Key information

Title
A well tool device and a method for temporary well isolation
Application number
20231373
Case type
National
Status
01.06.2026 Patent meddelt (B1)
Filed
20.12.2023
Effective date
20.12.2023
Publicly available
23.06.2025
Next annual fee due
31.12.2026
Applicant
SBS Technology AS (NO)
Owner
SBS Technology AS (NO)
Inventor
Jan Tore Tveranger (NO)
Agent
BRYN AARFLOT AS (NO)
Granted
01.06.2026
Patent number
349874
Expiry date
20.12.2043

Abstract and drawing

Disclaimer: This text has been machine-scanned and may contain errors – please refer to "Publications" for legally binding content.
A well tool device (10) comprising a tubular housing (12) with a first house part (12a) and a second house part (12b), said tubular housing (12) having a through running boring (14). A first barrier comprising a solid first glass disc (16) is closing off the through running boring (14) upstream in the tubular housing (12). A second barrier comprising a solid second glass disc (18) is closing off the through running boring (14) downstream in the tubular housing (12), wherein said first and second glass discs (16,18) are axially displaced from each other, with an atmospheric chamber (40) provided therebetween, and the first glass disc (16) is arranged to be shattered by applying a first hydraulic pressure and the second glass disc (18) is arranged to be shattered by applying a second hydraulic pressure, wherein said second hydraulic pressure is less than said first hydraulic pressure.

Publications

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Documents

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Date
 Date Doc. No. Process Case number In/Out Journal description To/from
 01.06.2026 13-01 Saksbehandling 20231373(349874) UT PT Registreringsbrev nasjonal patent (15) (PT20231373)
25.03.2026 12-01 Saksbehandling 20231373 UT PT Meddelelse om patent BRYN AARFLOT AS
 23.03.2026 11-02 Saksbehandling 20231373 INN 149196NO_Patentkrav_NO BRYN AARFLOT AS
 23.03.2026 11-01 Saksbehandling 20231373 INN Korrespondanse (Hovedbrev inn) BRYN AARFLOT AS
 11.03.2026 10-01 Saksbehandling 20231373 UT Generelt Brev Patent BRYN AARFLOT AS
29.01.2026 02-01 Endring av fullmektig 2026/00648 UT GH Forespørsel BRYN AARFLOT AS
27.01.2026 01-02 Endring av fullmektig 2026/00648 INN Generalfullmakt Bryn Aarflot AS BRYN AARFLOT AS
27.01.2026 01-01 Endring av fullmektig 2026/00648 INN Generell henvendelse BRYN AARFLOT AS
 26.11.2025 09-06 Saksbehandling 20231373 INN P34289NO00 Svar på realitetsuttalelse og anmodning om godkjenning ACAPO ONSAGERS AS
 26.11.2025 09-05 Saksbehandling 20231373 INN P34289NO00 Reviderte patentkrav på norsk ACAPO ONSAGERS AS
 26.11.2025 09-04 Saksbehandling 20231373 INN P34289NO00 Revidert beskrivelse ACAPO ONSAGERS AS
 26.11.2025 09-03 Saksbehandling 20231373 INN P34289NO00 Revidert beskrivelse (merket) ACAPO ONSAGERS AS
 26.11.2025 09-02 Saksbehandling 20231373 INN P34289NO00 Fig 7-12 revidert ACAPO ONSAGERS AS
 26.11.2025 09-01 Saksbehandling 20231373 INN Korrespondanse (Hovedbrev inn) ACAPO ONSAGERS AS
 18.10.2025 08-01 Saksbehandling 20231373 UT Realitet patent ACAPO ONSAGERS AS
 14.10.2025 07-02 Saksbehandling 20231373 INN P34289NO00 Anmodning om ny uttalelse ACAPO ONSAGERS AS
 14.10.2025 07-01 Saksbehandling 20231373 INN Korrespondanse (Hovedbrev inn) ACAPO ONSAGERS AS
 13.11.2024 06-04 Saksbehandling 20231373 INN P20813NO00 Reviderte patentkrav - ren ACAPO AS
 13.11.2024 06-03 Saksbehandling 20231373 INN P20813NO00 Reviderte patentkrav - markert ACAPO AS
 13.11.2024 06-02 Saksbehandling 20231373 INN P20813NO00 besvarelse til Patentstyret ACAPO AS
 13.11.2024 06-01 Saksbehandling 20231373 INN Korrespondanse (Hovedbrev inn) ACAPO AS
 25.06.2024 05-02 Saksbehandling 20231373 UT PT report 03:17:45
25.06.2024 05-01 Saksbehandling 20231373 UT Realitet patent ACAPO AS
 30.01.2024 04-02 Saksbehandling 20231373 INN P20813NO00 Overdragelse_Signert ACAPO AS
 30.01.2024 04-01 Saksbehandling 20231373 INN Korrespondanse (Hovedbrev inn) ACAPO AS
 22.12.2023 03-01 Saksbehandling 20231373 UT Formalia 1 ACAPO AS
 22.12.2023 02-01 Saksbehandling 20231373 UT Informasjon til oppfinner Jan Tore Tveranger
 20.12.2023 01-04 Saksbehandling 20231373 INN P20813NO00 patentsøknad ACAPO AS
 20.12.2023 01-03 Saksbehandling 20231373 INN P20813NO00 figurer ACAPO AS
 20.12.2023 01-02 Saksbehandling 20231373 INN Generell_Fullmakt_signert ACAPO AS
 20.12.2023 01-01 Saksbehandling 20231373 INN Søknadsskjema Patent ACAPO AS

