how many kwh does a mud pump use brands

This mud pump will deliver the consistent flow of drilling fluid that is vital to HDD pipeline drilling projects. Suction inlet valve suspends charged flow during drill rod makeup and breakout process, keeping excess drilling fluid from escaping as drill pipes separate. The lubrication pump is driven off the auxiliary pad on the engine. It provides 55 psi (3.8 bar) of continuous crankshaft lubrication. The internal hydraulic reservoir has a capacity of 49 gal (185.5 L). Clutch with continuous duty throw-out bearing allows for longer pump disengagement during drill rod makeup/breakout....

A triplex piston pump produces up to 435.3 gpm (1647.8 L/min), providing a continuous flow of drilling fluid during drill operations. An electric centrifugal pump provides constant flow, keeping the pump running cool and leading to a longer life for both pistons and liners. Remote pendant control allows operator to mount controls where it makes sense for them. The remote pendant control monitors mud rate and eliminates the need for stroke counter. The integrated liner wash tank eliminates the need for additional water containers or electricity when running the pump. An engine-mounted air...

Specifications Additional Components General Weights and Dimensions Weight: 26,600 lb (12,065.6 kg) Length: 19.1" (5.8 m) Width: 91.1" (231.4 cm) Height: 78" (198.1 cm) Controls Onboard: Open control station Remote: Tethered control box reaches 120" (36.6 m) Power Source Power source description: Non-detachable, onboard, open engine bay Engine description: CAT C9 or C9.3 ACERT IOPU EPA certification family: Tier 3 (EU Stage IIIA) or Tier 4i (EU Stage IIIB) Fuel type: Diesel Rated power: 350 hp (257.4 kW) Rated engine speed: 1800 rpm Fuel tank capacity: 191 gal (723 L) Electrical system:...

*Prices are pre-tax. They exclude delivery charges and customs duties and do not include additional charges for installation or activation options. Prices are indicative only and may vary by country, with changes to the cost of raw materials and exchange rates.

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Choose a used Emsco FB-1600 Triplex Mud Pump from our inventory selection and save yourself some money on your next shallow drilling oilfield project. This Emsco FB-1600 Triplex Mud Pump is used and may show some minor wear.

We offer wholesale pricing on new Emsco FB-1600 Triplex Mud Pump and pass the savings on to you. Contact us to compare prices of different brands of Mud Pump. This equipment is brand new and has never been used.

Our large network often has surplus Emsco FB-1600 Triplex Mud Pump that go unused from a surplus purchase or a project that was not completed. Contact us to see what Emsco FB-1600 Triplex Mud Pump we have in inventory. The surplus Emsco FB-1600 Triplex Mud Pump are considered new but may have some weathering depending on where it was stored. Surplus oilfield equipment is usually stored at a yard or warehouse.

We have refurbished Mud Pumpthat have been used and brought up to functional standards. It is considered a ready to use, working Mud Pump. Please contact us for more information about our refurbished Emsco FB-1600 Triplex Mud Pump. These Mud Pump have been used and brought up to functional standards. It is considered a working Mud Pump. Please contact us for more information about the product.

Since the NOV A1700-PT Triplex Mud Pump was built approximately 60 years ago, the industry has widely accepted the three cylinder or triplex style pump. Triplex mud pumps are manufactured worldwide, and many companies have emulated the original design and developed an improved form of the triplex pump in the past decade.

NOV A1700-PT Triplex Mud Pumps have many advantages they weight 30% less than a duplex of equal horsepower or kilowatts. The lighter weight parts are easier to handle and therefore easier to maintain. The other advantages include;They cost less to operate

One of the more important advantages of triplex over duplex pumps, is that they can move large volumes of mud at the higher pressure is required for modern deep hole drilling.

NOV A1700-PT Triplex Mud Pump is gradually phasing out duplex units. In a triplex pump, the pistons discharge mud only when they move forward in the liner. Then, when they moved back they draw in mud on the same side of the piston. Because of this, they are also called “single acting.” Single acting triplex pumps, pump mud at a relatively high speeds. NOV A1700-PT Triplex Mud Pump has three pistons each moving in its own liner. It also has three intake valves and three discharge valves. It also has a pulsation dampener in the discharge line.

