Boring or penetrating the earth – With tool shaft detail – Shaft carried guide or protector
Reexamination Certificate
1999-12-03
2001-12-11
Tsay, Frank (Department: 3672)
Boring or penetrating the earth
With tool shaft detail
Shaft carried guide or protector
C175S076000
Reexamination Certificate
active
06328119
ABSTRACT:
TECHNICAL FIELD
The present invention relates to a downhole drilling assembly for use primarily in directional drilling which drilling assembly includes a downhole motor and incorporates an adjustable gauge stabilizer.
BACKGROUND OF THE INVENTION
Directional drilling involves controlling the direction of a wellbore as it is being drilled. Since wellbores are drilled in three dimensional space, the direction of a wellbore includes both its inclination relative to vertical as well as its azimuth. Usually the goal of directional drilling is to reach a target subterranean destination with the drill string.
It is often necessary to adjust the direction of the wellbore frequently while directional drilling, either to accommodate a planned change in direction or to compensate for unintended and unwanted deflection of the wellbore. Unwanted deflection may result from a variety of factors, including the characteristics of the formation being drilled, the makeup of the bottom hole drilling assembly and the manner in which the wellbore is being drilled. Directional drilling typically utilizes a combination of three basic techniques, each of which presents its own special features.
First, the entire drill string may be rotated from the surface, which in turn rotates a drilling bit connected to the end of the drill string. This technique, sometimes called “rotary drilling”, is commonly used in non-directional drilling and in directional drilling where no change in direction is required or intended. This technique is relatively inexpensive because the use of specialized equipment such as downhole drilling motors can usually be kept to a minimum, but offers relatively little control over the direction of the wellbore.
Second, the drilling bit may be rotated by a downhole motor which is powered by the circulation of fluid supplied from the surface. This technique, sometimes called “sliding drilling”, is typically used in directional drilling to effect a change in direction of a wellbore, such as in the building of an angle of deflection, and almost always involves the use of specialized equipment in addition to the downhole drilling motor, including bent subs or motor housings, steering tools and nonmagnetic drill string components. Furthermore, since the drill string is not rotated during sliding drilling, it is prone to sticking in the wellbore, particularly as the angle of deflection of the wellbore from the vertical increases. For this reason, and due also to the relatively high cost of sliding drilling, this technique is not typically used in directional drilling except where a change in direction is to be effected.
Third, rotation of the drill string may be superimposed upon rotation of the drilling bit by the downhole motor. Although this technique utilizes much of the specialized equipment used in the second technique, it may in some cases be cost effective because of the high drilling rates that can sometimes be achieved and also because a change from sliding drilling to the third technique and back again can be made without first tripping the drill string in and out of the wellbore.
The design of the bottom hole assembly of the drill string can enhance the effectiveness of all three of these techniques. In particular, in all three techniques the use of stabilizers in the bottom hole assembly can assist both in reducing unwanted deflection of a wellbore and in effecting a desired change in direction of the wellbore.
Conventional stabilizers can be divided into two broad categories. The first category includes rotating blade stabilizers which are incorporated into the drill string and either rotate or slide with the drill string. The second category includes non-rotating sleeve stabilizers which typically comprise a ribbed sleeve rotatably mounted on a mandrel so that during drilling operations, the sleeve does not rotate while the mandrel rotates or slides with the drill string. Rotating blade type stabilizers are far more common and versatile than non-rotating sleeve stabilizers, which tend to be used primarily in hard formations and where only mild wellbore deflections are experienced.
The primary purpose of using stabilizers in the bottom hole assembly is to stabilize the drilling bit that is attached to the distal end of the bottom hole assembly so that it rotates properly on its axis. When a bottom hole assembly is properly stabilized, the weight applied to the drilling bit can be optimized.
A secondary purpose of using stabilizers in the bottom hole assembly is to assist in steering the drill string so that the direction of the wellbore can be controlled. For example, properly positioned stabilizers can assist either in increasing or decreasing the deflection angle of the wellbore either by supporting the drill string near the drilling bit or by not supporting the drill string near the drilling bit.
Stabilizers are thus versatile tools which are useful in all three directional drilling techniques. The design of a bottom hole assembly requires consideration of where, what type and how many stabilizers should be incorporated into the drill string.
A single stabilizing point directly above the drill bit will tend to act as a pivot point for the drill string and may result in the drilling bit pushing to one side as weight on bit is increased, thus causing deflection of the wellbore. A second stabilizing point may reduce some of this effect, but preferably at least three stabilizing points are utilized if a straight wellbore is desired. The specific design of these stabilization points, which results in a “packed hole assembly”, must be carefully determined in the context of the particular application.
In directional drilling applications, the pivot point provided by a near bit stabilizer can be used to advantage where deflection angle building is necessary. Alternatively, the deflection angle of the wellbore can sometimes be reduced by eliminating the near bit stabilizer but maintaining one or more stabilizers further up the drill string so that the drill string below the stabilizers will tend to drop down like a pendulum. This arrangement is sometimes referred to as a “packed pendulum assembly”.
Since it is usually necessary to adjust the direction of the wellbore frequently during directional drilling, it can be seen that the desired number and location of stabilizers in the drill string may vary from time to time during drilling. Unfortunately, the entire drill string must first be removed from the wellbore in order to add or remove a conventional stabilizer to or from the drill string. This is extremely costly and time consuming.
Furthermore, conventional rotating blade type stabilizers are not generally suited for use near the drilling bit in situations where a downhole motor is used to rotate the drill string, since the stabilizer is then rotated by the motor along with the drilling bit, which can result in excessive torque loading on the motor. In addition, the stabilizer may be damaged by being rotated in the wellbore at the speeds produced by downhole motors.
Some attempts have been made in the prior art to address these problems. None of these attempts, however, have provided a fully satisfactory solution.
U.S. Pat. No. 4,407,377 (Russell) and U.S. Pat. No. 4,491,187 (Russell) both describe an adjustable gauge surface controlled rotating blade type stabilizer in which the stabilizer blades can be alternated between retracted and extended positions by alternately circulating and not circulating fluid through the stabilizer body. The radial position of the stabilizer blades is controlled by a grooved barrel cam and a complementary pin which control the axial movement of an expander sleeve associated with the stabilizer blades while the fluid is alternately circulated and not circulated. The adjustable gauge stabilizer taught by Russell offers flexibility in drilling procedures since the stabilizer blades can be extended or retracted downhole without first removing the drill string from the wellbore. It is intended, however, to be connected directly into the drill string an
Comeau Laurier E.
Crase Gary M.
Gillis Ian
Hay Richard Thomas
Konschuh Christopher W.
Halliburton Energy Service,s Inc.
Kuharchuk Terrence N.
McCully Michael D.
Shull William
Tsay Frank
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