Apparatus and method for recovering fluids from a well and/or injecting fluids into a well

• US 9,556,710 B2
• Filed: 05/22/2014
• Issued: 01/31/2017
• Est. Priority Date: 07/16/2002
• Status: Expired due to Fees

• Current Assignee: Onesubsea IP UK Limited (Schlumberger NV)
• Original Assignee: Onesubsea IP UK Limited (Schlumberger NV)
• Inventors: Donald, Ian, Reid, John
• Primary Examiner(s): WILLS III, MICHAEL R
• Application Number:
  US14/285,114
• Publication Number:
  US 20140332226A1
• Time in Patent Office: 985 Days
• Field of Search: 166/75.11, 166/75.12, 166/75.13
• US Class Current: 1/1
• CPC Class Codes: E21B 33/03 Well heads; Setting-up thereof
• CPC Class Codes: E21B 33/0353 Horizontal or spool trees, i.e. without production valves in the vertical main bore
• CPC Class Codes: E21B 33/0387 Hydraulic stab connectors
• CPC Class Codes: E21B 33/047 for plural tubing strings
• CPC Class Codes: E21B 33/068 having provision for introducing objects or fluids into, or removing objects from, wells cementing-heads E21B33/05
• CPC Class Codes: E21B 33/076 specially adapted for underwater installations
• CPC Class Codes: E21B 34/025 Chokes or valves in wellheads and sub-sea wellheads for variably regulating fluid flow
• CPC Class Codes: E21B 34/04 in underwater well heads
• CPC Class Codes: E21B 41/0007 for underwater installations E21B41/005, E21B41/04, E21B41/06, E21B41/08, E21B41/10 take precedence
• CPC Class Codes: E21B 43/01 specially adapted for obtaining from underwater installations
• CPC Class Codes: E21B 43/12 Methods or apparatus for controlling the flow of the obtained fluid to or in wells E21B43/25 takes precedence; valve arrangements E21B34/00
• CPC Class Codes: E21B 43/16 Enhanced recovery methods for obtaining hydrocarbons
• CPC Class Codes: E21B 43/162 Injecting fluid from longitudinally spaced locations in injection well
• CPC Class Codes: E21B 43/166 Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium CO2 injection E21B43/164; steam injection E21B43/24
• CPC Class Codes: E21B 43/36 Underwater separating arrangements E21B43/38 takes precedence

Abstract

Methods and apparatus for diverting fluids either into or from a well are described. Some embodiments include a diverter conduit that is located in a bore of a tree. The invention relates especially but not exclusively to a diverter assembly connected to a wing branch of a tree. Some embodiments allow diversion of fluids out of a tree to a subsea processing apparatus followed by the return of at least some of these fluids to the tree for recovery. Alternative embodiments provide only one flowpath and do not include the return of any fluids to the tree. Some embodiments can be retro-fitted to existing trees, which can allow the performance of a new function without having to replacing the tree. Multiple diverter assembly embodiments are also described.

Claims

1. An assembly for a first well with a first tree and a second well with a second tree, comprising:

an injection line connected to the first tree of the first well forming a first flowpath for injection fluids to an outlet of the first tree;

a processing apparatus in fluid communication with the first tree outlet;

a flow diverter having an injection conduit inserted into the second tree of the second well and forming a second flowpath for injection fluids into a production bore of the second tree; and

the processing apparatus being connected to the injection conduit of the second tree to form an injection flowpath from the injection line, the processing apparatus and injection conduit into the production bore of the second tree.

2. An assembly for a first well with a first tree and a second well with a second tree, comprising:

a first fluid line connected to the first tree forming a first flowpath for flowing fluids from the first fluid line to an outlet of the first tree;

a second fluid line connected to the second tree forming a second flowpath for flowing fluids into a production bore of the second tree; and

the first fluid line communicating with the second fluid line via the first and second flowpaths for flowing fluids from the first fluid line into the production bore of the second well.

3. The assembly of claim 2, further including a processing apparatus connected between the first and second fluid lines.

4. The assembly of claim 3, wherein the processing apparatus pressurizes the fluids for injection of the fluids into the production bore of the second tree.

5. The assembly of claim 3, wherein the processing apparatus is selected from the group consisting of pressure boosting apparatus, injection apparatus, materials injection apparatus, gas injection apparatus, chemical injection apparatus, chemical treatment apparatus, and measurement apparatus.

6. The assembly of claim 3, wherein fluids from other wells are collected and passed through the processing apparatus.

7. The assembly of claim 2, wherein the first fluid line is connected to the first tree through an aperture in a pipework of the first tree.

8. An assembly for a first well with a first tree and a second well with a second tree, comprising:

a first fluid line connected to the first tree forming a first flowpath for flowing fluids from a production bore of the first tree to an outlet of the first tree;

a second fluid line connected to the second tree forming a second flowpath for flowing fluids into a production bore of the second tree; and

the first fluid line communicating with the second fluid line via the first and second flowpaths for flowing fluids from the production bore of the first well into the production bore of the second well.

9. The assembly of claim 8, further including a processing apparatus disposed between the first and second fluid lines.

10. The assembly of claim 9, wherein the processing apparatus includes a separating apparatus and a fluid riser extending to the surface.

11. The assembly of claim 10, wherein the separating apparatus separates hydrocarbons from the fluids and flows the hydrocarbons into the riser with the remaining fluids flowing into the production bore of the second well.

12. The assembly of claim 8, wherein the first well is a production well and the second well is an injection well.

13. The assembly of claim 8, wherein the first and second fluid lines include diverter assemblies on pipeworks of the first and second trees.

14. The assembly of claim 13, wherein flowlines on the first and second trees are closed to flow by the diverter assemblies.