1. An apparatus for fluid treatment of a borehole, the apparatus comprising a tubing string having a long axis, a first port opened through the wall of the tubing string, a second port opened through the wall of the tubing string, the second port offset from the first port along the long axis of the tubing string, a first packer operable to seal about the tubing string and mounted on the tubing string to act in a position offset from the first port along the long axis of the tubing string, a second packer operable to seal about the tubing string and mounted on the tubing string to act in a position between the first port and the second port along the long axis of the tubing string; a third packer operable to seal about the tubing string and mounted on the tubing string to act in a position offset from the second port along the long axis of the tubing string and on a side of the second port opposite the second packer; a first sleeve positioned relative to the first port, the first sleeve being moveable relative to the first port between a closed port position and a position permitting fluid flow through the first port from the tubing string inner bore and a second sleeve being moveable relative to the second port between a closed port position and a position permitting fluid flow through the second port from the tubing string inner bore; and a sleeve shifting means for moving the second sleeve from the closed port position to the position permitting fluid flow, the means for moving the second sleeve selected to create a seal in the tubing string against fluid flow past the second sleeve through the tubing string inner bore.
2. The apparatus of claim 1 wherein in the closed port position, the first sleeve is positioned over the first port to close the first port against fluid flow therethrough.
3. The apparatus of claim 1 wherein the first port has mounted thereon a cap extending into the tubing string inner bore and in the position permitting fluid flow, the first sleeve has engaged against and opened the cap.
4. The apparatus of claim 3 wherein in the position permitting fluid flow the first sleeve has sheared the cap.
5. The apparatus of claim 3 further comprising a third port having mounted thereon a cap extending into the tubing string inner diameter and in the position permitting fluid flow, the first sleeve also engages against the cap of the third port to open it.
6. The apparatus of claim 1 wherein the first port has mounted thereover a sliding sleeve and in the position permitting fluid flow, the first sleeve has engaged and moved the sliding sleeve away from a the first port.
7. The apparatus of claim 6 wherein the sliding sleeve includes a profile and the first sleeve includes a locking dog biased outwardly therefrom and selected to lock into the profile on the sleeve.
8. The apparatus of claim 6 wherein there is a third port with a sliding sleeve mounted thereover and the first sleeve is selected to engage and move the third port sliding sleeve after it has moved the sliding sleeve of the first port.
9. The apparatus of claim 1 wherein the means for moving the second sleeve is selected to move the second sleeve without also moving the first sleeve.
10. The apparatus of claim 1 wherein the second sleeve has formed thereon a seat and the means for moving the second sleeve includes a sealing device selected to seal against the seat, such that fluid pressure can be applied to move the second sleeve and the sealing device can seal against fluid passage past the second sleeve.
11. The apparatus of claim 10 wherein the sealing device is a plug.
12. The apparatus of claim 10 wherein the sealing device is a ball.
13. The apparatus of claim 1 wherein the first sleeve has formed thereon a first seat and the means for moving the first sleeve includes a first sealing device selected to seal against the first seat, such that once the first sealing device is seated against the first seat fluid pressure can be applied to move the first sleeve and the first sealing device can seal against fluid passage past the first sleeve and the second sleeve has formed thereon a second seat and the means for moving the second sleeve includes a second sealing device selected to seal against the second seat, such that when the second sealing device is seated against the second seat pressure can be applied to move the second sleeve and the second sealing device can seal against fluid passage past the second sleeve, the first seat having a larger diameter than the second seat, such that the second sealing device can move past the first seat without sealing thereagainst to reach and seal against the second seat.
14. The apparatus of claim 1 wherein at least one of the first, second and third packer is a solid body packer each including multiple packing elements.
