Office Action 2: Notice of Allowance (2025-02-05)

CLAIMS:
Amendments to the Claims:

The following claims replace all previous versions and listings of the claims.

1\. (Currently Amended) A method of attaching risers to a buoy, which buoy and risers are to be arranged for injecting fluid from a vessel on a water surface into a subterranean void beneath a seabed, the method comprising:controlling a remote operated vehicle to attach a winch wire to a head end of a first riser of the SVG {EMBED HERE} 0.1530.43 controlling the remote operated vehicle to lead the winch wire via the buoy to a winch unit on a seabed below the buoy,
controlling the winch unit to pull up the head end of the first riser to a bottom side of the buoy, and
controlling the remote operated vehicle to connect the head end of the first riser to a first connector arrangement in the bottom of the buoy.
2\. (Currently Amended) The method according to claim 1, further comprising:controlling the remote operated vehicle to attach the winch wire to a head end of a second riser of the SVG {EMBED HERE} 0.1530.43 controlling the remote operated vehicle to lead the winch wire via the buoy to the winch unit on the seabed below the buoy,
controlling the winch unit to pull up the head end of the second riser to the bottom side of the buoy, and
controlling the remote operated vehicle to connect the head end of the second riser to a second connector arrangement in the bottom of the buoy.

3\. (Currently Amended) A method of attaching risers to a subsea template on a seabed, which risers \[\[is\]\] are connected to a buoy for receiving fluid from a vessel on a water surface, and which risers \[\[is\]\] are to be arranged for feeding the received fluid to the subsea template for injection into a subterranean void beneath a seabed, the method comprising:controlling a remote operated vehicle to steer an emitting end of a base section of a first riser of the risers to a first template guide member on the subsea template,
controlling the remote operated vehicle to feed the emitting end of the base section of the first riser via the first template guide member to a first sleeve member having first penetration means configured to penetrate the first riser so as to cause the first penetration means to penetrate the first riser in the emitting end of the base section and create a first opening in the first riser, and
controlling the remote operated vehicle to connect the first sleeve member to a first injection valve tree comprised in the subsea template, which first injection valve tree is in fluid connection with a first wellhead for a drill hole to the subterranean void.

4\. (Currently Amended) The method according to claim 3, wherein the method further comprises:controlling the remote operated vehicle to steer an emitting end of a base section of a second riser of the risers to a second template guide member on the subsea template,
controlling the remote operated vehicle to feed the emitting end of the base section of the second riser via the second template guide member to a second sleeve member having second penetration means configured to penetrate the second riser so as to cause the second penetration means to penetrate the second riser in the emitting end of the base section and create a first opening in the second riser, and
controlling the remote operated vehicle to connect the second sleeve member to a second injection valve tree comprised in the subsea template, which second injection

valve tree is in fluid connection with a second wellhead for a drill hole to the subterranean void.

5\. (Previously Presented) The method according to claim 4, wherein the method further comprises:controlling the remote operated vehicle to steer the first riser against a third penetration means of a third sleeve member, which third penetration means is configured to penetrate the first riser so as to cause the third penetration means to penetrate the base section of the first riser and create a second opening in the first riser, and
controlling the remote operated vehicle to connect the third sleeve member to a third injection valve tree comprised in the subsea template, which third injection valve tree is in fluid connection with a third wellhead for a drill hole to the subterranean void.

6\. (Previously Presented) The method according to claim 5, wherein the method further comprises:controlling the remote operated vehicle to steer the second riser against a fourth penetration means of a fourth sleeve member, which fourth penetration means is configured to penetrate the second riser so as to cause the fourth penetration means to penetrate the base section of the second riser and create a second opening in the second riser, and
controlling the remote operated vehicle to connect the fourth sleeve member to a fourth injection valve tree comprised in the subsea template, which fourth injection valve tree is in fluid connection with a fourth wellhead for a drill hole to the subterranean void.

