BRIEF DESCRIPTION OF THE DRAWINGS
So that the above recited features and advantages of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to the embodiments thereof that are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.
FIG. 1 is a sectional schematic representation of a wellbore having a horizontal section that penetrates a producing formation, with the wellbore having a production tubing string therein that employs a temperature-perturbing means and a temperature sensor according to the present invention.
FIG. 2 is a sectional schematic representation of a wellbore having a vertical section that penetrates two producing formations or zones, with the wellbore having a production tubing string therein that employs a temperature-perturbing means and a temperature sensor according to the present invention.
FIG. 3 is a detailed representation of one embodiment of a temperature-perturbing means and a temperature sensor according to the present invention.
FIGS. 4A-4B are detailed sectional and isometric representations of a further embodiment of a temperature-perturbing means and a temperature sensor according to the present invention.
FIGS. 5A-5B are detailed sectional and isometric representations of a still further embodiment of a temperature-perturbing means and a temperature sensor according to the present invention.
FIG. 6 is a graphical correlation between temperature relaxation half-life and flowrate within a passage according to the present invention.
DETAILED DESCRIPTION OF THE INVENTION
FIG. 1 is a sectional schematic representation of one embodiment of the present invention for determining the mass flowrate of a fluid produced from a subsurface formation F and flowing upwardly through a production tubing string TS disposed in a wellbore W and terminating at a wellhead WH. The wellbore W is characterized by a substantially vertical section WV and at least one substantially horizontal section WH that penetrates a producing formation F, with the horizontal section WH being isolated from the vertical section WV by a packer assembly P.
As embodied in FIG. 1, an apparatus according to the present invention comprises a means (collectively referenced as 110, 111, 114) for perturbing the temperature of one or more locations L1, L2 of interest within the horizontal section WH of the wellbore W. The temperature perturbing means includes one or more temperature sinks 110 carried on the tubing string TS so as to be positionable at or near the respective locations of interest L1, L2. The temperature sink(s) (described in greater detail below in reference to FIG. 3) may comprise various applications of a heat sink or a cold sink (e.g., an adaptive heat exchanger), so as to induce a temperature perturbation at the respective locations of interest L1, L2.
In the embodiment of FIG. 1, the temperature-perturbing means is controllable from a surface system 111 that generates and controls the transmission of a cooling medium or a heating medium to the temperature sinks 110 so as to perturb the temperature of the respective locations of interest L1, L2 to a temperature other than the equilibrium temperature at the locations of interest. The temperature-perturbing means illustrated in FIG. 1 further comprises a conduit 114 through which the cooling medium or heating medium from the surface system 111 is transmitted to the temperatures sinks 110. Such a transmission conduit 114 may include two parallel branches in the shape of a U-tube, beginning and ending at the surface system 111. Accordingly, the surface system 111 is operable to transmit, as appropriate, either a cooling or heating medium (e.g., a gas or other fluid, or even electrical current in the case of heating) through the transmission conduit 114 to the temperature sinks 110, causing perturbation of the local temperatures at the respective locations of interest L1, L2 for a temporary period of time, after which the temperature perturbation is removed (as described further below).
The inventive apparatus embodied in FIG. 1 further comprises one or more temperature sensors 112 positionable at or near the locations of interest L1, L2. The temperature sensors 112 are connected for communication with surface control and recording electronics 118 by way of a communication link 116. The communication link 116 can take various forms, including a wired link and a wireless link, with the latter possibly including one or more of the following: a satellite connection, a radio connection, a connection through a main central router, a modem connection, a web-based or internet connection, a temporary connection, and/or a connection to a remote location such as the offices of an operator. The communication link 116 may enable real time or near-real time transmission of data or may enable time-lapsed transmission of data, as is required to permit a user to monitor the wellbore conditions and take necessary remedial action based on a diagnosis. The temperature sensors 112 may constitute a number of various sensor types that are known to those having ordinary skill in the art, such as resistance temperature detectors (RTDs) or thermocouple-based sensors, as well as fiber optic-based sensors.
