Patent Grant
10294771
The invention relates to a production logging tool and a downhole fluid analysis probes deploying method. Such a production logging tool is used to analyze a multiphase fluid mixture flowing from a hydrocarbon bearing zone into a hydrocarbon well. Such a production logging tool is particularly adapted to a hydrocarbon well comprising from deviated well sections to horizontal well sections where multiphase fluid mixtures exhibit a large degree of segregation. Production logging tools typically operate in the harsh downhole environment of hydrocarbon wells at downhole pressure (typically in the range of one hundred to 2000 bars) and temperature (typically in the range of 50 to 200° C.) conditions, and in corrosive fluid.
During the production of a hydrocarbon well, it is necessary to monitor the relative volumetric flow rates of the different phases (e.g. oil, gas and water) of the multiphase fluid mixture flowing into the pipe of the well from the hydrocarbon bearing zones. Further, current hydrocarbon well often comprises vertical well section, deviated well sections and horizontal well sections. The interpretation of the flow in such complex wells is challenging because small changes in the well inclination and the flow regime influence the flow profile. Thus, an accurate monitoring requires sensors or probes capable of imaging a surface section or a volume section of the pipe and providing an estimation of the surface section or the volume section occupied by each phase.
Production logging of hydrocarbon wells (e.g. oil and gas wells) has numerous challenges related to the complexity of the multiphasic flow conditions and the severity of the downhole environment.
Gas, oil, water, mixtures flowing in wells, being either openhole or cased hole wells, will present bubbles, droplets, mist, segregated wavy, slugs structures depending on the relative proportions of phases, their velocities, densities, viscosities, as well as pipe dimensions and well deviations. In order to achieve a good understanding of the individual phases flowrates and determine the relative contributions of each zones along the well, an accurate mapping of fluids types and velocities is required on the whole section of the hole (openhole well portion) or pipe (cased well portion) at different depth (i.e. the measured depth is different from the true vertical depth and generally longer than true vertical depth, due to intentional or unintentional curves in the well).
Further, production issues greatly vary depending on reservoir types and well characteristics resulting in the need for a flexible production logging technology working with different types of sensing physics. For example, due to the phases segregation, deviated wells showing high water cuts require an accurate detection of thin oil layer at the top of the pipe. The effect of well inclination will have a strong impact on velocities and holdups.
Furthermore, high pressure, up to 2000 bars, high temperature, up to 200° C., corrosive fluid (H2S, CO2) put constraints on sensors and tool mechanics.
Furthermore, solids presence in flowing streams can damage equipments. In particular, the sand entrained from reservoir rocks will erode parts facing the fluid flow. Solids precipitated from produced fluids due to pressure and temperature changes, such as asphaltenes, paraffins or scales create deposits contaminating sensors and/or blocking moving parts (e.g. spinners).
Furthermore, the tool deployment into the well can be difficult and risky. In highly deviated or horizontal wells, tools must be pushed along the pipe using coiled tubing or pulled using tractor which is difficult when tools are long and heavy. Pipes may be damaged by corrosion or rock stress which may create restrictions and other obstacles. During the logging operation, equipments can be submitted to high shocks. Thus, in such environments, it is highly preferable to have light and compact tools.
Furthermore, the cost is also an important parameter in order to provide an economically viable solution to well performance evaluation even in mature fields having low producing wells in process of depletion with critical water production problems.
With respect to the hereinbefore described challenges, the state of the art production logging equipments have limitations.
Certain production logging tools available on the market have limited or no pipe section imaging capabilities and work correctly only in near vertical wells. These tools use a gradiomanometer and/or capacitance sensor to identify fluid entries. Further, these tools use spinner rpm and insitu calibration data to compute holdups and flowrates.
Other production logging tools available on the market are intended to identify fluid types from local probe sensors (electrical or optical) and to compute the fluid velocities from miniaturized spinners. Some of these production logging tools comprise probes attached to the centralizer arms creating a two dimensional (2D) array of local measurements. Achieving sufficient coverage requires a large number of arms/probes which leads to complex and expensive designs, tool maintenance is complex and reliability is poor. In addition, the measurements on different phases are made at different positions on a long tool string resulting in interpretation issues. Another production logging tool comprises a one dimensional (1D) array of sensors attached to a moving arm providing a scan of measurements along one line of the pipe section. Thus, the measurements coverage is limited and, depending on tool position, some production zone may be missed. The operation of such complex and costly tools results in important deployment difficulties that render compulsory the presence of highly trained engineering teams on the field.
