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Collaborating Authors
Hammer Motor Breaks Ground In China
Herrington, D.. (NOV) | Barton, S.. (NOV) | Sha, D.. (NOV) | Cote, B.. (BB Tools) | Gaines, M.. (NOV) | Morrison, R.. (NOV)
Abstract Bit and bottomhole assembly (BHA) dynamics are a challenge when drilling in hard and interbedded formations. Dynamic conditions such as stick-slip and whirl can limit performance or in the worst case destroy downhole components. A new percussive mud hammer motor is being implemented in China to improve drilling performance by imparting a controlled impact to the bit while drilling. Conventional technologies to address these challenges may have limited improvement significant added costs: Conventional motors can generate large amounts of torque to the bit but can be difficult to control tool face and depth of cut as the bit transitions through various formations. This can result in stick-slip and bit bounce that can quickly damage or destroy the bit and BHA. Rotary steerable systems can control downhole dynamics with complex electronic, hydraulic and mechanical components but are very expensive, require higher system pressures and on-site supervision. Turbines with impregnated diamond bits can provide smooth drilling but can have limited rates of penetration in the softer portions of interbedded formations. In operation they also require higher pressure drops, have limited build rates and require on-site supervision by a turbine technician. These conventional system limitations created an opportunity for a new technology that is simpler and brings greater value to the drilling operation. The hammer motor is a conventional power section and drivetrain with the patent pending hammer mechanism fitted in place of the lower bearing. This assembly has the same geometry of a bent housing motor with all of its capability plus the impact of a rotary hammer. A series of field trials in China have recently been performed to validate the performance increases created by the hammer motor. These trials demonstrated significant cost savings, improved drilling performance, and simplicity of operation.
- Asia > China > Xinjiang Uyghur Autonomous Region > Tarim Basin (0.99)
- North America > United States > Louisiana > China Field (0.97)
Abstract Drilling efficiency is a key factor in determining the viability of potential hydrocarbon plays throughout the world. Pushing our capabilities for speed and accuracy changes the evaluation of value that not only operators place on emerging and potential plays, but also the evaluation that countries place on the value of their available natural resources. Fundamental drilling challenges such as formation hardness, reactive torque, tortuosity, and abrasive formation types continue to inhibit our ability to seek out less conventional reserves. Reaching our targets faster and at a reduced overall cost allows us to expand the breadth of viable drilling opportunities in all regions while accessing additional value previously out of reach in existing plays. Today we are pushing current technology to the threshold of its capabilities with longer laterals and deeper targets in more complex well profiles. Without a step change in technology, we are nearing our maximum potential. A simple yet revolutionary technology has added new life to existing drilling technologies and is now addressing some of the fundamental drilling dynamics that currently limit our drilling efficiency and restrict our ability to reach for the next level of performance. This technology works in conjunction with existing drilling systems to amplify the vertical forces applied to the bit. By varying this amplification at specific frequencies, more efficient failing of the formation can be achieved. Increased ROP well above 50% has been achieved with consistent results over offset data with reduction in reactive torque and stick slip events. This paper details how by increasing cutting efficiency, a major operator has greatly extended bit life resulting in an increase in interval drilled lengths of as much as 125%.
- Asia (0.69)
- North America > United States (0.69)
- Asia > China > Xinjiang Uyghur Autonomous Region > Tarim Basin (0.99)
- North America > United States > Louisiana > China Field (0.97)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Equipment (1.00)
- Well Drilling > Drill Bits > Bit design (1.00)
Abstract Increasing drilling efficiency and performance are key factors for determining whether or not a new play is viable for drilling. Although several factors affect drilling cost, one key element in reducing cost is reducing drilling time by increasing the rate of penetration. This is accomplished by changing the way a drill bit interacts with the formation and analyzing different ways to overcome the factors that limit drilling performance. New performance drilling tool designs are brining conventional mud motors into the next generation with performance driven technology. This technology features the latest generation of performance elastomers with a new energy distribution system which enhances the rock failing properties of the attached bit. This is achieved by applying both axial and torsional loading to the bit at the same time. Conventional motors are limited by torsional loading which correlates to the differential pressure a power section can hold before it stalls. The interaction between the bit and the rock correlates to this stall pressure of the power section used. The new performance technology takes this torsional load and merges it with the axial load created by the weight of the drill string, which it then oscillates axially. The combination of axial and torsional oscillating movement amplifies the cutting interaction of the bit to help overcome the compressive strength of the formation being drilled. Due to the unique design and different available configurations, this technology is compatible with both roller cone and fixed cutter bit designs. This design allows for constant contact between the bit and formation, reducing any bit bounce or stick slip which could reduce drilling efficiency. Along with increasing bit performance it also helps reduce weight stacking by reducing friction caused from interaction between the BHA and formation. This has proven to help with weight transfer to the bit and to reduce motor stalling, thereby improving directional control.