Description, claims and drawings

Disclaimer: This text has been machine-scanned and may contain errors – please refer to "Publications" for legally binding content. Description
3498741A well tool device and a method for temporary well isolationField of the inventionThe present invention relates to a well tool device comprising a tubular housing with 5 a first house part and a second house part, said tubular housing having a through running boring. The invention also relates to a method for temporary well isolation during a well completion phase.The present invention relates to a well tool device for temporary well isolation during 10 well completion phase. Typical activities are pressure test and packer setting.Background of the inventionIn different types of well operations, it is a need for well tool devices providing a temporary isolation of a tubing or casing string during well completion activities. A 15 common solution is a frangible plug configured to break at a given differential pressure across the plug, in example 5000 psi (35 MPa). In example if there are a hydrostatic pressure on both sides of the plug i.e., 3000 psi (20,7 MPa), the differential pressure is zero across the plug. If pressure at wellhead/surface is increased to i.e., 5000 psi (34,5 MPa), the pressure above the plug will be 8000 psi 20 (55,2 MPa), and the differential pressure across the plug will be 5000 psi (34,5 MPa), at this point the plug will activate and open.In some cases, there can be overbalance across the plug. I.e., 5000 psi (34,5 MPa) above the plug, and i.e.4000 psi (27,6 MPa) below the plug. If the breaking pressure 25 across the plug is set to 5000 psi (34,5 MPa), the well head pressure must be increased to 4000 psi (27,6 MPa) to break the plug. This can be a problem if it is required to pressure test the well to 4500 psi (31,0 MPa). The plug will break before test pressure level is reached.30 In some cases, there can be underbalance across the plug. I.e., 4000 psi (27,6 MPa) above the plug, and i.e.5000 psi (34,5 MPa) below the plug. If the breaking pressure across the plug is set to 5000 psi (34,5 MPa), the well head pressure must be increased to 6000 psi (41,4 MPa) to break the plug. This can be a problem if the wellhead equipment has a pressure limitation of i.e., 5000 psi (34,5 MPa), the 35 pressure limitation is reached before the required differential pressure across the plug is reached, and the plug cannot be activated. 3498742Disclosure of the state of artBarrier valves are known that isolates wellbore reservoir pressure utilizing two internal barrier devices. For instance, can a sub be run on the bottom of the tubing and/or below a packer BHA to isolate the tubing and act as a barrier to set hydraulic 5 set packers. After all tests are performed, the barriers are knocked out using a drop bar, coiled tubing, slickline, or sand line. Once the barriers are removed, the wellbore fluids can then be produced up the production tubing.Barriers that separate tubing and wellbore fluids when running tubing and completion 10 BHAs is also known, wherein internal burst discs are designed to withstand high differential pressure before being removed.WO2019/083376 A1 discloses a well tool device comprising a housing with a breakable ball seat, wherein a drop ball received in the ball seat partially or fully 15 closes fluid communication in the through channel of the housing. The breakable ball seat is made of brittle and/or tempered glass, and the ball seat is broken by a pressure build up in the housing forcing the ball seat against one or more disintegrating means provided as inside protrusions in the through channel.20 WO2020/117069 A1 discloses packer setting device comprising a tubular with a breakable plug seated in a load ring axially movable within the boring the tubular between a first position in where the plug is with a distance to a breaking pin and a second position in where the plug is forced against the breaking pin.25 US 2014/0083716 A1 describes an isolation tool having two oppositely directed halfspherical domes which may be made of glass. The domes are oriented so as for the upper dome to withstand much presure from above, but not from below, and the lower dome withstands much pressure from below, but little from above.Between the domes are a chamber which is in communication with the tubing above 30 the upper dome through a channel. The isolation tool is used to set a pressure-set packer in that the lower dome is so strong that one may pressure upp against it to set the packer. After the packer is set, the pressure is increased further and the lower dome is broken because it experiences the pressure from above the upper dome through the channel and withstands relatively little