The last true revolutionary change in PDC bits occurred in the late 1980s after Amoco Production Co. identified bit whirl, an inefficient mode of drilling. New bit designs and changes in drilling parameters to combat bit whirl have drastically improved bit life and rate of penetration (ROP).

For example, Enron Oil & Gas Co. and Diamond Products International have such an agreement in which Enron helped design a new PDC bit for an area in the Gulf of Mexico where PDC bits have been used successfully for years. Although previous PDC bits worked well in the area, changes in hydraulics design, cutter layout, and blade spiraling increased penetration rates 20-30%.

In one case, Exeter Drilling Corp. and Hughes Christensen formed an alliance to design a PDC bit that would drill wells in the Denver-Julesberg basin of the Rocky Mountain region fast but with reduced pump pressure. They codeveloped a 77/ 8-in. multiport PDC bit that drilled more than 75,000 ft without repair, averaging 103.2 ft/hr.

Another relatively recent advance is the use of polished diamond cutters. The polished PDC surface has a significantly lower coefficient of friction, preventing cuttings from building up on the cutter surface.

As PDC bit design improves, the bits tend to drill longer intervals, and many can be used in several wells. In such cases, footage drilled per bit is more important than the number of bits used.

Exeter received proprietary rights to the bit, and Hughes Christensen developed a new bit it could manufacture for costs similar to that of old style bits.

They also can be used in low strength, poorly compacted, nonabrasive, shallow sediments, precipitates, and evaporites -- for example, salts, anhydrites, marls, and chalk -- and in moderately strong, somewhat abrasive and ductile formations such as silty claystone, siliceous shales, porous carbonates, and anhydrites.

Several service companies and operators use rock strength analysis computer programs to determine the hardness of formations in a well. These computer models use well log analysis techniques and empirical formulas to determine the confined compressive strength of formations to be drilled.

Sources such as service companies, operators, vendors, and investment bankers use various methods to gauge the success and growth of PDC bits in the drilling industry. Some market analyses include the number of bits sold or purchased, footage drilled per bit, or bit revenue.

One of the biggest limitations on high penetration rates is the need to avoid overheating the PDC. The PDC wafer and tungsten carbide base have different coefficients of thermal expansion, which can lead to cracking at high temperatures.

This diamond/tungsten carbide interface can be made successfully with various geometrical shapes, instead of conventional flat surfaces, to reduce stress on the diamond face during drilling. As these premium cutters wear, there is more diamond remaining on the stud to continue cutting. This nonplanar geometry has significantly lengthened cutter life downhole.

For example, BP Exploration Co. (Colombia) Ltd. used only one newly designed PDC bit in place of two other PDC bits to drill an interval in a well in Colombia. It saved $419,000 because of the faster ROP and one less bit trip.

At about $10,000-150,000 apiece, PDC bits generally cost five to 15 times more than roller cone bits. But a PDC bit run in the proper application can substantially lower total drilling costs despite the higher initial expense.

PDC bits generally work better in oil based muds than in water based muds. Oil-based muds, however, are not viable options in many areas because of environmental regulations and the high cost of disposal or treatment. As a result, many operators may use water based muds.

“In a typical, traditional approach, when machinists use end mills for more material [removal], more roughing, and if the tool is buried more, the fewer flutes they would use,” said Drew Strauchen, executive vice president at GWS Tool Group, Tavares, Fla. “With conventional wisdom, roughing uses two- or three-flute end mills and semi-finishing and finishing operations uses more flutes—four, five and beyond.”

PDC bits are less effective in hard, cemented abrasive sandstones, hard dolomites, chert, and granites.

Advances in metallurgy, hy- draulics, and cutter geometry have not cut the cost of the bits. Rather, they have allowed PDC bits to drill longer or more effectively in a greater number of formations. Another key advantage of these design improvements is the ability of PDC bits to withstand hard formation stringers.

“There are several general indicators that chip formation is insufficient,” Fiedler said. “Chips are very curled or rippled, have no uniform edge, or they are deeply colored. For instance, when the side that rolls over the cutting edge is no longer shiny but shows color changes.”

Improvements in ROP and bit life allow PDC bits to drill harder formations, previously thought drillable only by rock bits or tungsten carbide insert bits.