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drill Bits > Bit design (1.00)
Abstract Drilling the Taoudenni Basin in Mauritania has posed a costly and time consuming challenge for operators looking to develop the basin economically. The formation's compressive strength limits the bit selection to heavyset PDC bits or hard rock roller cone insert bits due to their abrasive composition. One way to increase the effectiveness and drilling efficiency is to add a percussion force, increasing the axial energy, along with a hybrid PDC bit with PDC cutters and impregnated diamond material on the blades and secondary cutting structures. The main similarity between fixed cutter hybrid bits and roller cone bits is that both incorporate a similar means of energy transfer when used with a positive displacement motor. Axial weight from a drilling rig is applied while a hydraulic motor turns the bit at different speeds. A proposed improvement to this drilling system would be a new energy distribution system that induces axial oscillations and percussion force while still applying the same weight and torsional energy as previous systems. The system combines the torsional power of a conventional positive displacement motor with a high frequency axial pulse created by a mechanical action. The torque is still transferred directly to the bit and 100% of the hydraulic flow is utilized by the bit nozzles. The mechanical lifting and falling action creates a rapid variation in weight on bit (WOB), allowing the bit's depth of cut to fluctuate while overcoming different stresses. The percussion force created after each downward stroke, along with weight on bit variations, lead to increased rates of penetration (ROP). This system has already been utilized on two wells in Mauritania, drilling a variety of formations with PDC, hybrid fixed cutter and roller cone insert bits. This paper will focus on the 8½″ interval, drilling the Atar Group and Jbeliat Teniagouri formations. These formations consist of sandstone, shale interbedded with siltstone, dolerite and pyrite. Confined compressive strengths range from 20 to 30kpsi in top section to 60kpsi in lower intervals where dolerite appears. This new technology increased ROP by more than 52% and interval drilled by over 100% through these intervals.
- North America > United States (1.00)
- Africa > Mauritania (0.90)
- Africa > Mali (0.71)
- Africa > Mali > Taoudenni Basin (0.99)
- North America > Canada > Alberta > Hector Field > Aberford Hector 6-17-16-17 Well (0.97)
- North America > United States > Louisiana > China Field (0.91)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drill Bits > Bit design (1.00)
Percussion Performance Drilling Motor Delivered Extreme Cost Saving In Hard and Abrasive Formation in Ahnet Basin, Algeria.
Ziani, Said (Sonatrach) | Fetayah, Salah (Sonatrach) | Boudebza, Abdelhadi (Sonatrach) | Bendoudou, Mohammed Miloud (Sonatrach) | Bouabba, Yacine (Sonatrach) | Fatah, Madjidi (Sonatrach)
Abstract The percussion performance drilling motor was proposed in combination with polycrystalline diamond cutter (PDC) drill bits to overcome the drilling challenges of the 12 ¼ in. vertical section in Ahnet field (South-West of Algeria), consisting of harsh lithology types habitually drilled using several bits run. Introducing the percussion drilling motor is the next step for performance optimization in harsh drilling environments. Utilizing the advanced generation of performance elastomers in combination with new energy distribution system enhances the drill bit's rock failing mechanism by combining the torque and rotation speed with a high frequency axial oscillation. This lifts the entire BHA with each pulse while maintaining the drill bit always fully embedded into the formation, resulting in an increased penetration rate. This paper presents a case study that evidences the benefit of using such a tool to reduce the drilling cost. The 12 ¼ in. section in the subject field is usually drilled using 6-10 drill bits with the associated excessive non-productive time (NPT) and increased drilling costs for the operator. Extreme dull characteristics are also exhibited by all drill bits after every run. The introduction of the percussion drilling motor in this section represents a step change in performance and drilling efficiency to reduce drilling time. In combination with optimized PDC drill bits, the percussion drilling motor completed the interval with just 2 bits compared to offsets using 10, 8, and 6 bits, respectively. In conclusion, this approach crucially contributed to save 7.72 drilling days to the client compared to the initial plan. Moreover, an increase of 119% was recorded in term of ROP compared to the best offset well and a very good hole quality with only 0.7% excess recorded on the caliper log. The innovation of the percussion performance drilling motor is a completely new telescopic bearing mandrel design to keep the drill bit always in contact with the formation while gently oscillating the upper BHA reducing friction, improving weight transfer, and improving bit cutting structure efficiency enhancing its rock-failing properties.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.48)
- North America > United States > Oklahoma > Arkoma Basin > Cana Woodford Shale Formation (0.99)
- North America > United States > Arkansas > Arkoma Basin > Cana Woodford Shale Formation (0.99)
- Africa > Middle East > Algeria > Central Algeria > Gourara Basin (0.99)
- Africa > Middle East > Algeria > Central Algeria > Ahnet-Timimoun Basin (0.99)