Background Art In wells drilled for petroleum production, a plurality of well casings of different sizes are suspended from a wellhead. A problem encountered in such wells is that of annular pressure control. In the annulus between different casing sizes, pressure may develop due to leaks between strings of casing. Previously, to control the pressure, a relatively heavy liquid is pumped into the annulus at the upper end of the well. The heavy liquid migrates slowly downward, displacing lighter liquid. This technique does not always work.

Disclosure of Invention In this system, a flexible hose is lowered into an annulus between strings of casing. A nozzle is affixed to the lower end of the hose. The hose may be inserted several hundred feet into the well. Therefore, the hose must be pressurized and rigid to keep the hose from winding about the well. To keep the hose rigid, internal pressure is maintained in the hose. The nozzle is provided with a valve or burst disk in it that holds the pressure. Once the hose is lowered to a desired depth, the operator increases the pressure sufficiently in the hose to break the disk or open the valve, thereby allowing heavy liquid to flow out. The heavy liquid displaces the lighter well production, which flows out of the outlet. An injection sealer at the surface seais around the hose. A gate valve is employed to shear the hose in the event of an emergency.

Brief Description of Drawings Figure 1 is a sectional side view of a wellhead constructed in accordance with the invention.

Figure 2 is a sectional side view of a remediation valve and remediation hose capture assembly secured to the wellhead of Figure 1.

Figure 3 is an enlarged, split sectional side view of a gate in the remediation valve of Figure 2 showing a sealing position on the left side and a retrieval position on the right side.

Figure 4 is an enlarged sectional side view of a hose guide bushing in a port in the wellhead of Figure 1.

Figure 5 is an end view of the hose guide bushing of Figure 4.

Figure 6 is an enlarged sectional side view of a hose and nozzle.

Best Mode for Carrying Out the Invention Referring to Figure 1, a wellhead 11 having multiple strings of casing 1 3, 1 5, 17, 1 9 suspended from it is shown. A longitudinal annulus extends between each pair of adjacent strings of casing. Each annulus has at least one access port at wellhead 11. For example, annulus 21 extends between casing strings 1 5 and 17, and has access ports 23, 25, while annulus 31 extends between casing strings 13 and 15, and has access port 35. Conventional vaives 27 and 37 control flow through ports 25 and 35, respectively.

A gate valve 41 is bolted to the outer surface of wellhead 11 and controls access to port 23. A stuffing box assembly 43 is secured to gate valve 41. As shown in Figure 2, in this embodiment, stuffing box assembly 43 comprises a remediation valve 45, a pinning device 47, a packoff 49 and an axial passage 57.

A flexible elastomeric hose 51 extends through passage 57. In the preferred embodiment, hose 51 comprises a strong polyester braid surrounded by two layers of plastic and has an outer diameter of about one inch. Hose 51 is coiled on a hose driver assembly 70 further upstream from stuffing box assembly 43.

As shown in Figure 3, remediation valve 45 has a vertically slidable gate 53, and upstream and downstream seats 55 with axial holes 58 which register with passage 57. Gate 53 has two horizontal openings 54, 56 that are approximately the same diameter. Opening 54 and holes 58 have sharpened edges 60 made from tool steel for shearing hose 51 in an emergency. Gate 53 has three possible positions.

In the running position (Figure 2), opening 54 registers with holes 58. In the sealing or fail-safe position, a solid portion of gate 53 seals between seats 55 (left side of Figure 3). Finally, in the retrieval position, opening 56 registers with holes 58 (right side of Figure 3).

Returning to Figure 2, pinning device 47 is located between remediation valve 45 and gate valve 41. Pinning device 47 has a cylindrical rod 48 on the end of a shaft 50. Rod 48 and shaft 50 are vertically moveable between an open position and a closed or pinning position (not shown) wherein hose 51 is clamped between rod 48 and a stop 52. Packoff 49 is a sealing system that is located on the upstream side of remediation valve 45. A conventionai injection sealer 59 pumps grease around hose 51 to seal between hose 51 and passage 57.

Referring to Figures 4 and 5, a hose guide bushing 61 is threaded into and extends radially inward from access port 23 into wellhead 11. Hose guide bushing 61 has a passage 63 which communicates with passage 57 through gate valve 41.