OFFICE ACTION:
DETAILED ACTION
The present application, filed on or after March 16, 2013, is being examined under the first inventor to file provisions of the AIA .
Allowable Subject Matter
The following is an examiner’s statement of reasons for allowance.
Installing risers between offshore drilling rigs or drilling vessels to transport fluid is very well known in the art. Representative art which appears close to the claimed invention includes Pollack et al. (US 20060140726), Mancini et al. (US 20140318791), Daniel et al. (US 20080135258), Gentry et al. (US 4367055), Anderson et al. (US 20030188873), Millheim (US 8202023), Wright et al. (US 9435185), Sanderford et al. (US 20030159581), and Smith et al. (US 20030106714). In general, this art, alone or in combination, discloses various recited features, including but not limited to, a riser, attaching risers, controlling ROV’s to manipulate the riser lines , controlling riser connections, using a winch to manipulate risers, a buoy, and various connection means for connection to the buoys. However, this art fails to disclose or fairly suggest the specifically combined structural relationship between the ROV, the winch, and the buoy as well as the positional relationship between the winch, bout and riser. It could be argued that the individual structure and certain method steps are generally known in the art and thus, could just be assembled to disclose the claimed invention. However, the instant invention clearly and specifically recites structural relationships, steps, and combinations, which require a greater effort than just cobbling together known structures and steps. Further, the claimed structures and steps are sufficiently detailed to be distinguishable when configured as claimed. The examiner can find no motivation to combine or modify the references which would define a fully functioning apparatus and method as claimed in the instant application. Thus, it would not have been within routine skill to glean the specifically combined limitations of the instant invention, from the art, without the benefit of hindsight reasoning or extensive experimentation.
Any comments considered necessary by applicant must be submitted no later than the payment of the issue fee and, to avoid processing delays, should preferably accompany the issue fee.  Such submissions should be clearly labeled “Comments on Statement of Reasons for Allowance.”
Conclusion

APPLICANT REBUTTAL: REMARKS
Status of the Claims and Amendments
In the present application, Claims 1 to 6 were previously pending and examined.
In the Non-Final Office Action, Claims 1 to 6 are rejected under 35 U.S.C. §112(b). No claims are allowed, however, the Office indicates that Claims 1 to 6 include allowable subject matter if rewritten to overcome the §112 rejections, and if the Office's understanding of the claimed invention is correct.
By the subject Amendment and Response, Claims 1 to 4 are amended and no claims are cancelled or added. Accordingly, Claims 1 to 6 are pending and presented for further examination. Of these claims, Claims 1 and 3 remain in independent form.
Support for the clarifying amendments to Claims 1 to 4 can be found throughout the original disclosure including the Specification, claims, and drawings, as originally filed. In particular, support for the amended and added claims can be found at least in Claims 1 to 6 as filed, at least at paragraphs [0044], [0045], and [0053] to [0056], and at least at Figs. 1 to 5 of Applicant's Published Patent Application US 2024/0368947 Al (Applicant's Published Patent Application, "APPA"). Thus, no new matter is added herein.
Initially, Applicant notes that while Claims 1 to 4 have been amended to clarify subject matter for which Applicant regards as its invention, Applicant respectfully disagrees with and traverses the outstanding rejections of the claims as originally and previously presented. However, the amended claims are submitted in the interest of expediting prosecution by clarifying the recitation of claimed elements and their interaction than was previously presented. Applicant expressly reserves the right to pursue previously claimed and now cancelled subject matter, as well as any other subject matter supported by the subject application.
Entry of this Amendment and Response, including the below remarks, which are believed to place the application in condition for immediate allowance, and favorable reconsideration of this application are respectfully requested.
Turning to the substantive rejections in the Non-Final Office Action, Applicant submits the following remarks.
