Well related injection pressure regulation methods and systems
A technique facilitates regulation of pressure in a well to avoid deleterious effects. The technique involves use of a completion deployed downhole in a borehole. The completion may comprise a variety of equipment assembled to facilitate a desired injection operation. A choke is positioned below, i.e. downhole, of the equipment. When an injection fluid is delivered down through the completion, the choke is able to provide a desired pressure regulation. For example, the choke may be controlled or otherwise utilized so as to control pressure of the injection fluid such that the injection fluid above the choke is maintained at a pressure higher than the liquid to gas transition level of the injection fluid.
1 . A method for regulating pressure in a borehole, comprising:
suspending a liner downhole in the borehole via a liner hanger;
running a completion downhole within the liner, wherein the completion includes an inner tubular having an interior bore;
positioning a choke within the interior bore of the inner tubular of the completion;
delivering an injection fluid down through the completion such that the injection fluid flows through the choke in the interior bore; and
using the choke disposed in the interior bore to control pressure of the injection fluid such that the injection fluid above the choke is maintained at a pressure above the liquid to gas transition line of the injection fluid.
2 . The method as recited in claim 1 , further comprising forming a seal between the completion and the liner with a packer.
3 . The method as recited in claim 2 , further comprising employing a subsurface safety valve along the completion at a location above the liner.
4 . The method as recited in claim 3 , wherein suspending comprises suspending the liner from well casing via the liner hanger.
5 . The method as recited in claim 3 , wherein the choke is a passive choke.
6 . The method as recited in claim 3 , wherein the choke is an active choke.
7 . The method as recited in claim 3 , wherein the choke is in the form of a wireless active choke.
8 . The method as recited in claim 3 , wherein the choke is an inline flow control valve.
9 . The method as recited in claim 3 , wherein the choke is a drop-in mechanical choke.
10 . The method as recited in claim 3 , wherein the choke is an electrical choke.
11 . The method of claim 10 , wherein the liner includes an inductive coupler portion and the electrical choke includes an inductive coupler, and wherein running the completion downhole includes aligning the inductive coupler of the electrical choke with the inductive coupler portion of the liner.
12 . The method as recited in claim 3 , wherein the choke is a wireless, electrical choke.
13 . The method of claim 3 , wherein the completion comprises an upper completion portion including the subsurface safety valve and a lower completion portion including the choke, and wherein the injection fluid flows from the subsurface safety valve through the choke in the lower completion portion.
14 . A system for use in a well, comprising:
a completion disposed in a liner suspended within a borehole, the completion being configured to accommodate an injection operation, wherein the completion includes an inner tubular having an interior bore configured to deliver an injection fluid;
a subsurface safety valve positioned along the completion; and
a choke located within the interior bore of the inner tubular of the completion at a location downhole of the subsurface safety valve, the choke being configured to control pressure of the injection fluid such that the injection fluid within the interior bore above the choke is maintained at a pressure above a phase transition line of the injection fluid so as to protect the subsurface safety valve against an unwanted decrease in temperature.
15 . The system as recited in claim 14 , wherein the liner is suspended within the borehole via a liner hanger, and wherein the completion is disposed in the liner such that the choke is located within the liner while the subsurface safety valve is located uphole from the liner.
16 . The system as recited in claim 14 , wherein the choke comprises a passive choke.
17 . The system as recited in claim 14 , wherein the choke comprises an active choke.
18 . The system as recited in claim 14 , wherein the choke comprises a wireless active choke.
19 . The system as recited in claim 14 , wherein the choke comprises an electrically powered choke.
20 . A method, comprising:
deploying a completion into a liner suspended in a borehole, the completion including an inner tubular having an interior bore;
providing the completion with equipment for facilitating a desired injection operation;
positioning a choke below the equipment and within the interior bore of the inner tubular of the completion;
delivering an injection fluid down through the interior bore of the completion; and
using the choke to control pressure of the injection fluid such that the injection fluid above the choke is maintained at a pressure above a phase transition line of the injection fluid so as to protect the equipment and the borehole against an unwanted decrease in temperature due to phase change.
21 . The method as recited in claim 20 , wherein delivering the injection fluid comprises delivering carbon dioxide (CO2).
22 . The method as recited in claim 20 , wherein the liner is suspended in the borehole via a liner hanger.