mud pump drill bit brands

Continental Emsco Drilling Products, Inc., which consisted of Emsco drilling machinery and Wilson mobile rigs, was purchased by National-Oilwell, Inc on July 7, 1999. To our knowledge, no pumps have been manufactured and sold under the Emsco brand name since National-Oilwell acquired them.

Fairbanks Morse pumps are currently manufactured in Kansas City, Kansas. Fairbanks Morse is a division of Pentair ever since August, 1997 when Pentair purchased the General Signal Pump Group.

Gaso pumps are manufactured by National Oilwell Varco. Gaso was acquired as "Wheatley Gaso" by National-Oilwell in the year 2000. At the time, Wheatley Gaso was owned by Halliburton.

Skytop Brewster pumps are no longer available as new pumps. Skytop Brewster(Cnsld Gold), a unit of Hansen PLC"s Consolidated Gold Fields subsidiary, was acquired while in bankruptcy by National-Oilwell, Inc. in November, 1999.

A mud pump (sometimes referred to as a mud drilling pump or drilling mud pump), is a reciprocating piston/plunger pump designed to circulate drilling fluid under high pressure (up to 7,500 psi or 52,000 kPa) down the drill string and back up the annulus. A mud pump is an important part of the equipment used for oil well drilling and manufactured according to API specification 7K.

The advantages of the drilling mud pump include the ability to move high-solids-content fluids laden with abrasives, the ability to pump large particles, ease of operation and maintenance, reliability, and the ability to operate over a wide range of pressures and flow rates by changing the diameter of pump liners and pistons.

As an important equipment for oilfield drilling operation, a drilling mud pump delivers circulating high-pressure drilling fluid or drilling mud to the bottom of the oil well, flushes the bottom of the well, breaks the rock, cools, lubricates and clean the drill bit, and carries the cuttings back to the ground.

The drilling mud is also used to suspend and carry out drill cuttings from the drill bits as it is brought in and out of the hole. This ensures that the drill bit does not clog and overheat, and makes the entire drilling operation smooth and safe.

Rotational power is supplied to the mud pump through an external power source like a diesel engine or electric motor. The power end of the mud pump converts the rotational energy through a crankshaft to a reciprocating motion of pistons.

The pistons move back and forth in mud pump liners, exerting a force on the cylinder chamber. During the retraction of the piston, valves open to allow the fluid to be drawn into the cylinder. Once the piston has fully retracted, it is pushed back into the cylinder.

During drilling in Oil and Gas exploration, drilling mud or Bentonite is pumped into boreholes for multiple reasons. Pumping drill mud into boreholes cools the drill bit as well as bringing drill cuttings to the surface as the way in which mud is pumped into boreholes forms a closed loop system. The use of drilling mud also provides hydrostatic pressure to prevent liquids such as oil and gas rising to the surface, as drilling mud is thixotropic meaning when it is not agitated it stiffens forming a mud which is an effective liquid and gas barrier.

What sets us apart is that we start developing a bit design where the bit meets the rock—the cutting element. It’s very small, but how it interacts with the rock type has really big impact. And this approach is how we are reshaping bit performance with huge leaps in results.

But this is really just the tip of the iceberg—we advance better bit performance every day because of our continuing work to understand customers" drilling challenges, and answering those challenges with something not quite as small as it seems.

Smith Bits is redefining how a bit should interact with the formation—by communicating with our customers and understanding exactly what they need. And it is this customer-centric methodology that continues fueling our record-breaking performance for nearly 20 years in a row. That"s what 120 years of experience, know-how, and dedication can bring to the table.

The 2,200-hp mud pump for offshore applications is a single-acting reciprocating triplex mud pump designed for high fluid flow rates, even at low operating speeds, and with a long stroke design. These features reduce the number of load reversals in critical components and increase the life of fluid end parts.

The pump’s critical components are strategically placed to make maintenance and inspection far easier and safer. The two-piece, quick-release piston rod lets you remove the piston without disturbing the liner, minimizing downtime when you’re replacing fluid parts.

The reason we have to leave the middle of our “drill bit” open when we are washing/drilling a well with two hoses is that at the end of the drilling process we need to be able to slip a wellscreen down through the pipe and “bit” and then pull the drillpipe up and out of the ground.  Otherwise the sand at the bottom of the hole will quickly collapse when we pull the drillpipe out and we won’t be able to get a well screen back down to the bottom of the hole.