Allowable Sub
j
ect Matter
At page 3 under a heading "Allowable Subject Matter" of the Non-Final Office Action, the Office notifies Applicant that:
"[i]t should be noted that no art rejections have been made and this if the examiner's understanding is correct, claims 1-6 would be allowable if amended to overcome the rejections discussed above [112(b) rejections]." See Non-Final
Office Action at page 3, first paragraph.
Applicant thanks the Office for this notification of allowable subject matter.
As noted herein, clarifying amendments are made to Claims 1 to 4 to remove the reference to "at least one riser" and to recite "risers" such that further recitation of "a first riser of the risers" (Claims 1 and 3) and "a second riser of the risers" (Claims 2 and 4) are clearly supported and our consistent with the Office's understanding of the claimed invention.
In view thereof, Applicant respectfully submits that Claims 1 to 6, as now written, are in condition for immediate allowance. Notice thereof is respectfully requested.
Claim Re
j
ections - 35
U.S.C. $
At page 2 of the Non-Final Office Action, the Office rejects Claims 1 to 6, as previously presented, under 35 U.S.C. §112(b) or 35 U.S.C. 112 (pre-AIA), second paragraph, as allegedly being indefinite for failing to particularly point out and distinctly claim the subject matter which Applicant regards as its invention.
Specifically, the Office asserts that:
"Claimsl-4 recite 'at least one riser'. Claims 1 and 3 recite 'a first riser of the at least one riser' and claims 2 and 4 recite 'a second riser of the at least one riser'.
These recitations are cumbersome and unclear making the metes and bounds of the claims not easily ascertainable. It appears that the claims encompass a plurality of risers and not just a single riser. It is suggested that claims 1 and 3 be written to either disclose a single riser (first riser) or a plurality of risers. Then claims 2 and 4 can introduce a second riser." See Non-Final Office Action, at page 2, fifth
paragraph.
Applicant respectfully disagrees with these rejections and traverses the same below.
Firstly, without addressing the patentability of Claims 1 to 6, as previously presented, without admitting that Claims 1 to 4 as previously presented are indefinite, and merely to streamline prosecution of the present application, amendments have been made to Claims 1 to 4, to even further clarify the subject matter for which Applicant regards as its invention. For example, the Claims 1 to 4 have been amended to remove the recitation of "at least one riser" and to now recite "risers," Claims 1 and 3 have been amended to recite "a first riser of the risers" and Claims 2 and 4 have been amended to recite "a second riser of the risers". As noted above, support for the clarifying amendments may be found in the original disclosure, thus no new matter is added. Applicant respectfully submits this rejection is now moot.
Applicant respectfully asserts that Claims 1 to 6, as previously and as now presented, clearly meet the requirements of 35 U.S.C. §112(b), by particularly pointing out and distinctly claiming subject matter of its invention.
In view of the foregoing, Applicant respectfully requests reconsideration and withdrawal of the rejections of Claims 1 to 6, as now written, under 35 U.S.C. §112(b).
Conclusion:


CITED REFERENCE SUMMARIES: Ref US20060140726: Claims:
1. Vessel for exploration of hydrocarbons, comprising one or more risers extending from the vessel to the sea bed, a hydrocarbon processing unit connected to the one or more risers and to a storage or transport structure for storing or transporting of the processed hydrocarbons, characterized in that, the vessel is anchored to the seabed, the vessel comprising a lifting means for lowering risers vertically towards the sea bed and for connecting a riser with a first end to a subsea hydrocarbon structure, which riser comprises a connector on a second end, the vessel comprising a connector for attaching to the riser connector and for placing the riser in fluid connection with the processing unit.
2. Vessel according to claim 1, the storage structure comprising a tank on the vessel.
3. Vessel according to claim 1, wherein the means for lowering comprise a crane, placed on the vessel.
4. Vessel according to claim 1, the risers extending alongside of the vessel.
5. Vessel according to claim 1, wherein the vessel comprises a derrick and a drill string extending from the derrick to the seabed.
