None
1. Field of the Invention
The present invention pertains to a method and apparatus for treating and conditioning of drilling mud and other fluids. More particularly, the present invention comprises a method and apparatus for down hole conditioning of drilling mud and other fluids in a well.
2. Brief Description of the Prior Art
Drilling fluids (including, but not limited to, “drilling muds”) are typically used in connection with drilling, completion, recompletion and/or working over of oil and gas wells. Such drilling fluids provide a number of benefits during such operations including, without limitation: (1) cooling and lubricating of a drill bit and/or other down hole equipment during drilling operations; (2) transportation of rock cuttings and other debris from the bottom of a well to the surface, as well as suspension of said rock cuttings and debris during periods when circulation is stopped; and (3) providing hydrostatic pressure to control encountered subsurface pressures. Drilling fluids often contain various additives or other components such as gelling agents (e.g. colloidal solids and/or emulsified liquids), weighing materials and chemicals necessary to control properties of such drilling fluids within desired limits.
Frequently, drilling fluids are pumped from the surface of a well, through a tubular drill string deployed in a well bore and having a drill bit or other equipment attached to the distal end of such tubular drill string. Such drilling fluids are pumped out of the drill bit or other down hole equipment, and then back to the surface of the earth via the annular space formed between the outside of the tubular drill string and the inside of the well bore. This pumping of drilling fluids down-hole and back to the surface is frequently referred to as “circulation.”
The characteristics of such drilling fluids can have a significant impact on the overall quality and performance of the operations at issue. Further, the condition of such drilling fluids (including additives that are sometimes mixed with the fluids) can greatly impact the quality and efficiency of operations being performed. For example, the cutting efficiency of a rotary drill bit will frequently decrease as drilling fluid density is increased.
Accordingly, there is a need for a system for down hole conditioning of drilling fluids. The system should be compatible with existing down hole and surface equipment, and should treat and/or condition drilling fluids to generate improved performance of well operations including, without limitation, drilling operations.
The down hole fluid conditioning assembly of the present invention uses vortex flow to separate drilling fluids into a lower density first portion and higher density second portion. In the preferred embodiment, a lower density first portion of the drilling fluid stream is directed generally downward toward a drill bit or other equipment so that the drilling fluids adjacent to said bit have a density less than an initial density of the drilling fluids (that is, the density of the drilling fluids being pumped into the well from the surface). Such lower density fluid typically exhibits decreased viscosity, solids content, yield point, gel strength, sand content and fluid loss characteristics. The second, higher-density portion of the drilling fluid stream is directed into a well annulus with an upward component of velocity, thereby reducing the hydrostatic drilling fluid pressure immediately adjacent to the drill bit.
The method and apparatus of the present invention promotes increased drilling performance with conventional drilling equipment by generating a lower viscosity fluid that is directed toward the bottom hole assembly (including, without limitation, a drill bit) while producing a localized reduced specific weight in the vicinity of said bottom hole assembly. Such separated drilling fluids can be used to achieve higher rates of penetration with less expensive drilling and pumping equipment. Because the down hole fluid conditioning assembly of the present invention modifies the rheology of the drilling fluids in the vicinity of the drill bit, higher penetration rates are possible with less hydraulic horsepower and weight-on-bit requirements.
When used in connection with a mud motor, the present invention also improves both mud motor and bit life. The down hole fluid conditioning assembly of the present invention permits easy removal of abrasive solids from the mud system which, if allowed to re-circulate, would cause damage and premature failure of drilling equipment including, without limitation, a mud motor and bit.
The down hole fluid conditioning assembly of the present invention also reduces the need for fine particle separation equipment, which is typically located at the surface, by minimizing the grinding of drill cuttings. Such reduction in the grinding of drill cuttings enables drilling fluids to transfer larger-sized drill cuttings to the surface. Larger cuttings are easier and less costly to remove from the drilling mud system which, in turn, reduces equipment requirements and associated costs. The present invention also makes more reservoirs economically viable, because it allows drilling of wells in a less costly manner enabling smaller reservoirs to be economically viable.
Although the above discussion primarily addresses benefits associated with drilling efficiency, it is to be observed that the present invention also improves down hole performance of numerous other operations. Specifically, the method and apparatus of the present invention can be used to improve the performance of any operation aided by down-hole conditioning of fluid. By way of illustration, but not limitation, such operations include circulating, cleaning, reaming and hole-opening operations. The apparatus of the present invention is also fully scalable. The dimensions of the apparatus can be adjustable such that the apparatus can be used in smaller diameter.
