Patent application number | Description | Published |
20090090556 | Methods and Systems to Predict Rotary Drill Bit Walk and to Design Rotary Drill Bits and Other Downhole Tools - Methods and systems may be provided to simulate forming a wide variety of directional wellbores including wellbores with variable tilt rates, relatively constant tilt rates, wellbores with uniform generally circular cross-sections and wellbores with non-circular cross-sections. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials, relatively hard stringers disposed throughout one or more layers of formation material, and/or concretions (very hard stones) disposed in one or more layers of formation material. Values of bit walk rate from such simulations may be used to design and/or select drilling equipment for use in forming a directional wellbore. | 04-09-2009 |
20090229888 | METHODS AND SYSTEMS FOR DESIGNING AND/OR SELECTING DRILLING EQUIPMENT USING PREDICTIONS OF ROTARY DRILL BIT WALK - Methods and systems may be provided simulating forming a wide variety of directional wellbores including wellbores with variable tilt rates and/or relatively constant tilt rates. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials and relatively hard stringers disposed throughout one or more layers of formation material. Values of steer force, bit walk rate and average walk rate from such simulations may be used to design and/or select drilling equipment for use in forming a directional wellbore. | 09-17-2009 |
20100000800 | Rotary Drill Bits with Protected Cutting Elements and Methods - A rotary drill bit with cutting elements operable to control depth of cut and rate of penetration during formation of a wellbore are provided. Respective sets of secondary cutting elements and primary cutting elements may also be disposed on exterior portions of a rotary drill bit. A number of blades may extend from exterior portions of the drill bit with a number of cutting elements disposed on exterior portions of each blade. Each cutting element may include a substrate with a cutting surface disposed thereon. A respective protector may extend from the cutting surface of one or more cutting elements to limit depth of penetration of the associated cutting element into adjacent portions of a downhole formation and/or to control rate of penetration of an associated rotary drill bit. | 01-07-2010 |
20100133015 | Rotary Drill Bit with Improved Steerability and Reduced Wear - A rotary drill bit having blades with cutting elements disposed on exterior portions thereof may be formed with either a continuous cutting zone or a substantially continuous cutting zone between the last cutting element on each blade and an adjacent gage pad. Such rotary drill bits may have improved steerability during the formation of a directional wellbore and/or may experience substantially reduced wear on gage pads and/or portions of each blade adjacent to respective gage pads. For some rotary drill bits an additional cutter may be disposed in one or more gage pads adjacent to the last cutting element. For other rotary drill bits a gage cutter may be disposed between and in close proximity to both the last cutting element and adjacent portions of the associated gage pad. | 06-03-2010 |
20100163312 | Rotary Drill Bits with Gage Pads Having Improved Steerability and Reduced Wear - A rotary drill bit having blades with gage pads disposed on exterior portions thereof to improve steerability of the rotary drill bit during formation of a directional wellbore without sacrifice of lateral stability. One or more of the gage pads may include radially tapered exterior portions and/or cut out portions to assist with reducing wear of the associated gage pad. For some applications, a rotary drill bit may be formed having blades with gage pads having a relatively uniform exterior surface. Hard facing material and/or buttons may be disposed on exterior portions of the gage pad to form a radially tapered portion to improve steerability, reduce wear of the gage pad and/or improve ability of the rotary drill to form a wellbore having a generally uniform inside diameter, particularly during directional drilling of the wellbore. | 07-01-2010 |
20100300758 | METHODS AND SYSTEMS FOR DESIGNING AND/OR SELECTING DRILLING EQUIPMENT USING PREDICTIONS OF ROTARY DRILL BIT WALK - Methods and systems may be provided simulating forming a wide variety of directional wellbores including wellbores with variable tilt rates and/or relatively constant tilt rates. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials and relatively hard stringers disposed throughout one or more layers of formation material. Values of bit walk rate from such simulations may be used to design and/or select drilling equipment for use in forming a directional wellbore. | 12-02-2010 |
20110015911 | METHODS AND SYSTEMS TO PREDICT ROTARY DRILL BIT WALK AND TO DESIGN ROTARY DRILL BITS AND OTHER DOWNHOLE TOOLS - Methods and systems may be provided to simulate forming a wide variety of directional wellbores including wellbores with variable tilt rates, relatively constant tilt rates, wellbores with uniform generally circular cross-sections and wellbores with non-circular cross-sections. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials, relatively hard stringers disposed throughout one or more layers of formation material, and/or concretions (very hard stones) disposed in one or more layers of formation material. Values of bit walk rate from such simulations may be used to design and/or select drilling equipment for use in forming a directional wellbore. | 01-20-2011 |
20110077928 | METHODS AND SYSTEMS FOR DESIGN AND/OR SELECTION OF DRILLING EQUIPMENT BASED ON WELLBORE DRILLING SIMULATIONS - Methods and systems may be provided for simulating forming a wide variety of directional wellbores including wellbores with variable tilt rates and/or relatively constant tilt rates. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials and relatively hard stringers disposed throughout one or more layers of formation material. | 03-31-2011 |