Historically, two factors have been mainly responsible for limiting the operating range and economics of running PDC bits: shortened life because of cutter fracture and slower ROP because of inadequate cutter cleaning.

Operators and bit manufacturers have developed many ways to prevent bit whirl and overcome or minimize it when it shows up.

The DOC can also be increased. For example, the machinist could run a process using a 5/8" (1.6-cm) diameter, two-flute end mill on titanium 6AL-4V at 130 sfm using full slotting and 1× the diameter DOC for productivity of 1.49 in³/min. (24.4 cm3/min.). Doing the same process with an eight-flute end mill with 230 sfm and 0.019" (0.048-cm) radial engagement or width of cut and 2× the diameter depth of cut increases productivity to 1.57 in³/min. (25.7 cm3/min.). “So, the net gain on productivity is significant,” said Tonne.

Using these tools in an HEM/VoluMill environment (toolpath software from Celeritive Technologies, Moorpark, Calif.) will mitigate assembly disasters, he said. This approach can make the smaller tapered machines competitive with larger taper machines. “The metal removal rates we can achieve are very close if they aren’t in fact beating the standard way to rough material out on bigger taper machines like 50-taper and HSK A100,” Clynch said. As a result, a wider segment of the industry can be competitive because smaller taper machines are less expensive and easier to learn.

In contrast to the linear radial toolpath in conventional machining, trochoidal milling uses a spiral (or D-shaped) toolpath with a low radial DOC to reduce load and wear on the tool. Since trochoidal milling uses a tool to machine a slot wider than its cutting diameter, the same tool can be used to create slots of varying sizes. This can free up space in the tool carousel and save time on tool changeouts, depending on the requirements of the part.

The newer processes enabled by modern CAM software are a boon for machining hard materials that need to be machined with low radial engagement, which otherwise would risk breaking the end mill. For example, when machining steel greater than 50-60 HRC, a two-flute end mill probably will snap.

Tonne agreed with Strauchen that modern CAM software is what helps make possible processes like trochoidal milling and high dynamic milling. “CAM software has gotten really good at high dynamic milling, where it’s managing the chip thickness,” he said. “So, you can use that in a roughing operation.”

Some new synthetic muds, based on mineral oils or glycerin, and friction-reducing additives for water base muds have helped improve PDC bit penetration rates compared with that in typical water based muds.

Designing and building a new bit has become very fast, mainly because of advances in CAD/CAM and engineering practices. PDC bits have become a specialty tool, not a commodity that can be bought in large number in advance of need.

About 75% of the PDC bit market lies outside the U.S., say Diamond Products International Inc. and Security DBS. Many non-U.S. areas have relatively soft formations or are expensive to drill because of high rig day rates, remote or offshore locations, or deep wells. Those factors present favorable economics for PDC bit use.

The higher the number of flutes per given diameter, the smaller the flute space on the end mill, Fiedler said. Depending on the material and its specific chip formation behavior, sufficient chip evacuation is critical and needs to be closely observed. In general, cut-off material moves down to the core and then breaks or rolls into chips, but it’s helpful to know how to read different materials and their tendencies. Steels up to 45 HRC, depending on the type of alloy, tend to roll and then break. Hardened steels are brittle and create thin chips. In general, stainless steels have less tendency to roll, but this is also heavily dependent on the alloy. Cast iron breaks into dust particles. Titanium tends to curl and fills up the available flute space quickly.

Improvements in computer aided design and computer aided manufacturing (CAD/CAM), along with improvements in dull bit grading, allowed optimization of bit design for specific applications.

Some operators and manufacturers prefer not to take part in such formal agreements because of the speed with which PDC bits undergo improvements. Bits often are left out of many drilling alliance agreements between operators and service companies.

The U.S., by contrast, has many areas in which rig day rates are relatively low, especially onshore. That makes the economics of running PDC bits less favorable.

Don’t equate cycle time with tool life, though, said Clynch. Just because a machine ran six hours, that doesn’t mean it used six hours of tool life. The end mill may have only been engaged with the workpiece a fraction of that time due to the short arc of contact. “Pay close attention to this to make sure you are getting the maximum [life] out of your tools,” he said. “If not, you may be leaving money on the table!”