Other attempts have been made to develop tools with rotating arms in order to improve coverage. The documents U.S. Pat. Nos. 5,531,112 and 5,631,413 describe a production logging tool for use within a well to determine fluid holdup of a multiphase fluid flow within the well. The production logging tool includes a plurality of sensors secured within a plurality of arms which radially extend from a tool housing to points distal from the tool housing. A plurality of sensors are included within the plurality of arms for detecting variations in fluid properties attributable to different flow constituents of the multiphase fluid flow along a path which circumscribes an exterior of the tool housing. The plurality of arms are rotated about the tool housing for moving these sensors through the path in order to ensure that the volumetric proportions of the different flow constituents of the multiphase fluid flow are accurately detected in highly deviated and in horizontal wells. Such production logging tools are complex apparatuses. Their reliability is problematic when taking into account the harsh downhole environment of hydrocarbon wells. In particular, the difficulty of operating motor/shafts mechanics under high pressure and complexity of rotating electrical connections kept such development at prototype level and technology has never been commercialized.
It is an object of the invention to propose a production logging tool that overcomes one or more of the limitations of the existing apparatus, in particular that is structurally simple and reliable to operate whatever the downhole conditions.
According to one aspect, there is provided a production logging tool to analyze at least one property of a multiphase fluid mixture flowing in a hydrocarbon well having an elongated cylindrical body shape and comprising a central pressure-resistant rigid housing carrying a centralizer arrangement comprising multiple external centralizer arms circumferentially distributed about said housing and adapted for contact with a production pipe wall of a hydrocarbon well and operable from a retracted configuration into a radially extended configuration, the centralizer arms being coupled at a first side to the body and at a second side to a first sliding sleeve and a spring, wherein the production logging tool further comprises a deploying arrangement nested within the centralizer arrangement, the deploying arrangement comprising:
At least one other downhole fluid properties analysis probe may be secured on an inner or lateral face of each centralizer arm such as to expose a tip of said other probe to the multiphase fluid mixture flowing in the hydrocarbon well.
The centralizer arrangement is arranged to radially and/or angularly position the tip of said, at least one, probe associated with each centralizer arm in a second circumferential zone of the hydrocarbon well section substantially perpendicular to the longitudinal axis of the well.
The first and second circumferential zone may be confused.
A spring may be positioned between the second sliding sleeve and the body at the first side of the deploying arrangement.
The first sliding sleeve and the second sliding sleeve may be supported by a stem of the central pressure-resistant rigid housing, the stem comprising a longitudinal or an helical guiding slot cooperating with a radial pin of the second sliding sleeve.
Each deploying arm of the deploying arrangement may comprise an extension part, a length of the extension part defining a radial extension of the tip of the downhole fluid properties analysis probe carried by the deploying arm.
The deploying arrangement may comprise at least four centralizer arms and at least four deploying arms, each deploying arm being nested in-between two adjacent centralizer arms.
Two downhole fluid properties analysis probes may be secured on lateral faces of each deploying arm.
Two downhole fluid properties analysis probes may be secured on lateral faces or on one inner face and one lateral face of each centralizer arm.
Said, at least one, probe associated with the centralizer arms may be connected to an electronic module located into a first housing part, said, at least one, other probe associated with the deploying arms may be connected to another electronic module located into a second housing part, a protective tube extending from each electronic module to the tip along the respective arm through a pressure feedthrough of said respective housing part.
According to a further aspect, there is provided a method of deploying downhole fluid analysis probes in a hydrocarbon well in which a multiphase fluid flows, comprising the steps of:
The deploying method may further comprise providing at least one downhole fluid analysis probe carried on each centralizer arm and deploying said downhole fluid analysis probes in a second circumferential zone of a hydrocarbon well section substantially perpendicular to a longitudinal axis of said well.