In the case of fiber optic-based sensors, the communication link 116 constitutes a string of optical fibers and the surface electronics 118 constitutes an opto-electronic unit (including a light source and a light detector) and an appropriate processor/recorder as are known to those skilled in the art. Unlike the previously-known fiber optic applications (mentioned above) that relied on distributed temperature sensing, the sensors according to the present invention are adapted for a localized temperature determination at the locations of interest L1, L2. As is also known to those skilled in the art, in an optical fiber-based sensor solution the optical fibers may be routed between the surface electronics 118 and the sensor 112 via an appropriate conduit that may be attached to the tubing string TS via clamps or the like, and that constitutes part of the communication link 116. Such a routing conduit may include two parallel branches in the shape of a U-tube, beginning and ending at the surface electronics 118. Accordingly, the surface electronics 118 are operable to transmit optical pulses through the optical fibers in the communication link 116 to the fiber optic-based sensors 112, causing backscattered light signals to be returned from the sensors 112 that contains information representing the temperatures of both of the respective sensors 112.
In the embodiment of FIG. 1, the temperature sinks 110 and the temperature sensors 112 are shown as integrated within a single unit. It will be appreciated by those having ordinary skill in the art, however, that the temperature sensor(s) may be installed separately from the temperature sink(s) within the wellbore.
FIG. 2 is a sectional schematic representation of another embodiment of the present invention for determining the mass flowrate of a fluid produced through a production tubing string TS′ disposed in a wellbore W′ and terminating at a wellhead WH. The wellbore W′ is substantially vertical and penetrates a pair of producing zones or formations F1, F2, isolated from one another by a packer assembly P′.
As embodied in FIG. 2, an apparatus according to the present invention comprises a means (collectively referenced as 210, 211, 214) for perturbing the temperature of one or more locations L3 L4 of interest within the respective formations F1, F2 penetrated by the vertical wellbore W′. The temperature perturbing means includes one or more temperature sinks 210 carried on the tubing string TS′ so as to be positionable at or near the respective locations of interest L3, L4. As with the temperature sink(s) 110 described above, the temperature sinks 210 may comprise various applications of a heat sink or a cold sink (e.g., an adaptive heat exchanger), so as to induce a temperature perturbation at the respective locations of interest L3, L4.
In the embodiment of FIG. 2, the temperature-perturbing means is controllable from a surface system 211 that generates and controls the transmission of a cooling medium or a heating medium to the temperature sinks 210 so as to perturb the temperature of the respective locations of interest L3, L4 to a temperature other than the equilibrium temperature at the locations of interest. The temperature-perturbing means illustrated in FIG. 2 further comprises a conduit 214 through which the cooling medium or heating medium from the system 211 is transmitted to the temperatures sinks 210. Such a transmission conduit 214 may include two parallel branches in the shape of a U-tube, beginning and ending at the surface system 211. Accordingly, the surface system 211 is operable to transmit, as appropriate, either a cooling or heating medium (e.g., a gas or other fluid, or even electrical current in the case of heating) through the transmission conduit 214 to the temperature sinks 210, causing perturbation of the local temperatures at the respective locations of interest L3, L4 for a temporary period of time, after which the temperature perturbation is removed (as described further below).
The inventive apparatus embodied in FIG. 2 further comprises one or more temperature sensors 212 positionable at or near the locations of interest L3, L4. The temperature sensors 212 are connected for communication with surface control and recording electronics 218 by way of a communication link 216. As with communication link 116 described above, the communication link 216 can take various forms, including a wired link and a wireless link. The temperature sensors 212 may constitute a number of various sensor types that are known to those having ordinary skill in the art, such as RTD or thermocouple-based sensors, as well as fiber optic-based sensors.
