of the pump causes spillage of well fluid into the surrounding environment. Clearly, this occurrence is environmentally unsound. To prevent said spillage, various attempts have been made to actuate a valve beneath the pump.
One prior art method employs a sleeve valve under the pump which is shiftable by a shifting sub. The sub includes an elongated section having a shifting profile thereon that engages a sleeve, through profile receptacles, shifts the same and then disengages therefrom in the downhole direction. The length of the shifting sub and all of the pipe joints thereabove must be exactly the same each time the upper section is pulled and run back in the hole or the sleeve will be damaged. Damage is caused by things being smashed into each other due to different lengths. Certainty about whether or not the sleeve is closed is also lacking.
Another prior art method for controlling flow when the pump is removed and, thus, the well is open is to employ a ball choke below the pump. The device operates on 50 to 200 psi and upon such pressure causes the valve to cycle in a “J” groove between on and off positions. The valve contains a ball receptacle which contains a “J” groove well known in the art, to cycle the valve to alternating on/off positions. The groove feature is actuated by pressurizing the well from the surface. Although the valve does function correctly in controlled conditions, the confidence in the positioning of the valve in the field is low. It is very difficult to definitively determine that the valve has been cycled only once when the pressure inducing apparatus is large. Because the valve is actuated between 50 and 200 psi and then bleeds pressure past the ball it is extremely easy to double cycle the valve which leaves it open again. Because of the lack of confidence in the position of the valve, delay is experienced. The well operator must wait a period of time after an attempted cycling to see if pressure climbs within the well or does not. This is the only assurance of the condition of the valve. If pressure does not rise, the valve is closed, if pressure does rise, the valve is open. Since, of course, in the oil production industry time is tremendously expensive, the method leaves much to be desired.
A system having a pump which can be separately removed from the well while leaving the valving structure intact and wherein such a system is reliable and in communication with other well functions.
SUMMARY
The above-discussed and other problems and deficiencies of the prior art are overcome or alleviated by the production well control system of the present disclosure.
The disclosure solves the problems inherent in the prior art and additionally provides optimization of well production.
In the disclosure, the pump is mechanically separated both from the valve structure and from valve operation such that the removal of the pump for repair or replacement may be accomplished without removal of or any deleterious effect on the valve system. Since, of course, communication is required between the pump and valve system and is desirable even beyond the valve system, a hydrophone or geophone is employed on each portion of the pump and valve system of the disclosure to provide communication across the mechanical gap between the pump assembly and the valve assembly. The first concept of the disclosure is sufficient to enhance the state of the art for pump repair and replacement. The disclosure however includes an additional and important feature.
In the additional feature of the disclosure, the valve assembly includes both primary and secondary valve structures, the primary valve being actuatable selectively, preferably by a downhole intelligence package, and the secondary valve structure being actuatable by removal or insertion of the primary valve structure. Because of the sensor(s) and controller involved with actuation of the primary valve, the system of the disclosure provides not only an on/off valve for pump issues but, further provides optimization of production of the well by enabling the valve to sense certain parameters regarding production and tailor the valve opening to produce the well as efficiently as the particular formation will allow. The information gained and decision made by the controller can also, of course, be transmitted to other locations by the hydrophone/geophone link or by wireline. The information is then also employed to modify pump rate to match the well production capability.
The above-discussed and other features and advantages of the present disclosure will be appreciated by and understood by those skilled in the art from the following detailed description and drawings.
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Bussear Terry R.
Jones Kevin R.
Bagnell David
Baker Hughes Incorporated
Bomar Shane
Cantor & Colburn LLP
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