WO2015065387A1 - Système de surveillance de puits abandonné - Google Patents
Système de surveillance de puits abandonné Download PDFInfo
- Publication number
- WO2015065387A1 WO2015065387A1 PCT/US2013/067551 US2013067551W WO2015065387A1 WO 2015065387 A1 WO2015065387 A1 WO 2015065387A1 US 2013067551 W US2013067551 W US 2013067551W WO 2015065387 A1 WO2015065387 A1 WO 2015065387A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- wellbore
- isolation
- downhole
- mandrel
- assembly
- Prior art date
Links
- 238000012544 monitoring process Methods 0.000 title claims abstract description 50
- 238000000034 method Methods 0.000 claims abstract description 90
- 238000002955 isolation Methods 0.000 claims abstract description 51
- 238000007789 sealing Methods 0.000 claims abstract description 39
- 230000007613 environmental effect Effects 0.000 claims abstract description 18
- 239000012530 fluid Substances 0.000 claims description 18
- 230000015572 biosynthetic process Effects 0.000 claims description 16
- 230000000712 assembly Effects 0.000 claims description 14
- 238000000429 assembly Methods 0.000 claims description 14
- 230000003213 activating effect Effects 0.000 claims description 12
- 230000005540 biological transmission Effects 0.000 claims description 12
- 230000003287 optical effect Effects 0.000 claims description 6
- 239000010453 quartz Substances 0.000 claims description 6
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 6
- 238000011065 in-situ storage Methods 0.000 claims description 4
- 238000005259 measurement Methods 0.000 abstract description 5
- 239000000463 material Substances 0.000 description 18
- 230000004888 barrier function Effects 0.000 description 10
- 239000004568 cement Substances 0.000 description 8
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 6
- 238000005553 drilling Methods 0.000 description 6
- 239000000835 fiber Substances 0.000 description 6
- 238000002347 injection Methods 0.000 description 6
- 239000007924 injection Substances 0.000 description 6
- 230000007774 longterm Effects 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 6
- 230000008961 swelling Effects 0.000 description 6
- 241000191291 Abies alba Species 0.000 description 4
- KAKZBPTYRLMSJV-UHFFFAOYSA-N Butadiene Chemical compound C=CC=C KAKZBPTYRLMSJV-UHFFFAOYSA-N 0.000 description 4
- RRHGJUQNOFWUDK-UHFFFAOYSA-N Isoprene Chemical compound CC(=C)C=C RRHGJUQNOFWUDK-UHFFFAOYSA-N 0.000 description 4
- XUIMIQQOPSSXEZ-UHFFFAOYSA-N Silicon Chemical class [Si] XUIMIQQOPSSXEZ-UHFFFAOYSA-N 0.000 description 4
- 125000000484 butyl group Chemical class [H]C([*])([H])C([H])([H])C([H])([H])C([H])([H])[H] 0.000 description 4
- 229930195733 hydrocarbon Natural products 0.000 description 4
- 150000002430 hydrocarbons Chemical class 0.000 description 4
- 238000012986 modification Methods 0.000 description 4
- 230000004048 modification Effects 0.000 description 4
- 150000002825 nitriles Chemical class 0.000 description 4
- 229920002635 polyurethane Chemical class 0.000 description 4
- 239000004814 polyurethane Chemical class 0.000 description 4
- 238000005086 pumping Methods 0.000 description 4
- 229910052710 silicon Chemical class 0.000 description 4
- 239000010703 silicon Chemical class 0.000 description 4
- 238000011144 upstream manufacturing Methods 0.000 description 4
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 4
- 229920002943 EPDM rubber Polymers 0.000 description 2
- 230000009471 action Effects 0.000 description 2
- 230000004913 activation Effects 0.000 description 2
- 238000004891 communication Methods 0.000 description 2
- 230000009977 dual effect Effects 0.000 description 2
- HQQADJVZYDDRJT-UHFFFAOYSA-N ethene;prop-1-ene Chemical group C=C.CC=C HQQADJVZYDDRJT-UHFFFAOYSA-N 0.000 description 2
- 238000007667 floating Methods 0.000 description 2
- NBVXSUQYWXRMNV-UHFFFAOYSA-N fluoromethane Chemical compound FC NBVXSUQYWXRMNV-UHFFFAOYSA-N 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 229920001084 poly(chloroprene) Chemical class 0.000 description 2
- 229920000642 polymer Polymers 0.000 description 2
- 239000011253 protective coating Substances 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 230000031070 response to heat Effects 0.000 description 2
- 229910001220 stainless steel Inorganic materials 0.000 description 2
- 239000010935 stainless steel Substances 0.000 description 2
- 238000003860 storage Methods 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 238000010200 validation analysis Methods 0.000 description 2
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/127—Packers; Plugs with inflatable sleeve
- E21B33/1277—Packers; Plugs with inflatable sleeve characterised by the construction or fixation of the sleeve
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
- E21B47/07—Temperature
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
Definitions
- the present invention relates generally to operations performed and equipment utilized in conjunction with a subterranean well and, in an embodiment described herein, more particularly provides methods and apparatus for monitoring abandoned wellbores.
