Method for separating components in well fluids

• US 5,928,519 A
• Filed: 11/03/1997
• Issued: 07/27/1999
• Est. Priority Date: 06/27/1996
• Status: Expired due to Term

• Current Assignee: Weatherford Canada Partnership (Weatherford International PLC)
• Original Assignee: Entest Corp.
• Inventors: Homan, Edwin Daryl
• Primary Examiner(s): Popovics, Robert J.
• Application Number:
  US08/963,471
• Time in Patent Office: 631 Days
• Field of Search: 210/739, 210/741, 210/744, 210/747, 210/767, 210/774, 210/790, 210/799, 210/800, 210/805, 210/806, 210/808, 210/241, 210/92, 175/17, 175/24, 175/25, 175/28, 175/40, 175/48, 175/206, 175/207, 175/212, 175/62, 95/253, 95/1, 95/19, 95/22, 95/24, 95/241, 96/155-157, 96/182-185, 96/187, 96/193
• US Class Current: 210/741
• CPC Class Codes: B01D 17/005 by thermal diffusion
• CPC Class Codes: B01D 17/0208 by sedimentation
• CPC Class Codes: B01D 17/0211 with baffles
• CPC Class Codes: B01D 17/0214 with removal of one of the phases
• CPC Class Codes: B01D 19/0057 the centrifugal movement being caused by a vortex, e.g. using a cyclone, or by a tangential inlet
• CPC Class Codes: B01D 21/0039 Settling tanks provided with contact surfaces, e.g. baffles, particles
• CPC Class Codes: B01D 21/0042 Baffles or guide plates
• CPC Class Codes: B01D 21/009 Heating or cooling mechanisms specially adapted for settling tanks
• CPC Class Codes: B01D 21/10 Settling tanks with multiple outlets for the separated liquids
• CPC Class Codes: B01D 21/2405 Feed mechanisms for settling tanks
• CPC Class Codes: B01D 21/245 Discharge mechanisms for the sediments
• CPC Class Codes: B01D 21/2494 provided with means for the removal of gas, e.g. noxious gas, air
• CPC Class Codes: B01D 21/265 by using a vortex inducer or vortex guide, e.g. coil B01D21/0054 takes precedence
• CPC Class Codes: B01D 21/34 Controlling the feed distribution; Controlling the liquid level ; Control of process parameters
• CPC Class Codes: B01D 2221/04 Separation devices for treating liquids from earth drilling, mining separation of well effluents E21B43/34, flotation in general B03D1/00
• CPC Class Codes: E21B 21/06 Arrangements for treating drilling fluids outside the borehole
• CPC Class Codes: E21B 21/085 Underbalanced techniques, i.e. where borehole fluid pressure is below formation pressure

Abstract

A system for separation of fluids and drill cuttings received from a borehole during an under-balanced drilling procedure. The system is designed to cope with significantly varied pressures and flow rates, particularly in relation to gas content of drill fluids returned to the surface during the drilling process in a production zone, and to provide effective separation and to reduce the detrimental effect due to the presence of the drill cuttings in the returned drill fluids. In the present invention there is utilized a first stage, high pressure vessel in which a major portion of the gases ad drill cuttings are separated, and a second stage, horizontal low pressure vessel, preferably of greater volume than the high pressure vessel, in which further separating is achieved, including the separate removal of the drilling liquid to be returned to the drill tube. Because in under-balance drilling, the most serious variation in the pressure of the returning fluid is due to rapid increases in the proportion of gases in the drill fluid, the system of the present invention includes features allowing the control of the operating pressure in the high pressure vessel by way of the flow control of the gases exiting the high pressure vessel while the remaining separating procedure continues to provide effective results.

Claims

1. A process for separating drilling fluids received from a borehole subject to formation pressure fluctuations during a downhole drilling operation utilizing an underbalanced drilling system, said process comprising:

transferring said drilling fluids to a first stage, high pressure vessel,

passing said drilling fluids through a first separator means in said high pressure vessel to separate a major portion of gases from liquids in said drilling fluids so that a first separated stream is produced,

transferring said first separated stream from said high pressure vessel to a second stage, horizontal low pressure vessel,

passing said first separated stream through a second separator means in said low pressure vessel for separating at least some of the residual gases from said first separated stream so that a second separated stream is produced,

flowing said second separated stream through at least two separating chambers in said low pressure vessel while maintaining said second separated stream in said low pressure vessel at a liquid level within a predetermined range wherein said second separated stream is separated into at least two layers, a first layer comprising primarily a first liquid having a first density and a second layer comprising primarily a second liquid having a second density and further residual gases from said second separated stream escape to a gas collection zone above said liquid level, and

collecting at least a portion of liquid from at least one of said layers for return to said borehole, wherein an operating pressure in said high pressure vessel is maintained within a predetermined range by controlling the outflow of gas from said high pressure vessel, in response to pressure fluctuations in said borehole outside the predetermined range.

2. A process as defined in claim 1, wherein said first separator means also separates at least a portion of solids from the drilling fluids.

3. A process as defined in claim 2, and further comprising the steps of:

accumulating said solids in a first chamber of said high pressure vessel, and

removing said solids from said first chamber through a solids outlet means of said high pressure vessel.

4. A process as defined in claim 3, and further comprising the step of:

flowing said first separated stream from said first chamber through second and third chambers of said high pressure vessel while maintaining said first separated stream in said high pressure vessel at a liquid level within a predetermined range so that residual gases in said first separated stream in said high pressure vessel escape to a gas collection zone above said liquid level in said high pressure vessel.

5. A process as defined in claim 4 and further comprising the step of:

heating said first separated stream in at least one of said second and third chambers of said high pressure vessel by way of a heat transfer means disposed in said at least one of said second and third chambers of said high pressure vessel.

6. A process as defined in claim 4 and further comprising the steps of:

collecting a different fluid comprising primarily a liquid of one density in each of said second and third chambers, and

wherein said transferring of said first separated stream from said high pressure vessel to said low pressure vessel includes the step of individually withdrawing the different fluids from the second and third chambers.

7. A process as defined in claim 6, and further comprising the steps of:

separately metering the fluids withdrawn from the second and third chambers,

recombining the metered fluids, and

directing the recombined fluids to said low pressure vessel.

8. A process as defined in claim 5 and further comprising the steps of:

providing a heating jacket containing a medium in contact with an exterior surface of said low pressure vessel, and

heating said medium in said jacket for transfer of heat from said medium to said second separated stream within said low pressure vessel.

9. A process as defined in claim 8 wherein said heat transfer means in said high pressure vessel is a heating coil, and further comprising the step of:

transferring said heated medium from said heating jacket to said heating coil in said high pressure vessel for transferring heat from the heated medium to said first separated stream within said high pressure vessel.

10. A process as defined in claim 8, wherein said low pressure vessel is of greater volume than said high pressure vessel, and further comprising the step of:

transferring said recombined fluids through a heat transfer means extending through said heated medium in said jacket prior to introducing said recombined fluids into said low pressure vessel.

11. A process as defined in claim 1, and further comprising the step of:

controlling the outflow of gases from said low pressure vessel for thereby maintaining a positive operating pressure within a preselected operating range for said low pressure vessel.

12. A process as defined in claim 11, and further comprising the step of:

directing the outflowing gases from the high pressure vessel and the low pressure vessel through a heat transfer means for raising the temperature of said outflowing gases.

13. A process as defined in claim 3, and further comprising the step of:

providing means for removing test samples of solids from immediately below said first separator means in said first chamber of said high pressure vessel while maintaining a hermetically sealed condition within said high pressure vessel.