We could achieve much more effective drilling if we could use a point or some other shape in the middle of the bit.  Basically with teeth cut in the end of a pipe, we are grinding away at the circumference of the hole and just using the general associated  loosening to evacuate the center of the hole.  This is obviously not the most efficient way to do this.

With a mud pump and a re-circulating drilling fluid system, everything changes.  It gets much easier.  Drilling is more efficient.   We can add bentonite to the drilling fluid and solidify the sandy walls of the hole so they won’t collapse when we remove the drill bit.

Using this techique permits us to drill the hole with a more efficient drillbit that will mechanically eat away the entrie area of the hole, not just the edges.  After we drill the hole, the bentonite will hold the hole open so we can remove our drilling pipe and replace it with out well screen pipe.  Here are some photographs of the drill bit I use.  It was fabricated by a local welding shop for $55.00.

John, in Brandon, Mississippi sent this picture of a drill bit that he fabricated.  It has square pieces of carbide on the outside and he welded a piece across the middle and ran quarter inch bolts through it.  This looks like a great bit for mud pump drilling!

PESI and Halliburton offer many solutions for excellent drilling performance. Our complete line of matrix and steel-bodied drill bits utilize premium cutter technology to deliver best-in-class performance. Standard products include steel tooth and insert roller cone drill bits. The QuadPack® Plus bit series marks a significant advancement in roller cone technology to improve durability and enhance ROP.

Drilling through the most challenging formations, the MegaForce™ bit delivers higher ROP and longer intervals drilled than any other bit. Designed for every operator"s specific application using Halliburtons industry-unique Design at the Customer Interface (DatCI℠) service, this bit features advanced SelectCutter™ PDC Technology, ultra-efficient cutter layout force balancing, improved erosion resistant matrix material and enhanced hydraulics.

The drilling industry has roots dating back to the Han Dynasty in China. Improvements in rig power and equipment design have allowed for many advances in the way crude oil and natural gas are extracted from the ground. Diesel/electric oil drilling rigs can now drill wells more than 4 miles in depth. Drilling fluid, also called drilling mud, is used to help transfer the dirt or drill cuttings from the action of the drilling bit back to the surface for disposal. Drill cuttings can vary in shape and size depending on the formation or design of the drill bit used in the process.

Watch the video below to see how the EDDY Pump outperforms traditional pumps when it comes to high solids and high viscosity materials commonly found on oil rigs.

Solids control equipment including shakers, hydro-cyclones, and centrifuges are utilized to clean the drill cuttings from the drilling fluid, which then allows it to be reused and recirculated. The circuit includes the mixing of the drilling fluid in the rig tanks.

The drilling fluid is prepared to control fluid loss to the formation by the addition of chemicals or mineral agents. Commercial barite or other weighting agents are added to control the hydrostatic pressure exuded on the bottom of the well which controls formation pressures preventing fluid or gas intrusion into the wellbore.

The fluid is charged into high-pressure mud pumps which pump the drilling mud down the drill string and out through the bit nozzles cleaning the hole and lubricating the drill bit so the bit can cut efficiently through the formation. The bit is cooled by the fluid and moves up the space between the pipe and the hole which is called the annulus. The fluid imparts a thin, tough layer on the inside of the hole to protect against fluid loss which can cause differential sticking.

The fluid rises through the blowout preventers and down the flowline to the shale shakers. Shale shakers are equipped with fine screens that separate drill cutting particles as fine as 50-74 microns. Table salt is around 100 microns, so these are fine cuttings that are deposited into the half-round or cuttings catch tank. The drilling fluid is further cleaned with the hydro-cyclones and centrifuges and is pumped back to the mixing area of the mud tanks where the process repeats.

The drill cuttings contain a layer of drilling fluid on the surface of the cuttings. As the size of the drill cuttings gets smaller the surface area expands exponentially which can cause rheological property problems with the fluid. The fluid will dehydrate and may become too thick or viscous to pump so solids control and dilution are important to the entire drilling process.

