The disclosures herein relate generally to a device and a method for the hydraulic fracturing, also referred to as fracing, of multiple zones in a well bore.
During the production of oil from an oil well, one of the well bore operations involves fracing multiple zones of the well bore. The term “frac” means introducing a fluid into a sub-surface area of earth which is likely to yield a hydro-carbon product. The frac fluid facilitates collection of the product by creating a conduit in the zones in which the product is trapped. The product can then flow through the conduit into the well bore where the product can be collected. The fracing operations are often conducted after the well has been placed into production, therefore it is important that the fracing operation be conducted as quickly and efficiently as possible.
Some of the known methods to accomplish this involve retrievable methods where all elements or tools used in the fracing process are removed from the well bore. One method includes a bridge plug and a packer used with either jointed tubing or coiled tubing. A frac port is located between the bridge plug and the packer. Another method involves using at least two cups opposing each other with a frac port located between the cups. Still another method uses a straddle packer which straddles a zone. A cup is positioned above the zone. The frac port is located between the straddle packer and the cup.
Disadvantages of the retrievable methods are that the tools are complex and could become stuck in the well. A stuck tool would require fishing the tool out, drilling through the tool, or leaving the tool in the well. Drilling through the tool is difficult because the tool is formed of heat treated steel.
A more recent method involves the use of drillable tools, i.e., tools that are made of softer material and can be drilled out of the well. However, use of this method involves a first trip down the well to set a bridge plug below the frac zone and a second trip down the well to do the frac job. However, this process must be repeated for each zone. Therefore, if there are ten zones to be treated, twenty trips down the well are required. This is disadvantageous because it is time consuming and each trip causes wear on the coiled tubing. Therefore, cost and complexity of the operation are major disadvantages.
A service tool is provided for individually isolating and pumping fluid into multiple zones in a well or subterranean formation. A single trip downhole (into the well bore) is required to treat one or more zones. A second trip may be required to drill out drillable packers left behind in the casing. An advantage of this tool is that it can be used with either jointed tubing or coiled tubing.
The tool includes a packer assembly 10 located in a well bore 12, FIG. 1. The well bore 12 can be either a cased completion as shown in
The stinger 16 is elongated and includes an outer diameter 24 slidably mounted in a passage formed in respective packer 18a, FIG. 4. An inner fluid passage 26 extends through stinger 16. A generally cylindrical wall of stinger 16 defines a ported mandrel 28 having a plurality of ports 28a and 28b. A collet mandrel 30 is formed on stinger 16 adjacent a distal open end 32 and includes a collet 34 and a plurality of elongated slots 36 adjacent the collet 34. The elongated slots 36 provide for radial compressibility of the collet mandrel 30. A ball seat 38 is also provided adjacent distal open end 32, for use in connection with a ball 40, discussed below.
Each packer 18a, 18b, 18c is identical and therefore, only one packer 18a is described in detail. In order to better illustrate the details of packer 18a,
A first or distal portion A,
A second portion B,
A third portion C,
A port 72 is formed in packer mandrel 44 adjacent the ports 28b of stinger 16. A chamber 76 is in fluid communication with port 72. Fluid pressure in chamber 76 moves the setting sleeve 60 to set the packer 18a.
In operation, ball 40,
After a packer is set, stinger 16 is moved so that ports 28a and 28b are below a bottom end E of mule shoe 42. The fluid used for hydraulic fracturing is released under high pressure through the ports 28a and 28b. After fracturing is completed, removal of stinger 16 from the secured packer as stated above, permits flapper valve 68 to pivot and seal and the remaining packers are separated from the secured packer. The process is then repeated as the remaining packers are sequentially secured and separated. The flapper valve 68 provides the advantage that the operator can let the well produce immediately after fracing, and drill out the drillable packers at a convenient time.
Although only a few exemplary embodiments of this invention have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the exemplary embodiments without materially departing from the novel teachings and advantages of this invention. Accordingly, all such modifications are intended to be included within the scope of this invention as defined in the following claims.
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Number | Date | Country | |
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20030183391 A1 | Oct 2003 | US |