GB2396637A - A method of enabling gravel packing of a wellbore - Google Patents
A method of enabling gravel packing of a wellbore Download PDFInfo
- Publication number
- GB2396637A GB2396637A GB0401595A GB0401595A GB2396637A GB 2396637 A GB2396637 A GB 2396637A GB 0401595 A GB0401595 A GB 0401595A GB 0401595 A GB0401595 A GB 0401595A GB 2396637 A GB2396637 A GB 2396637A
- Authority
- GB
- United Kingdom
- Prior art keywords
- well
- sleeve
- service tool
- gravel
- housing
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 238000000034 method Methods 0.000 title claims abstract description 39
- 238000012856 packing Methods 0.000 title claims abstract description 28
- 239000012530 fluid Substances 0.000 claims abstract description 85
- 239000012065 filter cake Substances 0.000 claims abstract description 21
- 239000002002 slurry Substances 0.000 claims abstract description 19
- 238000000151 deposition Methods 0.000 claims abstract description 8
- 238000004891 communication Methods 0.000 description 55
- 238000004519 manufacturing process Methods 0.000 description 15
- 230000015572 biosynthetic process Effects 0.000 description 13
- 238000005755 formation reaction Methods 0.000 description 13
- 239000004576 sand Substances 0.000 description 13
- 238000013461 design Methods 0.000 description 5
- 238000005406 washing Methods 0.000 description 4
- 239000002253 acid Substances 0.000 description 3
- 150000007513 acids Chemical class 0.000 description 3
- 238000005553 drilling Methods 0.000 description 3
- 239000003112 inhibitor Substances 0.000 description 3
- 230000000903 blocking effect Effects 0.000 description 2
- -1 breakers Substances 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 238000005260 corrosion Methods 0.000 description 2
- 230000007797 corrosion Effects 0.000 description 2
- 230000018044 dehydration Effects 0.000 description 2
- 238000006297 dehydration reaction Methods 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000007789 sealing Methods 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 241001649081 Dina Species 0.000 description 1
- 235000008331 Pinus X rigitaeda Nutrition 0.000 description 1
- 235000011613 Pinus brutia Nutrition 0.000 description 1
- 241000018646 Pinus brutia Species 0.000 description 1
- 238000009825 accumulation Methods 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 239000011248 coating agent Substances 0.000 description 1
- 238000000576 coating method Methods 0.000 description 1
- 239000000356 contaminant Substances 0.000 description 1
- 239000000835 fiber Substances 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 239000013618 particulate matter Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000011282 treatment Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
- E21B34/142—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
- E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/04—Gravelling of wells
- E21B43/045—Crossover tools
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Earth Drilling (AREA)
Abstract
A method that enables gavel packing a wellbore whilst also removing of filter cakes. The method comprises inserting a service tool into the well to a desired location, gravel packing the well, and circulating fluids within the wellbore through the service tool to dislodge and remove filter cake residue. The gravel packing can comprise flowing a gravel laden slurry through the service tool, thereby selectively depositing gravel within the well. The service tool can define multiple, selectable flow paths through which fluids and slurries can flow. The service tool comprises cylindrical housing 40 having an exterior and a longitudinal bore 42. A lateral port 44 is between the housing longitudinal bore and exterior of the housing. A first sleeve 46 within the housing longitudinal bore 42 and having a cylindrical wall and a longitudinal passageway is movable between an upper position and a lower position relative to the housing. First 48 and second 50 lateral passageways extend through the wall of the first sleeve 46. A second sleeve 54 is disposed within the first sleeve 46 and having a longitudinal passageway is movable between an upper position and a lower position relative to the first sleeve 46.
Description
GB 2396637 A continuation (72) Inventor(s): Harold S Bissonnette Jake A
Danos Mehmet Parlar Colin J Price-Smith (74) Agent and/or Address for Service: Sensa Gamma House, Enterprise Road, Chilworth Science Park, SOUTHAMPTON, Hampshire, S016 7NS, United Kingdom
METHODS FOR IJSE IN GRAVEL PACKING OF WELLBORES
5 BACKGROUND C)F THEE INVENTION
1. Field of the Invention
This invention relates generally to methods used to complete subterranean wells and more particularly provides methods for use in gravel pack operations.
2. Description of Related Art
lo Hydrocarbon fluids such as oil and natural gas are obtained from a subterranean geologic formation, i.e. a reservoir, by drilling a well that penetrates the hvdrocarbon bearing formation. Once a wellbore has been drilled, the well must be completed before hydrocarbons can be produced from the well. A completion involves the design, selection, and installation of equipment and materials in or around the wellbore for conveying, 15 pumping, or controlling the production or injection of fluids. After the well has been completed, production of oil and gas can begin.
Sand or silt flowing into the wellbore from unconsolidated formations can lead to an accumulation of fill within the wellbore, reduced production rates and damage to subsurface production equipment. Due to its highly abrasive nature, sand contained within production to stiearrs cart result in.1-.e erosiol' of tubing, flowliiles, -v-elves and processing eqaipmerlt. The problems caused by sand production can significantly increase operational and maintenance expenses and can lead to a total loss of the well. One means of controlling sand production is the placement of relatively large sand (i.e., "gravel") around the exterior of a slotted, perforated, or other type liner or screen. The gravel prevents the fine sand from packing off 25 around the production tubing and screen, and the screen prevents the gravel from entering the production tubing. It is important to size the gravel for proper containment of the formation sand, and the screen must be designed in a manner to prevent the flow of the gravel through the screen.