In the case of fiber optic-based sensors, the communication link 216 constitutes a string of optical fibers and the surface electronics 218 constitutes an opto-electronic unit (including a light source and a light detector) and an appropriate processor/recorder as are known to those skilled in the art. Unlike the previously-known fiber optic applications (described above) that focused on distributed temperature sensing, the sensor 212 according to the present invention is adapted for a localized temperature determination at the locations of interest L3, L4. As is also known to those skilled in the art, the optical fibers may be routed between the surface electronics 218 and the sensor 212 via an appropriate conduit that may be attached to the tubing string TS′ via clamps or the like, and that constitutes part of the communication link 216. Such a routing conduit may include two parallel branches in the shape of a U-tube, beginning and ending at the surface electronics 218. Accordingly, the surface electronics 218 are operable to transmit optical pulses through the optical fibers in the communication link 216 to the fiber optic-based sensors 212, causing backscattered light signals to be returned from the sensors 212 that contains information representing the temperatures of both of the respective sensors 212.
In the embodiment of FIG. 2, the temperature sinks 210 and the temperature sensors 212 are shown as integrated within a single unit. It will be appreciated by those having ordinary skill in the art, however, that the temperature sensor(s) may be installed separately from the temperature sink(s) within the wellbore.
FIG. 3 is a detailed representation of a portion of the tubing string TS″ like the tubing strings TS and TS′ shown in FIGS. 1 and 2, respectively, equipped with one embodiment of a temperature-perturbing means and a temperature sensor according to the present invention. More particularly, one or more joints of the tubing string TS″ is equipped with a generally U-shaped transmission conduit 314 that includes a coiled portion wrapped around a reduced-diameter length of the tubing joint (preferably at a mandrel portion of the joint). Conduit 314 is characterized by a smaller diameter branch 314a for delivering a suitable cooling gas, such as nitrogen or carbon dioxide, downhole along the tubing string TS″, a larger diameter branch 314b for returning the transmitted cooling gas back to the surface, and a transition region 314c that undergoes an expansion from the smaller diameter of branch 314a to the larger diameter of branch 314b to effect a cooling of the transmitted gas in situ. Thus, in the embodiment depicted in FIG. 3, the temperature sink 310 resulting from the coils in larger diameter conduit branch 314b constitutes a heat sink for effecting a drop in the temperature of the location of interest L5, thereby inducing a temperature transient in accordance with the present invention. It will be appreciated by those having ordinary skill in the art that the gas flow could easily be reversed so as to transition from the larger diameter conduit branch 314b to the smaller diameter conduit branch 314a, thereby constituting a cold sink for effecting a rise in the temperature of the location of interest L5.
With reference again to FIG. 3, the illustrated joint of the tubing string TS″ is further equipped with a generally U-shaped, conduit for routing optical fibers therein between surface electronics (like electronics 118 and 218 described above with reference to FIGS. 1 and 2) and the location of interest L5, with the routing conduit constituting—along with the optical fibers—part of a communication link 316 that includes a coiled portion wrapped around the reduced-diameter length of the tubing joint. The optical fibers may be equipped with a fiber optic-based temperature sensor (not shown) that is deployed in the communication link 316 at or near the location of interest L5 for a purpose that will be described below. The temperature sensor may be a conventional sensor or a customized instrument having appropriate measurement performance, as will be apparent to those having ordinary skill in the art. The temperature sensor may be used with appropriate data acquisition and signal processing means, as are also known to those skilled in the art.
In the embodiment of FIG. 3 (as well as some others described herein), a temperature sensing conduit 316 and a temperature-perturbing conduit 314 are coiled together such that the two are in full contact with each other at the flowrate-determining location of interest L5. This promotes an efficient use of the cooling or heating medium that is transmitted via the temperature-perturbing conduit to effect a measurable temperature transient via the temperature-sensing conduit and its conveyed temperature sensor.