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Pumps tend to be one of the biggest energy consumers in industrial operations. Pump motors, specifically, require a lot of energy. For instance, a 2500 HP triplex pump used for frac jobs can consume almost 2000 kW of power, meaning a full day of fracking can cost several thousand dollars in energy costs alone!

So, naturally, operators should want to maximize energy efficiency to get the most for their money. Even a 1% improvement in efficiency can decrease annual pumping costs by tens of thousands of dollars. The payoff is worth the effort. And if you want to remotely control your pumps, you want to keep efficiency in mind.

In this post, we’ll point you in the right direction and discuss all things related to pump efficiency. We’ll conclude with several tips for how you can maintain pumping efficiency and keep your energy costs down as much as possible.

In simple terms, pump efficiency refers to the ratio of power out to power in. It’s the mechanical power input at the pump shaft, measured in horsepower (HP), compared to the hydraulic power of the liquid output, also measured in HP. For instance, if a pump requires 1000 HP to operate and produces 800 HP of hydraulic power, it would have an efficiency of 80%.

Remember: pumps have to be driven by something, i.e., an electric or diesel motor. True pump system efficiency needs to factor in the efficiency of both the motor AND the pump.

Consequently, we need to think about how electrical power (when using electric motors) or heat power (when using combustion engines) converts into liquid power to really understand pump efficiency.

Good pump efficiency depends, of course, on pump type and size. High-quality pumps that are well-maintained can achieve efficiencies of 90% or higher, while smaller pumps tend to be less efficient. In general, if you take good care of your pumps, you should be able to achieve 70-90% pump efficiency.

Motor efficiency is also an important factor here. Motor efficiency depends on the fuel type, whether electricity or hydrocarbon, which in turn depends on availability and cost.

AC motors can achieve 90%+ efficiency when converting electrical to mechanical energy. Combustion engines are much less efficient, with typical efficiency ratings coming in at ~20% for gasoline and ~40% for diesel. Your choice of engine or motor type will depend on the availability and cost of fuel or electricity in your area.

Electric motors are more efficient than combustion engines, but site location and the cost of fuel can make the choice of combustion engines more practical.

Now that we have a better understanding of the pump efficiency metric, let’s talk about how to calculate it. The mechanical power of the pump, or the input power, is a property of the pump itself and will be documented during the pump setup. The output power, or hydraulic power, is calculated as the liquid flow rate multiplied by the "total head" of the system.

Remember: we’re trying to find the ratio of power in to power out. Since rations require equal units on both sides, we"ll have to do some conversions to get our hydraulic power units in HP. You"ll see how this is done in the example below.

IMPORTANT: to calculate true head, you also need to factor in the work the pump does to move fluid from the source. For example, if the source water is below the pump, you need to account for the extra work the pump puts in to draw source water upwards.

*Note - this calculation assumes the pump inlet is not pressurized and that friction losses are minimal. If the pump experiences a non-zero suction pressure, or if there is significant friction caused by the distance or material of the pipe, these should be factored in as well.

Every foot of water creates an additional 0.434 PSI of pressure, so we"ll find the elevation head by converting the change in elevation in feet to the suction pressure created by the water.

You"ll notice that the elevation head is minimal compared to the discharge pressure, and has minimal effect on the efficiency of the pump. As the elevation change increases or the discharge pressure decreases, however, elevation change will have a greater impact on total head.

Obviously, that’s a fair amount of math to get at the pump efficiency, considering all of the units conversions that need to be done. To avoid doing these calculations manually, feel free to use our simple pump efficiency calculator.

Our calculations use static variables (pump-rated horsepower and water source elevation) and dynamic variables (discharge flow and pressure). To determine pump efficiency, we need to measure the static variables only once, unless they change.