Recent advances in metallurgy have allowed use of various PDC cutter geometries. These cutters are less susceptible to breakage and can withstand stress better.

“There are many modern machining techniques and strategies that really turn [that wisdom] on its head,” said Strauchen. Now, faster machines with more horsepower and faster, more precise spindles have made possible aggressive machining strategies like high-efficiency milling (HEM), also known as dynamic milling, and trochoidal milling.

“But using a multi-flute end mill with high-speed techniques and low radial engagement you can mill a slot or any kind of feature in it,” Tonne said.

There’s even more encouraging news for smaller shops when it comes to multi-flute end mills and CAM software. “They’re great tools for low power and smaller taper machines like 40-taper because with multi-flutes we’re taking deep axial cuts and balancing the radial forces by using the length of the tool for stability,” said Matt Clynch, national product specialist-milling, Iscar USA, Arlington, Texas. “With those smaller taper machines, if we take deep radial cuts with the large widths of cut it would start to bend and the assembly topples.”

Some of today's PDC bits can drill entire intervals that required two to three PDC bits or five to 10 roller cone bits only a few years ago. The big advantage comes in reducing the number of bit trips and increasing penetration rates, especially for deep wells or those with high rig costs.

Furthermore, the cost of tungsten carbide, used in the stud that holds the diamond, has increased during the past few years.

Many formations in the U.S. are not well suited to PDC bits. Extremely hard rock and soft formations with hard stringers can often be drilled more economically with roller cone bits than with PDC bits.

In general, positive displacement mud motors last longer during drilling. Therefore, bits have to be robust to keep up.

Commercial practical limits for PDC bit sizes have been 31/ 2-in. and 171/ 2-in. diameters. These limits are due mainly to economics, not technology.

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Don’t forget about the material you’re removing, said Clynch. “In theory there is not a limit, but you’ve got to have some place for the chip to form correctly,” he said. For normal, everyday materials like ISO P, ISO M, and high-temperature alloys there has to be a limit on the number of flutes. The rule of thumb is for every millimeter in diameter of a tool you get one flute, he said. For example, for tools with a ½" (12.7-mm) diameter, the maximum flute number to be effective is 12 and for tools with a 1" (25.4-mm) diameter the maximum flute number to be effective is 25. “For practicality that’s a good way to do it,” Clynch said.

Cutters are no longer limited to a 13-mm round shape. They come in various sizes (8 mm to 19 mm) and shapes. A few companies have had success with dome shaped cutters.

Hughes Christensen(27064 bytes) predicts diamond bits will account for almost 25% of world footage drilled by 1997. About 10 years ago, PDC bits had only 10% of the market.

Is there a limit on the number of flutes for one end mill? The primary method of manufacturing end mills is grinding using automatic NC grinding machines, said OSG’s Hashizume. As long as they are manufactured using such machines, the capabilities of CAD/CAM applications and the grinding machines themselves (especially the size of the grinding wheel) impose limitations on the number of flutes it is possible to create. “The larger the OD of the end mill manufactured, the bigger the space that can be used for one cutting edge, and the more cutting edges that can be manufactured,” said Hashizume. The maximum number of flutes depends on the diameter of the tool, Tonne agreed.

Much of the knowledge on how to run PDC bits properly flowed from Shell International Petroleum Co. Ltd.'s research on torque and vibration problems, Amoco's antiwhirl developments, and work by other major oil companies and service companies.

From what he’s seen in the industry, 20 flutes on a 1.25" (3.18-cm) tool is the maximum. “With that many flutes, the radial engagement due to the limited usable flute volume is much less than 10 percent,” he said. “So, you start to diminish the practicality in most applications or limit your work to pure finishing and not much else.”

Some operators and manufacturers work together informally, usually to improve bit design by adding specific features to suit a given formation.

Economic success of the first PDC bits stemmed from high operating costs for the rig and use in very select geological intervals. In the early 1980s, PDC bits underwent true engineering to suit specific field applications.

The rock strength analysis programs help an operator better determine PDC drillable intervals, make the optimum bit selection, and select appropriate drilling parameters. Such programs have been instrumental in expanding the number of formations drillable by PDC bits.