15. The apparatus of claim 14 wherein the multiple packing elements are spaced apart.
16. A method for fluid treatment of a borehole, the method comprising: providing an apparatus for wellbore treatment including a tubing string having a long axis, a first port opened through the wall of the tubing string, a second port opened through the wall of the tubing string, the second port offset from the first port along the long axis of the tubing string, a first packer operable to seal about the tubing string and mounted on the tubing string to act in a position offset from the first port along the long axis of the tubing string, a second packer operable to seal about the tubing string and mounted on the tubing string to act in a position between the first port and the second port along the long axis of the tubing string; a third packer operable to seal about the tubing string and mounted on the tubing string to act in a position offset from the second port along the long axis of the tubing string and on a side of the second port opposite the second packer; a first sleeve positioned relative to the first port, the first sleeve being moveable relative to the first port between a closed port position and a position permitting fluid flow through the first port from the tubing string inner bore a second sleeve being moveable relative to the second port between a closed port position and a position permitting fluid flow through the second port from the tubing string inner bore; and a sleeve shifting means for moving the second sleeve from the closed port position to the position permitting fluid flow, the means for moving the second sleeve selected to create a seal in the tubing string against fluid flow past the second sleeve through the tubing string inner bore and; running the tubing string into a wellbore in a desired position for treating the wellbore; setting the packers; conveying the means for moving the second sleeve to move the second sleeve and increasing fluid pressure to wellbore treatment fluid out through the second port.
The claims below are in addition to those above.
All refrences to claim(s) which appear below refer to the numbering after this setence.
1. A method of finishing an interior wall, comprising:
preparing a substrate of panels comprising gypsum, cement or combinations thereof, said substrate having a surface;
applying a coating to the substrate, said coating comprising 10-40% by weight of a latex emulsion binder, 30-80% by weight calcium sulfate hemihydrate, 0.1-2% by weight of a set inhibiting agent, 0.05-2% of a polymer having a molecular weight less than 6,000 Daltons and 10-40% by weight water.
2. The method of claim 1 wherein the coating further comprises an antisedimentation agent.
3. The method of claim 1 wherein the coating further comprises a biocide.
4. The method of claim 1 wherein the coating further comprises an organic water retainer.
5. The method of claim 1 wherein said applying step comprises spraying, brushing or rolling of the coating onto the surface of the substrate.
6. The method of claim 1 wherein the chelating agent comprises at least one of the group consisting of polymers having a molecular weight less than 6,000 Daltons, a polyphosphonic acid compound or mixtures thereof.
7. The method of claim 6 wherein said polyphosphonic acid compound is one of the group consisting of tetrasodiumpyrophosphate, tetrapotassiumpyrophosphate, aminotri(methylene-phosphonic acid), diethylenetriamine penta (methylene phosphonic acid) trisodium salt, hexamethylene diamine tetra(methylene phosphonic acid) and mixtures thereof.
8. The method of claim 1 wherein said preparing step further comprises one of the group consisting of installing, cleaning, sanding, scraping, stripping, and combinations thereof.
9. The method of claim 1, further comprising filling defects in the substrate surface with the coating.
10. The method of claim 1, wherein said applying step comprises one of the group consisting of spreading said coating with a trowel, spraying said coating and mixtures thereof.
11. A coated panel comprising:
a building panel comprising one of the group consisting of gypsum panels, cement panels, panels having both gypsum and cement and mixtures thereof; and
a coating comprising calcium sulfate hemihydrate in a matrix of a latex polymer, wherein said matrix further comprises a set inhibiting agent distributed throughout said matrix.
12. The coated panel of claim 11, wherein said calcium sulfate hemihydrate comprises alpha-calcined gypsum, beta-calcined gypsum or mixtures thereof.
13. The coated panel of claim 11, wherein said set inhibiting agent comprises at least one of the group consisting of polymers having a molecular weight less than 6,000 Daltons, a polyphosphonic acid compound and mixtures thereof.
14. The coated panel of claim 13 wherein said polyphosphonic acid compound is one of the group consisting of tetrasodiumpyrophosphate, tetrapotassiumpyrophosphate, aminotri(methylene-phosphonic acid), diethylenetriamine penta (methylene phosphonic acid) trisodium salt, hexamethylene diamine tetra(methylene phosphonic acid) and mixtures thereof.
15. The coated panel of claim 11, further comprising an antisedimentation additive.
16. The coated panel of claim 15, wherein said antisedimentation additive comprises one of a modified clay, a silicate and mixtures thereof.
17. The coated panel of claim 16, wherein said modified clay is one of a modified smectite clay, a modified hydrous sodium lithium magnesium silicate and mixtures thereof.
18. The coated panel of claim 11 further comprising a texturing material.
19. The coated panel of claim 18, wherein said texturing material is selected from the group consisting of sand, calcium carbonate, expanded perlite, calcium sulfate dihydrate, synthetic ceramic spheres, synthetic silicate-based spheres and cellulosic fibers.