pressure from above. When 35 the lower dome is broken, one may reduce the pressure from above, so as for the reservoir pressure to break the upper dome which withstands little pressure from 3498743below. Several varieties are described, all with communication in to the chamber between the upper and lower dome, either from annulus or tubing.US 2014/0008085 A1 describes a plug with corresponding oppositely directed 5 domes but the domes are built from arch segments in pressure archs as in a stone bridge. The domes are covered by a rubber membrane in order to be fluid proof. As in the above cited document the dome may only withstand pressure in one direction. US 2011/0284242 A1 is similar to US 2014/0083716 A1 and also describes an 10 isolation tool having two oppositely directed half-spherical domes which may be made of glass. The domes are oriented so as for the upper dome to withstand much presure from above, but not from below, and the lower dome withstands much pressure from below, but little from above. Between the domes are a chamber which is in communication with the tubing above the upper dome through a channel.15Objects of the present inventionIt is an object of the invention to provide a well tool device having a tubular housing with a combination of two glass discs placed with some distance between them forming an atmospheric chamber. The atmospheric chamber below the upper disc, 20 will make the upper disc breaking pressure inert to any pressure present below the lower glass disc. This way, there is no need to consider if the system is over- or underbalanced to calculate the required break pressure.The lower glass disc will only need to hold pressure from below and can have a 25 break setting pressure from above at a low value compared to the upper one. As soon as the upper glass disc is broken, the second disc will be broken by the residual differential pressure from above.It is also an object to provide a method for temporary well isolation during a well 30 completion phase, particularly for use during pressure testing and packer setting.Summary of the inventionThe above objects are achieved withA well tool device (10) comprising a tubular housing (12) with a first house part (12a) 35 and a second house part (12b), said tubular housing (12) having a through running boring (14), wherein 3498744a first barrier comprising a solid first glass disc (16) is closing off the through running boring (14) upstream in the tubular housing (12),a second barrier comprising a solid second glass disc (18) is closing off the through running boring (14) downstream in the tubular housing (12),5 said first and second glass discs (16,18) are axially displaced from each other, withan atmospheric chamber (40) is provided between said first and second glass discs (16,18), andsaid first and second glass discs (16,18) are solid, frangible glass discs made 10 of brittle and/or tempered glass, whereinthe first glass disc (16) is resting on a first glass disc break mechanism (20) and is arranged to be shattered by applying a first hydraulic pressure and the second glass disc (18) is resting on a second glass disc break mechanism (30) and is arranged to be shattered by applying a second hydraulic pressure, wherein said second15 hydraulic pressure is less than said first hydraulic pressure.Alternative embodiments of the well tool device according to the invention are disclosed in the dependent claims.20 Said object are also achieved with a method for temporary well isolation during a well completion phase, comprising running in hole a well tool device as disclosed, wherein the method comprises the steps:- running a tubing or casing string including said well tool device into a borehole, providing temporary isolation with a hydrostatic pressure upstream the well tool 25 device equal to a reservoir pressure downstream the well tool device and with an atmospheric pressure between the first and second barrier in a chamber therebetween,- increasing pressure upstream the well tool device to a first high pressure higher than the hydrostatic pressure, and performing well completion activities in the 30 borehole,- decreasing pressure upstream the well tool device to a pressure lower than the hydrostatic pressure,- increasing pressure upstream the well tool device to a second high pressure higher than the first high pressure,35 - applying said second high pressure on the first barrier to shatter the first solid glass disc and allowing fluid communication into the atmospheric chamber, 3498745- applying residual differential pressure on the second barrier to shatter the second solid glass disc, and- open for fluid communication through the well tool device.5 Alternative embodiments of the method according to the