The typical product life is about 2 years, and the number of variants of a particular design are increasing rapidly.

These strategies change the way a machinist tackles a job, and it’s becoming popular for machinists to use multi-flute end mills—those with five or more flutes—to do both roughing and finishing, eliminating the need to fill up the tool carousel with an array of different end mills. These modern strategies mitigate the need to bury the tool into a part and any worries about getting chips clogged up in the flute gullets, which can lead to a broken end mill and the failure of the part in progress.

Bit performance economics are measured in terms of cost per foot drilled. This involves factors such as bit cost, footage drilled, time spent drilling, trip time, and daily rig costs.

Diamond is 10 times harder than steel and twice as hard as tungsten carbide. Diamond also is the most wear resistant material known. It has a wear resistance about 10 times that of tungsten carbide. Diamond, however, is brittle and susceptible to impact damage.

Much of this focus has been on making the diamond layer more abrasion resistant and reducing the stress behind the diamond layer. The bond between diamond layer and tungsten carbide stud is critical for a PDC bit.

Edwin Tonne, training and technical specialist, Horn USA Inc., Franklin, Tenn., said the perceived application for multi-flute end mills is for semi-finishing and finishing workpieces. “But, actually, if the shop is willing to re-program the job multi-flutes can be used to rough and to pocket as well,” he said.

PDC bit design improvements are driven by research, good engineering practices (finite element analysis, accurate analysis of dull bit grading, rock strength analysis, and the like), and fierce competition from other PDC bit manufacturers and the rock bit industry.

If peculiar wear is found, that information can be used to alter the design of the next bit. Most manufacturers can then redesign and build the new bit and have it on location almost anywhere in the world within a couple of weeks.

These bits, most of which use PDC cutters, generally drill the more critical, expensive wells around the world. Diamond bits account for almost one third of the world bit market, and sales exceed $200 million/year, the U.S. Department of Energy reports.

PDC cutters consist of a layer of bonded diamond particles backed up by a thicker layer of tungsten carbide.

“Once these conditions are met, it is possible that not only high efficiency is achieved, but also that tool life and the life of the machine spindle are greatly extended,” said Hashizume. “In such an environment, it is less important to consider chip evacuation by enlarging the chip pocket of the end mill, but rather how to increase the number of flutes to increase the tool rigidity and feed rate to achieve high efficiency.”

The question is how can a machinist seemingly defy the laws of physics and use the speed of a higher-flute tool without clogging it with chips and causing it to break? The answer is in new programming strategies. Today, CAD/CAM software, with sophisticated toolpath generation built in, allows programmers to generate more efficient toolpaths that are speedy but prevent the tool from getting into danger zones. The software’s approach is very specific, so the mill is never over-engaged with the part. Users can tell CAM software, “I don’t want to exceed this amount of tool engagement,” and the application will create the toolpath necessary to ensure the tool never gets engaged beyond the point he defined.

Round cutters with a buttress or beveled edge have significantly improved PDC bit performance in several areas. These cutters have worked well in applications in which cutting elements are subjected to high impact loads, such as in hard formations, dynamically unstable drilling, or highly interbedded formations.

Hughes Christensen has formed many successful alliances with operators. Many of such alliances focus on a technical objective.

Advances in polycrystalline diamond compact (PDC) bits have sharply increased penetration rates(31588 bytes) in oil and gas wells.

Bit whirl can be caused by cutter/ rock interaction forces and things such as formation characteristics and undesirable bottom hole assembly motions. Conventional PDC bit technology provides little resistance to whirl and may reinforce whirl once it starts.

How can the use of multi-flute end mills lead to higher productivity if they take such small bites of metal? “Because the normal operation of the multi-flute is decreased radial engagement, let’s say less than 25 percent of the diameter, the arc of contact is smaller,” said Horn’s Tonne. This allows the use of two to three times the normal cutting speed range.

Larger hole sizes are generally thought uneconomic for PDC bits because large holes are typically shallow and easily drilled by roller cone bits. The high cost to manufacture such large PDC bits usually is not justified. One operator in South America, however, used recently 26-in. PDC bits with success.