6. Vessel according to claim 5, wherein the drill string extends through a shaft in the vessel.
7. Vessel according to claim 1, the riser comprising a lower part being made of a rigid material and being connected to a submerged buoy, an upper part of the riser being made of a flexible material and extending from the buoy to the vessel.
8. Vessel according to claim 1, the vessel comprising a shaft extending from deck level to keel level, the lifting means being located near the shaft for lowering a riser through the shaft towards the sea bed.
9. Method of installing a number of risers between a floating vessel and the sea bed, the vessel comprising a hydrocarbon processing unit connected to the one or more risers and a storage or transport structure for storing or transporting of the processed hydrocarbons, the vessel being anchored to the sea bed, characterized in that, the vessel comprises a lifting means for lowering risers vertically towards the sea bed and for connecting a riser with a first end to a subsea hydrocarbon structure, and a connector means on a second end of the riser and on the vessel for placing the riser in fluid connection with the processing unit, the method comprising the steps of 
lowering the first riser part from the lifting means,  connecting an upper end of the riser to a buoyancy device,  lowering the riser and buoyancy device,  connecting the lower end of the first riser part to a subsea structure with a remote operated vehicle,  releasing the buoyancy device from the lifting means,  lowering the flexible riser part from the lifting device  connecting the lower part of the flexible riser part to the buoyancy device, in fluid communication with the lower riser part, and the upper end of the flexible riser part to the processing unit.
10. Method according to claim 9, wherein prior to lowering the first riser part, 
a connector base is lowered to the seabed at a distance from a distribution member,  a transverse pipe section is lowered to the distribution member, and is attached thereto,  the vessel is moved sideways to extend the transverse pipe section over the seabed from the distribution member to the connector base,  the transverse pipe section is connected to the connector base.
11. Method according to claim 8, wherein the lower end of the flexible riser part is lowered from a second vessel alongside the vessel.
12. Method according to claim 8, wherein the lower riser part and the buoyancy device are lowered from a second vessel alongside the vessel.
13. Method according to claim 11, wherein the lower riser part is attached to the connector base and the second vessel is displaced sideways to extend the lower riser part at least partially horizontally over the seabed.
14. Method according to claim 9, wherein the lower end of the flexible riser part is lowered from a second vessel alongside the vessel.
15. Method according to claim 9, wherein the lower riser part and the buoyancy device are lowered from a second vessel alongside the vessel.
16. Vessel according to claim 2, wherein the means for lowering comprise a crane, placed on the vessel.
17. Vessel according to claim 2, the risers extending alongside of the vessel.
18. Vessel according to claim 3, the risers extending alongside of the vessel.
19. Vessel according to claim 2, wherein the vessel comprises a derrick and a drill string extending from the derrick to the seabed.
20. Vessel according to claim 3, wherein the vessel comprises a derrick and a drill string extending from the derrick to the seabed.
Ref US20140318791: Claims:
1. A system for providing a hot fluid subsea, comprising:
a. a plurality of reservoirs adapted to contain a corresponding plurality of chemical reactants; b. a manifold disposed downstream from the plurality of reservoirs; c. a plurality of chemical reactant fluid conduits providing fluid pathways between corresponding ones of the plurality of reservoirs and the manifold; d. a baffled mixing conduit in fluid communication with and located downstream from the manifold, the baffled mixing conduit comprising an internal baffle adapted to mix fluid entering into the baffled mixing conduit inside the baffled mixing conduit; e. a reaction chamber in fluid communication with and located downstream from the baffled mixing conduit, the reaction chamber adapter to maintain mixed reactant fluid for a predetermined amount of time while the reaction takes place and the fluid heats up; and f. a hot fluid conduit in fluid communication with the reaction chamber, the hot fluid conduit comprising a hot fluid exit portal.
2. The system for providing a hot fluid subsea of claim 1, wherein at least one of the reservoirs is located on a supporting vessel.
3. The system for providing a hot fluid subsea of claim 1, wherein at least one of the reservoirs is located subsea.
4. The system for providing a hot fluid subsea of claim 1, wherein at least one of the chemical reactant fluid conduits comprises coiled tubing.
