| Customization: | Available |
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| Customized: | Customized |
| Standard: | AISI, API |
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| Body material: | steel body & matrix body |
| Available size: | 3-7/8''~26'' |
| Painting color: | customized |
| Condition: | new manufacture |
| Applicable industrial: | energy & mining |
| Machinery test: | as requirements |
| Place of origin: | Suzhou,China |
| Certificate: | API & ISO |
| Manufacture Processing: | casting or forging |
| Usage: | water/oil/gas wells |
| Warranty: | 1 year or based on products |
Regardless of type, drill bits must satisfy two primary design goals: maximize the rate of penetration (ROP) of the formation and provide a long service life.
The reason for this is a direct consequence of the rotary drilling method. Modern oilfield drilling operations require substantial capital and operating expense.
It might cost hundreds of thousands of dollars to mobilize the equipment and manpower resources required for drilling to the site. Once the rig is in place, substantial daily expenses are incurred regardless of whether or not a wellbore is actually being drilled. Obviously the faster the wellbore reaches required total depth, the lower the overall cost.
Additionally, if the bit fails or wears out, it must be replaced by removing the perhaps several miles of the drill pipe to which it is attached.
During this time, known as a "trip", the depth of the hole is not advanced, but much of the operating costs are still incurred.
For this reason, the effectiveness of a bit is often measured as drilling cost per foot of hole drilled, where a lower number indicates a higher performing bit.
Note that the cost of the bit itself often is a rather small part of the overall drilling cost.
Within the last couple of decades, a third design goal has become important in some cases.
Many wells today are drilled using directional technology, where the wellbore is intentionally directed from vertical.
For bits to be used in these situations, the ability of the bit to be more easily "steered" during drilling has become a third, possibly driving, primary goal of the design.
The ability of a bit design to satisfy the two primary goals is constrained by a number of factors, most importantly the wellbore diameter.
Other constraints are dictated by its intended use: formation type (hardness, plasticity, abrasiveness) to be drilled, operating environment at depth (temperature, pressure, corrosiveness), the capabilities of the equipment used in the operation (rotating speed, available weight on bit, pump horsepower) and the angle of the wellbore (vertical, directional, horizontal).
Modern drill bit designs try to balance these constraints to achieve the primary goals.
Most rolling cutter and fixed cutter drill bits have internal passages to direct drilling fluid, conveyed by the drill pipe from surface pumps, through hydraulic nozzles directed at the bottom of the wellbore to produce high velocity fluid jets that assist in cleaning the old cuttings off the bottom before the next tooth contacts the rock.
Placement of the nozzles, particularly in rolling cutter bits, is also often done to assist in keeping the cutting elements free of cuttings build-up in certain kinds of clay and shale formations.
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