Pumps – Processes – Of pumping one fluid by contact or entrainment with another
Reexamination Certificate
2000-04-07
2001-03-27
Michalsky, Gerald A. (Department: 3753)
Pumps
Processes
Of pumping one fluid by contact or entrainment with another
C137S155000
Reexamination Certificate
active
06206645
ABSTRACT:
BACKGROUND OF THE INVENTION
1. Field of the Invention
The present invention relates to subsurface well completion equipment and, more particularly, to an apparatus for lifting hydrocarbons from subterranean formations with gas at high production rates. Additionally, embodiments of independent and detachable actuators are disclosed.
2. Description of the Related Art
Artificial lift systems, long known by those skilled in the art of oil well production, are used to assist in the extraction of fluids from subterranean geological formations. The most ideal well for a company concerned with the production of oil, is one that flows naturally and without assistance. Often wells drilled in new fields have this advantage. In this ideal case, the pressure of the producing formation is greater than the hydrostatic pressure of the fluid in the wellbore, allowing the well to flow without artificial lift. However, as an oil bearing formation matures, and some significant percentage of the product is recovered, a reduction in the formation pressure occurs. With this reduction in formation pressure, the hydrocarbon issuance therefrom is likewise reduced to a point where the well no longer flows without assistance, despite the presence of significant volumes of valuable product still in place in the oil bearing stratum. In wells where this type of production decrease occurs, or if the formation pressure is low from the outset, artificial lift is commonly employed to enhance the recovery of oil from the formation. This disclosure is primarily concerned with one type of artificial lift called “Gas Lift.”
Gas lift has long been known to those skilled in the art, as shown in U.S. Pat. No. 2,137,441 filed in November 1938. Other patents of some historic significance are U.S. Pat. Nos. 2,672,827, 2,679,827, 2,679,903, and 2,824,525, all commonly assigned hereto. Other, more recent developments in this field include U.S. Pat. Nos. 4,239,082, 4,360,064 of common assignment, as well as U.S. Pat. Nos. 4,295,796, 4,625,941, and 5,176,164. While these patents all contributed to furthering the art of gas lift valves in wells, recent trends in drilling and completion techniques expose and highlight long felt limitations with this matured technology.
The economic climate in the oil industry of the 1990's demands that oil producing companies produce more oil, that is now exponentially more difficult to exploit, in less time, and without increasing prices to the consumer. One successful technique that is currently being employed is deviated and horizontal drilling, which more efficiently drains hydrocarbon bearing formations. This increase in production makes it necessary to use much larger production tubing sizes. For example, in years past, 2⅜ inch production tubing was most common. Today, tubing sizes of offshore wells range from 4½ to 7 inches. While much more oil can be produced from tubing this large, conventional gas lift techniques have reached or exceeded their operational limit as a result.
In order for oil to be produced utilizing gas lift, a precise volume and velocity of the gas flowing upward through the tubing must be maintained. Gas injected into the hydrostatic column of fluid decreases the column's total density and pressure gradient, allowing the well to flow. As the tubing size increases, the volume of gas required to maintain the well in a flowing condition increases as the square of the increase in tubing diameter. If the volume of the gas lifting the oil is not maintained, the produced oil falls back down the tubing, and the well suffers a condition commonly known as “loading up.” If the volume of gas is too great, the cost of compression and recovery of the lift gas becomes a significant percentage of the production cost. As a result, the size of a gas injection orifice in the gas lift valve is of crucial importance to the stable operation of the well. Prior art gas lift valves employ fixed diameter orifices in a range up to ¾ inch, which may be inadequate for optimal production in large diameter tubing. This size limitation is geometrically limited by the gas lift valve's requisite small size, and the position of its operating mechanism, which prevents a full bore through the valve for maximum flow.
Because well conditions and gas lift requirements change over time, those skilled in the art of well operations are also constantly aware of the compromise of well efficiency that must be balanced versus the cost of intervention to install the most optimal gas lift valves therein as well conditions change over time. Well intervention is expensive, most especially on prolific offshore or subsea wells, so a valve that can be utilized over the entire life of the well, and whose orifice size and subsequent flow rate can be adjusted to changing downhole conditions, is a long felt and unresolved need in the oil industry. There is also a need for a novel gas lift valve that has a gas injection orifice that is large enough to inject a volume of gas adequate to lift oil in large diameter production tubing. There is also a need for differing and novel operating mechanisms for gas lift valves that will not impede the flow of injection gas therethrough.
SUMMARY OF THE INVENTION
The present invention has been contemplated to overcome the foregoing deficiencies and meet the above described needs. In one aspect, the present invention is a gas lift valve for use in a subterranean well, comprising: a valve body with a longitudinal bore therethrough for sealable insertion in a mandrel; a variable orifice valve in the body for controlling fluid flow into the body; and, an actuating means connected to the variable orifice valve. Another feature of this aspect of the present invention is that the actuating means may be electro-hydraulically operated, and may further include: a hydraulic pump located in a downhole housing; an electric motor connected to and driving the hydraulic pump upon receipt of a signal from a control panel; hydraulic circuitry connected to and responding to the action of the pump; and, a moveable hydraulic piston responding to the hydraulic circuitry and operatively connected to the variable orifice valve, controlling movement thereof. Another feature of this aspect of the present invention is that the actuating means may further include a position sensor to report relative location of the moveable hydraulic piston to the control panel. Another feature of this aspect of the present invention is that the actuating means may be selectively installed and retrievably detached from the gas lift valve.
Another feature of this aspect of the present invention is that the actuating means may further include at least one pressure transducer communicating with the hydraulic circuitry, and transmitting collected data to the control panel. Another feature of this aspect of the present invention is that the actuating means may further include a mechanical position holder. Another feature of this aspect of the present invention is that the actuating means may be selectively installed and retrievably detached from the gas lift valve.
Another feature of this aspect of the present invention is that the actuating means may be hydraulically operated, and may further include: a hydraulic actuating piston located in a downhole housing and operatively connected to the variable orifice valve; a spring, biasing the variable orifice valve in a full closed position; and, at least one control line connected to the hydraulic actuating piston and extending to a hydraulic pressure source. Another feature of this aspect of the present invention is that the actuating means may further include a position sensor to report relative location of the moveable hydraulic piston to a control panel. Another feature of this aspect of the present invention is that the actuating means may further include at least one pressure transducer communicating with the hydraulic actuating piston, and transmitting collected data to a control panel. Another feature of this aspect of the present invention is th
Goldstein & Healey LLP
Michalsky Gerald A.
Schlumberger Technology Corporation
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