20110166837 | Reamer and Bit Interaction Model System and Method - Teachings of the disclosure are directed to a reamer and/or bit interaction model system and method. The method may include receiving performance data regarding a cutting structure, and calculating a characteristic curve, using the performance data. The characteristic curve may be weight-based and/or torque-based. The method may also include storing the characteristic curve. In particular embodiments, the characteristic curve may include either weight on cutting structure or torque on the cutting structure, as a function of the rate of penetration. | 07-07-2011 |
20110240376 | MULTILEVEL FORCE BALANCED DOWNHOLE DRILLING TOOLS AND METHODS - Various downhole drilling tools designed and manufactured at least in part on evaluating respective forces acting on respective groups and sets of cutting elements during simulated engagement with the downhole end of a wellbore and drilling from a first downhole formation into a second downhole formation. Simulating forces acting on each cutting element as the cutting element contacts a downhole formation may be used to force balance downhole drilling tools during transition drilling or non-uniform downhole drilling conditions. Multilevel force balanced downhole drilling tools may be designed using five respective simulations, cutter group level, neighbor cutter group level, cutter set level, group of N (N=3 or N=4) consecutive cutters level and all cutters level. Various cutter layout procedures and algorithms may also be used to design multilevel force balanced downhole drilling tools which may drill faster with higher lateral stability, especially during downhole transiting drilling conditions. | 10-06-2011 |
20120111637 | ROTARY DRILL BIT WITH GAGE PADS HAVING IMPROVED STEERABILITY AND REDUCED WEAR - A rotary drill bit having blades with gage pads disposed on exterior portions thereof to improve steerability of the rotary drill bit during formation of a directional wellbore without sacrifice of lateral stability. One or more of the gage pads may include radially tapered exterior portions and/or cut out portions to assist with reducing wear of the associated gage pad. For some applications, a rotary drill bit may be formed having blades with gage pads having a relatively uniform exterior surface. Hard facing material and/or buttons may be disposed on exterior portions of the gage pad to form a radially tapered portion to improve steerability, reduce wear of the gage pad and/or improve ability of the rotary drill to form a wellbore having a generally uniform inside diameter, particularly during directional drilling of the wellbore. | 05-10-2012 |
20120152623 | PDC BITS WITH CUTTERS LAID OUT IN BOTH SPIRAL DIRECTIONS OF BIT ROTATION - Downhole drilling tools designed and manufactured to reduce bit axial force and torque and to enhance drilling efficiency comprising laying out some cutters in one spiral direction of rotation about a bit rotational axis and other cutters in an opposite spiral direction of rotation; evaluating forces acting on cutters during simulated engagement with a downhole formation (straight and transitional drilling); and modifying cutter layout with respect to a spiral direction of rotation. Some embodiments further comprise, prior to simulation, placing cutters in cutter groups/sets at respective locations to obtain a level of force balance. Multilevel force balanced downhole drilling tools may be designed using five respective simulations: cutter group level, neighbor cutter group level, cutter set level, group of N (N=3 or N=4) consecutive cutters level and all cutters level. Cutter layout procedures and algorithms to minimize respective bit forces and in some embodiments to obtain force balance are described. | 06-21-2012 |
20120152624 | PDC Bits with Mixed Cutter Blades - Downhole drilling tools designed and manufactured to minimize or reduce imbalance forces and wear by disposing cutting elements in cutter groups and cutter sets in a level of force balance and by placing impact and/or wear resistant cutters on blades subject to high impact forces and/or large loadings. Manufacturing costs may be reduced by placing inexpensive cutters on blades not subject to high impact forces and/or loadings. Some embodiments comprise designing downhole tools with combinations of thicker blades to receive high impact forces and/or loadings with thinner blades. Some embodiments comprise designing downhole drilling tools with optimized fluid-flow properties. Designing methods may comprise performing simulations on a designed tool, evaluating respective forces acting on cutters during simulated engagement with a downhole (uniform and transitional) and/or evaluating wear on cutters and bit, and/or CFD simulations to evaluate fluid-flow optimization on a tool. Various cutter layout procedures and algorithms are described. | 06-21-2012 |
20130013267 | Rotary Drill Bits with Protected Cutting Elements and Methods - A rotary drill bit with cutting elements operable to control depth of cut and rate of penetration during formation of a wellbore are provided. Respective sets of secondary cutting elements and primary cutting elements may also be disposed on exterior portions of a rotary drill bit. A number of blades may extend from exterior portions of the drill bit with a number of cutting elements disposed on exterior portions of each blade. Each cutting element may include a substrate with a cutting surface disposed thereon. A respective protector may extend from the cutting surface of one or more cutting elements to limit depth of penetration of the associated cutting element into adjacent portions of a downhole formation and/or to control rate of penetration of an associated rotary drill bit. | 01-10-2013 |