If you want to measure the true efficiency of your pump, taking energy consumption into account, you could add an electrical meter. Your meter should consist of a current transducer and voltage monitor (if using DC) for electrical motors or a fuel gauge for combustion. This would give you a true understanding of how pump efficiency affects energy consumption, and ultimately your bank account.

Up until this point, we’ve covered the ins and outs of how to determine pump efficiency. We’re now ready for the exciting stuff - how to improve pump efficiency!

One of the easiest ways to improve pump efficiency is to actually monitor pumps for signs of efficiency loss! If you monitor flow rate and discharge (output power) along with motor current or fuel consumption, you’ll notice efficiency losses as soon as they occur. Simply having pump efficiency information on hand empowers you to take action.

Another way to increase efficiency is to keep pumps well-maintained. Efficiency losses mostly come from mechanical defects in pumps, e.g., friction, leakages, and component failures. You can mitigate these issues through regular maintenance that keeps parts in working order and reveals impending failures. Of course, if you are continuously monitoring your pumps for efficiency drops, you’ll know exactly when maintenance is due.

You can also improve pump efficiency by keeping pumps lubricated at all times. Lubrication is the enemy of friction, which is the enemy of efficiency (“the enemy of my enemy is my friend…”).

The best way to ensure lubrication is to monitor lube tanks or sumps and make sure you always have lubrication on hand. You can also monitor lubricant consumption for significant changes. If lubricant usage goes up, it could signal that friction has increased in the system.

A fourth way to enhance pump efficiency is to ensure your pumps and piping are sized properly for your infrastructure. Although we’re bringing this up last, it’s really the first step in any pumping operation. If your pumps and piping don’t match, no amount of lubricant or maintenance will help.

Pipes have physical limits to how much fluid they can move at a particular pressure. If pipes aren’t sized properly, you’ll lose efficiency because your motor will have to work harder. It’s like air conditioning - if your ductwork isn’t sized appropriately for your home, you’ll end up paying more on your energy bill.

In this post, we’ve given you the full rundown when it comes to calculating and improving pump efficiency. You can now calculate, measure, and improve pump efficiency, potentially saving your business thousands of dollars annually on energy costs.

For those just getting started with pump optimization, we offer purpose-built, prepackaged solutions that will have you monitoring pump efficiency in minutes, even in hazardous environments.

Mud pump is one of the most critical equipment on the rig; therefore personnel on the rig must have good understanding about it. We’ve tried to find the good training about it but it is very difficult to find until we’ve seen this VDO training and it is a fantastic VDO training about the basic of mud pumps used in the oilfield. Total length of this VDO is about thirteen minutes and it is worth to watch it. You will learn about it so quickly. Additionally, we also add the full detailed transcripts which will acceleate the learning curve of learners.

Powerful mud pumps pick up mud from the suction tank and circulate the mud down hole, out the bit and back to the surface. Although rigs usually have two mud pumps and sometimes three or four, normally they use only one at a time. The others are mainly used as backup just in case one fails. Sometimes however the rig crew may compound the pumps, that is, they may use three or four pumps at the same time to move large volumes of mud when required.

Rigs use one of two types of mud pumps, Triplex pumps or Duplex pumps. Triplex pumps have three pistons that move back-and-forth in liners. Duplex pumps have two pistons move back and forth in liners.

Triplex pumps have many advantages they weight 30% less than a duplex of equal horsepower or kilowatts. The lighter weight parts are easier to handle and therefore easier to maintain. The other advantages include;

• One of the more important advantages of triplex over duplex pumps, is that they can move large volumes of mud at the higher pressure is required for modern deep hole drilling.

Triplex pumps are gradually phasing out duplex units. In a triplex pump, the pistons discharge mud only when they move forward in the liner. Then, when they moved back they draw in mud on the same side of the piston. Because of this, they are also called “single acting.” Single acting triplex pumps, pump mud at a relatively high speeds. Input horsepower ranges from 220 to 2200 or 164 to 1641 kW. Large pumps can pump over 1100 gallons per minute, over 4000 L per minute. Some big pumps have a maximum rated pressure of over 7000 psi over 50,000 kPa with 5 inch/127 mm liners.