- FIG. 1 is a schematic of an abandoned well monitoring system positioned in a wellbore according to an embodiment of the disclosure
- FIGS. 2A-B are schematic elevational and end views of the mandrel assembly according to an aspect of the disclosure.
- FIG. 3 is a schematic of an abandoned well monitoring system utilizing multiple mandrel assemblies and instrument tools positioned in a multi-zone wellbore according to an embodiment of the disclosure.
- Upstream, uphole, downstream and downhole are used to indicate location or direction in relation to the surface, where upstream indicates relative position or movement towards the surface along the wellbore and downstream indicates relative position or movement further away from the surface along the wellbore, unless otherwise indicated.
- FIG. 1 is a schematic of an abandoned well monitoring system 10 positioned in a wellbore according to an embodiment of the disclosure.
- Wellbore 12 extends through at least one subterranean zone or formation 14.
- a casing 16 is cemented into position along at least a portion of the length of the well.
- a liner 19 is shown hanging from the casing 16 and extending along the wellbore below the casing.
- the system is shown with a wellhead, tubing hanger, or other device 27 schematically represented. It is understood that the well can have various configurations, tubulars, surface and subsurface equipment, etc. Alternately, the liner can hang from a liner hanger or other tubular. The liner is often cemented into position as well.
- a tubing string 18 has been run-in to the well and extends to the surface. The tubing string defines an open bore therein.
- the tubing string 18 can be coiled tubing, a series of tubulars made-up into a string, etc., as is known in the art.
- a tubing annulus 20 is defined between the casing and tubing.
- the well has been or is considered abandoned and can have zero or positive formation pressure at depth. Where the well has been plugged and abandoned it is common to place a cement plug 24 in the tubing annulus. Often a pressure barrier 25, such as a packer, plug tool, etc., is positioned downhole, below the cement plug, during plugging operations and left in the well.
- the system can be deployed in wells having various types of plugs, packers, etc. In some instances, the system can enhance or even replace a cement plug or packer since the mandrel assembly provides a pressure seal.
- An abandoned well monitoring system 10 is seen deployed in the well.
- the system 10 includes a mandrel assembly 26 positioned uphole from, and connected to, an instrument tool 30 below.
- the system 10 is run-in via wireline, slick-line, coiled tubing, work string, or other method, in the tubing string 18.
- the mandrel assembly can be pumped or flowed downhole.
- a cable 42 extends from the surface, through the mandrel assembly 26 and to the instrument tool 30.
- the cable 42 is preferably a control line and communicates the sensor, gauge, instrument readings, and various outputs from the instrument tool, etc., to the surface.
- the cable can also be a wireline, etc., as is known in the art.
- the instrument tool 30 can hang in the tubing string or below the tubing string, as shown. Depending on the wellbore and equipment in place, the tool can hang in a space defined by a perforated or non-perforated tubing, liner, casing, or open hole.
- the disclosure focuses on a specific embodiment to facilitate discussion. It is understood, however, that the apparatus and methods are applicable to a wide variety of situations.