In open hole completions that are gravel packed, a drilling fluid residue is left on the . so formation adjacent to the borehole in the form of a filter cake. Filter cake removal treatments are conventionally done through coiled tubing after gravel packing. This necessitates the pulling of the gravel pack assembly out of the well and running in the well with coiled tubing for filter cake removal or to spot post gravel pack fluids such as breakers, acids or corrosion inhibitors. The final production/injection tubing is then run in the well after the coiled tubing
is removed. The ability to perform the steps of gravel packing, filter cake removal operations and post gravel pack fluid spotting on a single trip would save significant time and expense.
SUMMARY OF TlIE INVENTION
The present invention comprises an apparatus for use in gravel packing operations in 5 wel]bores. Some embodiments of the invention enable the running in, washing down, gravel packing, reversing excess slurry, and the spotting of post gravel pack fluids on a single trip.
One embodiment of the invention comprises a housing having an exterior and a longitudinal bore extending therethrough; and a lateral port providing a communication path between the housing longitudinal bore and the exterior of the housing. A first sleeve is lo disposed within the housing longitudinal bore that has a longitudinal passageway therethrouh and is capable of being positioned in an upper position and a lower position relative to the housing. First and second lateral passageways extend through the wall of the first sleeve. A second sleeve is disposed within the first sleeve and also has a longitudinal passageway therethrough. The second sleeve is capable of being positioned in an upper 15 position and a lower position relative to the first sleeve. A first flow passage extends longitudinally through the housing and a second flow passage extends longitudinally through the housing. When the first sleeve is in the upper position, and the second sleeve is in the lower position, communication is established between the longitudinal bore of the housing above the second sleeve and the exterior of the housing, and communication is established to bet-weep the longitudinal bore of the housing below-' He second sleeve and the first OVA passage. When the first sleeve is in the lower position, communication is established between the longitudinal bore of the housing above the first sleeve and the second flow passage. The apparatus can have the first and second sleeves releasably secured in their upper 25 positions with retaining elements. The retaining elements can be of a shear element design.
The first and second sleeves can comprise ball seating elements, wherein the ball seating element of the second sleeve hats a smaller diameter than the ball seating element of the first sleeve. The apparatus can further comprise a first ball that can be sized so as to pass through the first sleeve, and to seat within the second sleeve. When the first sleeve is in the so upper position and the first ball is seated within the second sleeve, the first ball can form a primary seal that restricts communication between the longitudinal bore of the housing above the second sleeve and the longitudinal bore of the housing below the second sleeve. The invention can further comprise a second ball that is sized so as to seat within the first sleeve.
When the first sleeve is in the upper position and the second ball is seated within the first
sleeve, the second ball forms a seal that restricts communication between the longitudinal bore of the housing above the second ball and the longitudinal bore below the second ball.
The first sleeve can be in sliding contact with the housing and the second sleeve can be in sliding contact with the first sleeve.
5 When both the first and second sleeves are in the upper position, the second sleeve prevents communication between the longitudinal bore of the housing and the first lateral passageway. When the second sleeve is in the lower position, a secondary seal can be formed by contact of the second sleeve with the first sleeve that restricts communication between the longitudinal bore of the housing above the second sleeve and the longitudinal bore of the lo housing below the second sleeve. This secondary seal can comprise an elastomeric sealing element, which can be an O-ring element, for example.
When the first lateral passageway is aligned with the lateral port, communication is established between the longitudinal bore of the housing above the second sleeve and the exterior of the housing, and communication is established between the longitudinal bore of 5 the housing below the second sleeve and the first flow passage.
When the first sleeve is in the lower position, the second lateral passageway is aligned with the second flow passage and communication is established between the longitudinal bore of the housing above the first sleeve and the second flow passage. This can also establish communication between the longitudinal bore of the housing above the first sleeve to and the!ongitudin.a! bore of the housing below. the second sleeve through the second flow.
passage. When the first sleeve is in the lower position, the first sleeve restricts communication between the longitudinal bore of the housing and the lateral port and can also restrict communication between the longitudinal bore of the housing and the first flow passage. 25 The apparatus can be connected to a gravel pack screen element, to a packer element, and to a tubing string, each having a longitudinal bore. These tubulars can be located inside a wellbore, wherein an annular space is formed between the tubing and the wellbore.
Communication can be established between the longitudinal bore of the tubing and the longitudinal bore of the gravel pack screen element.
so An alternate embodiment of the present invention comprises a cylindrical housing having an exterior and a longitudinal bore and a lateral port communicating between the housing longitudinal bore and the exterior of the housing. A first sleeve is disposed within the housing longitudinal bore and in sliding contact with the housing, having a longitudinal passageway and a ball seating element. It is capable of being positioned in an upper position
and a lower position relative to the housing and can have a first and second lateral passageways extending through the wall of the first sleeve. A second sleeve can be disposed within the longitudinal bore of the first sleeve, in sliding contact with the first sleeve and have a longitudinal passageway and a ball seating element. It can be capable of being 5 positioned in an upper position and a lower position relet ve to the first sleeve. The embodiment can have a first flow passage extending longitudinally through the housing and a second flow passage extending longitudinally through the housing. A first ball is sized so as to pass through the first sleeve, and to seat within the second sleeve and a second teal! is sized so as to seat within the first sleeve. The ball seating element of the second sleeve has a lo smaller diameter than the ball seating element of the first sleeve. When the first sleeve is in the upper position and the second sleeve tic in the upper position; commmication is established between the longitudinal bore of the housing above the sleeves and the longitudinal bore of the housing below the sleeves. The first lateral passageway is prevented by the second sleeve. When the first sleeve is in the upper position and the second sleeve is 15 in the lower position, the first lateral passageway is aligned with the lateral port and communication is established between the longitudinal bore of the housing above the second sleeve and the exterior of the housing through the lateral port and communication is established between the longitudinal bore of the housing below the second sleeve and the first flow passage. When the first sleeve is in the lower position, the second lateral passageway is so aligned with the second flow passage and communication is established between the longitudinal bore of the housing above the sleeves and the longitudinal bore of the housing below the sleeves through the second flow passage, communication between the longitudinal bore of the housing and the exterior of the housing through the lateral port is prevented by the first sleeve, and communication through the first flow passage is prevented by the first sleeve.
