System and method for treating drilling mud in oil and gas well drilling applications

• US 6,926,101 B2
• Filed: 03/17/2003
• Issued: 08/09/2005
• Est. Priority Date: 02/15/2001
• Status: Expired due to Fees

• Current Assignee: Dual Gradient Systems, LLC
• Original Assignee: Luc Deboer
• Inventors: deBoer, Luc
• Primary Examiner(s): Walker, Zakiya
• Application Number:
  US10/390,528
• Publication Number:
  US 20030217866A1
• Time in Patent Office: 876 Days
• Field of Search: 175/5, 175/7, 175/8, 175/65, 175/66, 175 69- 71, 175/206, 175/207, 175/209, 175/217, 166/357, 166/358, 166/367, 166/368
• US Class Current: 175/70
• CPC Class Codes: E21B 21/001 specially adapted for underwater drilling dual gradient drilling E21B21/082
• CPC Class Codes: E21B 21/06 Arrangements for treating drilling fluids outside the borehole
• CPC Class Codes: E21B 21/063 by separating components
• CPC Class Codes: E21B 21/065 Separating solids from drilling fluids
• CPC Class Codes: E21B 21/082 Dual gradient systems, i.e. using two hydrostatic gradients or drilling fluid densities
• CPC Class Codes: E21B 21/085 Underbalanced techniques, i.e. where borehole fluid pressure is below formation pressure
• CPC Class Codes: E21B 33/076 specially adapted for underwater installations

Abstract

A system and method for controlling drilling mud density at a location either at the seabed (or just above the seabed) or alternatively below the seabed of wells in deep water and ultra deep water applications. A base fluid of lesser density than the drilling mud required at the wellhead is used to produce a diluted mud in the riser. By combining the appropriate quantities of drilling mud with base fluid, a diluted riser mud density at or near the density of seawater may be achieved. The present invention also includes a wellhead injection device for injecting the base fluid into the rising drilling mud. The riser charging lines are used to carry the low density base fluid to the injection device for injection into the return mud. At the surface, the diluted return mud is passed through a treatment system to cleanse the mud of drill cuttings and to separate the heavier drilling mud from the lighter base fluid. The present invention further includes a control unit for manipulating drilling fluid systems and displaying drilling and drilling fluid data.

Claims

1. A system for treating return mud rising to the surface from a wellbore via a tubular member in well drilling operations, said return mud comprising a first material having a first density, a second material having a second density which is greater than the first density, and drill cuttings, said system comprising:

(a) a shaker device for receiving the return mud from the tubular member and removing the drill cuttings from the return mud to produce a clean return mud, said shaker device comprising a first outlet capable of passing a dual gradient fluid consisting of said first and second materials and a second outlet capable of passing said drill cuttings;

(b) a centrifuge device comprising a first inlet in fluid communication with said first outlet of said shaker, a first outlet capable of passing said first fluid and a second outlet capable of passing said second fluid;

(c) a first tank in fluid communication with said first outlet of said centrifuge device, said first tank comprising a first outlet;

(d) a second tank in fluid communication with said second outlet of said centrifuge device.

2. The system of claim 1, wherein the first material is base fluid, and the second material is drilling fluid.

3. The system of claim 1, further comprising:

(a) a mud preparation system in fluid communication with said first tank;

(b) a drill string; and

(c) a riser line separate from said drill string, said riser line in fluid communication with said second tank.

4. The system of claim 3, further comprising:

(a) a third tanks in fluid communication with the second tank for receiving and storing the base fluid;

(b) a fourth tank in fluid communication with the first tank for receiving and adding at least one conditioning agent to the drilling fluid; and

(c) a fifth tank in fluid communication with the fourth tank for receiving and storing the drilling fluid.

5. The system of claim 4, further comprising a first pump for circulating the drilling fluid from the fifth tank into the wellbore via a drill tube.

6. The system of claim 5, further comprising a second pump for injecting the base fluid from the third tank into the tubular member.

7. The system of claim 5, further comprising a sixth tank disposed inline between the shaker and the centrifuge device and a second pump for injecting the clean return mud from the sixth tank into the tubular member.

8. The system of claim 5, further comprising means for transferring base fluid from the second tank to a sixth tank disposed inline between the shaker and the centrifuge device.

9. The system of claim 5, further comprising means for transferring drilling fluid from the first tank to a sixth tank disposed inline between the shaker and the centrifuge device.