- the monitoring system can be deployed in vertical, horizontal, or deviated wellbores; in cased, lined, or open-hole bores; in wellbores having multiple zones of interest; in played-out or dry wells; in wells having no, one, or multiple plugs or pressure isolation barriers; in zero pressure or positive pressure wells; onshore or offshore; with or without full rig and hoist; with various wellhead, Christmas tree, BOP, risers, and other termination and control equipment; etc.
- FIGS. 2A-B are schematic elevational and end views of the mandrel assembly according to an aspect of the disclosure.
- the mandrel assembly has a mandrel body 32, sealing element(s) 28, a longitudinal through-bore 34 defined therethrough, and connectors 36 for assembling the device on a tool string, tubular, etc.
- the mandrel assembly is seen having a threaded connector 36 and connected to hardware 38 and upper and lower tubular conduits 40.
- the hardware can include tube fittings, tubes, connectors, and the like. Swagelok (trade name) commercially supplies such hardware.
- the mandrel body is preferably of relatively small OD, and more preferably about one inch OD.
- the sealing element 28 is preferably low-profile in its pre-expanded state, and more preferably has a run-in OD of about 1-1/8 inch.
- the mandrel body 32 defines a through-bore 34 which is preferably of about 3/8 inch ID.
- a communication cable 42 runs through the bore 34. Preferably the cable is about 1 ⁇ 4 inch in diameter.
- the mandrel assembly includes connectors 36, which, in a preferred embodiment, include a 3/8 inch NPT female threaded connector.
- the hardware can include 3/8 inch NPT male threaded connections, bored-through. Cable options can include 1 ⁇ 4 inch, of stainless steel, such as A825/316 Stainless. Where the system is deployed in a casing or open hole wellbore, the mandrel dimensions are preferably larger.
- the mandrel assembly 26 has a gripping and sealing element 28, or elements, mounted on the mandrel 32 for sealingly engaging the interior surface of the tubing string.
- a gripping and sealing element 28, or elements mounted on the mandrel 32 for sealingly engaging the interior surface of the tubing string.
- Such elements are well-known in the art and not described in detail herein.
- One or more elements can be employed.
- the sealing element(s) are low-profile on run-in and do not require bulky actuation devices such as slips, wedges, hydraulic or electric actuators, etc.
- the sealing element 28 is made of swellable materials. Swelling of the element causes radial expansion into sealing engagement with the interior of the tubing string.
- the sealing element 28 can be sized and made of selected materials according to the specifics of the wellbore. For example, when deployed in a casing, the element can have a greater OD. Similarly, when deployed in an open hole, the element materials may be selected to better seal against the open bore wall. Other arrangements will be apparent to those of skill in the art.
- Swellable materials are known in the art and will not be described in detail herein.
- An example of a swellable material is a 50 duro nitrile with a low CAN content, or a soft EPDM. These substances swell in the presence of hydrocarbons, so the activating fluid can be in situ wellbore fluids. Alternately, the activating fluid can be pumped-down or introduced artificially to the wellbore.
- Further possible swellable materials include, but are not limited to, hydrogenated nitrile, polychloroprene, butyl, polyurethane and silicon, for instance, which swell in benzene.
- brake fluid will swell elements made of fluorocarbon, hifluor, and flourosilicon, for example. Diesel will cause swelling of ethylene propylene, polyurethane, butyl, butadiene, isoprene and silicon, for example.
- Other swellable materials and activating fluids will present themselves to those skilled in the art, including those which activate in response to heat, pH, etc.
- the sealing element can be made of swellable material with a delay mechanism which retards swelling for a period. The material itself can react slowly upon exposure to the activating fluid, or the element can have a temporary protective coating, etc. The time delay can be used to position the device in the wellbore.
- the instrument or measuring tool can include various sensors, gauges, optical cable, computing devices, recording devices, transmitters, and the like, all of which are known in the art.
- tools and instruments can be used such as SmartLog (trade name) gauge, available commercially from DescoEMIT, ROC (trade name) downhole gauge, commercially available from Halliburton Energy Services, Inc., quartz gauges, strain gauges, piezoelectric gauges, fiber optic sensors, etc., as are known in the art.