Said probes carried by deploying arms and said probes carried by centralizer arms are positioned, when deployed, in the same plane perpendicular to a longitudinal axis of the well.
According to a still further aspect, there is provided an apparatus for deploying in a hydrocarbon well a plurality of probes for analyzing at least one property of a multiphase fluid mixture flowing in the hydrocarbon well, having an elongated cylindrical housing shape and comprising a central pressure-resistant rigid housing carrying a centralizer arrangement comprising multiple external centralizer arms circumferentially distributed about said housing and adapted for contact with a production pipe wall of a hydrocarbon well and operable from a retracted configuration into a radially extended configuration, the centralizer arms being coupled at a first side to the housing and at a second side to a first sliding sleeve and a first spring, wherein the apparatus further comprises a deploying arrangement nested within the centralizer arrangement, the deploying arrangement comprising:
The production logging tool of the invention has a simple and compact structure achieving low cost, easy operation and maintenance.
Other advantages will become apparent from the hereinafter description of the invention.
The present invention is illustrated by way of examples and not limited to the accompanying drawings, in which like references indicate similar elements:
The production logging tool 1 has an elongated cylindrical body shape and comprises a central pressure-resistant rigid housing 10 carrying a centralizer arrangement 11 and a deploying arrangement 30. The production logging tool 1 extends longitudinally about the longitudinal axis XX′. The centralizer arrangement 11 substantially centers the production logging tool 1 with respect to the well bore axis YY′ (see
The central pressure-resistant rigid housing 10 comprises, at one end, a first housing part 12 including a master and telemetry electronic module 60 and probe electronic modules 61, at another end, a second housing part 13 that may include another master and telemetry electronic module 62 and other probe electronic modules 63, and, centrally, a stem 14 under the form of an elongated, reduced diameter, hollow tube connecting the first and second housing parts 12, 13. As an example, the stem 14 may be connected to the housing parts 12, 13 by welding or a threaded connection. Both first and second housing part 12, 13 may be fitted with a corresponding pin connector 64, 65 connected to the corresponding master and telemetry electronic module 60, 62, respectively. The different arrows 66 schematically illustrate either connections, or data transfer or power transfer between various electronic components. The master and telemetry electronic module 60 may comprise accelerometer and gyrometer sensors which allow the measurement of tool inclination and relative bearing and, consequently, positions of downhole fluid properties analysis probes (general references 50 and 55 thereafter) within the well section with respect to top and bottom.
The centralizer arrangement 11 comprises articulated centralizer arms 15, 16 and associated bows 17. The bows 17 are positioned externally with respect to the articulated centralizer arms 15, 16 and to the stem 14 and enter into contacting engagement with the well bore wall or the production pipe wall 6 of the hydrocarbon well 2. In particular the bows 17 are adapted for a smooth and low frictional drag contact with such walls. Each articulated centralizer arm includes a first arm part 15 and a second arm part 16 coupled together by an appropriate pivot connection, e.g. a hinge 18 at one of their ends. The first centralizer arm part 15 and the second centralizer arm part 16 may be identical. The centralizer arms 15, 16 and bows 17 are coupled at a first side to the first housing part 12 of the housing 10 by respective pivot connection, e.g. hinges 19, 20 and at a second side to a first sliding sleeve 21 by respective pivot connection, e.g. hinges 22, 23. The first sliding sleeve 21 can slide on the stem 14. As an example, the present embodiment comprises a centralizer arrangement 11 including four centralizer arms 15A, 16A, 15B, 16B, 15C, 16C, 15D, 16D and their respective bows 17A, 17B, 17C, 17D (see
The centralizer arrangement 11 operates as follows. The first coil spring 24 exerts an axial force substantially along the longitudinal axis XX′ of the production logging tool 1. The axial forces acts onto the first sliding sleeve 21 that slide onto the stem 14. Thus, the first coil spring 24 causes radial forces that acts on the articulated centralizer arms 15, 16 and associated bows 17 urging them to move radially outwardly toward the well bore wall or the production pipe wall 6 until an outmost extended position corresponding to the bows 17 being urged into engagement with the surface of the wall 6. When the production logging tool 1 is run into a hydrocarbon well 2 having diameter that changes, in particular through restriction of smaller diameter, the wall 6 acts on the articulated centralizer arms 15, 16 and associated bows 17 that are urged to move radially inwardly towards the stem 14. This causes an inwardly oriented axial force acting onto the first sliding sleeve 21 that slide onto the stem 14 in the other direction compressing the first coil spring 24. In an extreme configuration, the articulated centralizer arms 15, 16 and associated bows 17 may be fully retracted such as being parallel to the stem 14, lying on the stem circumference surface, flush with the external surface of the first and second housing parts 12, 13.