Here is a schematic of a triplex pump. It has three pistons each moving in its own liner. It also has three intake valves and three discharge valves. It also has a pulsation dampener in the discharge line.

Look at the piston at left, it has just completed pushing mud out of the liner through the open discharge valve. The piston is at its maximum point of forward travel. The other two pistons are at other positions in their travel and are also pumping mud. But for now, concentrate on the left one to understand how the pump works. The left piston has completed its backstroke drawing in mud through the open intake valve. As the piston moved back it instead of the intake valve off its seat and drew mud in. A strong spring holds the discharge above closed. The left piston has moved forward pushing mud through the now open discharge valve. A strong spring holds the intake valve closed. They left piston has completed its forward stroke they form the length of the liner completely discharging the mud from it. All three pistons work together to keep a continuous flow of mud coming into and out of the pump.

Crewmembers can change the liners and pistons. Not only can they replace worn out ones, they can also install different sizes. Generally they use large liners and pistons when the pump needs to move large volumes of mud at relatively low pressure. They use a small liners and pistons when the pump needs to move smaller volumes of mud at a relatively high pressure.

In a duplex pump, pistons discharge mud on one side of the piston and at the same time, take in mud on the other side. Notice the top piston and the liner. As the piston moves forward, it discharges mud on one side as it draws in mud on the other then as it moves back, it discharges mud on the other side and draws in mud on the side it at had earlier discharge it. Duplex pumps are therefore double acting.

Double acting pumps move more mud on a single stroke than a triplex. However, because of they are double acting they have a seal around the piston rod. This seal keeps them from moving as fast as a triplex. Input horsepower ranges from 190 to 1790 hp or from 142 to 1335 kW. The largest pumps maximum rated working pressure is about 5000 psi, almost 35,000 kPa with 6 inch/152 mm linings.

A mud pump has a fluid end, our end and intake and the discharge valves. The fluid end of the pump contains the pistons with liners which take in or discharge the fluid or mud. The pump pistons draw in mud through the intake valves and push mud out through the discharge valves.

The power end houses the large crankshaft and gear assembly that moves the piston assemblies on the fluid end. Pumps are powered by a pump motor. Large modern diesel/electric rigs use powerful electric motors to drive the pump. Mechanical rigs use chain drives or power bands (belts) from the rig’s engines and compounds to drive the pump.

A pulsation dampener connected to the pump’s discharge line smooths out surges created by the pistons as they discharge mud. This is a standard bladder type dampener. The bladder and the dampener body, separates pressurized nitrogen gas above from mud below. The bladder is made from synthetic rubber and is flexible. When mud discharge pressure presses against the bottom of the bladder, nitrogen pressure above the bladder resists it. This resistance smoothes out the surges of mud leaving the pump.

Here is the latest type of pulsation dampener, it does not have a bladder. It is a sphere about 4 feet or 1.2 m in diameter. It is built into the mud pump’s discharge line. The large chamber is form of mud. It has no moving parts so it does not need maintenance. The mud in the large volume sphere, absorbs this surges of mud leaving the pump.

A suction dampener smooths out the flow of mud entering into the pump. Crewmembers mount it on the triplex mud pump’s suction line. Inside the steel chamber is a air charged rubber bladder or diaphragm. The crew charges of the bladder about 10 to 15 psi/50 to 100 kPa. The suction dampener absorbs surges in the mud pump’s suction line caused by the fast-moving pump pistons. The pistons, constantly starts and stops the mud’s flow through the pump. At the other end of the charging line a suction pumps sends a smooth flow of mud to the pump’s intake. When the smooth flow meets the surging flow, the impact is absorbed by the dampener.

Workers always install a discharge pressure relief valve. They install it on the pump’s discharge side in or near the discharge line. If for some reason too much pressure builds up in the discharge line, perhaps the drill bit or annulus gets plugged, the relief valve opens. That opened above protects the mud pump and system damage from over pressure.

