oil rig mud pump diagram free sample

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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.

Fig. 1. Kick illustration: Schematic of mud circulating system, with a close up view of the drill bit hitting the lower vein at unexpected higher pressure. KICK occurring. Mud pit fills. Shut-in well. Above the animation is the illustration of the mud return from the surface to the mud pit through the circulating system.

*Liberty Process Equipment, Inc. is not affiliated with nor distributor for Seepex®, Allweiler®, Moyno®, Tarby®, Netzsch®, or Continental Inc.® All referenced product names, brands, models, or part numbers is solely for identification purposes. Seepex® is a registered trademark of Seepex®. Moyno® and Tarby® are registered trademarks of Robins and Myers® and NOV®, Netzsch® Incorporated is a registered trademark of the Netzsch® Group, Allweiler® is a registered trademark of Colfax® Corporations Continental® Pumps is a Trademark of Continental® Ultra Pumps.

Positive displacements pumps are generally used on drilling rigs to pump high pressure and high volume of drilling fluids throughout a drilling system. There are several reasons why the positive displacement mud pumps are used on the rigs.

The duplex pumps (Figure 1) have two cylinders with double acting. It means that pistons move back and take in drilling mud through open intake valve and other sides of the same pistons, the pistons push mud out through the discharge valves.

When the piston rod is moved forward, one of intake valves is lift to allow fluid to come in and one of the discharge valve is pushed up therefore the drilling mud is pumped out of the pump (Figure 2).

On the other hand, when the piston rod is moved backward drilling fluid is still pumped. The other intake and discharge valve will be opened (Figure 3).

The triplex pumps have three cylinders with single acting. The pistons are moved back and pull in drilling mud through open intake valves. When the pistons are moved forward and the drilling fluid is pushed out through open discharge valves.

On the contrary when the piston rods are moved backward, the intake valve are opened allowing drilling fluid coming into the pump (Figure 6). This video below shows how a triplex mud pump works.

Because each pump has power rating limit as 1600 hp, this will limit capability of pump. It means that you cannot pump at high rate and high pressure over what the pump can do. Use of a small liner will increase discharge pressure however the flow rate is reduces. Conversely, if a bigger liner is used to deliver more flow rate, maximum pump pressure will decrease.

As you can see, you can have 7500 psi with 4.5” liner but the maximum flow rate is only 297 GPM. If the biggest size of liner (7.25”) is used, the pump pressure is only 3200 psi.

Finally, we hope that this article would give you more understanding about the general idea of drilling mud pumps. Please feel free to add more comments.

Bell nipple (#22) is a section of large diameter pipe fitted to the top of the blowout preventers that the flow line attaches to via a side outlet, to allow the drilling mud to flow back to the mud tanks.

Casing head (#27) is a large metal flange welded or screwed onto the top of the conductor pipe (also known as drive-pipe) or the casing and is used to bolt the surface equipment such as the blowout preventers (for well drilling) or the Christmas tree (oil well) (for well production).

Centrifuge (not pictured) is an industrial version of the device that separates fine silt and sand from the drilling fluid. It is typically mounted on top or just off of the mud tanks.

Desander / desilter (not pictured) contains a set of hydrocyclones that separate sand and silt from the drilling fluid. Typically mounted on top of the mud tanks.

Drill floor (#21) is the area on the rig where the tools are located to make the connections of the drill pipe, bottom hole assembly, tools and bit. It is considered the main area where work is performed.

Drill pipe (#16) is a joint of hollow tubing used to connect the surface equipment to the bottom hole assembly (BHA) and acts as a conduit for the drilling fluid. In the diagram, these are stood in the derrick vertically, usually to save time while tripping pipe.

Flow line (#28) is large diameter pipe that is attached to the bell nipple and extends to the shale shakers to facilitate the flow of drilling fluid back to the mud tanks.

Mud motor (not pictured) is a hydraulically powered device positioned just above the drill bit used to spin the bit independently from the rest of the drill string.

Setback (#17) is a part of the drill floor (#21) where the stands of drill pipe are stood upright. It is typically made of a metal frame structure with large wooden beams situated within it. The wood helps to protect the end of the drill pipe.

Stand (#16) is a section of 2 or 3 joints of drill pipe connected and stood upright in the derrick. When they are pulled out of the hole, instead of laying down each joint of drill pipe, 2 or 3 joints are left connected and stood in the derrick to save time.

Vibrating hose (#6) is a flexible, high pressure hose (similar to the kelly hose) that connects the mud pump to the stand pipe. It is called the vibrating hose because it tends to vibrate and shake (sometimes violently) due to its close proximity to the mud pumps.

