Method and system for monitoring smart structures utilizing distributed optical sensors

• US 6,913,079 B2
• Filed: 06/26/2001
• Issued: 07/05/2005
• Est. Priority Date: 06/29/2000
• Status: Expired due to Term

• Current Assignee: Ziebel (Us), Inc.
• Original Assignee: Tube Technology, Inc.
• Inventors: Tubel, Paulo S.
• Primary Examiner(s): Bagnell, David
• Assistant Examiner(s): Bomar, Shane
• Application Number:
  US10/312,235
• Publication Number:
  US 20030094281A1
• Time in Patent Office: 1,470 Days
• Field of Search: 356/72, 356/326, 356/328, 356/301, 250/256, 731/523.9, 731/525.4, 166/250.01, 114/382, 246/1.R, 246/1.C, 246/120
• US Class Current: 166/250.01
• CPC Class Codes: E21B 41/0099 specially adapted for drilling for or production of natural hydrate or clathrate gas reservoirs; Drilling through or monitoring of formations containing gas hydrates or clathrates
• CPC Class Codes: E21B 47/114 using light radiation
• CPC Class Codes: E21B 47/135 using light waves, e.g. infrared or ultraviolet waves
• CPC Class Codes: G01N 21/774 the reagent being on a grating or periodic structure
• CPC Class Codes: G01V 2210/647 Gas hydrates
• CPC Class Codes: G01V 8/16 using optical fibres

Abstract

A monitoring system and method for monitoring a predetermined set of physical characteristics associated with a structure using the monitoring system. The system is distributed in the structure and comprises a distributed optical sensing device (30), further comprising a fiber optic cable (20, 22); a light source (18a) operatively in communication with the fiber optic cable (20, 22); a light detection device (18b), operatively in communication with the fiber optic cable (20, 22), for measuring the light received at the light detection device (18b) from the fiber optic cable (20, 22); and a data processor (18) capable of using the light measured to calculate a predetermined set of physical parameters describing the predetermined set of physical characteristics.

Claims

1. A system for monitoring physical parameters distributed in a structure, comprising:

a. a distributed optical sensing device (30), comprising a fiber optic cable (20,22), deployed proximate a predetermined structure, the fiber optic cable (20,22) being encapsulated in a jacket;

b. a light source (18a) operatively in communication with the fiber optic cable (20,22);

c. a light detection device (18b), operatively in communication with the fiber optic cable (20,22), for measuring the light received at the light detection device (18b) from the fiber optic cable (20,22); and

d. a data processor (18) operatively connected to the light detection device (18b);

e. wherein;

(i) the data processor (18) uses light measured at the light detection device (18b) to calculate a desired physical parameter distributed in the structure;

(ii) the structure is a downhole structure comprising at least one of (a) a wellbore (10), (b) production tubing, (b) casing (12), and (d) non-production tubing;

(iii) the physical parameter comprises parameters of at least one of (a) the wellbore (10), (b) production tubing, (c) non-production tubing, (d) a geological formation, and (e) casing (12); and

(iv) the distributed optical sensing device (30) is integrated within a downhole component deployed permanently or temporarily in the wellbore (10) to measure at least one of (a) a physical parameter of the well, (b) drilling of and production from the well, or (c) geological formation parameters.

2. The system of claim 1 wherein at least one fiber optic cable (20,22) comprises fiber optic cable (20,22) optimized for use undersea and capable of measuring physical parameters over a predetermined portion of a length of the fiber optic cable (20,22).

3. The system of claim 2 wherein the fiber optic cable (20,22) is deployed undersea.

4. The system of claim 3 wherein the physical parameters comprise predetermined physical characteristics of methane hydrate.

5. A method for monitoring a predetermined set of physical characteristics associated with a structure or a process involving the structure, for a monitoring system, distributed in the structure, the method comprising:

a. deploying a distributed optical sensing device (30) proximate a structure;

b. providing light to the distributed optical sensing device (30) from a light source (18a);

c. providing continuous light from a source of continuous light;

d. providing pulsed light from a pulsed light probe beam;

e. measuring light from the distributed optical sensing device (30) incident at a light detection device (18b) with the light detection device (18b);

f. using a data processor (18) to substantially simultaneously obtain and continuously monitor a plurality of measurements from the distributed optical sensing device (30) at a plurality of locations along the distributed optical sensing device (30) using the measured light incident at the light detection device (18b);

g. determining Brillouin loss;

h. using the Brillouin loss to obtain the desired physical parameter measurements; and

i. calculating a predetermined set of physical characteristics for a desired physical parameter using the plurality of measurements.

6. The method of claim 5 further comprising:

i. stepping the continuous light source and the pulsed light probe beam through a range of frequencies around an anticipated Brillouin frequency and measuring power loss at each frequency;

ii. determining a Brillouin shift at a frequency where a highest power loss is encountered; and

iii. determining a desired physical parameter measurement by using a predetermined relationship between power loss and desired signal amplitude.

7. The method of claim 5, further comprising monitoring construction processes of the structure wherein step (e) further comprises calculating a progression of the construction of the structure using the one or more desired physical parameters.