25 The apparatus can be located above and connected to a gravel pack screen element having a longitudinal bore and the apparatus can be located below and connected to a packer element having a longitudinal bore. The packet eler.,ent can be connected to a tubi".= stri.nD having a longitudinal bore and the packer element inserted inside a wellbore, thereby forming an annular space between the tubing and the wellbore.
so When the first sleeve is in the upper position and the second sleeve is in the lower position, the first lateral passageway is aligned with the lateral port and communication is established between the longitudinal bore of the housing above the second sleeve and the exterior of the housing through the lateral port and communication is established between the
longitudinal bore of the housing below the second sleeve and the annular space above the packer element through the first flow passage.
When the first sleeve is in the lower position, the second lateral passageway is aligned with the second flow passage and communication is established between the longitudinal 5 bore of the housing above the sleeves and the longitudinal bore Of the housing below the sleeves through the second flow passage, communication between the longitudinal bore of the housing and the exterior of the housing through the lateral port is prevented by the first sleeve and com..m.rmication between the longitudinal bore of the housing and the annular space above the packer through the first flow passage is prevented by the first sleeve.
lo The apparatus can further comprise a third lateral passageway through the first sleeve wherein when the first sleeve is in the tinner position communication is established between the longitudinal bore of the housing below the sleeves and the first flow passage through the third lateral passageway. When the third lateral passageway is aligned with the first flow passage, communication is established between the longitudinal bore of the housing below 15 the sleeves and the annular space above the packer element through the first flow passage.
A further embodiment of the invention includes an apparatus comprising a cylindrical housing having an exterior and a longitudinal bore and a lateral port communicating between the housing longitudinal bore and the exterior of the housing. A first sleeve can be disposed within the housing longitudinal bore, having a cylindrical wall and a longitudinal passageway 20 tneret'nrough, capable OI being positioned in an upper position and a lower position relative to the housing. First and second lateral passageways can extend through the wall of the first sleeve. A second sleeve can be disposed within the first sleeve, having a longitudinal passageway and capable of being positioned in an upper position and a lower position relative to the first sleeve. A third sleeve can be disposed within the first sleeve, having a Z5 longitudinal passageway therethrough and capable of being positioned in an upper position and a lower position relative to the first sleeve. A first flow passage can extend longitudinally through the housing and a second flow passage can also extend!ongit'dina!!y through the housing. When the first sleeve is in the upper position and the second sleeve is in the lower position, communication can be established between the longitudinal bore of the so housing above the second sleeve and the exterior of the housing and communication can be established between the longitudinal bore ofthe housing below the second sleeve and the first flow passage. When the first sleeve is in the lower position and the third sleeve is in its lower position, communication is established between the longitudinal bore of the housing above the third sleeve and the second flow passage.
When the third sleeve is in its upper position, communication is restricted through the second lateral passageway. When the third sleeve is in its lower position, communication is possible through the second lateral passageway. The second and third sleeves can comprise ball seating elements. The ball seating element of the second sleeve can have a smaller 5 diameter than the ball seating element of the third sleeve. T he apparatus can farther comprise a first ball that is sized so as to pass through the third sleeve and to seat within the second sleeve, and a second ball that is sized so as to seat within the third sleeve. When the first sleeve is in the upper position and the first ball is seated within the second sleeve, the first ball forms a primary seal that restricts communication between the longitudinal bore of the lo housing above the second sleeve and the longitudinal bore of the housing below the second sleeve. The third sleeve can be in sliding contact with the first sleeve. The first and third sleeves can be releasably secured in their upper positions with at least one retaining element.
When the first sleeve is in the upper position and the second sleeve is in the upper position, 15 the second sleeve prevents communication between the longitudinal bore of the housing and the first lateral passageway.
Yet another embodiment of the invention comprises a circulation tool having a housing with a longitudinal bore, a wall, and at least one lateral port through the housing wall. It can include at least two sliding sleeves, at least one flow passage within the housing 20 wall and a plurality of circulation paths that can be created by tile selective positioning OI the sliding sleeves.
The circulation tool can comprise a first sleeve movable between an upper position and a lower position and a second sleeve movable between an upper position and a lower position. The second sleeve is capable of being shifted into its lower position independent of 25 the movement of the first sleeve.
When the first and second sleeve are in their upper position, fluid communication is established through the longitudinal bole of the tool and restricted through the!at.era! port through the housing wall, creating a standard circulation path.
When the second sleeve is in its lower position and the first sleeve is in its upper so position, fluid communication is established between the longitudinal bore of the housing above the second sleeve and the lateral port through the housing wall. Fluid communication is also established between the longitudinal bore of the housing below the second sleeve and the first flow passage, creating a gravel pack circulation path.
When the second sleeve is in its lower position, the first sleeve in its lower position, and the third sleeve is in its lower position, fluid communication is restricted between the longitudinal bore of the housing above the first sleeve and the lateral port through the housing wall. Fluid communication is established between the longitudinal bore of the housing above 5 the first sleeve and the second flow passage. Fluid communication is also established between the longitudinal bore of the housing below the second sleeve and one of the flow passages within the housing wall, creating a modified standard circulation path.