- the instruments can be used in conjunction with fiber optic distributed measurements to provide distributed temperature sensing or distributed acoustic sensing.
- the parameters to be measured can include temperature, pressure, pH, salinity, and other parameters.
- more than one instrument tool can be run-in, spaced apart from one another.
- a single downhole permanent or temporary gauge, a multi-drop downhole permanent or temporary gauge (up to six or more), or a downhole permanent or temporary gauge with fiber optic DTS can be used. These are merely examples of gauge types which can be used.
- Downhole measurement or instrument tools are available which provide reliable, real-time data about downhole conditions. Such tools can be used for single or multi-zone monitoring applications. In multi-zone applications, dual, triple, or quad splitter block assemblies can be used for multi-drop capabilities.
- a low cost onshore monitoring method and system can be as simple as lowering an instrument tool, such as a Smartlog (trade name) gauge, on the mandrel inside the tubing on a well that is considered abandoned.
- the cable can be terminated at the surface through the top of the Christmas tree or other surface equipment.
- a pressure barrier is provided by the swellable mandrel and a secondary pressure barrier can be provided at the surface, for example, at the wellhead.
- This method allows use of an abandoned well, potentially avoiding the commercial outlay for drilling an observation well.
- the mandrel and instrument tool can preferably be run from a spooling unit rather than deploying a work-over hoist to recomplete the well, for example.
- a platform-based, offshore monitoring method and system are provided. Such a system is more suited for higher-end applications where several zones have been drilled but deemed uneconomical to produce. Multiple mandrels can be run-in hole, with the swellable sealing elements providing isolation between zones. Alternately, packers, plugs and the like can provide isolation. Distributed temperature, and single-point pressure and temperature gauges can be employed. The system provides valuable data on field pressure depletion, monitoring of enhanced recovery operations, such as water flood, validation of reserves, and long-term field pressure monitoring. Deployment can be by spooling unit, or using a hoist to make-up a string. It may be necessary in some applications to use a side-door splitter or BOP stack for pressure control.
- FIG. 3 is a schematic of an abandoned well monitoring system utilizing multiple mandrel assemblies and instrument tools positioned in a multi-zone wellbore according to an embodiment of the disclosure.
- An abandoned wellbore 50 with multiple zones 51 of interest isolated by packers 53 or other isolation devices for sealing the annulus between the string 57 and casing 55.
- a monitoring system 52 is deployed having a plurality of mandrel assemblies 54 and instrument tools 56.
- the swellable elements can provide isolation between zones. Alternately, isolation can be provided by packers and other devices known in the art.
- one or more instrument tools is positioned to measure environmental parameters.
- the gathered data is transmitted uphole, preferably by wire 28. Alternately, the data can be transmitted wirelessly or by any other known means. Multiple instrument tools can be daisy-chained together to utilize a shared computer and/or transmission device.
- a subsea well monitoring method and system are provided. Rather than abandon a subsea well that has been drilled, the well can be populated with instrument tools and mandrels, providing value in the form of field data.
- the system can be deployed in conjunction with a downhole computer and transmission system.
- a tree transmission system such as commercially available from Sonardyne Group of Companies, can be used to provide data back to surface before the subsea infrastructure and Floating Production Storage and Offloading unit are in place.
- the transmission of data from downhole can be via wire or wireless, or by any known or future means.
- a horizontal well monitoring method and system are provided.
- one method of deployment is pumping or flowing the mandrel assembly into the wellbore.
- a time-delay for activation of the swellable seal can be used to prevent the mandrel from deploying prematurely.
- suction cups can be employed to pump the system into the well.
- the methods and systems disclosed herein allow savings in utilizing a depleted well for long-term observation and monitoring rather than drilling a dedicated observation well. Further, savings are available where the system can be deployed on a wireline intervention set-up instead of a work-over hoist and rig. Savings are also realized since the system can be run inside an existing completion instead of pulling the existing completion and running new tubing. Savings in deploying gauges allows longer term monitoring in a field instead of running production logging tool interventions. Running data transmission systems allows longer term monitoring of single-phase and multi-zone wells to validate operations such as water flood, polymer flood, etc. The low cost barrier provided by the swellable element reduces cost in comparison to a cement pumping operation.