10. The system of claim 1, further comprising:

(a) a first set of jets in said second tank for circulating the base fluid in the second tank;

(b) a first set of jets in said first tank for circulating the drilling fluid in the first tank; and

(c) a mixing pump in fluid communication with the first and second tanks for transferring a predetermined volume of base fluid from the second tank to the first tank.

11. The system of claim 10, further comprising a control means for:

(a) manipulating system variables, (b) displaying drilling and drilling fluid data, (c) for activating and deactivating the first set of jets, (d) for activating and deactivating the second set of jets, (e) for activating and deactivating the mixing pumps.

12. The system of claim 1, wherein the first density is lower than 8.6 PPG.

13. The system of claim 12, wherein the first density is 6.5 PPG.

14. The system of claim 1, wherein the first density is lower than the density of seawater and the second density is higher than the density of seawater.

15. A mud treatment system for offshore drilling operations, said system comprising;

(a) a first combination fluid comprising a first fluid having a first density, a second fluid having a second density and a solid particulate material suspended therein;

(b) a shaker device with a first inlet into which said first combination fluid is introduced, wherein said first combination fluid is disposed in said shaker, said shaker further comprising a first outlet and a second outlet;

(c) a second combination fluid comprising the first fluid and the second fluid, wherein said first outlet of said shaker is disposed to receive said second combination fluid and said second outlet of said shaker is disposed to receive said solid particulate matter;

(d) a first tank comprising a storage area, a portion of said second combination fluid disposed therein, a first inlet in fluid communication with the first outlet of said shaker and a first outlet; and

(e) a centrifuge device having a first inlet in fluid communication with the first outlet of said first tank, a first outlet disposed to receive said first fluid and a second outlet disposed to receive said second fluid.

16. A method employed in offshore well drilling operations at the surface for use in treating a first combination fluid rising to the surface from a wellbore in a seabed via a tubular member, said first combination fluid comprising a first fluid having a predetermined first density, a second fluid having a predetermined second density, and drill cuttings, said method comprising the steps of:

(a) introducing the first combination fluid at the surface;

(b) removing the drill cuttings from the first combination fluid to produce a second combination fluid comprising the first fluid and the second fluid;

(c) processing the second combination fluid to separate the first fluid and the second fluid from one another; and

(d) storing the first fluid and the second fluid in separate storage units at the surface.

17. The method of claim 16, wherein the first fluid comprises base fluid, and the second fluid comprises drilling fluid.

18. The method of claim 17, further comprising the steps of:

(a) circulating the drilling fluid in the wellbore via a drill tube, and

(b) injecting the base fluid into the tubular member at a location near the seabed.

19. The method of claim 17, further comprising the steps of:

(a) circulating the drilling fluid in the wellbore via a drill tube, and

(b) injecting the base fluid into the tubular member at a location below the seabed.

20. The method of claim 16, wherein the first fluid comprises base fluid, and the second fluid comprises barite.

21. The method of claim 16, further comprising the step of adding at least one conditioning agent to the drilling fluid.

22. A system for treating return mud rising from a wellbore to a surface rig via a tubular member in well drilling operations, said return mud comprising a drilling fluid having a first selected density, a base fluid having a second selected density which is less than the first density of the drilling fluid, and drill cuttings, said surface rig having an operating deck, said system comprising:

(a) a shaker device for receiving the return mud from the tubular member and removing the cuttings from the return mud to produce a clean return mud;

(b) a first set of tanks for receiving the clean return mud from the shaker device and for storing the clean return mud;

(c) a separation unit located above the operating deck of the surface rig for receiving the clean return mud from the first set of tanks and separating the return mud into said drilling fluid and said base fluid, said separation unit comprising;

(i) a centrifuge device, (ii) a first set of pumps for pumping the clean return mud from the first set of tanks to the centrifuge device, (iii) a drilling fluid collection tank for receiving the drilling fluid, (iv) and a base fluid collection tank for receiving the base fluid;

(d) a second set of tanks for receiving the drilling fluid from the drilling fluid collection tank and for adding at least one conditioning agent to the drilling fluid;

(e) a third set of tanks for receiving the drilling fluid from the second set of tanks and for storing the drilling fluid;

(f) a fourth set of tanks for receiving the base fluid from the base fluid collection tank and for storing the base fluid;

(g) control means for manipulating system variables and for displaying drilling and drilling fluid data;

(h) a second set of pumps for returning the drilling fluid from the third set of tanks to the wellbore via a drill tube; and

(i) a third set of pumps for re-injecting the base fluid from the fourth set of tanks into the tubular member via a charging line.

23. The system of claim 22, wherein the rig is a land-based rig.

24. The system of claim 22, wherein the rig is an offshore rig.