One of the most expensive and troubling issues with drilling operations is the handling, processing, and circulation of drilling mud along with disposing of the unwanted drill cuttings. The drilling cuttings deposited in the half round tank and are typically removed with an excavator that must move the contents of the waste bin or roll-off box. The excavators are usually rented for this duty and the equipment charges can range from $200-300/day. Add in the cost for the day and night manpower and the real cost for a single excavator can be as much as $1800/day.

Using the excavator method explained above, the unloading of 50 barrels of drill cuttings from the half round can take as long as two hours. This task is mostly performed by the solids control technicians. The prime duty for the solids control technicians is to maintain the solids control equipment in good working order. This involves maintenance for the equipment, screen monitoring and changing, centrifuge adjustments, and retort testing to prepare a daily operational summary of the solids control program.

Offshore drilling rigs follow a similar process in which the mud is loaded into empty drums and held on the oil platform. When a certain number of filled drums is met, the drums are then loaded onto barges or vessels which take the drilling mud to the shore to unload and dispose of.

Oil field drilling operations produce a tremendous volume of drill cuttings that need both removal and management. In most cases, the site managers also need to separate the cuttings from the drilling fluids so they can reuse the fluids. Storing the cuttings provides a free source of stable fill material for finished wells, while other companies choose to send them off to specialty landfills. Regardless of the final destination or use for the cuttings, drilling and dredging operations must have the right high solids slurry pumps to move them for transport, storage, or on-site processing. Exploring the differences in the various drilling fluids, cutting complications, and processing options will reveal why the EDDY Pump is the best fit for the job.

The Eddy Pump is designed to move slurry with solid content as high as 70-80 % depending on the material. This is an ideal application for pumping drill cuttings. Drill cuttings from the primary shakers are typically 50% solids and 50% liquids. The Eddy Pump moves these fluids efficiently and because of the large volute chamber and the design of the geometric rotor, there is very little wear on the pump, ensuring long life and greatly reduced maintenance cost for the lifetime of the pump.

plumbed to sweep the bottom of the collection tank and the pump is recessed into a sump allowing for a relatively clean tank when the solids are removed. The Eddy Pump is sized to load a roll-off box in 10-12 minutes. The benefit is cuttings handling is quicker, easier, safer, and allows for pre-planning loading where the labor of the solids control technician is not monopolized by loading cuttings. Here, in the below image, we’re loading 4 waste roll-off bins which will allow the safe removal of cuttings without fear of the half-round catch tank running over.

Mud cleaning systems such as mud shaker pumps and bentonite slurry pumps move the material over screens and through dryers and centrifuges to retrieve even the finest bits of stone and silt. However, the pump operators must still get the raw slurry to the drill cuttings treatment area with a power main pump. Slurry pumps designed around the power of an Eddy current offer the best performance for transferring cuttings throughout a treatment system.

Options vary depending on whether the company plans to handle drill cuttings treatment on-site or transport the materials to a remote landfill or processing facility. If the plan is to deposit the cuttings in a landfill or a long-term storage container, it’s best to invest in a pump capable of depositing the material directly into transport vehicles. Most dredging operations rely on multiple expensive vacuum trucks, secondary pumps, and extra pieces of equipment.

Using an EDDY Pump will allow a project to eliminate the need for excavators/operators to load drill cuttings, substantially lowering both labor and heavy equipment costs. The EDDY Pump also allows a company to eliminate vacuum trucks once used for cleaning the mud system for displacing fluids. Since the pump transfers muds of all types at constant pressure and velocity throughout a system of practically any size, there’s little need for extra equipment for manual transfer or clean up on the dredge site.

The EDDY Pump can fill up a truck in only 10 minutes (compared to an hour) by using a mechanical means such as an excavator. For this reason, most companies can afford one piece of equipment that can replace half a dozen other units.

This application for the Eddy Pump has the potential to revolutionize the drilling industry. Moving the excavator out of the “back yard” (the area behind the rig from the living quarters) will make cuttings handling a breeze. Trucking can be easier scheduled during daylight hours saving on overtime and incidences of fatigued driving. Rig-site forklifts can move the roll-off boxes out of the staging area and into the pump loading area. The operator can save money on excavators rental, damages, and keep the technician operating the solids control equipment.