The foregoing summary, as well as any detailed description of the preferred embodiments, is better understood when read in conjunction with the drawings and figures contained herein. For the purpose of illustrating the invention, the drawings and figures show certain preferred embodiments. It is understood, however, that the invention is not limited to the specific methods and devices disclosed in such drawings or figures.
As depicted in
Referring back to
Cylindrical body section 40 has central through bore 41 extending through said cylindrical body section 40. In the preferred embodiment, conical member 30 and vortex sleeve member 20 are received within said central through bore 41 of body section 40. Lower threads 17 of upper cross over member 10 join with mating upper threads 42 of body section 40, thereby permitting interconnection of said upper cross over member 10 with body section 40.
Internal stator member 50 has substantially cylindrical body member 52 and base section 53; base section 53 has a larger outer diameter than body member 52. Central through bore 51 extends though said internal stator member 50. External flow channels or grooves 54 are disposed on the external surface of base section 53 of internal stator member 50. In the preferred embodiment, said external flow channels 54 are oriented in a substantially helical spiral pattern said base section 53. Internal stator member 50 is received within the bottom of central through bore 41 of body section 40 (obscured from view in
Referring to
Referring back to
In operation, down hole fluid conditioning assembly 100 of the present invention is included at a desired location within a bottom hole assembly or other drill string (using upper threaded connection 12 and lower threaded connection 73) and conveyed into a well on drill pipe or other tubular workstring. By way of illustration, but not limitation, it is to be observed that down hole fluid conditioning assembly 100 can be positioned above or adjacent to a drill bit or down hole mud motor. Once said fluid conditioning assembly 100 is positioned at a desired location within said well via tubular workstring, drilling fluid is pumped into the wellbore from a rig or other surface equipment through the inner bore of said tubular workstring.
Referring to
As the drilling fluid leaves said flow channels 22 on the external surface of said vortex sleeve member 20, such fluid is directed to inner stator member 50, itself having a plurality of helical external flow channels 54. Said helical external flow channels are not visible in
External flow channels 54 of said internal stator member 50 add directional rotational forces to fluid flowing through such channels. As such, fluid departing said external flow channels 54 creates a fluid vortex. Specifically, as such fluid is directed from said flow channels 54, said fluid vortex flows into the tapered internal chamber formed by central through bore 31 of conical member 30. As a result of said vortex flow, solids and fluid components having relatively higher density are directed generally radially outward toward the inner surface of bore 31 of conical member 30. Such solids and fluid components having relatively higher density travel upward through the tapered central through bore 31 of conical member 30 and, ultimately, into outlet flow channels 19 of upper cross over member 10 (see
As depicted in
Still referring to
In this manner, down hole fluid conditioning assembly 100 of the present invention performs down hole separation of drilling fluids (and other fluids) into a lower density first portion and higher density second portion. The lower density first portion of the fluid stream is directed downward, while the separated higher density second portion is directed upward.
The uses for the down hole fluid conditioning assembly of the present invention are many. However, in the preferred embodiment, such lower density fluids are directed to a drill bit or mud motor, so that the drilling fluids adjacent said bit have a density less than an initial density of the drilling fluid pumped into the well from the surface. Such lower density fluid can beneficially exhibit physical characteristics that will improve operational performance such as, for example, decreased viscosity, solids content, yield point, gel strength, sand content and fluid loss properties. The second, higher-density portion of the drilling fluid stream (together with any undesired solid or debris) is diverted away from said bit or bottom hole assembly, and is directed in the well annulus with an upward component of velocity, thereby reducing the hydrostatic drilling fluid pressure adjacent to the bottom hole assembly or drill bit.
The above-described invention has a number of particular features that should preferably be employed in combination, although each is useful separately without departure from the scope of the invention. While the preferred embodiment of the present invention is shown and described herein, it will be understood that the invention may be embodied otherwise than herein specifically illustrated or described, and that certain changes in form and arrangement of parts and the specific manner of practicing the invention may be made within the underlying idea or principles of the invention.
Priority OF U.S. PROVISIONAL PATENT APPLICATION Ser. No. 61/551,485, filed Oct. 26, 2011, incorporated herein by reference, is hereby claimed.
Number | Date | Country | |
---|---|---|---|
61551485 | Oct 2011 | US |