A pit in the ground to provide additional height between the rig floor and the well head to accommodate the installation of blowout preventers, ratholes, mouseholes, and so forth. It also collects drainage water and other fluids for disposal.†

The arrangement of piping and special valves, called chokes, through which drilling mud is circulated when the blowout preventers are closed to control the pressures encountered during a kick.†

A centrifugal device for removing sand from drilling fluid to prevent abrasion of the pumps. It may be operated mechanically or by a fast-moving stream of fluid inside a special cone-shaped vessel, in which case it is sometimes called a hydrocyclone.†

A small enclosure on the rig floor used as an office for the driller or as a storehouse for small objects. Also, any small building used as an office or for storage.†

The hoisting mechanism on a drilling rig. It is essentially a large winch that spools off or takes in the drilling line and thus raises or lowers the drill stem and bit.†

The cutting or boring element used in drilling oil and gas wells. Most bits used in rotary drilling are roller-cone bits. The bit consists of the cutting elements and the circulating element. The circulating element permits the passage of drilling fluid and uses the hydraulic force of the fluid stream to improve drilling rates.†

On diesel electric rigs, powerful diesel engines drive large electric generators. The generators produce electricity that flows through cables to electric switches and control equipment enclosed in a control cabinet or panel. Electricity is fed to electric motors via the panel.†

Shallow bores under the rig floor, usually lined with pipe, in which joints of drill pipe are temporarily suspended for later connection to the drill string.†

A series of open tanks, usually made of steel plates, through which the drilling mud is cycled to allow sand and sediments to settle out. Additives are mixed with the mud in the pit, and the fluid is temporarily stored there before being pumped back into the well. Mud pit compartments are also called shaker pits, settling pits, and suction pits, depending on their main purpose.†

A trough or pipe, placed between the surface connections at the well bore and the shale shaker. Drilling mud flows through it upon its return to the surface from the hole.†

A diesel, Liquefied Petroleum Gas (LPG), natural gas, or gasoline engine, along with a mechanical transmission and generator for producing power for the drilling rig. Newer rigs use electric generators to power electric motors on the other parts of the rig.†

A hole in the rig floor 30 to 35 feet deep, lined with casing that projects above the floor. The kelly is placed in the rathole when hoisting operations are in progress.†

Shallow bores under the rig floor, usually lined with pipe, in which joints of drill pipe are temporarily suspended for later connection to the drill string.†

A mud pit in which a supply of drilling fluid has been stored. Also, a waste pit, usually an excavated, earthen-walled pit. It may be lined with plastic to prevent soil contamination.†

The hose on a rotary drilling rig that conducts the drilling fluid from the mud pump and standpipe to the swivel and kelly; also called the mud hose or the kelly hose.†

A relatively short length of chain attached to the tong pull chain on the manual tongs used to make up drill pipe. The spinning chain is attached to the pull chain so that a crew member can wrap the spinning chain several times around the tool joint box of a joint of drill pipe suspended in the rotary table. After crew members stab the pin of another tool joint into the box end, one of them then grasps the end of the spinning chain and with a rapid upward motion of the wrist "throws the spinning chain"-that is, causes it to unwrap from the box and coil upward onto the body of the joint stabbed into the box. The driller then actuates the makeup cathead to pull the chain off of the pipe body, which causes the pipe to spin and thus the pin threads to spin into the box.†

A vertical pipe rising along the side of the derrick or mast. It joins the discharge line leading from the mud pump to the rotary hose and through which mud is pumped going into the hole.†

The top drive rotates the drill string end bit without the use of a kelly and rotary table. The top drive is operated from a control console on the rig floor.†

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Directional drilling is a broad term used to describe any boring that doesn’t go in a straight line vertically down. In fact, even in a vertical well, it might be necessary to deviate to avoid a geological formation or a previous stuck pipe, then return to the original path. In this instance, the driller uses sidetracking techniques.

In conventional drilling for oil and gas, the drill bit, drillstring, pipe and casing all go down in a straight line. If a driller aims away from the 180-degrees down, that’s technically directional drilling. Nowadays, however, it’s more likely that there’ll be a series of one or more carefully planned directional changes along the wellbore.

Techniques such as multilateral, horizontal and extended reach drilling (ERD) are enhanced oil recovery (EOR) methods that can increase the yield of a downhole dramatically. It’s possible for ERD specialists to drill for more than 10 kilometers/6.2 miles. Students of petroleum engineering often get shown illustrations and diagrams that look like tree roots. If we imagine the rig as the trunk of the tree, the directional possibilities of the roots are endless. Even the branches of the roots are comparable to multilateral drilling.

Multiple down holes can be drilled from the same rig, minimising surface disturbance and environmental impact. Also, these boreholes can extend up to a mile down, and for more than five miles at shallower angles. In an oilfield with dispersed deposits, a large radius can be tapped, maximising the expensive asset which is the rig. Rigs and crews have day rates that run into the hundreds of thousands of dollars, one rig working up to five or ten square miles is very cost-effective in comparison to having a dozen or more vertical rigs, which may or may not be tapping into the same accessible reservoir deposits.