Furthermore, operators in the U.S. still drill many shallow wells. So the ability to reduce the number of trips or trip time is not as significant as in deeper wells.

By eliminating the need to change out one mill for another and employing more cutting-edge techniques, today’s machinists can go faster, which leads to increased productivity.

“All the CAM systems have different names for this type of programming,” he said. “HEM, VoluMill—there’s all sorts of them. If you really want to give it a blanket name it’d be ‘optimized roughing.’ These CAM systems have made it so easy, you just say this is my percentage of diameter width of cut and it does a lot of the back figuring for elevated surface footages and correcting of feed rates. It figures the tool path for you. It’s just made it so much easier for the small guy to be competitive.”

The biggest change in the PDC bit industry was identification of bit instability, or bit whirl, by Amoco and the subsequent antiwhirl bit designs. Basically, bit whirl is any deviation of bit rotation from the bit's geometric center.

With a higher number of flutes, though, chip formation and evacuation become concerns. Mitigate these concerns by adjusting radial engagement and table feeds to the application and target material; choosing the correct tool for a specific application; and selecting tools tailored for a high number of flutes—for example, those with a specific core design enabling bigger flute space toward the front end, or a design that optimizes chip formation.

Tonne also agreed the software enables processes that lead to higher productivity. With trochoidal milling “you have some unproductive time in the cut but [the process] more than makes up for it because you can take a really big axial DOC, even with a small end mill,” he said.

Some of General Electric's original PDC patents expired during the past few years, opening the market to many small PDC manufacturers.

Dynamic milling relies on the ability of CAD/CAM software to create a trochoidal milling program; a milling machine to read complicated trochoidal programs at high speed; and a machine that can rapidly move the spindle and table.

Cost of the bit may be only about 2-3% of total well cost, yet the bit can affect up to three-fourths of the total cost.

The use of dual powerhead motors, basically two positive displacement mud motors in tandem, has helped stabilize downhole torque. Other improvements in bottom hole assembly components have helped minimize torque and whirl problems.

Bit whirl patterns can cause the PDC cutters diamond table to chip or spall, accelerating wear and decreasing bit life.

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“Very important is the amount of coolant that can be provided and ensuring that the coolant stream direction maximizes the chip evacuation out of the cutting zone,” said Bernd Fiedler, senior product manager-solid end milling, at Kennametal, Fuerth, Germany. “Sometimes high-pressured air can be a good option to remove chips out of the working area and prevent chip clogging, especially in pockets. ”

Newer software and machining techniques can even help make an older machine perform like a shiny new model. “If they have machines even with moderate speed, a lot of times an older machine that has moderate capabilities—if it’s partnered with a new machining strategy—can still take advantage of modern high-efficiency machining and toolpath strategies,” said Strauchen. “The best way to figure it out is to bring specialists in that are savvy with modern programming techniques … and help customers maximize what they have.”

By adding flutes, the machinist can decrease the feed per flute and still maintain the same feed compared to an end mill with a lower flute count. For example, for a four-flute end mill running 0.002" (0.005-cm) per flute, substitute a five-flute end mill and maintain the same feed with decreased pressure per flute. “So, you get a little more flexibility in your tool wear without decreasing your productivity,” Tonne said. “The linear feed rate can stay the same and the cycle time will stay the same but you’re decreasing the section each flute has to take.”

PDC bits historically have found applications in relatively deep or expensive wells and in soft to medium hard formations. In these wells, the longer bit life, compared with roller cone bits, usually offsets the greater bit cost. ROP ultimately determines the economics of the bit run.

General Electric introduced PDC in 1973. Bits with PDC cutters became commercially available the following year.

BP ran a 171/ 2-in. Hycalog PDC bit on the BA-X14 well in Colombia's Cusiana field, where offset well BA-X11 on the same drilling pad required two PDC bits, one from Hycalog and one from another manufacturer, for the same interval

There is no single solution to hydraulics problems at the bit. Each company has a slightly different technical perspective. The goal is to clean the bit effectively but not to erode it with mud flow through nozzles.

The technology to minimize downhole vibrations has yielded longer bit life, faster penetration rates, and reduced drilling costs.