5. The system for providing a hot fluid subsea of claim 1, further comprising a first pump in fluid communication with at least one of the reservoirs, the first pump adapted to pump a chemical fluid from the reservoir at a predetermined, variable rate into a corresponding conduit in fluid communication with the manifold.
6. The system of claim 1, further comprising a temperature sensor operatively in communication with the reaction chamber.
7. The system of claim 1, further comprising a temperature sensor operatively in communication with an external delivery point for the heated fluid.
8. The system of claim 1, further comprising a flow restrictor in fluid communication with the corresponding plurality of chemical reactant fluid conduits, the flow restrictor adapted to adjust flow rates of the reactants delivered to the reaction chamber.
9. The system of claim 1, further comprising a second pump in fluid communication with the hot fluid, the second pump adapted to mix ambient seawater into the hot fluid.
10. The system of claim 1, further comprising a flow diverter in fluid communication with the hot fluid conduit and adapted to selectively divert the flow of heated fluid away from an area of a subsea structure which comprises an obstruction.
11. The system of claim 1, further comprising a controllable valve in fluid communication with the hot fluid conduit, the controllable valve adapted to shut off flow of the heated fluid from the reaction chamber.
12. The system of claim 11, wherein the controllable valve comprises a remotely controllable valve.
13. The system of claim 1, wherein the predetermined amount of time while the reaction takes place and the fluid heats up ranges from around one minute to around one a half minutes.
14. The system of claim 1, further comprising an insulated chamber in fluid communication with the hot fluid exit portal, the insulated chamber adapted to be disposed proximate an area of a subsea structure which comprises an obstruction.
15. The system of claim 14, wherein the insulated chamber is adapted to be selectively engaged and disengaged from the subsea structure.
16. A method of removing an obstruction from a structure subsea, comprising:
a. selectively combining two chemical reactants obtained from respective ones of two chemical reactant reservoirs in a manifold; b. routing the two chemical reactants from the manifold through a fluid conduit to a baffled mixing chamber adapted to blend the chemical reactants; c. routing the blended fluid from the baffled mixing chamber into a reaction chamber for a predetermined amount of time to create a hot fluid by an exothermic chemical reaction between the two chemical reactants; d. routing the heated fluid through a heated fluid conduit to an area of a subsea structure proximate an area where the subsea structure contains an obstruction; and e. heating the area around the obstruction with the hot fluid.
17. The method of claim 16, where the predetermined amount of time to create a hot fluid by an exothermic chemical reaction between the two chemical reactants is between around one minute to around one and a half minutes.
18. The method of claim 16, wherein:
a. each of the chemical reactant reservoirs comprises a controllable pump; and b. the controllable pumps pump their respective chemicals at predetermined varying rates.
19. The method of claim 16, wherein the two chemical reactants comprise chemical reactants comprise ammonium chloride (NH4Cl) and sodium nitrite (NaNO2); hydrochloric acid (HCl) and ammonium hydroxide (NH4OH); hydrochloric acid (HCl) and sodium hydroxide (NaOH); or hydrogen peroxide (H2O2) and a solution containing metal ions.
20. The method of claim 16, wherein:
a. the reservoirs comprise fluid reservoirs located on a supporting vessel; and b. the chemical reactants comprise fluids delivered to the reaction chamber via separate coiled tubing strings.
21. The method of claim 16, wherein the reservoirs comprise fluid reservoirs located proximate the seabed.
22. The method of claim 16, wherein the reaction chamber is disposed proximate the subsea structure.
23. The method of claim 16, wherein the subsea structure comprises production piping.
24. The method of claim 16, wherein the obstruction comprises a plug.
25. The method of claim 16, wherein the plug comprises at least one of a hydrate or paraffin.
26. The method of claim 16, further comprising:
c. disposing a temperature sensor at a predetermined position with respect to the reaction chamber; and d. controlling the temperature of the hot fluid.