FIGS. 4A-4B are detailed sectional and isometric representations of a further embodiment of a temperature-perturbing means and a temperature sensor according to the present invention. Unlike the embodiments depicted in FIGS. 1-3, which were adapted for use with a tubing string typically having an opened end, the embodiment shown in these figures is adapted for use with a tubular “stinger” 420 having a closed conical end or nose 422. When so-equipped, the stinger 420 is adapted for placement within a wellbore W″ (shown as op hole, but could be cased and/or lined) so as to be immersed in the fluid flow stream. In other words, the fluid in the wellbore W″ will flow around the nose portion 422 and the stinger 420, rather than through the tubular joints that make up the stinger 420.
The stinger 420 is equipped with one embodiment of a temperature-perturbing means and a temperature sensor according to the present invention. More particularly, one or more joints of the stinger 420 is equipped with a generally U-shaped transmission conduit 414 that includes a coiled portion wrapped around a leading, reduced-diameter portion of the stinger 420. The conduit 414 (parallel branches thereof shown partially pulled away from the stinger in FIG. 4B for clarity) may be characterized by diameter changes like the conduit 314 of FIG. 3, but other known solutions for effecting a cooling or heating of a location of interest L6 may also be employed so as to induce a temperature transient in accordance with the present invention.
The illustrated portion of the stinger 420 is further equipped with a generally U-shaped, conduit (parallel branches thereof shown labeled as 416 and partially pulled away from the stinger in FIG. 4B for clarity) for routing optical fibers or other, known temperature sensing means therein between surface electronics (like electronics 118 and 218 described above with reference to FIGS. 1 and 2) and the location of interest L6, with the routing conduit constituting—with the optical fibers—part of a communication link 416. The optical fibers are equipped with a fiber optic-based temperature sensor that is deployed in the communication link 416 at or near the location of interest L6 for a purpose that will be described below.
FIGS. 5A-5B are detailed sectional and isometric representations of a still further embodiment of a temperature-perturbing means and a temperature sensor according to the present invention. This embodiment is very similar to that shown in FIGS. 4A-4B. Thus, one or more joints of the stinger 520 is equipped with a generally U-shaped transmission conduit 514 that includes a coiled portion wrapped around a leading, grooved portion of the stinger 520. The conduit 514 (parallel branches thereof shown partially pulled away from the stinger in FIG. 5B for clarity) may be characterized by diameter changes like the conduit 314 of FIG. 3, but other known solutions for effecting a cooling or heating of a location of interest L7 may also be employed so as to induce a temperature transient in accordance with the present invention.
The illustrated portion of the stinger 520 is further equipped with a generally U-shaped, conduit (parallel branches thereof shown labeled as 516 and partially pulled away from the stinger in FIG. 5B for clarity) for routing optical fibers or other, known temperature sensing means therein between surface electronics (like electronics 118 and 218 described above with reference to FIGS. 1 and 2) and the location of interest L7, with the routing conduit constituting—along with the optical fibers—part of a communication link 516. The optical fibers are equipped with a fiber optic-based temperature sensor that is deployed in the communication link 516 at or near the location of interest L7 for a purpose that will now be described.
The present invention provides, through various embodiments as described and suggested herein, a method for determining the flowrate of fluid flowing within a passage. As mentioned above, the present invention has particular application in which a fluid-flow passage is defined by a wellbore penetrating one or more subsurface earth strata. The fluid in such a passage may comprise at least one of oil, gas, water, and a combination thereof. The passage may be further defined by a conduit disposed in the wellbore, for example, by a conduit disposed in a portion of the wellbore that is substantially horizontal.
The flowrate-determining method comprises the step of measuring the equilibrium temperature of a location of interest within or proximate to the passage within which fluid flows. This may be achieved by a fiber-optic based solution as described above, but other solutions known to those having ordinary skill in the art may also be applied to advantage. Thus, for example, solutions involving the use of resistance temperature detectors (RTDs) or other thermocouple devices may be employed to measure the equilibrium temperature.