Another aspect of the present ir,vention consists of a method of corr. pleting a subterranean well that comprises tubing and an annulus between the wellbore and the tubing.
lo The method comprises providing a device as described above and positioning the device within a ellbore..herei". the first slee.,e is in the upper position and the second sleeve is in the upper position. The device is reconfigured so that the second sleeve is in the lower position, allowing communication between the longitudinal bore of the housing and the exterior of the housing. The device is reconfigured so that the first sleeve is in the lower 15 position, allowing circulation through the tubing and device and up the tubing/wellbore annulus. This method can further comprise using a first ball to reposition the second sleeve from the upper position to the lower position. A second ball can be used to reposition the first sleeve from the upper position to the lower position. The method can further comprise to attaching a gravel pack screen assembly below the device and a packer element above the device prior to positioning the device within the wellbore. A gravel laden slurry can be flowed through the lateral port when the first sleeve is in the upper position and the second sleeve is in the lower position, thereby depositing the gravel in the annulus adjacent the gravel pack screen assembly. The device can be released from the gravel pack screen 25 assembly after the gravel laden slurry is placed and the wellbore circulated through the tubing and the device after the first sleeve is in the lower position to place fluids at desired locations within the wellbo. e.
An alternate embodiment of the invention includes a wellbore completion method comprising providing a circulation tool as described above, positioning the tool within the i so wellbore, thereby creating a toolwellbore annulus. The tool is initially configured to provide a first circulation path, the first circulation path being through the tool and the tool-wellbore annulus. The tool can then be reconfigured to provide circulation through the lateral port to provide a second circulation path. The tool can then be reconfigured to seal off the lateral port and provide a third circulation path through the tool and the tool-wellbore annulus. The
tool can be reconfigured from the first circulation path to the second circulation path utilizing a first ball and from the second circulation path to the third circulation path utilizing a second ball, the balls sized to seat within the sliding sleeves. The method can further comprise attaching a gravel pack screen assembly to the tool. A gravel laden slurry can be flowed 5 through the second circulation path thereby depositing gravel within the wellbore outside of the gravel pack screen assembly. Fluids can then be circulated within the wellbore through the third circulation path, following the depositing of gravel outside of the gravel pack screen assembly. An alternate embodiment of the invention is a well completion method performed in a lo single trip into a well. The method comprises inserting a service tool into the well to a desired location, gravel packing the well, and circulating fluids within the wellbore through the service tool to dislodge and remove filter cake residue. The gravel packing can comprise flowing a gravel laden slurry through the service tool, thereby selectively depositing gravel within the well. The service tool can define multiple, selectable flow paths through which 15 fluids and slurries can flow. When the service tool is inserted into the well it can be in a first flow path configuration that allows circulation through the service tool. Once the service tool has been inserted to the desired location, the service tool can be reconfigured to a second flow path configuration to enable the gravel packing of the well. After the well has been gravel packed, the service tool can be reconfigured to a third flow path configuration to to enable the circulation of fluids within the wellbore' through the service too!, to dislodge and remove filter cake residue. After the circulation of fluids to dislodge and remove filter cake residue, specialty fluids can be spotted at selected locations within the well.
Yet another embodiment is a method of completing a subterranean well performed in a single trip into a wellbore. This method comprises running a service tool into the well, the 25 service tool defining multiple, selectable flow paths and the gravel packing of the well. A different flow path of the service tool is selected followed by the removing of a filter cake from the wellbore by circulating a fluid through the service tool. Specialty fluids are spotted within the wellbore at desired locations prior to the removing of the service string from the well. The gravel packing of the well can comprise flowing a gravel laden slurry through the so service tool, thereby selectively depositing gravel within the wellbore. The service tool can be inserted into the well in a first flow path configuration allowing fluid circulation through the service tool. When the service tool has been inserted to the desired location, the service tool can be reconfigured to a second flow path configuration to enable the gravel packing of the well.
In still another embodiment a well completion method performed in a single trip into a well is disclosed. This method comprises inserting a service tool into the well to a desired location and gravel packing the well with a fluid that contains at least one breaker for filtercake removal. Fluids are then circulated or injected within the well through the service 5 tool to displace the breakers away from predetermined downhole equipment. The service tool can be inserted into the well in a first flow path configuration allowing fluid circulation through the service tool. When the service tool has been inserted to the desired location, the service tool can be reconfigured to a second flow path configuration to enable the gravel packing of the well. Once the gravel packing of the well has been performed, the service tool lo is capable of being reconfigured to a third flow path configuration to enable the circulating of fluids through the service tool.
BRIEF DESCRIPTION OF TEIE DRAWINGS
Figure I is a cross section view of a typical gravel pack wellbore completion.
Figures 2A-E illustrate one embodiment of the present invention in its different 15 configurations. Figures 3A-E illustrate an alternate embodiment of the present invention in its different configurations.
DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS
Referring to the attached drawings, Figure 1 illustrates a wellbore 10 that has in pei-le..a.ed a subterlailean zone 12 that includes a producive foll.lat.Grl 14 The wellbore '0 has a casing 16 that has been cemented in place. The casing 16 has a plurality of perforations 18 which allow fluid communication between the wellbore 10 and the productive formation 14. A well tool 20 is positioned within the casing 16 in a position adjacent to the productive formation 14, which is to be gravel packed.
25 The well tool 20 comprises a tubular member 22 attached to a production packer 24, a cross-over 26, one or more screen elements 28 and optionally a lower packer 30. Blank sections 72 of pine may he used to properly space the relative positions of each of the components. An annulus area 34 is created between each ofthe components and the wellbore casing 16. The combination of the well tool 20 and the tubular string extending from the well so tool to the surface can be referred to as the production string.
