Author: claimsbot

1. In combination with a spa having a container (20) for holding water with a top rim (15) the improvement being a waterfall structure comprising:
a plenum chamber (23) having walls (24, 26), a water inlet (39) and a water outlet (30), the outlet being formed from the walls (24, 26) of the plenum chamber;
a spout (13) formed from the walls (24, 26) of the plenum chamber as a continuation of the water outlet (30), the spout (13) passing through the top rim and having a narrow and elongated mouth (14) and a top (17) and bottom (16);
a mounting plate (25) bordering the top and the bottom of the spout where the spout passes through the top rim; and
a light source (43) attached through the mounting plate at the bottom (16) of the spout (13) to inject light directly into water falling out of the spout (13).
2. The waterfall of claim 1 wherein the plenum chamber has a baffle (27) to prevent pressure surges.
3. The waterfall of claim 1 wherein the water inlet (29) of the plenum chamber (23) is larger in cross-section than the water outlet (30).
4. The waterfall of claim 1 further comprising a bezel (21) attached to the mounting plate (25) and encompassing the spout and the light source.
5. The waterfall of claim 4 wherein the light source (43) is a flat fiber-optic array.
6. The waterfall of claim 5 wherein the flat fiber-optic array directs light in a direction parallel to water flow through the spout to intersect the water falling out of the spout.
7. The waterfall of claim 1 further comprising a bezel (21) shaped to fit over the spout after it is mounted.
8. The waterfall of claim 1 wherein the water inlet (29) is a separate structure from the plenum chamber (23) that fits into and is permanently fastened to the walls (24, 26) of the plenum chamber (23).
9. The waterfall of claim 8 wherein the water inlet (29) has an inlet orifice (39) and water pipe connector (37).
10. The waterfall of claim 1 wherein the water inlet (29) has a baffle plate (27) mounted some distance from and over the inlet orifice (39), causing water flowing through the inlet orifice to strike the baffle plate and flow around it.
11. The waterfall of claim 1 wherein the mounting plate is formed from the walls (24, 26) of the plenum chamber.

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 process for producing crystals of a GLP-1 analogue comprising:
a) preparing an aqueous solution comprising a GLP-1 analogue, a salt, and an organic solvent, and
b) isolation of the crystals after formation.
2. The process according to claim 1 wherein in step a) adjusting pH to pl\u22124<pH<pl, or to pl<pH<pl+4, wherein pl is the isoelectric point of the GLP-1 analogue.
3. The process according to claim 1 wherein the crystals are needle shaped crystals of a GLP-1 analogue.
4. The process according to claim 1 wherein the crystals has a length of at least 0.5 \u03bcm.
5. The process according to claim 1 wherein the GLP-1 analogue in the aqueous solution has a purity of less than 95%, as measured by HPLC.
6. The process according to claim 1 wherein the GLP-1 analogue in the aqueous solution is present in a concentration of at least 0.5 mgml.
7. The process according to claim 1 wherein the GLP-1 analogue is selected from non-synthetic GLP-1 analogues.
8. The process according to claim 1 wherein the GLP-1 analogue is Arg34GLP-1 (7-37) or Arg26GLP-1 (7-37).
9. The process according to claim 1 wherein the salt is present in a concentration of at least 25 mM.
10. The process according to claim 1 wherein the organic solvent is present in a concentration of from 0.5 to 50% (volvol).
11. The process according to claim 1 wherein the organic solvent is selected from C1-6alkanol, C16-alkenol, C1-6alkynol, urea, guanidine, C1-6alkanoic acid, ketone, DMSO, C2-4-glycol, C3-7-polyalcohol including sugars, or mixtures thereof.
12. A method for producing a GLP-1 analogue or a GLP-1 analogue whereto is attached a lipophilic substituent comprising the steps:
a) preparing an aqueous solution comprising a GLP-1 analogue, a salt, and an organic solvent, and
b) isolation of the crystals after formation.
13. Crystals of a GLP-1 analogue optainable by the method according to claim 12.
14. Needle shaped crystals of a GLP-1 analogue.
15. A pharmaceutical composition comprising needle shaped crystals of a GLP-1 analogue and a pharmaceutically acceptable carrier.