27. The method of claim 16 wherein temperature control comprises initially optimizing an aqueous concentration of the stored reactants.
28. The method of claim 16, wherein temperature control comprises adjusting a bulk flow rate of the reactants delivered to the reaction chamber.
29. The method of claim 16, wherein temperature control comprises adjusting a ratio of the reactants delivered to the reaction chamber to achieve a desired temperature.
30. The method of claim 16, wherein temperature control comprises mixing ambient seawater into the hot fluid using a low pressure pump in fluid communication with the hot fluid.
31. The method of claim 16, wherein temperature control comprises diverting the flow of heated fluid away from the subsea structure.
32. The method of claim 16, wherein temperature control comprises shutting off flow of the heated fluid from the reaction chamber using a controllable valve.
Ref US20080135258: Claims:
1. A method of producing hydrocarbons from a subsea well, the method comprising:
a) connecting a turret buoy to a swivel having a pressure rating, the turret buoy having a production flowline connected to a subsea well; b) producing a flow of hydrocarbons from the subsea well, the flow of hydrocarbons having a hydrostatic pressure; c) sensing the pressure within the production flowline; and e) actuating a shut down valve on the production flowline within the turret buoy when the hydrostatic pressure of the flow of hydrocarbons in the production flowline is greater than the pressure rating of the swivel.
2. The method of claim 1, wherein the pressure rating of the swivel is less than about 5,000 psig.
3. The method of claim 2, wherein the pressure rating of the swivel is less than about 4,000 psig.
4. The method of claim 3, wherein the pressure rating of the swivel is less than about 3,000 psig.
5. The method of claim 4, wherein the pressure rating of the swivel is less than about 2,000 psig.
6. The method of claim 1, wherein the pressure is sensed at a plurality of locations.
7. The method of claim 1 further comprising actuating a plurality of shut down valves in response to the sensed pressure.
8. The method of claim 2 further comprising the step of opening a bypass line to reduce the pressure in the production flowline.
9. The method of claim 3 wherein the step of sensing pressure includes generating a signal indicative of the pressure within the production flowline.
10. The method of claim 9 further includes the step of comparing the signal with a stored pressure value and actuating the shut down valve when the signal exceeds the stored pressure value.
11. The method of claim 10 wherein the step of comparing the signal with a stored pressure value is performed by a programmable logic controller.
Ref US20030188873: Claims:
1. A method for producing a subsea well, comprising: 
conveying well fluid from a subsea well to a subsea separator;  separating water from the well fluid with the subsea separator to produce water with residual hydrocarbons and hydrocarbon liquids;  conveying the hydrocarbon liquids directly to a subsea collector for transportation to a remote processing facility;  pumping the water with the residual hydrocarbons to a vessel at the surface; and then separating the water from the residual hydrocarbons with a separator at the vessel.
2. The method of claim 1, further comprising pumping the water after separation from the residual hydrocarbons to the sea.
3. The method of claim 1, further comprising mixing the water after the separation from the residual hydrocarbons with a supply of sea water, and injecting the mixture into another subsea well.
4. The method of claim 1, further comprising conveying the residual hydrocarbons after separation at the vessel to the subsea collector for conveyance to the remote processing facility.
5. The method of claim 4, further comprising with the separator on the vessel, separating gaseous hydrocarbons and liquid hydrocarbons from the residual hydrocarbons; and pumping the liquid hydrocarbons to the subsea collector.
6. The method of claim 5, further comprising with the separator on the vessel, separating gaseous hydrocarbons and liquid hydrocarbons from the residual hydrocarbons; and conveying the gaseous hydrocarbons to the subsea collector.
7. The method of claim 1, further comprising adding sea water to the gaseous residual hydrocarbons to form a hydrate slurry, then pumping the hydrate slurry to the subsea collector for conveyance to the remote processing facility.