In a gravel pack operation the packer elements 24, 30 are set to ensure a seal between the tubular member 22 and the casing 16. Gravel laden slurry is pumped down the tubular member 22, exits the tubular member through ports in the cross-over 26 and enters the annulus area 34. In one typical embodiment the particulate matter (gravel) in the slurry has
an average particle size between about 40160 mesh - 12120 mesh, although other sizes may be used. Slurry dehydration occurs when the carrier fluid leaves the slurry. The carrier fluid can leave the slurry by way of the perforations 18 and enter the formation 14. The carrier fluid can also leave the slurry by way of the screen elements 28 and enter the tubular member 5 22. The carrier fluid flows up through the tubular member 22 until the cross-over 26 places it in the annulus area 36 above the production packer 24 where it can leave the wellbore 10 at the surface. Upon slurry dehydration the gravel grains should pack tightly together. The final gravel filled annu!us area is referred to as a gravel pack. The Annular areas 38 adjacent to the screen elements 28 are locations of particular need for tightly packed gravel placement.
lo As used herein, the term "screen" refers to wire wrapped screens, mechanical type screens and other filtering mec!h-anism-c t,voically employed with sand screens. Sand screens need to be have openings small enough to restrict gravel flow, often having gaps in the 60 120 mesh range, but other sizes may be used. The screen element 28 can be referred to as a sand screen. Screens of various types are produced by US Filter/Johnson Screen, among 15 others, and are commonly known to those skilled in the art.
It is often desirable to spot fluids within the wellbore after a gravel pack completion.
These fluids may be corrosion inhibitors placed in the wellbore for the protection of certain components, especially if the well will not be produced until a later time. Another common requirement is to spot breakers across the producing formation. These breakers will assist in 20 the cleaning and removal of the fiber cake residue that is ieIr on the formation face. The removal of the filter cake is required if the full productive capacity of the producing formation is to be obtained. Typically, once the gravel pack operation is completed, the work string is removed from the well and a string of coiled tubing is run into the well. The fluids are spotted and possibly the wellbore is circulated to remove any completion contaminants or 25 filter cake residue. The coiled tubing is then removed from the well and the production tubing is run into the well.
The apiJala+.us allows normal +uhing-annulus circulation as the gravel pack assembly is run into the well. This initial circulation is sometimesneeded if the wellbore has any fill, requiring the circulation of the wellbore to wash the fill out. This is known as washing the so gravel pack assembly down the well.
Once the assembly is in the proper location, the tool is reconfigured to allow circulation from the tubing to be directed to the annulus area 34 adjacent to the sand screens 28. The carrier fluid from the gravel pack slurry is able to pass through the sand screens 28
into the bore of the well tool 22 where it travels upwards until it is redirected to the annulus area 36 above the packer 24 and can be circulated out of the wellbore 10.
After the gravel pack operation is finished, the apparatus is reconfigured to close off the crossover ports 26 and allow the circulation of the tubing and annulus through the well 5 tool 22. The packer 24 can be released and the well tool 22 disengaged from the sand screen assembly, in this way the wellbore can be circulated and fluids spotted during the same trip in the hole as the gravel pack operation.
Figures 2A-E illustrate one embodiment of the present invention in its different configurations. lo The initial configuration that is used for running into the wellbore 10, and for washing down if necessary, is shown in Figure 2A. The present invention is shown generally as a well tool 20 comprising a housing 40 having a longitudinal bore 42 and a lateral port 44 through its wall. A first sleeve 46 is disposed within the housing 40 and is in sliding contact with the housing 40. It is capable of being in an upper and lower position relative to the housing 40.
15 In Figure 2A, the first sleeve 46 is shown in its upper position. The first sleeve 46 contains a first lateral passageway 48 that is aligned with the lateral port 44 when the first sleeve 46 is in its upper position. The first sleeve 46 also comprises a second lateral passageway 50 and can be releasably secured in the upper position by a first sleeve retaining element 52.
A second sleeve 54 is disposed within the first sleeve 46 and contains a ball seating to element 56. The second sleeve 54 is in sliding contact with the first sleeve 46 and is movable between an upper position and a lower position relative to the first sleeve 46. In Figure 2A the second sleeve is shown in its upper position. The second sleeve 54 can contain a retaining element 58 that secures the second sleeve 54 in its upper position. In its upper position the second sleeve 54 blocks off the fluid communication through the lateral port 44 25 and the first lateral passageway 48.
A third sleeve 60 is disposed within the first sleeve 46 and contains a ball seating element 62. The third sleeve 60 is in sliding contact with the first sleeve 46 and is movable between an upper position and a lower position relative to the first sleeve 46. The third sleeve 60 can contain a retaining element 64 that releasably secures the third sleeve 60 in its so upper position. In its upper position the third sleeve 60 blocks off the fluid flow through the second lateral passageway 50.
The retaining elements 52, 58, 64, used to secure the sleeves in the initial upper positions can take the form of a shear element that will break upon a known force being exerted and release the sleeve which it retains. They could likewise take the form of a
retaining spring or any other retaining element that is releasable. Nume. ous different designs are known in the art.
A first flow passage 65 is located within the housing 40 and provides fluid communication between the longitudinal bore 42 below the lateral port 44 and the exterior of 5 the housing 40 above the lateral port 44.
A second flow passage 68 is located within the housing 40 and provides fluid communication between the longitudinal bore 42 below the lateral port 44 and the exterior of the housing 40 below the lateral port 44.