According to the present exemplary embodiment, each centralizer arm may further comprise at least one, for example two, downhole fluid properties analysis probe 50, 50A, 50B, 50C, 50D, 50E, 50F, 50G, 50H secured on an internal side (the inner face facing the stem 14) or on a lateral side of the first centralizer arm part 15, 15A, 15B, 15C, 15D such as to expose a tip 51 of said probe 50 to the multiphase fluid mixture flowing in the hydrocarbon well, and at the same time protect the tip 51 from a direct harmful contact with the wall 6 by means of the bows 17, 17A, 17B, 17C, 17D. Probe attachments 75 at the side of centralizer arms allows positioning the probe tips close to the center of the bow spring in contact with the well bore or pipe 6 and therefore allows measuring fluid properties close to the wall while being protected from direct contact to the wall by the centralizer arm structure. This configuration allows reducing damage risks on the probes during logging and/or deployment. In the description, a downhole fluid properties analysis probe 50, 50A-50H respectively 55, 55A-55H may be understood as a set including a probe electronic module 61 respectively 63, a pressure feed-through 53, a protective tube 52 and a tip 51. The probe electronic module 61 connected to the associated probe 50 is located in the first housing part 12. A protective tube 52 enclosing a link extends from the electronic module 61 to the tip 51 through a pressure feedthrough 53 into said housing 12. The downhole fluid properties analysis probe 50 may be of any type, namely mechanical, magnetic, optical, electrical, ultrasonic, spinner or mini-spinner, etc responsive to various physical entities like pressure, temperature, density, viscosity, conductivity, refractive index, fluid velocity, gas bubble and oil droplet counts and holdups, fluorescence, spectroscopic absorption, etc
The production logging tool 1 further comprises a deploying arrangement 30 nested within the centralizer arrangement 11. The deploying arrangement 30 comprises articulated deploying arms 31, 32. Each articulated deploying arm includes a first arm part 31 and a second arm part 32 coupled together by an appropriate pivot connection, e.g. a hinge 33 at one of their ends. The first deploying arm part 31 may be longer than the second deploying arm part 32. In particular, the first deploying arm part 31 comprises an extension part 38 above the hinge 33. The deploying arms 31, 32 are coupled at a first side to a supporting member 34 of the stem 14 by a pivot connection, e.g. a hinge 35 and at a second side to a second sliding sleeve 36 by a pivot connection, e.g. a hinge 37. As an example, the present embodiment comprises a deploying arrangement 30 including four deploying arms 31A, 32A, 31B, 32B, 31C, 32C, 31D, 32D. The four deploying arms are spaced apart circumferentially about the longitudinal axis XX′ of the production logging tool 1. The four deploying arms may be identical and equally spaced on the circumference. Each deploying arm 31A, 32A, 31B, 32B, 31C, 32C, 31D, 32D is positioned in a middle position between two centralizer arms 15A, 16A, 15B, 16B, 15C, 16C, 15D, 16D such that each deploying arm and centralizer arm can move free of obstruction from the stem 14 towards the wall 6 and vice-versa. The first sliding sleeve 21 is prevented from rotation by using a radial pin (not shown) extending inwardly and arranged to slide inside a longitudinal slot 73 (parallel to the longitudinal axis XX′) machined on the outer surface of the stem 14 (visible in
Each deploying arm comprises at least one, for example two, downhole fluid properties analysis probe 55, 55A, 55B, 55C, 55D, 55E, 55F, 55G, 55H secured on the extension part 38 of the first deploying arm part 31. Said probes 55, 55A-55H are similar to the one described in relation with the centralizer arrangement except that the electronic module 63 connected to the associated probe 55 is located in the second housing part 13. The downhole fluid properties analysis probes 55, 55A, 55B, 55C, 55D are then positioned in-between the deploying arrangement 30 and the centralizer arrangement 11. As the deploying arrangement 30 is nested within the centralizer arrangement 11, this enables exposing the tip 51 of the probe 55 to the multiphase fluid mixture flowing in the hydrocarbon well with a robust control of its radial and angular position therefore protecting the tip 51 from a direct harmful contact with the wall 6 or other components of the centralizer arrangement 11. Probe attachments 75 are secured on deploying arms allowing reducing damage risks during logging and/or deployment.