The present invention further includes the establishment of a temperature transient by perturbing the local temperature at the flowrate-determining location of interest. Accordingly, the temperature of the location of interest is pulsed or perturbed to a second temperature (other than its equilibrium temperature), and the temperature of the location of interest is then allowed to return to its equilibrium temperature. The temperature of the location of interest is monitored by the fiber-optic based sensor, or other temperature-monitoring means employed, as the temperature transitions between the second temperature and the equilibrium temperature.
As mentioned above, the temperature-perturbing step may be performed using a temperature sink, such as a heat sink (e.g., a cooled fluid) or a cold sink (e.g., a heated fluid or an electrical heater). The temperature sink may be either permanently installed (e.g., on production tubing) or inserted on a temporary carrier (e.g., a stinger), and may be substantially collocated with the temperature sensor. It will therefore be appreciated by those skilled in the art that it is not necessary to change the temperature of the fluid flowing through the passage to practice the inventive method, even though the local temperature at the location of interest experiences a transient.
The monitored temperature transition is then used to determine the flowrate of the fluid flowing within the passage, such as, for example, by correlating the monitored temperature transition to flowrate within the passage. One aspect of the present invention relates to the discovery that the time required for the temperature of the location of interest to transition halfway between the second temperature and the equilibrium temperature defines a temperature relaxation half-life that may be correlated to flowrate within the passage. In particular embodiments of the inventive method, interpretive models such as Computational Fluid Dynamics (CFD) models are employed to correlate the monitored temperature transition to flowrate within the passage.
FIG. 6 is a graphical representation of a linear correlation between temperature relaxation half-life and flowrate within a wellbore passage according to the present invention. The graph represents data monitored over a 15-second cooling transition between a perturbed temperature and an equilibrium temperature. The monitored data for linear regression (R2) is 0.9825, indicating that 98.25% of the variation of corresponding fluid flowrate is accounted for by the natural log temperature relaxation half-life (i.e., the monitored temperature delta and its time).
In the case of wellbore flow of a formation-produced fluid, the fluid's temperature is influenced by: (a) the temperature of the subsurface formation or zone from which the fluid is recovered; (b) the temperature of the subsurface formation or zone(s) through which the fluid passes before it encounters the temperature sensor of the invention; and (c) the time required for the fluid to reach the temperature sensor after it enters the wellbore bore. By using the temperature relaxation half-life to determine fluid flowrate, many of the local effects of the wellbore passage, including type and size of the wellbore, flowrate-determining location within the wellbore, characteristics of the specific produced fluid, among others that may complicate flowrate determination, are minimized or eliminated. Further benefits of such a correlation relate to its independence of how long the temperature perturbation (e.g., cooling fluid) is applied, to what magnitude the perturbation is applied (e.g., volume of cooling fluid), and even the effectiveness of the perturbation (e.g., cooling fluid thermal properties).
Empirical data have indicated that a mass flowrate can be accurately derived solely from a temperature relaxation correlation of the type that is shown in FIG. 6. Additional information may be derived if the temperature relaxation profile is analyzed using a more detailed, first-principles approach to the relaxation dynamics. For example, the inventive method may further be useful for determining the composition of two-phase and three-phase production fluids, including the oil/water and oil/water/gas ratios.
It will be further appreciated that the inventive method is useful for developing a production profile for a horizontal wellbore, showing the specific volume of oil production along the length of the horizontal wellbore bore. The inventive method is also similarly useful for determining the mass flow volume of produced oil from one or more specific producing formations or zones which are penetrated by a common wellbore.
It will be understood from the foregoing description that various modifications and changes may be made in the preferred and alternative embodiments of the present invention without departing from its true spirit.
This description is intended for purposes of illustration only and should not be construed in a limiting sense. The scope of this invention should be determined only by the language of the claims that follow. The term “comprising” within the claims is intended to mean “including at least” such that the recited listing of elements in a claim are an open set or group. Similarly, the terms “containing,” having,” and “including” are all intended to mean an open set or group of elements. “A,” “an” and other singular terms are intended to include the plural forms thereof unless specifically excluded.
Patent Application
20080023196