A ported collet 74 is shown at the end of the well tool 20 and is used to prevent the lo first sleeve from sliding back to its original position. Other methods of connecting the tool 20 with other attachments can work en,,ally as well In the initial configuration as shown in Figure 2A, fluid can flow through the longitudinal bore of the housing 42 and through any attachments such as a gravel pack screen assembly. The fluid can then be returned through the annulus area between the well tool 20 15 and the wellbore wall or casing.
Figure 2B shows the embodiment of the invention as in Figure 2A with the addition of a first ball 70 that is sized to pass through the third sleeve ball seating element 62 and seat in the second sleeve ball seating element 56. In this configuration, fluid communication through the longitudinal bore 42 of the tool 20 is restricted. An increase in pressure above so the Orson ball 7v will apply force onto me second sleeve retaining element;8. II SUIIICient force is applied to overcome the second sleeve retaining element 58, then the second sleeve 54 can move from its upper position to its lower position.
Balls used in conjunction with ball seating elements are well known and widely used in the art. When referring to a ball seating "in" or "within" a ball seating element, it is meant 25 that the ball and ball seating element form a seating or sealing relationship that will restrict fluid flow through the bore of the ball seating element. This term is not meant to mean that the ball need be testily enclosed within the seating elerne. n.t. The ball may and typically Will be partially enclosed within the ball seating element. The illustration shown in Figure 2D is where the second ball 72 is seated with the first sleeve ball seating element 78.
?,0 Figure 2C shows the second sleeve 54 shifted into its lower position after the release of the second sleeve retaining element 58. The second sleeve 54 is no longer blocking passage through the lateral port 44 and the first lateral passageway 48. The first ball 70 that is seated in the second sleeve 54 is restricting fluid flow through the longitudinal bore 42. In this configuration fluid will pass down the longitudinal bore 42 of the tool 2O, will pass
through the first lateral passageway 48 of the first sleeve 46 and through the lateral port 44 of the housing 40. The fluid will then flow down the outside of the tool 20 and return up the longitudinal bore 42 of the tool 20 until it reaches the first flow passage 66. As shown in Figure 2C, the fluid will enter the first flow passage 66a below the second sleeve 54 and will 5 exit the first rDow passage 66b above line lateral port 44 and on the outside of the tool -0 above the packer 24. This configuration is used to perform a gravel pack operation to deposit gravel in the annulus area adjacent a screen element (as shown in Figure 1).
Al4ce. the grave' pack operation is complete, it is desired to reconfigure the tool and regain the ability to circulate in the normal tubing-annulus path. The present invention lo permits this reconfiguration and it is illustrated in Figures 2D and 2E.
ails shown in Figure 2n, a second ball 72 is i".seed Britain the!on, itudina! bore 42.
The second ball 72 seats within the ball seating element 62 of the third sleeve 60. In this configuration, fluid communication through the longitudinal bore 42 of the tool 20 is restricted. An increase in pressure above the second ball 72 will apply force onto the third 15 sleeve retaining element 64. If sufficient force is applied to overcome the third sleeve retaining element 64, then the third sleeve 60 can move from its upper position to its lower position. When the third sleeve 60 is in its lower position, it no longer blocks flow through the second lateral passageway 50 in the first sleeve 46. The second ball 72 seated within the ball seating element 62 of the third sleeve 60 will continue to restrict flow through the to longitudinal bore 42.:190 communication through the second lateral passageway:0 can be obtained while the first sleeve 46 is in its upper position, since the second lateral passageway is not aligned with any of the flow passages. Additional pressure exerted on the longitudinal bore 42 above the second ball 72 will apply force onto the first sleeve retaining element 52.
If sufficient force is applied to overcome the first sleeve retaining element 52, then the first 25 sleeve 46 can move from its upper position to its lower position. This sequence of shifting the third sleeve 60 prior to shifting the first sleeve 46 can be reversed and the first sleeve 46 can 'ue shifted prior- to tl,e shifting of the thi. d sleeve '0.
Figure 2E shows the tool 20 in the final configuration having all three sleeves 46, 54, 60 in their lower positions. In this configuration, the first sleeve 46-blocks the lateral port 44 ^,o and the first flow passage 66. The second lateral passageway 50 is aligned with the second flow passage 68 providing communication between the longitudinal bore 42 above the second ball 72 and the longitudinal bore 42 below the first ball 70. This configuration allows the circulation of fluid down the longitudinal bore 42, around the first ball 70 and second ball 72 by way of the second flow passage 68, and down through any other attachments to the well
tool 20. The final shifting of the first sleeve 46 into its lower position can result in the projection of a portion of the second sleeve 54 through the ported collet 74. Once all three sleeves 46, 54, 60 are in their lower positions, the wellbore can be circulated, breakers and other fluids spotted, and the well tool 20 pulled from the well.
5 Figures 3A-E illustrate an alternate embodiment of the present invention in its different configurations.
The initial configuration that is used for running into the wellbore 10, and for washing down if necessary, is shown in Figure 3A. The present invention is shown generally as a well tool 20 comprising a housing 40 having a longitudinal bore 42 and a lateral port 44 through lo its wall. A first sleeve 46 is disposed within the housing 40 and is in sliding contact with the housing 40. It is capable of being in an upper and lower position relative to the housing 40 and comprises a ball seating element 78. In Figure 3A, the first sleeve 46 is shown in its upper position. The first sleeve 46 contains a first lateral passageway 48 that is aligned with the lateral port 44 when the first sleeve 46 is in its upper position. The first sleeve 46 also 15 comprises a second lateral passageway 50 and can be secured in the upper position by a first sleeve retaining element 52. In the embodiment shown the first sleeve 46 also comprises a third lateral passageway 76, that is initially aligned with the first flow passage 66.