The EDDY Pump is ideal for drilling mud pump applications and can be connected directly onto the drilling rigs to pump the drilling mud at distances over a mile for disposal. This eliminates the need for costly vacuum trucks and also the manpower needed to mechanically move the drilling mud. The reasons why the EDDY Pump is capable of moving the drilling mud is due to the hydrodynamic principle that the pump creates, which is similar to the EDDY current of a tornado. This tornado motion allows for the higher viscosity and specific gravity pumping ability. This along with the large tolerance between the volute and the rotor allows for large objects like rock cuttings to pass through the pump without obstruction. The large tolerance of the EDDY Pump also enables the pump to last many times longer than centrifugal pumps without the need for extended downtime or replacement parts. The EDDY Pump is the lowest total life cycle pump on the market.

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The first documented spring-pole well in America was drilled in 1806 by David and Joseph Ruffner in West Virginia. It reached 58 feet in depth, containing 40 feet of bedrock. The project lasted two years.

Men in Kentucky were drilling an exploratory well for salt brine. Instead, they hit an oil well. The pressure of the gas and oil underneath the surface forced an enormous geyser into the air. This was noted to be America’s first oil well (although there are some disputes to this claim).

The French engineer Pierre-Pascal Fauvelle was the first to utilize water circulation in drilling. Using the new method, he drilled 560 feet in 23 days.

J.J. Couch invented the first mechanical percussion drill, which he later perfected with the help of fellow inventor J.W. Fowle. Steam was admitted alternately to each end of a cylinder. The drill was thrown like a lance at the rock on the forward stroke, caught and then drawn back on the reverse stroke, and then thrown again. It was the first drill that did not depend on gravity. It went to work on the Hoosac Tunnel project, which bored a passage for trains through hills near North Adams, Mass.

George Bissell and Edwin L. Drake made the first successful use of a drilling rig on a commercial well drilled especially to produce oil in Pennsylvania. They drilled to 69 feet.

In June, J.C. Rathbone drilled a discovery well to 140 feet using a steam engine on the banks of the Great Kanawha River in the Charleston, W.Va., area. The well produced about 100 barrels of oil a day.

Peter Sweeny, building on Robert Beart"s earlier design, made a huge advancement in rotary drill technology, enabling almost continuous drilling. His new design also improved on hole cleaning.

Charles Burleigh, John W. Brooks, and Stephen F. Gates patented a mechanical drill meant to be used on the Hoosac tunnel: the compressed air Burleigh drill. The tunnel spurred several innovations in drilling technology, including the earlier Couch/Fowle drill.

Simon Ingersoll received a patent for a rock drill on a tripod mount. The drill was designed for mining and tunneling. It enabled the operator to drill at virtually any angle. He formed Ingersoll Rock Drill to capitalize on this invention, a company that is a precursor to Ingersoll-Rand.

John Vivian was given the first U.S. patent for a diamond drill. While other drills before its time bored holes through a succession of blows, this invention allowed the core to remain intact. This made it very valuable for prospectors.

The Bucyrus Foundry and Manufacturing Company was founded in Bucyrus, Ohio. The company later became famous in the drilling industry as Bucyrus-Erie, a maker of cable-tool rigs, but it was an early producer of steam shovels. It supplied many of the steam shovels used in the building of the Panama Canal.

Henry C. Sergeant started the Sergeant Drill Company to manufacture a rock drill he had invented, which included using compressed air to move the drill’s piston onto the steel in a hammering motion. Sergeant Drill Company later merged with Ingersoll Rock Drill to form Ingersoll-Sergeant Drill Company.

Edmund J. Longyear drilled the first diamond core hole in the Mesabi Iron Range (shown above in 1903) in northern Minnesota. Shortly thereafter, he formed a contract diamond drilling company to serve the rapidly growing U.S. iron ore mining and steel industry.

John Smalley Campbell issued the first U.S. patent for the use of flexible shafts to rotate drilling bits. The patent was for dental applications, but was broad enough to cover larger scales, such as those used now in horizontal oil wells.

The Baker brothers were using their rotary method for oil well drilling in the Corsicana field of Navarro County, Texas. Their rig was powered by a mule.

Drillers at Spindletop, including brothers Curt and Al Hamill and Peck Byrd, noticed that muddied-up freshwater could help stabilize a formation and prevent borehole collapse. They started circulating it and drilling mud was born.