invention are disclosed in the independent claims.Description of the figuresEmbodiments of the present invention will now be described, by way of example 10 only, with reference to the following figures, wherein:Figure 1 shows a well tool device according to the invention in a first state and as run in hole.Figure 2 shows the well tool device in a second state with a first barrier broken.15 Figure 3 shows the well tool device in a third state with a second barrier broken.Figure 4 shows an example of a first glass disc break mechanism. Figure 5 shows an example of a second glass disc break mechanism.Figure 6 shows a schematic example of a well.20 Figures 7-12 show operational examples of the well tool device according to the invention.Fig. 7 illustrates Phydr = 12000 psi (82.7 MPa) hydrostatic pressure above the upper plug (16), atmospheric pressure "0 psi" in the chamber (40), and Pres = 12000 psi (82.7 MPa) reservoir pressure below the lower plug (18). The pressure25 differential P across the upper plug (16) is 12000 psi (82.7 MPa). The pressure differential P across the lower plug (18) is 12000 psi (82.7 MPa).Fig. 8 illustrates Phydr Psurf 12000 psi (82.7 MPa) hydrostatic pressure plus 4000 psi (27,6 MPa) applied from surface = 16000 psi (110.3 MPa), and 0 psi in the 30 chamber (40), and Pres = 12000 psi (82.7 MPa) reservoir pressure below the lower plug (18). The pressure differentialP across the upper plug (16) is 16000 psi (110.3 MPa). The pressure differentialP across the lower plug (18) is 12000 psi (82.7 MPa), upward.Fig. 9 illustrates P = 8000 psi (55.2 MPa) above the upper plug (16), the 35 pressure 0 psi in the chamber (40), and 12000 psi (82.7 MPa) reservoir pressure below the lower plug (18). ). The pressure differentialP across the upper plug (16) 3498746is 8000 psi (55.2 MPa). The pressure differentialP across the lower plug (18) is 12000 psi (82.7 MPa), upward.Fig. 10 illustrates Phydr Psurf 8000 psi (55.2 MPa) hydrostatic pressure plus 10000 psi (68.9 MPa) applied from surface = 18000 psi (124.1 MPa), and 0 psi in the 5 chamber (40), and Pres = 12000 psi (82.7 MPa) reservoir pressure below the lower plug (18). The pressure differentialP across the upper plug (16) is 18000 psi (124.1 MPa). The pressure differential pressure P across the lower plug (18) is 12000 psi (82.7 MPa), upward.Fig. 11 illustrates Phydr Psurf 8000 psi (55.2 MPa) hydrostatic pressure plus 10 10000 psi (68.9 MPa) applied from surface = 18000 psi (124.1 MPa), and the upper plug (16) is broken. The Pres = 12000 psi (82.7 MPa) reservoir pressure below the lower plug (18), and the differential pressureP across the lower plug (18) is 6000 psi (41.4 MPa), downward.Fig. 12 illustrates that the housing (12) is open.15Description of preferred embodiments of the inventionThe present invention relates to a well tool device 10. The well tool device comprises 20 a tubular housing 12, or sleeve, with an axial through running boring 14. In different types of well operations, it is a need for well tool devices to provide a temporary isolation of a tubing or casing string during well completion activities. The well tool device 10 according to the invention will provide such temporary isolation of the tubing or casing string 62.25Hence, in order to provide said temporary isolation, the well tool device 10 comprises a first and a second barrier in the through running boring 14 of the tubular housing 12. The first and second barriers are preferably a first solid glass disc 16 and a second solid glass disc 18.30Fig. 6 shows schematically a subsea or subterrain well with a wellhead 60 and a borehole 68. A production tubing 62, with one or more well tool devices 10 according to the invention, extends from the wellhead 60 and into a reservoir 66 for production of oil and gas. Packers 64 are placed in the annulus surrounding the production 35 tubing 62 in the borehole 68. The well tool device 10 with the first solid glass disc 16 creating the first barrier and the second solid glass disc 18 creating the second barrier closes off fluid communication in the production tubing 62, and a chamber 40 3498747with atmospheric pressure is provided between said first and second glass discs 16,18. Operational examples of the well tool device is explained in relation to fig.7-12.5 Fig. 1 shows the well tool device 10 in a first state when run in hole (RIH) with both first and second glass discs 16,18 intact. Fig.2 shows that pressure has been applied and that the first solid glass disc 16 has been shattered or broken. Fig.3 shows that the second solid glass disc 18 has been shattered or broken. The applied pressures shall be explained later.10The tubular housing 12 comprises an upper or first house part 12a and a lower or second house