1. A method of producing fluid from a well, comprising:
estimating an expected fluid flow rate from at least one production zone of the well as a function of time for a first setting of at least one flow control device in the well;
monitoring actual flow rate of the fluid from the at least one production zone into the well corresponding to the first setting of the at least one flow control device; and
determining, using a computer model and a plurality of inputs selected from downhole sensor measurements, surface sensor measurements and parameters of the at least one flow device, a second setting of the at least one flow control device from a declining trend of the actual flow rate, which second setting will increase the flow rate of the fluid from the well to at least the expected fluid flow rate; and
configuring the well corresponding to the at least one second setting to obtain enhanced production of the fluid from the well.
2. The method of claim 1 further comprising determining a second expected fluid flow rate over time for the well based on the at least one second setting.
3. The method of claim 2 further comprising computing a net present value (NPV) for the well based on the second expected fluid flow rate.
4. The method of claim 1, wherein the plurality of inputs are selected from a group consisting of information relating to: pressure in the well; flow rates in the well; flow rates at the surface; operating parameters of an electrical submersible pump; chemical injection rate; temperature; resistivity; density of the fluid; fluid composition; capacitance measurement; vibration; acoustic measurements; differential pressure across a device; water content; oil-water ratio; gas-and oil ration; oil-water ratio.
5. The method of claim 4 wherein the group further consists at least one of: micro-seismic measurements; pressure transient test measurements; well log measurements; measurements relating to presence of a chemical in the well that is one of scale, hydrate, corrosion and asphaltene, paraffin.
6. The method of claim 1 further comprising:
estimating an occurrence of at least one of a: water breakthrough; cross-flow condition; deterioration of a casing in the well; deterioration of a device in the well; and determining the at least one second setting based on such estimation.
7. The method of claim 1 further comprising, altering at least one of: a chemical injection rate; operation of an ESP; shutting in a selected production zone when the well includes a plurality of production zones.
8. The method of claim 1 further comprising sending a message relating to the at least one second setting to at least one of: an operator; and a remote location from the well.
9. The method of claim 1, wherein the at least one second setting includes a change in position of the at least one device, a change in a chemical injection rate and a change in fluid flow rate from an artificial lift mechanism in the well.
10. The method of claim 1 further comprising updating the expected fluid flow rate based on the at least one second setting.
11. The method of claim 1 further comprising monitoring the actual flow rate of the fluid from the at least one production zone into the well over a time period corresponding to the at least one second setting; and determining a third setting from a declining trend of the actual flow rate after operating the well at the at least second setting a third setting that will enhance the fluid flow from the at least one production zone.
12. A system for obtaining enhanced production from a well that includes a plurality of production zones, a separate flow control device associated with each production zone and an artificial lift device, the system comprising:
a computer system that includes a processor, a computer readable medium for storing computer programs and database that is accessible to the computer for executing instructions contained in the computer program and a display device for displaying information sent by the processor, wherein the computer program comprises;
a set of instruction to monitor actual flow rate of the fluid from each production zone over a time period corresponding to a first setting of each flow control device and the flow through the artificial device;
a set of instructions to utilize a nodal analysis on a plurality of inputs selected from downhole sensor measurements, surface sensor measurements, current position of at least one flow control device to determine a new setting for at least one flow control device from a declining trend of the actual flow rate to obtain enhanced production rate from the well; and
a set of instructions to continue to monitor the enhanced flow rate corresponding to the new setting.
13. The system of claim 12, wherein the computer program further comprises instructions to compute an expected enhanced fluid flow rate for the well based on the new setting.
14. The system of claim 13, wherein the computer program further includes instructions to compute a net present value (NPV) for the well based on the computed enhanced fluid flow rate.
15. The method of claim 12, wherein the plurality of inputs are selected from a group consisting of information relating to: pressure in the well; flow rate in the well; flow rate at the surface; an operating parameter of an electrical submersible pump; a chemical injection rate; temperature; resistivity; density of the fluid; fluid composition; a capacitance measurement relating to the fluid; vibration; acoustic measurements in the well; differential pressure across a device in the well; water content; oil-water ratio; gas-oil ratio; and oil-water ratio.