Captain Anthony F. Lucas at Spindletop began drilling with a steam-driven rotary rig and a double-pronged fishtail bit. The gusher at Spindletop lasted nine days and ushered in the first Texas oil boom.

Inspired by the success of Spindletop and what it meant for the future of oil drilling in Texas, Howard Hughes Sr. and Walter Sharp founded the Sharp-Hughes Tool Company. The Hughes name lives on today in the name of the company Baker-Hughes.

Edmund J. Longyear and John E. Hodge formed Longyear & Hodge, the manufacturing partnership that would eventually evolve into Boart Longyear. The company"s early drills were steam powered.

Howard Hughes Sr. and Walter Sharp introduced the Sharp-Hughes Rock Bit, which was nicknamed the "rock eater." It was suited for deep boring through medium and hard rock.

The rotary table and kelly were first used. The primary function of the rotary table was to transmit torque to the drillstring via the kelly, a section of pipe with a square cross-section that slotted through a similar shape on the rotating table.

Hugh Roberts, working as a geologist for Edmund Longyear, designed a new form of technology called a core splitter, which divided cores into 3- – 5-inch lengths for better analysis. Drilling firms used Roberts"s core splitter as standard equipment.

Hughes Tool Company (formerly the Sharp-Hughes Tool Company) introduced the sub, a large-diameter reamer placed above the bit designed to keep boreholes straight.

Victor York and Walter G. Black of Standard Oil Company of California were granted a patent for driving the rotary table with a shaft. This innovation guaranteed the ongoing success of the rotary drilling method.

John D. Grant drilled a geothermal well to power the world"s first geothermal power plant in California. The plant provided electricity to light a resort called The Geysers.

The first true horizontal oil well was drilled near Texon, Texas. By the early 1980s, with advancements in drilling motors and steering, the technology finally became widespread.

George E. Failing introduced the first portable rotary rig to the industry. The idea first came after he mounted an existing rig on a 1927 Ford farm truck, adding a power take-off assembly to transfer power from the truck engine to the drill. The new portable rotary rig could drill ten 50-foot-deep holes in a day.

Cal Talc, A. J. Lynch and National Pigment Chemical merged to form Baroid Sales Company. The new company, founded to serve the growing market for products for hydraulic rotary drilling, is based in Los Angeles.

Harlen Marsh of General Petroleum Company invented the funnel that carries his name. He donated the concept for the device, which measures relative viscosity of drilling fluid, to the drilling industry.

In June, the New York State Natural Gas Corporation abandoned a project after having drilled the world"s deepest cable-tool well to a depth of 11,145 feet. The well was located in Van Etten, N.Y. The project started five years earlier.

The first downhole drilling motors, or mud motors, were designed and manufactured by Dyna-Drill. The motor was based on the 1930 Moineau design for progressive cavity pumps.

General Electric Research Lab (GE) introduced a new synthetic material made of diamond grains sintered together with cobalt. This new material, Compax, could be made into various shapes and retained diamond’s natural property of extreme hardness, but not its weak cleavage planes. To make a cutter, a thin layer of the synthetic diamond material was deposited onto a disk-shaped tungsten carbide substrate so that the assembly, called a “compact,” could be attached to the bit. Bits with this kind of cutter are generically called PDC bits.

Teleco Oilfield Services Inc., together with the U.S. Department of Energy, introduced mud pulse telemetry, now a widely used method of transmitting measurement while drilling data to the surface. Commercialized in 1978, the technology had been under development since the late 1960s. Data transmitted by pulses, together with trigonometry, can give operators a three-dimensional plot of the well being drilled. Pulse telemetry improved on the slower process of wireline logging. Teleco was later acquired by Baker Hughes.

The Versa-Sonic drill rig was put into operation. Versa-Drill International Inc. and Bowser-Morner built this rig that incorporated Ray Roussy’s new sonic drill head. Roussy had worked to improve and perfect the technology over more than 20 years from original designs, which modified oscillators for drilling purposes. Sonic drills, like this one used by the Army Corps of Engineers, are now widely used for sampling.

Professors at Texas Tech University developed “zipper fracking,” which is when operators drill two wells side by side. The process allowed both wells to produce more oil and gas.

Advancements in drilling technology moved rapidly in five years, as 16,000-foot wells were taking an average of 32 days to drill. By 2013, the average drill time for 21,000-foot wells was 18 days or less.