Some rig owners install a suction line relief valve. They install it on top of the suction line near the suction dampener. They mount it on top so that it won’t clog up with mud when the system is shut down. A suction relief valve protects the charging pump and the suction line dampener. A suction relief valve usually has a 2 inch or 50 mm seat opening. The installer normally adjusts it to 70 psi or 500 kPa relieving pressure. If both the suction and the discharged valves failed on the same side of the pump, high back flow or a pressure surge would occur. The high backflow could damage the charging pump or the suction line dampener. The discharge line is a high-pressure line through which the pump moves mud. From the discharge line, the mud goes through the stand pipe and rotary hose to the drill string equipment.

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.

VATVA GIDC, Ahmedabad 195, Pushpak Industrial Estate, Old Nika Tube Compound Phase I, GIDC, Vatva, VATVA GIDC, Ahmedabad - 382445, Dist. Ahmedabad, Gujarat

Ramnath Industrial Park, Rajkot Ramnath Industrial Park, Kothariya Ring Road, Beside Murlidhar Way Bridge Aaji dem, Near Ramvan, Ramnath Industrial Park, Rajkot - 360002, Dist. Rajkot, Gujarat

mahila college circle, Bhavnagar FIRST FLOOR PLOT NO 851/B-4 K K AVENUE ROAD, KRUSHNANAGAR SHANTAM BUNGLOWS Blood Bank Road, mahila college circle, Bhavnagar - 364001, Dist. Bhavnagar, Gujarat

Amraiwadi, Ahmedabad No. 16, Bankar Estate, Near Anup Estate, Behind Bharat Party Plot National Highway No. 8, Amraiwadi, Amraiwadi, Ahmedabad - 380026, Dist. Ahmedabad, Gujarat

Near Chhotalal Cross Road, Odhav, Ahmedabad 6, Agrasen Estate Opposite LIG Quarters, D 44 Road, Near Chhotalal Cross Road, Odhav, Ahmedabad - 382415, Dist. Ahmedabad, Gujarat

Odhav, Ahmedabad 11, Karma Industrial Park, Kathwada, Odhav Ring Road Circle, Kathwada Singarva Road GIDC, Odhav, Ahmedabad - 382430, Dist. Ahmedabad, Gujarat

Sarkhe Highway, Ahmedabad No. 19, Ground Floor, Yogeswar Complex, Opposite Sola Overbridge, Near The Fern Hotel Gulab Tower Road, S.G Highway, Thaltej, Sarkhe Highway, Ahmedabad - 380054, Dist. Ahmedabad, Gujarat

Established in 1991, Laxmi Pumps Private Limited has been producing LADA Submersible Pumps exclusively with reliable quality and excellent after-sales service. LADA is the brand under which our products are manufactured and marketed.

Established in 1991, Laxmi Pumps Private Limited has been producing LADA Submersible Pumps exclusively with reliable quality and excellent after-sales service. LADA is the brand under which our products are manufactured and marketed.

We are one of the renowned Manufacturers, Exporters and Suppliers of precision-engineered Mud Pumps in Gujarat (India). Our LX-series of Mud Pumps sold under the brand name “Laxmi” is manufacturing in compliance with international standards as our company isISO 9001: 2008 certified.

Developed by a team of highly qualified engineers using computer-aided designing and manufacturing technologies, our Mud Pumps are double-acting and piston (reciprocating) type. They are designed to endure high pressure and high discharge application. In addition, they have several in-built design and constructional features that ensure high efficiency without much electricity intake.

Our Mud Pumps are available in various models and can be ordered in bulk. In addition, we offer them at very economical prices and provide customized solutions.

Our Mud Pumps are duplex double acting reciprocating type made from a single piece alloy casting capable of handling high discharge and high pressure applications. These are ideally suitable for seismograph survey, water well, oil well, core drilling mud and cement service applications. Moreover, the pumps feature continuous tooth herring-bone gears fitted with eccentric for easy economical replacement.

We have the requisite technical and commercial expertise to expand our business to new horizons of growth. Company’s main strength is its Quality and Innovative designs. This is the reason why our products are well established as POWERSAVER PUMPS in the market.