8. The method of claim 1, further comprising: 
separating gas from the residual hydrocarbons with the separator at the vessel;  burning the gas and generating electricity with the burned gas.
9. The method of claim 1, further comprising: 
providing at least one gas powered apparatus on the vessel, the gas powered apparatus having a fuel intake and is in fluid communication with the separator at the vessel; and then  supplying gaseous residual hydrocarbons from the separator at the vessel to the fuel intake of the gas powered apparatus.
10. The method of claim 9, further comprising supplying additional hydrocarbons to the gas powered apparatus by adding gaseous hydrocarbons to the separated water after separation with the subsea separator.
11. A method for producing a subsea well, comprising: 
separating water from well fluid produced by a subsea well with a subsea separator; then  pumping the water with residual hydrocarbons to a vessel at the surface, and conveying hydrocarbons remaining after the separation of the water with the subsea separator to a subsea collector;  separating the water from the residual hydrocarbons with a surface separator located at the vessel;  separating liquid residual hydrocarbons from gaseous residual hydrocarbons of the residual hydrocarbons; and  pumping the liquid residual hydrocarbon to the subsea collector.
12. The method of claim 11, further comprising pumping the water separated from the residual hydrocarbons with the surface separator to the sea.
13. The method of claim 11, further comprising conveying the gaseous residual hydrocarbons from the surface separator to the subsea collector.
14. The method of claim 11, further comprising: 
burning the gaseous residual hydrocarbons at the vessel and generating electricity thereby;  providing a riser for conveying the water and residual hydrocarbons to the vessel; and  heating the riser with the electricity generated to reduce the formation of hydrates in the water and residual hydrocarbons communicating to the vessel.
15. The method of claim 11, further comprising compressing the gaseous residual hydrocarbons after separation with the surface separator before conveying the gaseous residual hydrocarbons to the subsea collector.
16. The method of claim 11, further comprising adding sea water to the gaseous residual hydrocarbons after separation by the surface separator to form a hydrate slurry, then pumping the hydrate slurry with the liquid residual hydrocarbons to the subsea collector.
17. The method of claim 11, further comprising: 
burning the gaseous residual hydrocarbons at the vessel and producing electricity.
18. The method of claim 17, further comprising separating the hydrocarbons flowing from the subsea well to the subsea separator into liquid and gaseous hydrocarbons; 
and conveying a portion of the gaseous hydrocarbons from the subsea separator to the vessel;  and burning the gaseous hydrocarbons along with the gaseous residual hydrocarbons to produce electricity.
19. A well fluid treatment system, comprising: 
a vessel;  a subsea separator adapted to be located adjacent a subsea well for separating water from well fluid from a subsea well;  a riser extending from a water outlet of the subsea separator to the vessel;  a subsea collector which receives the hydrocarbons from a hydrocarbon outlet of the subsea separator and conveys them to a facility for process; and  a surface separator on the vessel for receiving the water from the riser and for separating residual hydrocarbons from the water.
Ref US20030159581: Claims:
1. A method of sea-based handling of fluid hydrocarbons with associated gas and possibly containing water, wherein there is carried out at least one separation operation on the sea bed, in which gas is separated from oil, and in which hydrocarbons are carried by means of a riser (22) up to a surface vessel/production vessel (12), a platform or another sea-based installation, characterized in that an unprocessed well flow (at 20) on sea bed level (16) is subjected to a so-called controlled first separation step in a separator (18) installed on the sea bed, that the fluid hydrocarbons output from this separator (18) and carried up to said surface vessel (12) or platform through said riser (22), will contain an essentially predefined percentage of residual gas, which is separated from the fluid hydrocarbons on board said surface vessel (12) or platform in a second separation step in a separator (24) installed there, and that the separated residual gas is used as consumption gas/fuel for the operation of said subsea plant and said surface plant which serves to handle/treat said hydrocarbons.
2. A method as claimed in claim 1, characterized in that gas and possible water s
[Truncated to input limit]