- a preferred method of monitoring an abandoned wellbore extending through a subterranean formation comprises the steps of: a) running into an abandoned wellbore an environmental parameter measuring device below a pressure isolation assembly; b) providing annular pressure isolation across the annulus defined exterior to the pressure isolation assembly; c) measuring at least one downhole environmental parameter in the wellbore downhole from the isolation assembly using the measuring device; and d) transmitting data related to a measured parameter to the surface.
- step a) can further comprise running the measuring device and isolation assembly in hole on a wire line, slick line, coiled tubing, or tubing string.
- step a) further comprises running the measuring device and isolation assembly into a tubing string positioned in the wellbore.
- step b) further comprises radially expanding at least one sealing element.
- the sealing element is radially expanded into sealing engagement with the tubing string.
- the sealing element is swellable upon contact with an activating fluid.
- step c) further comprises measuring a downhole temperature, pressure, pH, or salinity.
- step c) further comprises using at least one of a quartz gauge, piezoelectric gauge, or distributed optical cable.
- step d) further comprises transmitting data via wire or wirelessly to the surface.
- the wellbore extends through multiple zones, and further comprising the steps of: positioning a plurality of environmental parameter measuring devices in the wellbore, at least one measuring device in each of the plurality of zones.
- a preferred method further comprises the step of: positioning a plurality of pressure isolation assemblies adjacent the plurality of zones.
- a preferred method further comprises steps of radially expanding the plurality of isolation devices and isolating a plurality of zones.
- the present disclosure relates generally to operations performed and equipment utilized in conjunction with a subterranean well and, in an embodiment described herein, more particularly provides methods and apparatus for monitoring abandoned wellbores.
- FIG. 1 is a schematic of an abandoned well monitoring system positioned in a wellbore according to an embodiment of the disclosure
- FIGS. 2A-B are schematic elevational and end views of the mandrel assembly according to an aspect of the disclosure.
- FIG. 3 is a schematic of an abandoned well monitoring system utilizing multiple mandrel assemblies and instrument tools positioned in a multi-zone wellbore according to an embodiment of the disclosure.
- Upstream, uphole, downstream and downhole are used to indicate location or direction in relation to the surface, where upstream indicates relative position or movement towards the surface along the wellbore and downstream indicates relative position or movement further away from the surface along the wellbore, unless otherwise indicated.
- the disclosed methods and apparatus are designed to provide long-term monitoring in wells where the operator may have a considerable amount of sunk capital, but rather than simply abandoning the well, it is used to provide downhole data. For example, downhole or formation pressure, temperature, salinity, etc., is measured using appropriate sensors and communicated to the surface for use by the operator of nearby wells.
- FIG. 1 is a schematic of an abandoned well monitoring system 10 positioned in a wellbore according to an embodiment of the disclosure.
- Wellbore 12 extends through at least one subterranean zone or formation 14.
- a casing 16 is cemented into position along at least a portion of the length of the well.
- a liner 19 is shown hanging from the casing 16 and extending along the wellbore below the casing.
- the system is shown with a wellhead, tubing hanger, or other device 27 schematically represented. It is understood that the well can have various configurations, tubulars, surface and subsurface equipment, etc. Alternately, the liner can hang from a liner hanger or other tubular. The liner is often cemented into position as well.
- a tubing string 18 has been run-in to the well and extends to the surface.
- the tubing string defines an open bore therein.
- the tubing string 18 can be coiled tubing, a series of tubulars made-up into a string, etc., as is known in the art.
- a tubing annulus 20 is defined between the casing and tubing.
- the well has been or is considered abandoned and can have zero or positive formation pressure at depth. Where the well has been plugged and abandoned it is common to place a cement plug 24 in the tubing annulus. Often a pressure barrier 25, such as a packer, plug tool, etc., is positioned downhole, below the cement plug, during plugging operations and left in the well.