A radially inward portion of passage 63 is skewed downward at an obtuse angle relative to the outer portion of passage 63 into wellhead 11. A chamfer 62 is ground into passage 63 at the radially inward end of bushing 61. Chamfer 62 is elliptical and has a greater horizontal width than vertical height. Hose 51 is inserted from the hose driver assembly 70, through passage 57 and gate valve 41, and into passage 63.

As shown in Figure 6, one end of hose 51 has a cylindrical tubing nose assembly 65 with self-tapping threads 66 fastened to one end. The diameter of hose 51 is reduced a small amount on the end where tubing nose 65 attaches. This reduction allows tubing nose 65 to have the same final outer diameter as hose 51.

As tubing nose 65 is threaded into hose 51, ring 64a and wedges 64b crush hose 51 into threads 66. A pair of O-rings 68 provide the necessary seal. Tubing nose 65 has a tapered tip 67 that is designed to assist the movement of hose 51 through the components of wellhead 11 and annulus 21. Tubing nose 65 also has a small plastic burst disc, plug, or cap 69 that opens by being blown out, rupturing under a selected pressure or opening by some other means. Cap 69 serves as a pressure retaining mechanism to hold pressure in hose 51 until a selected pressure is revealed.

In operation, if one of the strings of casing 13, 15, 17, or 1 9 begins to leak, a pressure build-up may occur in the annulus between the strings of casing. In this invention, pressure build-up is alleviated by pumping a heavy liquid into that annular space and displacing well fluid. If casing 17 is leaking, the heavy liquid is delivered

to the annulus through hose 51, which is run through passages 57, 63 (Figures 2 and 4). Hose 51 is pressurized with the heavy liquid to sufficient pressure (approximately 100 psi) to make it substantially rigid. Hose 51 will be pushed into stuffing box assembly 43 and port 23 with gate 53 in the running position (Figure 2). Although hose 51 is fairly rigid, hose guide bushing 61 steers hose 51 and tubing nose 65 slightly downward into annulus 21 (Figure 4). Tip 67 of tubing nose 65 will glance off casing 17, and hose 51 is forced downward into annulus 21 (not shown). Chamfer 62 allows hose 51 some horizontal movement and prevents hose 51 from wedging between casing 17 and bushing 61. The hose driver assembly continues feeding hose 51 into annulus 21. Because of its rigidity, hose 51 may extend several hundred feet into annulus 21 without winding about the annulus (not shown). In an alternate embodiment, a fluid jet may be directed up to enhance the downward travel of the hose.

Once hose 51 and tubing nose 65 are at the correct depth, the pressure in hose 51 is sufficiently increased to burst cap 69, allowing the heavy fluid to flow out through tubing nose 65. The heavy liquid displaces the lighter well production fluid which flows out port 25 when valve 27 is opened (Figure 1). Once the heavy liquid fills annuius 21, hose 51 is removed and the valves are closed.

If packoff 49 is unable to prevent leakage around hose 51 due to high pressure in the well getting out of control or some other emergency occurs, pinning device 47 is used to pin hose 51 with rod 48 and stop 52. Gate 53 is then moved to the sealing position and hose 51 is sheared by edges 60 in a scissoring motion.

It is important to have a clean cut so that hose 51 can be plugged with a fishing tool and retrieved later after the pressure is under control. After the pressure in the well is under control, gate 53 is moved to the retrieval position with hole 56 aligning with seat holes 58. A tool is run in through hole 57 to grip the cut end of hose 51.

Pinning device 47 is then released and the remaining length of hose 51 is retrieved.

In the final step, gate 53 is moved back to the running position so that the small piece of cut hose 51 still lodged in opening 54 may be removed with the tool. This operation could be performed on any annulus in wellhead 11.

The invention has significant advantages. By pressurizing small diameter elastomeric tubing, inexpensive elastomeric tubing may be used instead of large and expensive coiled tubing to inject fluids in a well annulus. The tubing may be used to run an inspection camera. Additionally, the tube may be left in the well to be used for casing annulus pressure remediation and annulus pressure remediation or periodically unloading the well, pumping chemicals, etc.

While the invention has been shown in only one of its forms, it should be apparent to those skilled in the art that it is not so limited, but is susceptible to various changes without departing from the scope of the invention.