part 12b. The two house parts 12a,12b are in a known way threaded and screwed to each other, and packers are used to seal of the through running boring 14. Similarly, the first and second glass discs 16,18 are circumferentially 15 enclosed by packers to prevent any fluid flow past the discs.The first glass disc 16 is accommodated in the first house part 12a. The second glass disc 18 is also accommodated in the first house part 12a. More specifically, the second glass disc 18 is supported in a fixed carrier or support sleeve 42 in a lower 20 part of the first house part 12a, and with one side facing the second house part 12b.However, the second glass disc 18 could possibly be arranged in the second house part 12b.The first and second glass discs 16,18 are frangible glass discs made of brittle 25 and/or tempered glass. The glass discs 16,18 can basically have similar shape and design, but with different pressure or shear resistance. Both glass discs 16,18 have a flat side and an opposing side with chamfered side edges.The first glass disc 16 is resting on a first glass disc break mechanism 20 in the first 30 house part 12a. The first glass disc 16 is supported in the through running boring 14 between a shoulder 50 in an inner wall 14a of the first house part 12a and the first glass disc break mechanism 20. The flat side of the first glass disc 16 is facing and supported against the shoulder 50, i.e., facing upstream in the through running boring 14, while the opposing side with the chamfered side edges is facing and 35 supported by the first glass disc break mechanism 20. 3498748The second glass disc 18 is resting on a second glass disc mechanism 30, and the second glass disc 18 is supported in the through running boring 14 between the support sleeve 42 and the second glass disc break mechanism 30. The flat side of the second glass disc 18 is facing and supported on the second glass disc break 5 mechanism 30, i.e., facing downstream in the through running boring 14, while the opposing side with chamfered side edges is facing and supported against the support sleeve 42. Hence, the support sleeve 42 has a similar chamfered edge 52 as the second glass disc 18.10 The support sleeve 42 is fixed in a lower part of the first house part 12a, and the chamfered edge 52 of the support sleeve 42 is facing an upper part of the second house part 12b.The first and second glass disc break mechanisms 20,30 are shown in more detail in 15 figures 4 and 5. It should be noted that, as an alternative to what is shown in the enclosed drawings, it is possible to use two glass disc break mechanisms of the first type 20, or to use two glass disc break mechanisms of the second type 30.The first glass disc break mechanism 20 is shown in more details in fig.4, and 20 comprises in the shown embodiment a load ring 24 supporting the first glass disc 16.The load ring 24 has a similar chamfered edge 54 as the first glass disc 16. The load ring 24 is axially movable within the through running boring 14 of the tubular housing 12 between a first position in where the first glass disc 16 is with a distance to a breaking pin 22 and a second position in where the first glass disc 16 is forced 25 against the breaking pin 22. The second position will occur after build-up of sufficient pressure.The load ring 24 is further resting on a shear ring 26 with an annular shear lip 26a to prevent axial movement in the first position until the shear lip 26a is subjected to a 30 force higher than a predetermined force. The annular shear lip 26a of the shear ring 26 extends radially inward in the through running boring 12. The breaking pin 22 is resting on the shear ring 26, and the breaking pin 22 is accommodated in a pocket on an outside of the load ring 24. The shear ring 26 can as shown be resting on the support sleeve 42.35The second glass disc break mechanism 30 is shown in more details in fig.5, and comprises in the shown embodiment one or more break pins 32 for shattering the 3498749second glass disc 18 when the second glass disc 18 is pushed axially by the hydraulic pressure. The break pins 32 are facing the flat underside of the second glass disc 18. The break pins 32 are embedded axially in an inner wall 14b of the upper part of the second house part 12b. However, the break pins 32 could possibly 5 also protrude radially inwards in the through running boring 14.The method and operational examples with pressures shall now be explained with help av fig.7-12.10 In fig.7 the well tool device 10 is run in hole as disclosed previously, by running the tubing or casing string 62 including said well tool device 10 into the borehole 68, providing temporary isolation with a hydrostatic pressure upstream the well tool device 10 equal to