- the system can be deployed in wells having various types of plugs, packers, etc. In some instances, the system can enhance or even replace a cement plug or packer since the mandrel assembly provides a pressure seal.
- An abandoned well monitoring system 10 is seen deployed in the well.
- the system 10 includes a mandrel assembly 26 positioned uphole from, and connected to, an instrument tool 30 below.
- the system 10 is run-in via wireline, slick-line, coiled tubing, work string, or other method, in the tubing string 18.
- the mandrel assembly can be pumped or flowed downhole.
- a cable 42 extends from the surface, through the mandrel assembly 26 and to the instrument tool 30.
- the cable 42 is preferably a control line and communicates the sensor, gauge, instrument readings, and various outputs from the instrument tool, etc., to the surface.
- the cable can also be a wireline, etc., as is known
- the instrument tool 30 can hang in the tubing string or below the tubing string, as shown. Depending on the wellbore and equipment in place, the tool can hang in a space defined by a perforated or non-perforated tubing, liner, casing, or open hole.
- the disclosure focuses on a specific embodiment to facilitate discussion. It is understood, however, that the apparatus and methods are applicable to a wide variety of situations.
- the monitoring system can be deployed in vertical, horizontal, or deviated wellbores; in cased, lined, or open-hole bores; in wellbores having multiple zones of interest; in played-out or dry wells; in wells having no, one, or multiple plugs or pressure isolation barriers; in zero pressure or positive pressure wells; onshore or offshore; with or without full rig and hoist; with various wellhead, Christmas tree, BOP, risers, and other termination and control equipment; etc.
- FIGS. 2A-B are schematic elevational and end views of the mandrel assembly according to an aspect of the disclosure.
- the mandrel assembly has a mandrel body 32, sealing element(s) 28, a longitudinal through-bore 34 defined therethrough, and connectors 36 for assembling the device on a tool string, tubular, etc.
- the mandrel assembly is seen having a threaded connector 36 and connected to hardware 38 and upper and lower tubular conduits 40.
- the hardware can include tube fittings, tubes, connectors, and the like. Swagelok (trade name) commercially supplies such hardware.
- the mandrel body is preferably of relatively small OD, and more preferably about one inch OD.
- the sealing element 28 is preferably low-profile in its pre-expanded state, and more preferably has a run-in OD of about 1-1/8 inch.
- the mandrel body 32 defines a through-bore 34 which is preferably of about 3/8 inch ID.
- a communication cable 42 runs through the bore 34. Preferably the cable is about 1 ⁇ 4 inch in diameter.
- the mandrel assembly includes
- connectors 36 which, in a preferred embodiment, include a 3/8 inch NPT female threaded connector.
- the hardware can include 3/8 inch NPT male threaded connections, bored-through.
- Cable options can include 1 ⁇ 4 inch, of stainless steel, such as A825/316 Stainless. Where the system is deployed in a casing or open hole wellbore, the mandrel dimensions are preferably larger.
- the mandrel assembly 26 has a gripping and sealing element 28, or elements, mounted on the mandrel 32 for sealingly engaging the interior surface of the tubing string.
- a gripping and sealing element 28, or elements mounted on the mandrel 32 for sealingly engaging the interior surface of the tubing string.
- Such elements are well-known in the art and not described in detail herein.
- One or more elements can be employed.
- the sealing element(s) are low-profile on run-in and do not require bulky actuation devices such as slips, wedges, hydraulic or electric actuators, etc.
- the sealing element 28 is made of swellable materials. Swelling of the element causes radial expansion into sealing engagement with the interior of the tubing string.
- the sealing element 28 can be sized and made of selected materials according to the specifics of the wellbore. For example, when deployed in a casing, the element can have a greater OD. Similarly, when deployed in an open hole, the element materials may be selected to better seal against the open bore wall. Other arrangements will be apparent to those of skill in the art.
- Swellable materials are known in the art and will not be described in detail herein.