A second sleeve 54 is disposed within the first sleeve 46 and contains a ball seating element 56. The second sleeve 54 is in sliding contact with the first sleeve 46 and is movable 20 between an upper position and a lower position relative to the first sleeve 46. In Figure 3A the second sleeve is shown in its upper position. The second sleeve 54 can contain a retaining element 58 that releasably secures the second sleeve 54 in its upper position. In its upper position the second sleeve 54 blocks off the fluid communication through the lateral port 44 and the first lateral passageway 48.
25 The retaining elements 52, 58 used to secure the sleeves in the initial upper positions can take the form of a shear element that will break upon a known force being exerted and release the sleeve which it retains. They could likewise take the form of a retaining spring or any other retaining element that is releasable. Numerous different designs are known in the art. so A first flow passage 66 is located within the housing 40 and provides fluid communication between the longitudinal bore 42 below the lateral port 44 and the exterior of the housing 40 above the lateral port 44.
A second flow passage 68 is located within the housing 40 and provides fluid communication between the longitudinal bore 42 below the lateral port 44 and the exterior of the housing 40 below the lateral port 44.
A ported collet 74 is shown at the end of the well tool 20 and can be used to connect the tool 20 to other attachments, such as a gravel pack screen assembly. Other methods of connecting the tool 20 with other attachments can work equally as well.
In the initial configuration as shown in Figure 3A, fluid can flow through the longitudinal bore of the housing 42 and through any attachments such as a gravel pack screen assembly. The fluid can then be returned through the annulus area between the well tool 20 lo and the wellbore wall or casing.
Figure 3B shows the embodiment of the invention as in Figure 3A with the addition of a first ball 70 that is sized to pass through the first sleeve bal] seating element 78 and seat in the second sleeve ball seating element 56. In this configuration, fluid communication through the longitudinal bore 42 of the tool 20 is restricted. An increase in pressure above 15 the first ball 70 will apply force onto the second sleeve retaining element 58. If sufficient force is applied to overcome the second sleeve retaining element 58, then the second sleeve 54 can move from its upper position to its lower position.
Figure 3C shows the second sleeve 54 shifted into its lower position after the release of the second sleeve retaining element 58. The second sleeve 54 is no longer blocking :e passage through the lateral pole 44 arid Me first lateral passageway 4O. The first ball 70 that is seated in the second sleeve 54 is restricting fluid flow through the longitudinal bore 42. In this configuration fluid will pass down the longitudinal bore 42 of the tool 20, will pass through the first lateral passageway 48 of the first sleeve 46 and through the lateral port 44 of the housing 40. The fluid will then flow down the outside of the tool 20 and return up the 25 longitudinal bore 42 of the tool 20 until it reaches the first flow passage 66. As shown in Figure 3C, the fluid will enter the first flow passage 66a below the second sleeve 54 and will flow through the first flo.x. passage 66b above the lateral port 44 and can he exited on the outside of the tool 20. This configuration is used to perform a gravel pack operation to deposit gravel in the annulus area adjacent a screen element (as shown in Figure 1).
so The gravel pack carrier fluid can comprise acids, oxidizers and other breakers or specialty fluids that may be useful in the completion of a productive formation, such as in removal of a filtercake. U.S. Patent 6, 140,277 discloses well completion fluids and methods that can be used to remove wellbore damage and near-wellbore damage such as filtercake removal. When these breakers are used as the carrier fluid for the gravel pack, they often
need to be displaced or completely removed from the well due to their potentially corrosive nature. This would especially be of concern where these fluids are located adjacent to downhole equipment that could be damaged by the corrosive action of the fluids. The term filtercake is meant to refer to the wellbore damage and near-wellbore damage in the form of a 5 coating formed from drilling and production related operations.
ADrer the gravel pack operation is complete it is desired to reconfigure the tool and regain the ability to circulate in the normal tubing-annulus manner. The present invention perrr.its this and is illustrated in Figures 3D and E. As shown in Figure 3D, a second ball 72 is inserted within the longitudinal bore 42.
lo The second ball 72 seats within the ball seating element 78 of the first sleeve 46. In this configuration, fluid communication through the longitudinal bore 42 of the tool 20 is restricted. An increase in pressure above the second ball 72 will apply force onto the first sleeve retaining element 52. If sufficient force is applied to overcome the first sleeve retaining element 52, then the first sleeve 46 can move from its upper position to its lower 15 position. Figure 3E shows the tool 20 in the final configuration having both first sleeve 46 and second sleeve 54 in their lower positions. In this configuration, the first sleeve 46 blocks the lateral port 44 and the first flow passage 66. The second lateral passageway 50 is aligned with the second flow passage 68 providing communication between the longitudinal bore 42 so above the second bail 72 and the iongiudina; bore 42 below the first ball 70. This configuration allows the circulation of fluid down the longitudinal bore 42, around the first ball 70 and second ball 72 by way of the second flow passage 68, and down through any other attachments to the well tool 20. The final shifting of the first sleeve 46 into its lower position can result in the projection of a portion of the first sleeve 46 through the ported collet 25 74, which can release the well tool 20 from other attachments, such as the gravel pack screen assembly. Once released from the lower attachments the wellbore can be circulated, specialty fluids such as breakers, acids or ccrrcsicn. inhibitors can be spotted. Spotting fluids is a term used to describe the placement of fluids in desired locations within the wellbore or adjacent to specific well tools. The well tool 20 can then be pulled from the well.
so The discussion and illustrations within this application refer to a vertical wellbore that has casing cemented in place and comprises casing perforations to enable communication between the wellbore and the productive formation. The present invention can also be utilized to complete wells that are not cased and likewise to wellbores that have an orientation that is deviated from vertical.