a reservoir pressure downstream the well tool device 10 and with atmospheric pressure between the first and second barrier in the chamber 40.15The upstream hydrostatic pressure is for instance 12000 psi (82,7 MPa) and the downstream reservoir pressure is equally 12000 psi (82,7 MPa).Fig. 8 shows a well completion activity in the borehole 68 prior to open the first and 20 second barrier, such as setting packers 64. Other activities can for instance be performing pressure tests.After running the well tool 10 in hole, the pressure upstream the well tool device 10 is increased to a first high pressure by applying for instance 4000 psi (27,6 MPa) from 25 surface. The first high pressure is higher than the hydrostatic pressure.Thereafter, as shown in fig.9, the pressure upstream the well tool device 10 is decreased to a pressure lower than the hydrostatic pressure. This can for instance be done by displacing to a lighter fluid. The decreased pressure can for instance be 30 8 000 psi (55,2 MPa), while the reservoir pressure is still at 12000 psi (82,7 MPa).In order to open the first barrier, i.e., the first glass disc 16, as shown in fig.10, pressure upstream the well tool device 10 is increased to a second high pressure that is higher than the first high pressure, wherein the second high pressure on the 35 first barrier is used to shatter the first solid glass disc 16 and thus allowing fluid communication into the atmospheric chamber 40. The second high pressure can for instance be 18 000 psi (124,1 MPa) (8000 psi (55,2 MPa) plus 10000 psi (68,9 34987410MPa) applied from the surface). The reservoir pressure is still at 12000 psi (82,7 MPa).After the first glass disc 16 is shattered, the residual differential pressure on the 5 second barrier is used to shatter the second solid glass disc 18, as shown in fig.11.andAs shown in fig.12, the production tubing 62 is open for fluid communication through the well tool device 10 after the first barrier and the second barrier are opened.10
Claims
34987411Claims1. A well tool device (10) comprising a tubular housing (12) with a first house part (12a) and a second house part (12b), said tubular housing (12) having a through 5 running boring (14), whereina first barrier comprising a solid first glass disc (16) is closing off the through running boring (14) upstream in the tubular housing (12),a second barrier comprising a solid second glass disc (18) is closing off the through running boring (14) downstream in the tubular housing (12),10 said first and second glass discs (16,18) are axially displaced from each other, with an atmospheric chamber (40) provided therebetween, andthe first glass disc (16) is arranged to be shattered by applying a first hydraulic pressure and the second glass disc (18) is arranged to be shattered by applying a second hydraulic pressure, wherein said second hydraulic pressure is less than said 15 first hydraulic pressure.2. The well tool device (10) according to claim 1, wherein the first glass disc (16) is resting on a first glass disc break mechanism (20).20 3. The well tool device (10) according to claim 2, wherein the first glass disc (16) is supported in the through running boring (14) between a shoulder (50) on an inner wall (14a) of the first house part (12a) and the first glass disc break mechanism (20).4. The well tool device (10) according to claim 1, wherein the second glass disc 25 (18) is resting on a second glass disc break mechanism (30).5. The well tool device (10) according to claim 4, wherein the second glass disc (18) is supported in the through running boring (14) between a support sleeve (42) and the second glass disc break mechanism (30).306. The well tool device (10) according to claim 5, wherein the support sleeve (42) is fixed in a lower part of the first housing part (12a), and the support sleeve (42) is facing an upper part of the second housing part (12b).35 7. The well tool device (10) according to claim 2, wherein the first glass disc break mechanism (20) comprises a load ring (24) supporting the first glass disc (16), said load ring (24) is axially movable within the through running boring (14) of the34987412tubular housing (12) between a first position in where the first glass disc (16) is with a distance to a breaking pin (22) and a second position in where the glass disc (16) is forced against the breaking pin (22).5 8. The well tool device (10) according to claim 7, whereinsaid load ring (24) is resting on a shear ring (26) with an annular shear lip (26a) to prevent axial movement in the first position until the shear lip (26a) is subjected to a force higher than a predetermined force, wherein the annular shear lip (26a) of the shear ring (26) extends radially inward in the through running