Over the years, we have developed an ultramodern production unit spread over 550 Sq .ft of land. We have equipped our unit with the latest technologies and advanced machineries. Backed by these resources, we produce 15 pieces per month. Following are the equipment we have at our unit:

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Drilling for oil and natural gas is a complex process, but advanced technology has made the job more efficient and productive while providing less impact on the environment. Want to see how the oil and gas industry does it? Click each numbered component in the drawing to learn more.

1. Some people believe that oil and natural gas companies can explore for oil wherever they want. This is not true. Companies must secure permission from the owner of the mineral rights, whether the owner is a private citizen or the government. Many mineral owners and the government allow oil and natural gas companies to compete to drill on their land. The companies assume all the costs and risks of drilling and, in return, pay the mineral owners a portion of what they find and a signing bonus to secure the drilling rights. The share of the production paid by the company to the mineral owner is called a royalty payment.

The drilling derrick is used to position and support the drill string. Modern drilling equipment comes in a wide range of sizes. Many wells can be drilled with equipment that requires far less space than in the past.

Drill rigs now run on electricity to supply the power to turn the bit and raise and lower the drill pipe and casing. Since most drilling occurs in remote areas, the electricity is supplied by electric power generators that run on diesel fuel. These generators make drilling rigs much quieter than in the past.

The drill bit uses three conical shaped cutting surfaces to grind rock into rice-sized particles. The newest bits drill 150 percent to 200 percent faster than similar bits just a few years ago! The drill string consists of lengths of pipe fastened to each other and to the drill bit. The drill string transmits power from the top drive to the drill bit.

As the drill cuts into the rock, drilling mud is added to the hole. This helps cool the drill bit, and the mud is circulated to bring cuttings to the surface. The weight of the drilling mud keeps the hole open. It also helps counteract the pressure of any gas or fluids encountered along the way, in this way preventing a well from loss of control or "blow out.”

Protecting the aquifer from contamination is a major concern of the oil and natural gas industry. Casing made of steel or high-tech alloys is lowered into the hole and cemented into place to protect fresh water aquifers. The casing also keeps the hole open so that oil and natural gas can be brought to the surface.

To reduce waste, the drilling mud is passed through a sieve where the ground rock particles or cuttings can be removed. Then the mud is recycled back into the hole.

Dirt and rock cuttings are removed from the hole and temporarily stored nearby. Holding areas are carefully sited, lined and often times covered with nets to protect local wildlife.

All aspects of the drilling operations are closely monitored to ensure efficient drilling and safety. Electronic sensors measure drilling rates, vibration, pressure, rock type, mud properties and many other drilling parameters. Computers monitor operations and collect data from inside the well. With advanced communications technology, drilling personnel can share and review this data with engineers and geologists located thousands of miles away. If a problem is detected, the rig can be safely and quickly shut down.

Industrial pumps are essential devices required in every phase of oil and gas operations. Basically, they help transfer process fluids from one point to another.

For example, a pump can be used to transfer crude oil from a storage tank to a pipeline and mud pumps are used to circulate drilling mud into the annulus of a drill bit and back to a storage tank for re-purification.

In oil and gas operations, process fluids can range from easy to difficult.  Depending on the nature of the substance you want to transfer and your required flow rate, you’ll need a suitable pump for your needs.

Various types of industrial pumps are utilized for fluid transfer in the oil and gas industry. Pumps used in O&G can be classified based on their design and construction and generally fall into 6 major categories:

Centrifugal pumps are the most common types of pumps used in the oil and gas industry. Centrifugal pumps use centrifugal force through the rotation of the pump impeller to draw fluid into the intake of the pump and force it through the discharge section via centrifugal force. The flow through the pump is controlled by discharge flow control valves.

Single stage centrifugal pumps are primarily used for transferring low-viscosity fluids that require high flow rates. They are typically used as part of a larger pump network comprising other centrifugal pumps like horizontal multistage pump units for crude oil shipping or water injection pumps used in secondary oil and gas recovery.