1. Guideway beam for a guideway of a maglev vehicle, comprising
a guideway beam member having at least one u-shaped section pointing in a movement direction of a maglev vehicle, and
means for positioning and securement of the guideway beam member to a base support.
2. Guideway beam according to claim 1, wherein the U-shaped section has legs including opposing openings at predefined distances.
3. Guideway beam according to claim 2, wherein each of the legs includes a slot extending from each of openings toward an open side of the U-shaped section.
4. Guideway beam according to claim 3, wherein the slot has a width which is smaller than a width of the respective opening.
5. Stator lamination stack for a guideway of a maglev vehicle, comprising:
a plurality of laminations stacked in a travel direction of a maglev vehicle, said laminations having aligned bores extending transversely to a movement direction of the maglev vehicle and
fastening means for securement of the laminations and maintaining integrity of the stacked laminations.
6. Stator lamination stack according to claim 5, wherein the fastening means includes at least one member selected from the group consisting of locking ring and weld seam at the surfaces of the stacked laminations.
7. Support structure of a guideway of a maglev vehicle, comprising:
a guideway beam having a guideway beam member having at least one U-shaped section pointing in movement direction of a maglev vehicle, and means for positioning and securement of the guideway beam member to a base support,
a stator lamination stack having a plurality of laminations stacked in a travel direction of the maglev vehicle, said laminations having aligned bores extending transversely to a movement direction of the maglev vehicle, and first fastening means for securement of the laminations and maintaining integrity of the stacked laminations, and
second fastening means for securement of the stator lamination stack to the guideway beam.
8. Support structure according to claim 7, wherein the U-shaped section has legs including a predetermined number of openings in alignment with the bores of the laminations so as to realize in the area of the U section legs a securement and positioning of the stator lamination stack in relation to the guideway beam by the second fastening means.
9. Support structure according to claim 8, wherein the second fastening means are welded to the U section legs.
10. Support structure according to claim 7, wherein the second fastening means have a sleeve-shaped configuration.
11. Method of making a support structure for a guideway of a maglev vehicles, comprising the steps of:
providing a stator lamination stack by interlocking stacked and stamped stator laminations according to predefined stamping patterns with aligned openings on a backside thereof,
placing end plates at end surfaces of the stator lamination stack,
inserting load-bearing bolts into the openings the stator lamination stack,
urging means for holding the stator lamination stack under pressure against the end plates,
inserting the stator lamination stack with the load-bearing bolts into openings of a U section of a guideway beam, and
securing the load-bearing bolts to the U section of the guideway beam.
12. Method according to claim 11, wherein the stator lamination stack is treated prior to insertion into the U section by a casting process.
13. Method according to claim 11 wherein the load-bearing is bolts are secured to the guideway beam by an interference fit of fastening elements in a space between the load-bearing bolts and the openings of the U section.
14. Stator lamination stack according to claim 5, wherein the laminations are dynamo sheets.
15. Support structure according to claim 8, wherein the second fastening elements are bolted to the U section legs.
16. Support structure according to claim 8, wherein the stator lamination stack has coils received in slots of the laminations and terminating in winding heads on opposite ends of the laminations, and caps, connected to the stator lamination stack or the guideway beam, for covering the winding heads.
17. Support structure according to claim 8, further comprising a load-bearing bolt extending through the bores of the stator lamination stack for attachment to the openings of the legs of the U section.
18. Support structure according to claim 17, wherein the load-bearing bolt juts out from the bores of the stator lamination stack by about 50 mm to 100 mm for receiving the second fastening means.
19. Method according to claim 11, wherein the stator lamination stack is treated prior to insertion into the U by an impregnation process.
20. Method according to claim 11, wherein the load-bearing bolts are secured to the guideway beam by welding fastening elements to the U section.
21. Method according to claim 11, wherein the opening of the U section are made by milling or flame cutting.