boring (14) 10 of the tubular housing (12).9. The well tool device (10) according to claim 8, wherein the breaking pin (22) is resting on the shear ring (26), and said breaking pin (22) is accommodated in a pocket on an outside of the load ring (26).1510. The well tool device (10) according to claim 4, wherein the second glass disc break mechanism (30) comprises one or more break pins (32) for shattering the second glass disc (18) when the second glass disc (18) is pushed axially by the applied hydraulic pressure.2011. The well tool device (10) according to claim 10, wherein said break pins (32) is/are placed facing an underside of the second glass disc (18).12. The well tool device (10) according to claim 11, wherein said break pins (32) 25 is/are axially embedded in an inner wall (14b) of an upper part of the second house part (12b).13. The well tool device (10) according to claim 1, wherein said first and second glass discs (16,18) are solid, frangible glass discs made of brittle and/or tempered 30 glass.14. The well tool device (10) according to claim 5 and 8, wherein said shear ring (26) is resting on the support sleeve (42).35 15. A method for temporary well isolation during a well completion phase, comprising running in hole a well tool device (10) according to any of claims 1-14, wherein the method comprises the steps:34987413- running a tubing or casing string (62) including said well tool device (10) into a borehole (68), providing temporary isolation with a hydrostatic pressure upstream the well tool device (10) equal to a reservoir pressure downstream the well tool device (10) and with an atmospheric pressure between the first and second barrier in 5 a chamber (40) therebetween,- increasing pressure upstream the well tool device (10) to a first high pressure higher than the hydrostatic pressure, and performing well completion activities in the borehole (68),- decreasing pressure upstream the well tool device (10) to a pressure lower 10 than the hydrostatic pressure,- increasing pressure upstream the well tool device (10) to a second high pressure higher than the first high pressure,- applying said second high pressure on the first barrier to shatter the first solid glass disc (16) and allowing fluid communication into the atmospheric chamber 15 (40),- applying residual differential pressure on the second barrier to shatter the second solid glass disc (18), and- open for fluid communication through the well tool device (10).20 16. The method for temporary well isolation according to claim 15, wherein said well completion activities in the borehole (68) prior to open the first and second barrier comprises setting packers (64) and/or performing pressure tests.17. The method for temporary well isolation according to claim 15, wherein one or 25 more well tool devices (10) is/are included in a production string (62).18. The method for temporary well isolation according to claim 15, wherein the step of decreasing pressure upstream the well tool device (10) to a pressure less than the hydrostatic pressure comprises displacing to a lighter fluid.34987414PATENTKRAV1. En brønnverktøysanordning (10) som omfatter et rørformet hus (12) med en første 5 husdel (12a) og en andre husdel (12b), der nevnte rørformede hus (12) har en gjennomgående boring (14), hvorien første barriere som omfatter en massiv første glasskive (16) som stenger av den gjennomgående boringen (14) oppstrøms i det rørformede huset (12), en andre barriere som omfatter en massiv andre glasskive (18) som stenger 10 av den gjennomgående boringen (14) nedstrøms i det rørformede huset (12),nevnte første og andre glasskiver (16, 18) er aksialt forskjøvet i forhold til hverandre,karakterisert ved atet atmosfærisk kammer (40) er anordnet mellom nevnte første og andre 15 glasskiver (16, 18), ognevnte første og andre glasskiver (16, 18) er massive, skjøre glasskiver laget av sprøtt glass og/eller herdet glass, hvoriden første glasskiven (16) hviler på en første glasskiveknusemekanisme (20) og er anordnet til å bli knust ved å påføre et første hydraulisk trykk og den andre 20 glasskiven (18) hviler på en andre glasskiveknusemekanisme (30) og er anordnet til å bli knust ved å påføre et andre hydraulisk trykk, hvori nevnte andre hydrauliske trykk er mindre enn nevnte første hydrauliske trykk.2. Brønnverktøysanordningen (10) ifølge krav 1, hvori den første glasskiven (16) er 25 understøttet i den gjennomgående boringen (14) mellom en skulder (50) på en indre vegg (14a) av den første husdelen (12a) og den første glasskiveknusemekanismen (20).3. Brønnverktøysanordningen (10) ifølge krav 1, hvori den andre glasskiven (18) er 30 understøttet i den gjennomgående boringen (14) mellom en støttehylse (42) og den andre glasskiveknusemekanismen (30).4. Brønnverktøysanordningen (10) ifølge krav 3, hvori støttehylsen (42) er fastmontert i en nedre del av den første husdelen (12a), og støttehylsen (42) er 35 vendt mot en øvre del av den andre husdelen (12b).349874155. Brønnverktøysanordningen (10) ifølge krav 1, hvori den første glasskiveknusemekanismen (20) omfatter en lastring (24) som understøtter den første glasskiven (16), der den nevnte lastringen (24) er aksialt bevegelig innenfor den gjennomgående boringen (14) av det rørformede huset (12) mellom en første 5 posisjon der den første glasskiven (16) er plassert med en avstand til en knusepinne (22) og en andre posisjon der glasskiven (16) blir presset mot knusepinnen (22).6. Brønnverktøysanordningen (10) ifølge krav 5, hvori nevnte lastring (24) hviler på en skjærring (26) med en ringformet skjærleppe (26a) for å forhindre aksial10 bevegelse i den første posisjonen til skjærleppen (26a) blir utsatt for en kraft som er større enn en forhåndsbestemt kraft, hvori den ringformede skjærleppen (26a) av skjærringen (26) strekker seg radialt innover i den gjennomgående boringen (14) av det rørformede huset (12).15 7. Brønnverktøysanordningen (10) ifølge krav 6, hvori knusepinnen (22) hviler på skjærringen (26), og der nevnte knusepinne (22) er anordnet i en lomme på en utside av lastringen (24).8. Brønnverktøysanordningen (10) ifølge krav 1, hvori den andre20 glasskiveknusemekanismen (30) omfatter én eller flere knusepinner (32) for å knuse den andre glasskiven (18) når den andre glasskiven (18) blir skjøvet aksialt av det påførte hydrauliske trykket.9. Brønnverktøysanordningen (10) ifølge krav 8, hvori nevnte knusepinner (32) blir 25 plassert vendt mot en underside av den andre glasskiven (18).10. Brønnverktøysanordningen (10) ifølge krav 9, hvori nevnte knusepinner (32) er aksialt innfelt i en indre vegg (14b) av en øvre del av den andre husdelen (12b).30 11. Brønnverktøysanordningen (10) ifølge krav 6, hvori nevnte skjærring (26) hviler på støttehylsen (42).12. En fremgangsmåte for midlertidig brønnisolasjon under en brønnkompletteringsfase, som omfatter å kjøre inn i brønnen en35 brønnverktøysanordning (10) ifølge et hvilket som helst av kravene 1-11, karakterisert ved at fremgangsmåten omfatter trinnene å:34987416- nedføre et rør eller en casingstreng (62) inkludert nevnte brønnverktøysanordning (10) i et borehull (68) som tilveiebringer midlertidig isolasjon med et hydrostatisk trykk oppstrøms i brønnverktøysanordningen (10) som er lik et reservoartrykk nedstrøms i brønnverktøysanordningen (10) og med et atmosfærisk 5 trykk mellom den første og den andre barrieren i et kammer (40) derimellom,- øke trykket oppstrøms i brønnverktøysanordningen (10) til et første høye trykk som er større enn det hydrostatiske trykket, og utføre brønnkompletteringsaktiviteter i borehullet (68),- redusere trykket oppstrøms i brønnverktøysanordningen (10) til et trykk som 10 er mindre enn det hydrostatiske trykket,- øke trykket oppstrøms i brønnverktøysanordningen (10) til et andre høye trykk som er større enn det første høye trykket,- påføre nevnte andre høye trykk på den første barrieren for å knuse den første, massive glasskiven (16) og tillate fluidkommunikasjon inn i det atmosfæriske 15 kammeret (40),- påføre residualt differensialtrykk på den andre barrieren for å knuse den andre, massive glasskiven (18), og- åpne for fluidkommunikasjon gjennom brønnverktøysanordningen (10).20 13. Fremgangsmåten for midlertidig brønnisolasjon ifølge krav 12, hvori nevnte brønnkompletteringsaktiviteter i borehullet (68) i forkant av å åpne den første og den andre barrieren omfatter å installere packere (64) og/eller utføre trykktester.14. Fremgangsmåten for midlertidig brønnisolasjon ifølge krav 12, hvori én eller flere 25 brønnverktøysanordninger (10) er inkludert i en produksjonsstreng (62).15. Fremgangsmåten for midlertidig brønnisolasjon ifølge krav 12, hvori trinnet med å redusere trykket oppstrøms i brønnverktøysanordningen (10) til et trykk som er mindre enn det hydrostatiske trykket omfatter å erstatte til et lettere fluid.30
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Patent classes

IPC classesE21B 33/12E21B 33/134CPC classesE21B 33/1208E21B 33/134

Citations

US 2014/0083716 A1 (A1)US 2014/0008085 A1 (A1)US 2011/0284242 A1 (A1)

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Owners
SBS Technology AS
c/o c/o Entech Solutions AS, Storaneset 12 5260 INDRE ARNA NO (BERGEN Municipality, Vestland county)Org. number: 821689422Inventors
Jan Tore Tveranger
Garnestona 2 5264 GARNES NO (BERGEN Municipality, Vestland county)

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BRYN AARFLOT AS
BRYN AARFLOT AS

Org. number: 979993269

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