SYSTEMS AND METHODS OF FORMING SUBSURFACE WELLBORES

• US 20100108379A1
• Filed: 10/09/2009
• Published: 05/06/2010
• Est. Priority Date: 10/13/2008
• Status: Active Grant

• Current Assignee: Shell Oil Company (Shell Plc)
• Original Assignee: Shell Oil Company (Shell Plc)
• Inventors: Edbury, David Alston, MacDonald, Duncan Charles
• Granted Patent: US 9,129,728 B2
• Time in Patent Office: Days
• US Class Current: 175/17
• CPC Class Codes: E21B 43/24 using heat, e.g. steam injection
• CPC Class Codes: E21B 43/2401 by means of electricity
• CPC Class Codes: E21B 43/2405 in association with fracturing or crevice forming processes E21B43/247 takes precedence
• CPC Class Codes: E21B 44/02 Automatic control of the tool feed E21B44/005, E21B44/10 take precedence
• CPC Class Codes: H01C 3/00 Non-adjustable metal resistors made of wire or ribbon, e.g. coiled, woven or formed as grids
• CPC Class Codes: H05B 2214/03 Heating of hydrocarbons
• CPC Class Codes: H05B 3/48 heating conductor embedded in insulating material
• CPC Class Codes: Y10T 29/49083 Heater type

Abstract

A system for forming a subsurface wellbore includes a rack and pinion system including a chuck drive system. The chuck drive system operates a drilling string. An automatic position control system includes at least one measurement sensor coupled to the rack and pinion system. The automatic position control system controls the rack and pinion system to determine a position of the drilling string.

Claims

1-891. -891. (canceled)

892. A system for forming a subsurface wellbore, comprising:

a rack and pinion system comprising a chuck drive system, wherein the chuck drive system is configured to operate a drilling string; and

an automatic position control system comprising at least one measurement sensor coupled to the rack and pinion system, wherein the automatic position control system is configured to control the rack and pinion system to determine a position of the drilling string.

893. The system of claim 892, wherein the chuck drive system is configured to hold a tubular.

894. The system of claim 892, wherein the chuck drive system is configured to hold a tubular, and the tubular comprises one or more heaters.

895. The system of claim 892, wherein the chuck drive system is configured to hold a tubular comprising one or more heaters, and at least one of the heaters comprises one or more magnetic ranging sensors.

896. The system of claim 892, wherein the chuck drive system is configured to hold a tubular comprising one or more heaters, and at least one of the heaters comprises one or more non-rotating sensors.

897. The system of claim 892, wherein the automatic position control system is configured to be continuously or semi-continuously calibrated during drilling.

898. The system of claim 892, wherein the automatic position control system comprises one or more rotary steerable systems.

899. The system of claim 892, wherein the automatic position control system comprises one or more dual motor rotary steerable systems.

900. The system of claim 892, wherein the automatic position control system comprises one or more hole measurement systems.

901. The system of claim 892, wherein the automatic position control system comprises one or more hole measurement systems and wherein at least one hole measurement system comprises one or more canted accelerometers.

902. A method for forming a subsurface wellbore, comprising:

receiving position data about a tubular from at least one measurement sensor coupled to an automatic position control system; and

controlling a direction of the tubular in a subsurface formation using a rack and pinion system based on the position data from the measurement sensor.

903. The method of claim 902, wherein the measurement sensor comprises one or more canted accelerometers.

904. The method of claim 902, wherein the position data is obtainable in the presence of magnetic interference sources.

905. The method of claim 902, wherein the position data comprises relative rotational data of the tubular shaft.

906. A system for forming a subsurface wellbore, comprising:

a bottom drive system configured to couple to an existing tubular of a drilling string at least partially in the subsurface wellbore and to control a drilling operation in the wellbore, the bottom drive system comprising a circulating sleeve configured to accept a new tubular during the drilling operation; and

a top drive system configured to couple with the new tubular and to assume control of the drilling operation when the new tubular is coupled to the existing tubular.

907. The system of claim 906, wherein the bottom drive system is configured to move at least partially up to the top of the new tubular while the top drive system is controlling the drilling operation and to assume control of the drilling operation from the top drive system.

908. The system of claim 906, further comprising a tubular handling system configured to position the new tubular for coupling with the top drive system.

909. The system of claim 906, wherein the top drive system comprises a circulating sleeve, and the circulating sleeve of the bottom drive system is configured to receive fluid from the circulating sleeve of the top drive system.

910. The system of claim 906, wherein the circulating sleeve is configured to maintain a pressure up to pressures of about 13.8 MPa.

911. A method for adding a new tubular to a drilling string, comprising:

coupling a top end of the new tubular to a top drive system;

positioning a bottom end of the new tubular in an opening of a circulating sleeve of a bottom drive system while the bottom drive system controls a drilling operation;

while the drilling operation continues, coupling the new tubular to an existing tubular to form a coupled tubular;

transferring control of the drilling operation from the bottom drive system to the top drive system;

while the drilling operation continues, moving the bottom drive system up the coupled tubular towards the top drive system;

while the drilling operation continues, coupling the bottom drive system to a top portion of the coupled tubular;

transferring control of the drilling operation from the top drive system to the bottom drive system; and

disconnecting the top drive system from the coupled tubular.

912. The method of claim 911, further comprising providing fluid to the bottom drive system from the circulating sleeve of the bottom drive system;

and once the new tubular is positioned in the opening of the circulation sleeve of a bottom drive system, providing fluid from a circulating sleeve of the top drive system to the bottom drive system.

913. The method of claim 911, further comprising maintaining a pressure up to about 13.8 MPa in the circulating sleeve of the bottom drive system.

914. The method of claim 911, wherein coupling the new tubular to the existing tubular comprises applying sufficient pressure to pressure-fit the tubulars together.

915-1180. -1180. (canceled)