As depicted in
The second sliding sleeve 36 associated with the stem 14 forms a radial and/or rotational deploying means for radially and/or angularly positioning the tips 51 of the downhole fluid properties analysis probes 55, 55A, 55B, 55C, 55D, 55E, 55F, 55G, 55H associated with each deploying arm 31 within a circumferential zone CZ of the hydrocarbon well section, preferably close to the pipe or bore wall 6 (see
Thus, according to the embodiment depicted in
Therefore, the production logging tool 1 comprises a first set of downhole fluid properties analysis probes 50, 50A-50H associated with the centralizer arrangement 11 and extending from one end of the tool (i.e. from the first housing part 12), and a second set of downhole fluid properties analysis probes 55, 55A-55H associated with the deploying arrangement 30 and extending from the other end of the tool (i.e. from the second housing part 13). The measuring points (also corresponding to the black dots visible in
However, the radial extension of the probes (the radial position R of the probe tip) carried by the deploying arrangement 30 may also be adjusted by adjusting the length of the extension part 38. For example, it may be adjusted to define a radial extension lower than that of the centralizer arrangement 11. Thus, the measuring points associated to each downhole fluid properties analysis probe may be substantially positioned in a similar plane (or close planes) perpendicular to the well bore axis YY′ but in different circumferential zones CZ1 and CZ2 of the hydrocarbon well section as depicted in
In addition, the production logging tool 1 may rotate about its axis under the effect of the friction of the bows of the centralizer arrangement 11 on the wall of the well or pipe. This may result in sweeping the circumferential zones (CZ respectively CZ1 and CZ2) of the well section in a random manner.
In a particular tool configuration, the probes 55A, 55C, 55E, 55G are conductivity probes measuring water holdup; the probes 55B, 55D, 55F, 55H are optical probes measuring gas holdup; the probes 50A, 50C, 50E, 50G are fluorescence probes measuring oil holdup; and the probes 50B, 50D, 50F, 50H are mini-spinner probe measuring fluid velocity.
In another tool configuration, the probes 55A, 55B, 55C, 55D, 55E, 55F, 55G, 55H are three phase optical probes measuring gas-oil-water holdups; the probes 50A, 50B, 50C, 50D, 50E, 50F, 50G, 50H are ultrasonic doppler probe measuring fluid velocity.
With the production logging tool of the invention, it is possible to achieve:
The production logging tool structure of the invention is simple, compact achieving low cost and easy operation and maintenance.
The design is based on a 2D array of probes which can be displaced radially and angularly in order to cover the circumference of the pipe.
The probe deployment is secured by the tool centralizer arrangement allowing reducing damage risks during logging and allowing measurements up to the pipe wall.
It should be appreciated that embodiments of the production logging tool according to the present invention are not limited to the embodiment showing horizontal hydrocarbon well bore, the invention being also applicable whatever the configuration of the well bore, namely vertical, deviated or a succession of vertical, deviated and/or horizontal portions, cased or uncased. Also, the deploying apparatus of the invention is not limited to an application into a production logging tool, but can be easily adapted to various applications into analysis tools operating at downhole pressure and temperature conditions, e.g. a downhole fluid analysis tool, a wireline tool, a formation tester.
| Number | Date | Country | Kind |
|---|---|---|---|
| 16177670 | Jul 2016 | EP | regional |
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| Number | Date | Country | |
|---|---|---|---|
| 20180003027 A1 | Jan 2018 | US |