- An example of a swellable material is a 50 duro nitrile with a low CAN content, or a soft EPDM. These substances swell in the presence of hydrocarbons, so the activating fluid can be in situ wellbore fluids. Alternately, the activating fluid can be pumped-down or introduced artificially to the wellbore.
- Further possible swellable materials include, but are not limited to, hydrogenated nitrile, polychloroprene, butyl, polyurethane and silicon, for instance, which swell in benzene.
- brake fluid will swell elements made of fluorocarbon, hifluor, and flourosilicon, for example. Diesel will cause swelling of ethylene propylene, polyurethane, butyl, butadiene, isoprene and
- the sealing element can be made of swellable material with a delay mechanism which retards swelling for a period.
- the material itself can react slowly upon exposure to the activating fluid, or the element can have a temporary protective coating, etc. The time delay can be used to position the device in the wellbore.
- the instrument or measuring tool can include various sensors, gauges, optical cable, computing devices, recording devices, transmitters, and the like, all of which are known in the art.
- tools and instruments can be used such as SmartLog (trade name) gauge, available commercially from DescoEMIT, ROC (trade name) downhole gauge, commercially available from Halliburton Energy Services, Inc., quartz gauges, strain gauges, piezoelectric gauges, fiber optic sensors, etc., as are known in the art.
- the instruments can be used in conjunction with fiber optic distributed measurements to provide distributed temperature sensing or distributed acoustic sensing.
- the parameters to be measured can include temperature, pressure, pH, salinity, and other parameters.
- more than one instrument tool can be run-in, spaced apart from one another.
- a single downhole permanent or temporary gauge, a multi-drop downhole permanent or temporary gauge (up to six or more), or a downhole permanent or temporary gauge with fiber optic DTS can be used. These are merely examples of gauge types which can be used.
- Downhole measurement or instrument tools are available which provide reliable, real-time data about downhole conditions. Such tools can be used for single or multi-zone monitoring applications. In multi-zone applications, dual, triple, or quad splitter block assemblies can be used for multi-drop capabilities.
- a low cost onshore monitoring method and system can be as simple as lowering an instrument tool
- the cable 7 such as a Smartlog (trade name) gauge, on the mandrel inside the tubing on a well that is considered abandoned.
- the cable can be terminated at the surface through the top of the Christmas tree or other surface equipment.
- a pressure barrier is provided by the swellable mandrel and a secondary pressure barrier can be provided at the surface, for example, at the wellhead. This method allows use of an abandoned well, potentially avoiding the commercial outlay for drilling an observation well.
- the mandrel and instrument tool can preferably be run from a spooling unit rather than deploying a work-over hoist to recomplete the well, for example.
- a platform-based, offshore monitoring method and system are provided. Such a system is more suited for higher-end applications where several zones have been drilled but deemed uneconomical to produce. Multiple mandrels can be run-in hole, with the swellable sealing elements providing isolation between zones. Alternately, packers, plugs and the like can provide isolation. Distributed temperature, and single-point pressure and temperature gauges can be employed. The system provides valuable data on field pressure depletion, monitoring of enhanced recovery operations, such as water flood, validation of reserves, and long-term field pressure monitoring. Deployment can be by spooling unit, or using a hoist to make-up a string. It may be necessary in some applications to use a side-door splitter or BOP stack for pressure control.
- FIG. 3 is a schematic of an abandoned well monitoring system utilizing multiple mandrel assemblies and instrument tools positioned in a multi-zone wellbore according to an embodiment of the disclosure.
- An abandoned wellbore 50 with multiple zones 51 of interest isolated by packers 53 or other isolation devices for sealing the annulus between the string 57 and casing 55.
- a monitoring system 52 is deployed having a plurality of mandrel assemblies 54 and instrument tools 56.
- the swellable elements can provide isolation between zones. Alternately, isolation can be provided by packers and other devices known in the art.
- instrument tools is positioned to measure environmental parameters.
- the gathered data is transmitted uphole, preferably by wire 28.
- the data can be transmitted wirelessly or by any other known means.
- Multiple instrument tools can be daisy-chained together to utilize a shared computer and/or transmission device.