The particular embodiments disclosed herein are illustrative only, as the invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction, operation, materials of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular embodiments disclosed above may be altered or modified and all such variations are considered within the scope of the invention. Accordingly, the invention is therefore to be limited only by the scope of the following claims.
Claims (15)
1. A well completion method performed in a single trip into a well; the method comprising: 5 inserting a service tool into the well to a desired location; gravel packing the well; and circulating fluids within the wellbore through the service tool to dislodge and remove filter cake residue.
lo
2. The method of claim 1, wherein the gravel packing of the well comprises flowing a gravel laden slurry through the service tool, thereby selectively depositing gravel within the well.
3. The method of claim 1, wherein the service tool defines multiple, selectable flow i5 paths.
4. The method of claim 3, wherein the service tool is inserted into the well in a first flow path configuration allowing circulation through the service tool.
to
5. The method of clai... A, wherein Then the ser v ice tool has been i se.-ed to the desired location, the service tool is reconfigured to a second flow path configuration to enable the gravel packing of the well.
6. The method of claim 5, wherein after the well has been gravel packed, the service tool 25 iS reconfigured to a third flow path configuration to enable the circulation of fluids within the wellbore, through the service tool, to dislodge and remove filter cake residue.
7. The method of claim 6, wherein after the circulation of fluids to dislodge and remove so filter cake residue, specialty fluids are spotted at selected locations within the well.
8. A method of completing a subterranean well performed in a single trip into a wellbore, the method comprising:
running a service tool into the wel!, the service tool defining multiple, selectable flow paths; gravel packing the well; selecting a different flow path of the service tool; 5 removing a filter cake from the wellbore by circulating a fluid through the service tool; spotting specialty fluids within the wellbore at desired locations; and removing the service tool from the well.
lo
9. The method of claim 8, wherein the gravel packing of the well comprises flowing a gravel laden slurry through the service tool, thereby selectively depositing gravel within the wellbore.
l O. The method of claim 9, wherein the service tool is inserted into the well in a first flow 15 path configuration allowing fluid circulation through the service tool.
11. The method of claim 10, wherein when the service tool has been inserted to the desired location, the service tool is reconfigured to a second flow path configuration to enable the gravel packing of the well.
12. A well completion method performed in a single trip into a well, the method comprlsmg: inserting a service tool into the well to a desired location; gravel packing the well with a fluid that contains at least one breaker for filtercake 25 removal; and circulating or injecting fluids within the well through the service tool to displace the at least one breaker away from predetermined downhole equipment.
13. The method of claim 12, wherein the service tool is inserted into the well in a first so flow path configuration allowing fluid circulation through the service tool.
14. The method of claim 12, wherein when the service tool has been inserted to the desired location, the service tool is reconfigured to a second flow path configuration to enable the gravel packing of the well.
15. The method of claim 12, wherein when the gravel packing of the well has been performed, the service tool is reconfigured to a third flow path configuration to enable the circulating of fluids through the service tool.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US18320000P | 2000-02-17 | 2000-02-17 | |
| US09/782,701 US6571875B2 (en) | 2000-02-17 | 2001-02-13 | Circulation tool for use in gravel packing of wellbores |
| GB0218203A GB2377242B (en) | 2000-02-17 | 2001-02-14 | Circulation tool for use in gravel packing of wellbores |
Publications (3)
| Publication Number | Publication Date |
|---|---|
| GB0401595D0 GB0401595D0 (en) | 2004-02-25 |
| GB2396637A true GB2396637A (en) | 2004-06-30 |
| GB2396637B GB2396637B (en) | 2004-08-11 |
Family
ID=32397648
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| GB0401595A Expired - Fee Related GB2396637B (en) | 2000-02-17 | 2001-02-14 | Methods for use in gravel packing of wellbores |
Country Status (1)
| Country | Link |
|---|---|
| GB (1) | GB2396637B (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB2522264A (en) * | 2014-01-21 | 2015-07-22 | Swellfix Bv | Sliding Sleeve Tool |
Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4621692A (en) * | 1985-03-28 | 1986-11-11 | Texas United Chemical Corp. | Water soluble perforation pack |
| US5355956A (en) * | 1992-09-28 | 1994-10-18 | Halliburton Company | Plugged base pipe for sand control |
| WO2000008112A1 (en) * | 1998-08-03 | 2000-02-17 | Tetra Technologies, Inc. | Bromate/bromine filtercake removal fluid |
| WO2002025058A1 (en) * | 2000-09-20 | 2002-03-28 | Sofitech N.V. | Method for gravel packing open holes above fracturing pressure |
-
2001
- 2001-02-14 GB GB0401595A patent/GB2396637B/en not_active Expired - Fee Related
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4621692A (en) * | 1985-03-28 | 1986-11-11 | Texas United Chemical Corp. | Water soluble perforation pack |
| US5355956A (en) * | 1992-09-28 | 1994-10-18 | Halliburton Company | Plugged base pipe for sand control |
| WO2000008112A1 (en) * | 1998-08-03 | 2000-02-17 | Tetra Technologies, Inc. | Bromate/bromine filtercake removal fluid |
| WO2002025058A1 (en) * | 2000-09-20 | 2002-03-28 | Sofitech N.V. | Method for gravel packing open holes above fracturing pressure |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB2522264A (en) * | 2014-01-21 | 2015-07-22 | Swellfix Bv | Sliding Sleeve Tool |
Also Published As
| Publication number | Publication date |
|---|---|
| GB2396637B (en) | 2004-08-11 |
| GB0401595D0 (en) | 2004-02-25 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PCNP | Patent ceased through non-payment of renewal fee |
Effective date: 20170214 |