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 wellhead assembly for an injection tubing string, the wellhead assembly comprising:
a flange adapted to be connected to a wellhead, the flange having a longitudinal bore therethrough and an injection port, the injection port extending through the flange and communicating with the longitudinal bore of the flange;
a mandrel adapted to be inserted into the longitudinal bore of the flange, the mandrel comprising a longitudinal bore therethrough and a port, the port extending through the mandrel and communicating with the injection port of the flange; and
a hanger connected to an injection tubing string, the hanger being adapted to land in the longitudinal bore of the mandrel, the hanger comprising a communication passageway which facilitates fluid communication between the port of the mandrel and the injection tubing string.
2. A wellhead assembly as defined in claim 1, wherein the hanger further comprises a swivel connection connecting the hanger to the injection tubing string, the swivel connection allowing rotation of the hanger without imparting rotation to the injection tubing string.
3. A wellhead assembly as defined in claim 1, wherein the mandrel further comprises a connector proximate a lower end of the mandrel, the connector allowing the mandrel to be connected to a back pressure valve profile of a production tubing hanger.
4. A wellhead assembly as defined in claim 1, wherein the mandrel further comprises a connector for receiving a back pressure valve in the longitudinal bore of the mandrel above the hanger.
5. A wellhead assembly as defined in claim 1, wherein the hanger further comprises a connector for connecting a running tool.
6. A wellhead assembly as defined in claim 1, wherein the hanger further comprises a longitudinal flow area therethrough for the production of fluids from the wellbore and up past the hanger.
7. A wellhead assembly as defined in claim 1, wherein the hanger further comprises an annular channel extending around an outer surface of the hanger, the annular channel of the hanger intersecting the communications passageway of the hanger, thereby allowing fluid communication when the port of the mandrel and the communications passageway of the hanger are not radially aligned.
8. A wellhead assembly as defined in claim 1, wherein the mandrel further comprises an annular channel extending around an outer surface of the mandrel, the annular channel of the mandrel intersecting the port of the mandrel, thereby allowing fluid communication when the port of the mandrel and the injection port of the flange are not radially aligned.
9. A wellhead assembly as defined in claim 1, wherein the flange is mounted beneath a master gate valve and above a tubing head, the mandrel being such a height that the mandrel extends into a lower bore of the master gate valve but does not interfere with an operation of the master gate valve.
10. A method for allowing fluid communication in a wellhead assembly, the method comprising the steps of:
(a) mounting a wellhead assembly to a wellhead, the wellhead assembly comprising:
a flange adapted to be connected to the wellhead, the flange comprising a bore therethrough and a port;
a mandrel adapted to be inserted into the bore of the flange, the mandrel comprising a bore therethrough and a port; and
a hanger connected to an injection tubing string, the hanger being adapted to land inside the bore of the mandrel, the hanger comprising a communications passageway facilitating fluid communication between the port of the mandrel and the injection tubing string;

(b) injecting fluid through the port of the flange;
(c) injecting the fluid through the port of the mandrel;
(d) injecting the fluid through the communications passageway of the hanger; and
(e) injecting the fluid through the injection tubing string.
11. The method as defined in claim 10, the method further comprising the step of rotating the hanger without imparting rotation of the injection tubing string.
12. The method as defined in claim 10, wherein step (a) further comprises mounting the wellhead assembly beneath a master gate valve.
13. The method as defined in claim 12, the method further comprises the step of closing the master valve without damaging the injection tubing string.
14. A method for allowing fluid communication in a wellhead assembly, the method comprising the steps of:
(a) mounting a wellhead assembly on a wellhead, the wellhead assembly including an injection tubing string extending into a well;
(b) mounting a master valve above the wellhead assembly; and
(c) injecting fluids down the injection string while bypassing the master valve using the wellhead assembly.
15. The method as defined in claim 14, the method further comprising the step of closing the master valve without damaging an injection tubing string.
16. The method as defined in claim 14, wherein step (c) includes the steps of:
injecting fluid through a port of a flange of the wellhead assembly;
injecting the fluid through a port of a mandrel of the wellhead assembly;
injecting the fluid through a communications passageway of a hanger of the wellhead assembly; and
injecting the fluid through the injection tubing string of the wellhead assembly.
17. The method as defined in claim 14, wherein the wellhead assembly comprises:
a flange having a longitudinal bore therethrough and a port;
a mandrel adapted to be inserted into the longitudinal bore of the flange, the mandrel comprising a longitudinal bore therethrough and a port; and
a hanger connected to the injection tubing string, the hanger being adapted to land in the longitudinal bore of the mandrel, the hanger facilitating fluid communication between the port of the mandrel and the injection tubing string;
18. The method as defined in claim 14, wherein step (a) comprises the steps of:
mounting a flange having a longitudinal bore therethrough and a fluid injection port;
mounting a mandrel inside of the longitudinal bore of the flange, the mandrel having a longitudinal bore and a port; and
mounting a hanger inside the longitudinal bore of the mandrel, the hanger having a port facilitating fluid communication between the port of the mandrel and a location beneath the wellhead assembly.