- a subsea well monitoring method and system are provided. Rather than abandon a subsea well that has been drilled, the well can be populated with instrument tools and mandrels, providing value in the form of field data.
- the system can be deployed in conjunction with a downhole computer and transmission system.
- a tree transmission system such as commercially available from Sonardyne Group of Companies, can be used to provide data back to surface before the subsea infrastructure and Floating Production Storage and Offloading unit are in place.
- the transmission of data from downhole can be via wire or wireless, or by any known or future means.
- a horizontal well monitoring method and system are provided.
- one method of deployment is pumping or flowing the mandrel assembly into the wellbore.
- a time-delay for activation of the swellable seal can be used to prevent the mandrel from deploying prematurely.
- suction cups can be employed to pump the system into the well.
- the methods and systems disclosed herein allow savings in utilizing a depleted well for long-term observation and monitoring rather than drilling a dedicated observation well. Further, savings are available where the system can be deployed on a wireline intervention set-up instead of a work-over hoist and rig. Savings are also realized since the system can be run inside an existing completion instead of pulling the existing completion and running new tubing. Savings in deploying gauges allows longer term
- Running data transmission systems allows longer term monitoring of single-phase and multi-zone wells to validate operations such as water flood, polymer flood, etc.
- the low cost barrier provided by the swellable element reduces cost in comparison to a cement pumping operation.
- a preferred method of monitoring an abandoned wellbore extending through a subterranean formation comprises: a) running into an abandoned wellbore an environmental parameter measuring device below a pressure isolation assembly; b) providing annular pressure isolation across the annulus defined exterior to the pressure isolation assembly; c) measuring at least one downhole environmental parameter in the wellbore downhole from the isolation assembly using the measuring device; and d) transmitting data related to a measured parameter to the surface.
- a) can further comprise running the measuring device and isolation assembly in hole on a wire line, slick line, coiled tubing, or tubing string.
- a) further comprises running the measuring device and isolation assembly into a tubing string positioned in the wellbore.
- b) further comprises radially expanding at least one sealing element.
- the sealing element is radially expanded into sealing engagement with the tubing string.
- the sealing element is swellable upon contact with an activating fluid.
- c) further comprises measuring a downhole temperature, pressure, pH, or salinity.
- c) further comprises using at least one of a quartz gauge, piezoelectric gauge, or distributed optical cable.
- d) further comprises transmitting data via wire or wirelessly to the surface.
- the wellbore extends through multiple zones, and further comprising: positioning a plurality of environmental
- a preferred method further comprises: positioning a plurality of pressure isolation assemblies adjacent the plurality of zones.
- a preferred method further comprises radially expanding the plurality of isolation devices and isolating a plurality of zones.
Abstract
La présente invention concerne un procédé et un appareil permettant de surveiller des paramètres environnementaux dans un ou plusieurs puits de forage abandonnés. Un mandrin doté d'un élément de scellement déployable dans le sens radial est positionné au fond du trou, comme dans une colonne de production, pour permettre une isolation de pression. Un outil de mesure possédant un ou plusieurs capteurs ou jauges est positionné sous le mandrin afin de mesurer les paramètres environnementaux. Les données sont transmises vers la surface par câble ou sans fil.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
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US15/021,223 US20160230531A1 (en) | 2013-10-30 | 2013-10-30 | Abandoned well monitoring system |
PCT/US2013/067551 WO2015065387A1 (fr) | 2013-10-30 | 2013-10-30 | Système de surveillance de puits abandonné |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
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PCT/US2013/067551 WO2015065387A1 (fr) | 2013-10-30 | 2013-10-30 | Système de surveillance de puits abandonné |
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WO2015065387A1 true WO2015065387A1 (fr) | 2015-05-07 |
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PCT/US2013/067551 WO2015065387A1 (fr) | 2013-10-30 | 2013-10-30 | Système de surveillance de puits abandonné |
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US (1) | US20160230531A1 (fr) |
WO (1) | WO2015065387A1 (fr) |
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GB2538821A (en) * | 2014-11-06 | 2016-11-30 | Baker Hughes Inc | Property mointoring below a nonpenetrated seal |
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