16. The method of claim 15 wherein the group further consists information relating to: micro-seismic measurements; pressure transient measurements; well log measurements; a measurement relating to presence of a chemical in the well that is one of scale, hydrate, corrosion, paraffin, and asphaltene.
17. The system of claim 12, wherein the computer program further comprises a set of instructions to: estimate an occurrence: cross flow condition; deterioration of a casing in the well; and deterioration of a device in the well; and
determine the new setting based on at least one such estimation.
18. The system of claim 12, wherein the computer program further comprises a set of instructions that uses a selected criterion to determine the new setting.
19. The system of claim 18, wherein the selected criterion includes at least one of: sand production is less than a selected amount; water content from a selected production zone is below a selected amount; a cross flow-condition is not present; deterioration of a device in the well is within selected limits; and ESP operation is within selected limits.
20. The system of claim 12, wherein the at least one new setting includes aplurality of: a change in position of the at least one device, a change in a chemical injection rate and a change in fluid flow rate from an artificial lift mechanism in the well.
The claims below are in addition to those above.
All refrences to claim(s) which appear below refer to the numbering after this setence.
1. A method comprising:
decoding, using a processor, machine-readable information encoded in each of a plurality of physical objects, wherein each instance of machine-readable information includes identifying information;
determining, using the processor, an order in which the encoded physical objects are presented for evaluation via the identifying information; and
comparing, using the processor, the order to a predetermined sequence to determine whether to allow access to a computerized system.
2. The method of claim 1, wherein access is granted to the computerized system when the order and the predetermined sequence coincide in an expected manner.
3. The method of claim 2, further comprising:
determining an orientation of at least one physical object utilizing at least some orientation information provided in encoded information; and
comparing the orientation information to a predetermined orientation to determine whether to allow access.
4. The method of claim 2, wherein the computerized system is remotely located relative to the processor.
5. The method of claim 3, wherein the computerized system is remotely located relative to the processor.
6. A non-transitory computer-readable medium, having instructions stored thereon, the instructions comprising:
instructions to decode machine-readable information encoded in each of a plurality of physical objects, wherein each instance of machine-readable information includes identifying information;
instructions to determine an order in which the encoded physical objects are presented for evaluation via the identifying information; and
instructions to compare the order to a predetermined sequence to determine whether to allow access to a remotely located computerized system.
7. The non-transitory computer-readable medium of claim 6, wherein the computerized system is remotely located relative to the non-transitory computer-readable medium.
8. The method of claim 1, wherein the machine-readable information encoded in each of the plurality of physical objects comprises digital watermarking.
9. An apparatus comprising:
an image or video sensor for capturing image or video data;
a processor configured to:
decode machine-readable information encoded in captured image or video data representing a plurality of physical objects, wherein each instance of machine-readable information includes identifying information;
determine an order in which the physical objects are presented to the image or video sensor for evaluation via the identifying information; and
compare the order to a predetermined sequence to determine whether to allow access to a computerized system.
10. A cell phone comprising the apparatus of claim 9.
11. The apparatus of claim 9, wherein access is granted to the computerized system when the order and the predetermined sequence coincide in an expected manner.
12. The apparatus of claim 9, wherein the processor is further configured to:
determine an orientation of at least one physical object utilizing at least some orientation information provided in encoded information; and
compare the orientation information to a predetermined orientation to determine whether to allow access.
13. The method of claim 1, wherein the computerized system is remotely located relative to the processor.
14. The apparatus of claim 9, wherein the computerized system is remotely located relative to the processor.
15. The cell phone of claim 10, wherein the computerized system is remotely located relative to the cell phone.
16. The apparatus of claim 11, wherein the computerized system is remotely located relative to the processor.
17. The apparatus of claim 12, wherein the computerized system is remotely located relative to the processor.
18. The apparatus of claim 9, wherein the machine-readable information encoded in the captured image or video data comprises digital watermarking.