Annulus pressure control drilling systems and methods

A method for drilling a wellbore, comprising acts of:

• drilling the wellbore by injecting drilling fluid through a tubular string disposed in the wellbore, the tubular string comprising a drill bit disposed on a bottom thereof, wherein:
• the drilling fluid exits the drill bit and carries cuttings from the drill bit,
• the drilling fluid and cuttings (returns) flow to a surface of the wellbore via an annulus defined by an outer surface of the tubular string and an inner surface of the wellbore
• a pressure sensor is attached to a casing string and in communication with a surface monitoring and control unit (SMCU) via a cable disposed along an outer surface of the casing string or within a wall of the casing string,
• the casing string is hung from a wellhead of the wellbore,
• a liner string is hung from the casing string at or near a bottom of the casing string,
• the liner string has a second pressure sensor configured to measure a third annulus pressure (TAP), and
• each of the casing string and the liner have part of an inductive coupling;
• and
• while drilling the wellbore:
• measuring a first annulus pressure (FAP) using the pressure sensor;
• transmitting the FAP measurement to a surface of the wellbore using a high-bandwidth medium;
• controlling a second annulus pressure (SAP) exerted on a formation exposed to the annulus
• measuring the TAP with the liner sensor;
• transmitting the TAP measurement from the liner to the casing string via the inductive coupling;
• and
• relaying the TAP measurement to the SMCU via the cable.

A method for drilling a wellbore, comprising acts of:

• drilling the wellbore by injecting drilling fluid through a tubular string disposed in the wellbore, the tubular string comprising a drill bit disposed on a bottom thereof, wherein:
• the drilling fluid exits the drill bit and carries cuttings from the drill bit,
• the drilling fluid and cuttings (returns) flow to a surface of the wellbore via an annulus defined by an outer surface of the tubular string and an inner surface of the wellbore
• the tubular string is a drill string further comprising an equivalent circulation density reduction tool (ECDRT),
• the ECDRT comprises a motor, a pump, and an annular seal,
• the drilling fluid operates the motor,
• the annular seal is engaged with the casing string and diverts the returns from the annulus and through the pump,
• the pump is rotationally coupled to the motor, thereby being operated by the motor,
• the pump adds energy to the returns, thereby reducing an equivalent circulation density (ECD) of the returns, and
• a pressure sensor is attached to a casing string hung from a wellhead of the wellbore,
• a second pressure sensor is attached along the casing string so that the pressure sensor is in fluid communication with an inlet of the pump and the second pressure sensor is in fluid communication with an outlet of the pump;
• and
• while drilling the wellbore:
• measuring a first annulus pressure (FAP) using the pressure sensor;
• controlling a second annulus pressure (SAP) exerted on a formation exposed to the annulus;
• measuring a third annulus pressure (TAP) using the second pressure sensor while drilling the wellbore;
• and
• monitoring operation of the ECDRT using the FAP and the TAP.

A method for drilling a wellbore, comprising acts of:

• drilling the wellbore by injecting drilling fluid through a tubular string disposed in the wellbore, the tubular string comprising a drill bit disposed on a bottom thereof, wherein:
• the drilling fluid exits the drill bit and carries cuttings from the drill bit, and
• the drilling fluid and cuttings (returns) flow to a surface of the wellbore via an annulus defined by an outer surface of the tubular string and an inner surface of the wellbore;
• while drilling the wellbore:
• measuring a first annulus pressure (FAP) using a pressure sensor attached to a casing string hung from a wellhead of the wellbore;
• and
• controlling a second annulus pressure (SAP) exerted on a formation exposed to the annulus;
• running a sand screen into the formation;
• and
• expanding the sand screen into engagement with the formation, wherein:
• the casing string is cemented to the wellbore and comprises [[a]] the pressure sensor and a first part of an inductive coupling,
• the sand screen comprises:
• a second pressure sensor, and
• a cable disposed along an outer surface of the sand screen or within a wall of the sand screen, the cable in communication with the second pressure sensor and a second part of an inductive coupling disposed at or near a top of the sand screen, and
• the sand screen is expanded when the second part of the inductive coupling is in longitudinal alignment or near alignment with the first part of the inductive coupling.