Geologists and engineers use terms such as an ‘oil reservoir’ or a ‘hydrocarbon reservoir’ to describe underground pockets of resources. Scientific terms give a label to help everyone understand each other, but Mother Nature has different ideas about the way she organises things.

People who perform well plans such as seismic geologists, geoscientists, exploration engineers and CAD experts join together to give the best idea of where oil and gas deposits may lie. Their estimates are based on different types of surveys, and past experience. What they’re unlikely to do is pinpoint the exact place where they’d access the maximum amount of resources.

The deposit might not resemble a reservoir at all, it might be oil-saturated sand or shale. Directional drilling is especially valuable in shale, where the formation can be explored to follow richer seams.

Rather than the oil and gas settling in a single deposit, it’s in separate distinct pockets, not clearly joined to each other. This can occur where there are multiple bed dips or altitudes.

This depends on the amount of underground pressure. In some instances, a second control well is drilled so that it intercepts the same point where the original wellbore meets the reservoir. Once the new directional well is completed, it can be pumped with kill fluid.

If the well pressure isn’t too severe a relief well can help to release gas so that the original gusher reduces in intensity, allowing it to be controlled. Mud and water are pumped in from a different angle, to get the first well under control and back to proper working order.

It’s not possible to see hundreds of metres underground, in fact, the drillers and engineers rely entirely on technology to ‘see’ where they are going. A directional driller has a guide that has been created by the engineers and geologists. Every 10-150 metres, (with 30-40 being typical), survey data is sent back to make sure that the original ‘blue line’ well path is being followed.

Directional drilling software receives input from multiple measurements while drilling (MWD) sensors in the drill bit, and at any branches or junctions. (Other measurement tools include Electromagnetic MWD and Global Positioning Sensors (GPS)). In addition to MWD technology, mud loggers use logging while drilling (LWD) sensors and software. The drill bit has vibration sensors that can detect the type of formation being drilled at any point. Collars can be added along the length of the well, sending back information to the surface regarding torque, weight and bending.

The rotational speed of the drill and the weight and stiffness of the drillstring can also be used to influence direction. One of the original methods was jetting, a high-pressure nozzle shot water or drilling fluid from one edge to the drill bit, creating a weaker side in the formation.

Drill bit sensors can tell the driller about external weight, and rotary speed that can also be used to influence the trajectory. Mud motors can also be used to change direction. With a steerable drill pipe, there’s a bend near the bit. The drillstring stops turning, and then there is plenty of time to use chosen directional techniques to reposition the bit to the desired trajectory. When it starts spinning again, it’ll start going in the direction that it’s now pointing towards. (More about steerable mud motors in the next section).

Specialised drillbits are used to improve performance and reduce the chance of failure. Schlumberger supply directional PDC drill bits for both push- and point-the-bit rotary steerable systems. Horizontal Technology, Inc. provides ‘Varel High Energy Series bits’ designed for the unique, rigorous conditions of horizontal directional drilling.

Mud Motors. Downhole steerable mud motors get positioned near the drill bit, which has a bend in it. What happens is that at the correct depth the drillstring stops rotating, then drilling fluid is pumped through the mud motor so that the drill bit starts to turn just due to the force of the liquid. This mud pressure pushes the drill bit into a different angle, and also begins to bite into the formation at a different angle to the central well trajectory. Once the sensors verify that the drill bit is pointing in the right direction, the drillstring starts to turn again.

Rotary Steerable Systems (RSS). Directional drilling by using the mud motor means that often the drill pipe needs to be slid forward while the drill is motionless. A rotary steerable system can drill and steer at the same time. This means that previously inaccessible formations can be accessed.

Networked or wired pipe. The Intelliserve system from National Oilwell Varco is a broadband networked drilling string system. It can transmit data from the sensors back to the surface.

For example, a downhole drilling motor will always be far smaller and less powerful than one connected to a robust drilling rig above ground. It’s more likely to fail, or have insufficient torque or speed to get through challenging geological formations.

There are a few different types of directional drilling. Multilateral drilling is where a downhole bore has multiple lateral (90 degrees) offshoots. For example, a well might be 1000 metres in depth but have numerous lateral wells connected to it.  Extended reach drilling (ERD) is categorised by ever longer wellbores drilled from the rig.

Land tenders offer the right to explore and extract resources from a particular square meterage of land. It’s possible to purchase a lease for an oil patch, then drill horizontally into neighbouring territory. Close to a national border, it’s been known for drillers to drill into another country.

The oil industry is aware of the ability to horizontally tap deposits under other peoples leases, lawsuits related to this started way back in the 1920s.