Systems and methods for multiphase formation fluid production utilizing an electric submersible pump
A system for producing a multiphase formation fluid utilizing an electric submersible pump comprises a subsurface formation comprising the multiphase formation fluid; a surface collection point; a wellbore; a packer positioned within the wellbore; the electric submersible pump (ESP); a gas separator; a first tubing string; and a second tubing string, wherein the gas separator is configured to separate a gaseous phase of the multiphase formation fluid to produce the gaseous phase through the second tubing string to the surface collection point, and the ESP is configured to produce a liquid phase of the multiphase formation fluid from the subsurface formation through the gas separator and the first tubing string to the surface collection point.
1. A system for producing a multiphase formation fluid utilizing an electric submersible pump, the system comprising:
a subsurface formation comprising the multiphase formation fluid;
a surface collection point;
a wellbore extending from the surface collection point to the subsurface formation;
a packer positioned within the wellbore, the packer defining a first cavity and a second cavity, both the first cavity and the second cavity extending from a top surface of the packer to a bottom surface of the packer;
the electric submersible pump (ESP) comprising an ESP inlet end and an ESP outlet end, the ESP outlet end coupled to the bottom surface of the packer at the first cavity;
a gas separator comprising a multiphase formation fluid inlet, a gaseous phase outlet, and a liquid phase outlet, the liquid phase outlet coupled to the ESP inlet end;
a first tubing string coupled to the top surface of the packer at the first cavity, wherein the first tubing string, the ESP, and the gas separator together define a first fluid pathway from the multiphase formation fluid inlet to the surface collection point; and
a second tubing string coupled to the top surface of the packer at the second cavity, the second tubing string and the packer together defining a second fluid pathway from the bottom surface of the packer to the surface collection point, and wherein
the gas separator is configured to separate a gaseous phase of the multiphase formation fluid to produce the gaseous phase through the second tubing string to the surface collection point, and
the ESP is configured to produce a liquid phase of the multiphase formation fluid from the subsurface formation through the gas separator and the first tubing string to the surface collection point.
2. The system of claim 1 , wherein the ESP further comprises a motor section, a seal section and a pump section, the motor section configured to supply drive to the pump section, the seal section configured to prevent the multiphase formation fluid from entering the motor section, and the pump section configured to lift the multiphase formation fluid through the gas separator and the first tubing string to the surface collection point.
3. The system of claim 1 , further comprising:
a power source positioned at the surface collection point; and
one or more power cables extending from the power source to the ESP, the one or more power cables electrically coupled to the ESP and the power source.
4. The system of claim 3 , wherein the packer further defines a third cavity extending from the top surface of the packer to the bottom surface, the third cavity sized to accept the one or more power cables.
5. The system of claim 3 , further comprising a plurality of tubing clamps spaced along the length of the first tubing string, wherein:
the plurality of tubing clamps are coupled to both the first tubing string and the second tubing string, and
the one or more power cables are coupled to the plurality of the tubing clamps.
6. The system of claim 4 , wherein the surface collection point comprises a dual-string wellhead defining a fourth cavity sized to accept the one or more power cables.
7. The system of claim 1 , wherein the surface collection point comprises a dual-string wellhead having a first wellhead flange fluidly connected to the first tubing string and a second wellhead flange fluidly connected to the second tubing string.
8. The system of claim 7 , wherein the dual-string wellhead comprises a tubing hanger configured to suspend the first tubing string and the second tubing string from the dual-string wellhead.
9. The system of claim 7 , wherein the dual-string wellhead further comprises:
a first length of pipe fluidly connected to the first wellhead flange and a downstream choke valve;
a second length of pipe fluidly connected to the second wellhead flange and a downstream check valve; and
a third length of pipe fluidly connected to the downstream choke valve, the downstream check valve, and a treatment facility, wherein the downstream choke valve is fluidly connected to the third length of pipe upstream from the downstream check valve.
10. The system of claim 9 , wherein the treatment facility comprises one or more hydrocarbon refining units.
11. The system of claim 1 , wherein the gas separator comprises centrifugal gas separator or a turbulent-flow gas separator.
12. The system of claim 1 , wherein the surface collection point comprises a dual-string wellhead comprising:
a first wellhead flange fluidly connected to the first tubing string;
a second wellhead flange fluidly connected to the second tubing string;
a tubing hanger configured to suspend the first tubing string and the second tubing string from the dual-string wellhead;
a first length of pipe fluidly connected to the first wellhead flange and a downstream choke valve;
a second length of pipe fluidly connected to the second wellhead flange and a downstream check valve; and
a third length of pipe fluidly connected to the downstream choke valve, the downstream check valve, and a treatment facility wherein the downstream choke valve is fluidly connected to the third length of pipe upstream from the downstream check valve.
13. The system of claim 1 , further comprising:
a plurality of tubing clamps spaced along the length of the first tubing string, the plurality of tubing clamps coupled to both the first tubing string and the second tubing; and
one or more power cables coupled to the plurality of the tubing clamps, and wherein
the packer further defines a third cavity extending from the top surface of the packer to the bottom surface, the third cavity sized to accept the one or more power cables,
the ESP further comprises a motor section, a seal section and a pump section, the motor section configured to supply drive to the pump section, the seal section configured to prevent the multiphase formation fluid from entering the motor section, and the pump section configured to lift the multiphase formation fluid through the gas separator and the first tubing string to the surface collection point,
the one or more power cables extend from a power source to the ESP and are electrically coupled to the motor section of the ESP as well as the power source positioned at the surface collection point, and
the surface collection point comprises a dual-string wellhead defining a fourth cavity sized to accept the one or more power cables.
14. The system of claim 1 , wherein the multiphase formation fluid comprises hydrocarbons.
15. A method of utilizing the system of claim 1 , the method comprising:
producing a liquid phase of the multiphase formation fluid along the first tubing string utilizing the ESP; and
producing the gaseous phase of the multiphase formation fluid along the second tubing string utilizing the gas separator.
16. The method of claim 15 , further comprising actuating the packer prior to producing the liquid phase.
17. The method of claim 15 , wherein the surface collection point of the system further comprises a dual-string wellhead comprising:
a first wellhead flange fluidly connected to the first tubing string;
a second wellhead flange fluidly connected to the second tubing string;
a tubing hanger configured to suspend the first tubing string and the second tubing string from the dual-string wellhead;
a first length of pipe fluidly connected to the first wellhead flange and a downstream choke valve;
a second length of pipe fluidly connected to the second wellhead flange and a downstream check valve; and
a third length of pipe fluidly connected to the downstream choke valve, the downstream check valve, and a treatment facility.
18. The method of claim 15 , wherein the system further comprises:
a plurality of tubing clamps spaced along the length of the first tubing string, the plurality of tubing clamps coupled to both the first tubing string and the second tubing string; and
one or more power cables coupled to the plurality of the tubing clamps, and wherein
the packer further defines a third cavity extending from the top surface of the packer to the bottom surface, the third cavity sized to accept the one or more power cables,
the ESP further comprises a motor section and a pump section, the motor section configured to supply drive to the pump section and the pump section configured to lift the multiphase formation fluid through the gas separator and the first tubing string to the surface collection point,
the one or more power cables extend from the surface collection point to the ESP and are electrically coupled to the motor section of the ESP as well as a power source positioned at the surface collection point, and
the surface collection point comprises a dual-string wellhead defining a fourth cavity sized to accept the one or more power cables.
19. The method of claim 15 , wherein the gas separator comprises a centrifugal gas separator or a turbulent-flow gas separator.
20. The method of claim 15 , wherein the subsurface formation further comprises hydrocarbons.