A comprehensive review on proppant technologies

The present invention is an improved method and apparatus for testing and monitoring wellbore operations The invention is (1) a data acquisition device capable of monitoring, recording wellbore and/or reservoir characteristics while capable of fluid flow control; and (2) a method of monitoring and/or recording at least one downhole characteristic during testing, completion and/or maintenance of a wellbore The invention includes an assembly within a casing string comprising a sensor probe having an optional flow port allowing fluid flow while sensing wellbore and/or reservoir characteristics It also includes a microprocessor, a transmitting device, and a controlling device located in the casing string for processing and transmitting real time data A memory device is also provided for recording data relating to the monitored wellbore or reservoir characteristics Examples of downhole characteristics which may be monitored include: temperature, pressure, fluid flow rate and type, formation resistivity, cross-well and acoustic sesmometry, perforation depth, fluid characteristic or logging data With the microprocessor, hydrocarbon production performance may be enhanced by activating local operations in additional associated downhole equipment, eg, water shut-off operations at a particular zone, maintaining desired performance of a well by controlling flow in multiple wellbores, zone mapping on a cumulative basis, flow control operations, spacing casing and its associated flow ports in multiple zone wellbores, maintaining wellbore and/or reservoir pressure, sensing perforation characteristics, sensing reservoir characteristics or any number of other operations

Method and apparatus for testing, completing and/or maintaining wellbores using a sensor device

This invention provides a method for controlling production operations using fiber optic devices. An optical fiber carrying fiber-optic sensors is deployed downhole to provide information about downhole conditions. Parameters related to the chemicals being used for surface treatments are measured in real time and on-line, and these measured parameters are used to control the dosage of chemicals into the surface treatment system. The information is also used to control downhole devices that may be a packer, choke, sliding sleeve, perforating device, flow control valve, completion device, an anchor or any other device. Provision is also made for control of secondary recovery operations online using the downhole sensors to monitor the reservoir conditions. The present invention also provides a method of generating motive power in a wellbore utilizing optical energy. This can be done directly or indirectly, e.g., by first producing electrical energy that is then converted to another form of energy.

Wellbores utilizing fiber optic-based sensors and operating devices

A closed-loop circulating system for drilling wells has control of the flow rates in and out of the wellbore. Kicks and fluid losses are quickly controlled by adjusting the backpressure. Kick tolerance and tripping margins are eliminated by real-time determination of pore and fracture pressure. The system can incorporate a rotating BOP and can be used with underbalanced drilling.

Drilling system and method

A method of real time field wide reservoir management comprising the steps of processing collected field wide reservoir data in accordance with one or more predetermined algorithms to obtain a resultant desired field wide production/injection forecast, generating a signal to one or more individual well control devices instructing the device to increase or decrease flow through the well control device, transmitting the signal to the individual well control device, opening or closing the well control device in response to the signal to increase or decrease the production for one or more selected wells on a real time basis. The system for field wide reservoir management comprising a CPU for processing collected field wide reservoir data, generating a resultant desired field wide production/injection forecast and calculating a target production rate for one or more wells and one or more down hole production/injection control devices.

System and method for real time reservoir management

The present invention provides a drilling system for drilling oilfield boreholes or wellbores utilizing a drill string having a drilling assembly conveyed downhole by a tubing (usually a drill pipe or coiled tubing). The drilling assembly includes a bottom hole assembly (BHA) and a drill bit. The bottom hole assembly preferably contains commonly used measurement-while-drilling sensors. The drill string also contains a variety of sensors for determining downhole various properties of the drilling fluid. Sensors are provided to determine density, viscosity, flow rate, clarity, compressibility, pressure and temperature of the drilling fluid at one or more downhole locations. Chemical detection sensors for detecting the presence of gas (methane) and H2S are disposed in the drilling assembly. Sensors for determining fluid density, viscosity, pH, solid content, fluid clarity, fluid compressibility, and a spectroscopy sensor are also disposed in the BHA. Data from such sensors may be processed downhole and/or at the surface. Corrective actions are taken based upon the downhole measurements at the surface which may require altering the drilling fluid composition, altering the drilling fluid pump rate or shutting down the operation to clean wellbore. The drilling system contains one or more models, which may be stored in memory downhole or at the surface. These models are utilized by the downhole processor and the surface computer to determine desired fluid parameters for continued drilling. The drilling system is dynamic, in that the downhole fluid sensor data is utilized to update models and algorithms during drilling of the wellbore and the updated models are then utilized for continued drilling operations.

Drilling system with sensors for determining properties of drilling fluid downhole

A method and apparatus for effecting the completion of non-vertical, including horizontally disposed, portions of a deviated well bore traversing a production formation. To facilitate the insertion of a gravel packing tool string through the curved portion of the well bore, stabilizer elements are maintained in a radially retracted position and then operated to engage the well bore after the tool string is run-in. An anti-rotation tool may be incorporated for connecting the work string to the left hand threads conventionally provided on a conventional packer in order to permit rotation of the entire tool string to facilitate passage through the curved portion of the well bore. Two gravel packing modifications are disclosed, the one employing a single packer and a cross-over tool located at the top end of a plurality of serially connected screens. In the order modification, a plurality of gravel packing sections, including stabilizers, screens, a sleeve valve housing and a packer are serially connected together and run-in. A cross-over tool is then inserted by a separate tubular work string to be initially positioned adjacent the lowermost packer to accomplish the packing of the lowermost screens and then moved to the next packer to successively effect the gravel packing of all of the gravel packing sections.

Method and apparatus for completing a non-vertical portion of a subterranean well bore

A method and apparatus for effecting the completion of non-vertical, including horizontally disposed, portions of a deviated well bore traversing a production formation. To facilitate the insertion of a gravel packing tool string through the curved portion of the well bore, stabilizer elements are maintained in a radially retracted position and then operated to engage the well bore after the tool string is run-in. An anti-rotation tool may be incorporated for connecting the work string to the left hand threads conventionally provided on a conventional packer in order to permit rotation of the entire tool string to facilitate passage through the curved portion of the well bore. Two gravel packing modifications are disclosed, the one employing a single packer and a cross-over tool located at the top end of a plurality of serially connected screens. In the other modification, a plurality of gravel packing sections, including stabilizers, screens, a sleeve valve housing and a packer are serially connected together and run-in. A cross-over tool is then inserted by a separate tubular work string to be initially positioned adjacent the lowermost packer to accomplish the packing of the lowermost screens and then moved to the next packer to successively effect the gravel packing of all of the gravel packing sections.

Method for completing a non-vertical portion of a subterranean well bore

Frac-Packing: Best Practices and Lessons Learned from over 600 Operations

Frac Packing: Best Practices and Lessons Learned From More Than 600 Operations

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