8. The method of claim 5, wherein the structure is a downhole structure, further comprising:

a. deploying the distributed optical sensing device (30) in the downhole structure in conjunction with a drilling, production, or fishing apparatus; and

b. obtaining measurements using the distributed optical sensing device (30), the measurements comprising measurements of;

i. parameters comprising borehole and geological parameters as a drilling or hydrocarbon production apparatus traverses formations during construction of a wellbore (10) wherein the borehole and geological parameters comprise pressures of formations through which the borehole proceeds and temperature of the formations;

ii. production of fluids from formations in the wellbore (10) wherein the parameters comprise pressures of the formations and temperature of the formations;

iii. strain on drilling pipe deployed in the structure;

iv. parameters calculated from data obtained while drilling wherein noise created by a drilling process or external acoustic source located at a remote location generates an acoustic signal capable of traveling through geological formations proximate the structure, the noise being detected by the fiber optic cable (20,22) as the light from the light source (18a) travels through the fiber optic cable (20,22) by using reflected phonos or photons to determine information related to temperature, strain, pressure, and acoustic disturbances;

v. corrosion of casing (12) or tubing deployed within the structure;

vi. parameters comprising production parameters required to optimize production in intelligent wells;

vii. parameters comprising production and physical parameters in laterals to determine optimum parameters, the optimum parameters further comprising pressure and flow, useful for production of hydrocarbons;

viii. parameters comprising production and physical parameters in laterals to monitor production in the laterals where at least one lateral is divided in multiple zones isolated by downhole hardware including Intelligent Completion Systems;

ix. parameters obtained from data measurements in abandoned wells useful to determine presence of leaks within formations in the well;

x. parameters obtained from data measurements in wells useful to monitor compaction and subsidence of formations through which the structure passes;

xi. parameters obtained from data measurements during artificial lift applications, the parameters comprising pressure, strain, flow, fluid identification, and temperature, the parameters useful to optimize production in gas lift, rod pump, progressive cavity pump, and electrical submersible pump applications;

xii. parameters obtained from data measurements in injector wells to monitor movement of injected fluid or steam into the structure to assure that injected fluid reaches its proper destination in the structure;

xiii. parameters obtained from data measurements in geothermal wells, the parameters comprising pressure, strain, and temperature; and

xiv. parameters obtained from data measurements in multilateral wells comprising laterals wherein each lateral is monitored.

9. The method of claim 5 wherein the distributed optical sensing device (30) is deployed on a seabed to monitor a desired set of physical characteristics of the seabed, the set of physical characteristics comprising movement of the seabed, temperature of the seabed, and predetermined characteristics of methane hydrate present proximate the seabed useful in evaluating methane hydrate stability subsea.

10. The method of claim 5, wherein the structure is a downhole structure, further comprising:

a. deploying the distributed optical sensing device (30) in the downhole structure in conjunction with a drilling, production, or fishing apparatus; and

b. obtaining measurements using the distributed optical sensing device (30), the measurements comprising measurements of at least one of;

i. parameters comprising borehole and geological parameters as a drilling or hydrocarbon production apparatus traverses formations during construction of a wellbore (10) wherein the borehole and geological parameters comprise pressures of formations through which the borehole proceeds and temperature of the formations;

ii. production of fluids from formations in the wellbore (10) wherein the parameters comprise pressures of the formations and temperature of the formations;

iii. strain on drilling pipe deployed in the structure;

iv. parameters calculated from data obtained while drilling wherein noise created by a drilling process or external acoustic source located at a remote location generates an acoustic signal capable of traveling through geological formations proximate the structure, the noise being detected by the fiber optic cable (20,22) as the light from the light source (18a) travels through the fiber optic cable (20,22) by using reflected photons to determine information related to temperature, strain, pressure, and acoustic disturbances;

v. corrosion of casing (12) or tubing deployed within the structure;

vi. parameters comprising production parameters required to optimize production in intelligent wells;

vii. parameters comprising production and physical parameters in laterals to determine optimum parameters, the optimum parameters further comprising pressure and flow, useful for production of hydrocarbons;

viii. parameters comprising production and physical parameters in laterals to monitor production in the laterals where at least one lateral is divided in multiple zones isolated by downhole hardware including Intelligent Completion Systems;

ix. parameters obtained from data measurements in abandoned wells useful to determine presence of leaks within formations in the well;

x. parameters obtained from data measurements in wells useful to monitor compaction and subsidence of formations through which the structure passes;

xi. parameters obtained from data measurements during artificial lift applications, the parameters comprising pressure, strain, flow, fluid identification, and temperature, the parameters useful to optimize production in gas lift, rod pump, progressive cavity pump, and electrical submersible pump applications;

xii. parameters obtained from data measurements in injector wells to monitor movement of injected fluid or steam into the structure to assure that injected fluid reaches its proper destination in the structure;

xiii. parameters obtained from data measurements in geothermal wells, the parameters comprising pressure, strain, and temperature;

or

xiv. parameters obtained from data measurements in multilateral wells comprising laterals wherein each lateral is monitored.