As PDC bit use has become more widespread, directional drillers and drilling engineers have become more familiar with the proper operational parameters to run a PDC bit successfully in a given formation. Those parameters include weight on bit, mud pressure, flow rate, and rotational speed.

Today's PDC bits drill about 1 1/ 2 times faster than comparable PDC bits in use only 2 years ago. The polycrystalline diamond now used is about twice as abrasion resistant as the diamond used 2 years ago. Many of these types of improvements are considered fine tuning or evolutionary changes in design.

Some companies use cutter force balancing, bit asymmetry, gauge design, bit profile, cutter configuration, and cutter layout to eliminate whirl. Other manufacturers control whirl through engineered cutter placement designed to create a net imbalance force, pushing against the borehole wall, to create a stable rotating condition.

Although most PDC still comes from General Electric and De Beers, several smaller companies have begun making high quality diamond wafers. This increased competition has not reduced cutter cost, mainly because PDC manufacturing is an expensive, capital intensive process.

Even though PDC bits may be considered a specialty tool, their use is still governed in most instances by economics. The decision to run a PDC bit often focuses on cost per foot or total well cost.

PDC bits usually have applications when long on-bottom times are important, oil-based muds are used, or water-based muds are used in nonhydrating formations. PDC bits also are advantageous for high rotational speed drilling, such as with a turbine or mud motor, or for drilling deviated hole sections.

End mills, traditionally made with two to four flutes, are used in one of the oldest mechanized machining processes—milling. Cutting-edge software, machine tools, novel strategies, ever-improving techniques and design updates in the tools themselves keeps milling useful in the 21st century. The machinist who masters the art of these metal eaters can save their shop time and money while producing superior parts.

Improvements in PDC bit stability, hydraulics, and cutter design have contributed to increased footage per bit in recent years. Roller cone bits also have shown improvement in performance.

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Each manufacturer has a slightly different design concept, and no one design seems to stop or prevent whirl in all situations.

PDC bits are most effective in very weak, poorly consolidated, brittle, hydratable sediments -- sands and silts, for example.

What to do if chip formation doesn’t look right? “Unfortunately, there is not a simple answer to this. It depends on the application and material,” said Fiedler. In the case of chips changing their color, the coolant supply into the work zone needs to be improved. Vibration might be the cause of all this, so the tool and workpiece clamping need to be checked. Modifying the feed rates and axial DOC can also help. Curling and ruffling of chips often indicates feed rates are too high, so adjusting the feed rates can help, but it is important to maintain sufficient average chip thickness

What's more, design improvements have allowed PDC bits to drill harder formations and soft formations with hard stringers, previously thought to be drillable only by roller cone bits.

If the price premium for a PDC bit is less than the value of the saved drilling and tripping time, the PDC bit will be the most economic choice.

The new bit drilled 1,338 ft in 145.8 rotating hr for an average ROP of 9.2 ft/hr. The two bits run in the offset well drilled a total 1,017 ft at an average ROP of 6.3 ft/hr.

Many operators still prefer to choose the bit themselves, usually with assistance from the manufacturer. Manufacturers agree that the most prudent method is to choose a bit based on the interval to be drilled, not on purchase agreements or inventory on hand.

The bottom hole pattern (left) of a whirling PDC bit has an irregular pattern, whereas the bottom hole pattern (right) of an antiwhirl PDC bit shows smooth drilling.

During whirl, the instantaneous center of rotation of the bit changes, instead of staying in line with the borehole center. Cutters can move laterally and even backwards relative to the local rock surface.

“Dynamic milling is defined as a method that is done with a large axial depth of cut (DOC) and small radial DOC to reduce the engagement time of the cutting edge of an end mill, which reduces the force load on the tool and spindle and the generation of cutting heat, while increasing the amount of material removed,” said Tyler Hashizume, product engineer II, OSG USA Inc., St. Charles, Illinois.

However, Clynch offers several cautions. When using this strategy, a machine tool’s acceleration/deceleration rates have to be higher because with the smaller moves the tool makes, the machine has to ramp up and down more to adjust the speed. The machine tool needs more memory for longer programs and it also needs enough “look-ahead,” or buffer space, to run smoothly. If the machine can’t read the code fast enough, it jerks, stalls or dwells trying to keep up, he said.