Plunger pumps are some of the most ubiquitous industrial pumps in the oil and gas industry. Plunger pumps use the reciprocating motion of plungers and pistons to pressurize fluid in an enclosed cylinder to a piping system. Plunger pumps are considered constant flow pumps since at a given speed, the flow rate is constant despite the system pressure. A relief valve is an essential part of any plunger pump discharge piping system to prevent overpressuring of the pump and piping system.

Plunger pumps require more frequent maintenance than centrifugal pumps due to the design of the moving parts. They also have a noisier operation than centrifugal pumps.

A progressive cavity pump is a type of positive displacement pump and is also known as an eccentric screw pump or cavity pump. It transfers fluid by means of the progress, through the pump, of a sequence of small, fixed shape, discrete cavities, as its rotor is turned. Progressive cavity pumps are used in high viscosity applications or if blending the of the pumped fluid is not desired.

Progressive cavity pumps are also considered constant flow pumps since at a given speed, the flow rate is relatively constant despite the system pressure. Flow slippage is normal at higher pressures. A relief valve is an essential part of any progressive cavity pump discharge piping system to prevent overpressuring of the pump and piping system.

Diaphragm pumps are one of the most versatile types of oil and gas pumps in the industry and transfer fluid through positive displacement with a valve and diaphragm. The working principle of this pump is that a decrease in volume causes an increase in pressure in a vacuum and vice versa.

Diaphragm pumps are suitable for high-volume fluid transfer operations in oil refineries. They also require much less maintenance than positive displacement pumps due to their fewer moving parts and less friction during operation and are available in compact designs.

On the downside, diaphragm pumps are susceptible to ‘winks’ – low-pressure conditions inside the system that slow down pumping operations. Fortunately, winks can be rectified by using a back-pressure regulator. For the same reason, they are not suitable for continuous or long-distance pumping operations as they generally don’t meet the high-pressure conditions required.

A gear pump uses the meshing of gears to pump fluid by displacement. Gear pumps are one of the most common types of positive displacement pumps for transferring industrial fluids.

Gear pumps are also widely used for chemical transfer applications for high viscosity fluids. There are two main variations: external gear pumps which use two external spur gears or timing gears that drive the internal gear set. The internal gears do not touch, so non-lubricating fluids can be pumped with external gear pumps. Internal gear pumps use a shaft driven drive gear to drive the internal mating gear. Gear pumps are positive displacement (or fixed displacement), meaning they pump a constant amount of fluid for each revolution.

Since the pumped fluid passes between the close gear tolerances, gear pumps are normally used for clean fluids. A relief valve is an essential component in the discharge piping system to protect the pump and piping from over pressurizing.

A metering pump moves a precise volume of liquid in a specified time period providing an accurate flow rate. Delivery of fluids in precise adjustable flow rates is sometimes called metering. The term “metering pump” is based on the application or use rather than the exact kind of pump used. Most metering pumps are simplex reciprocating pumps with a packed plunger or diaphragm liquid end. The diaphragm liquid end is preferred since the pumped fluid is sealed inside the diaphragm. No pumped liquid leaks to the atmosphere.

At IFS, we design and manufacture modular and custom process solutions to suit diverse oilfield applications. Our expert process skid manufacturers have engineered a range of products and solutions for upstream, midstream, and downstream sectors.

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.

The fluid end includes cylinders (module), valve assembly, cylinder liners, piston assembly, suction manifold, discharge manifold, piston rod, pulsation dampener assembly, etc.

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.

At this time the intake valves are closed and the exhaust valves open, allowing the piston to force the fluid out of the cylinder under pressure. Once the piston reaches its maximum depth into the cylinder, the exhaust valves close and the process repeats.

For Fluid End: piston rod clamp, piston rod, piston assembly, cylinder cover, liner, liner flange, wear plate, cylinder, valve assembly, valve cover, valve guide, flashboard assy., cylinder cover flange, cylinder head, gaskets, studs, nuts, seal rings, pulsation dampener, bladder, discharge manifold, suction manifold, etc.

Geothermal energy is heat that is generated within the Earth. (Geo means “earth,” and thermal means “heat” in Greek.) It is a renewable resource that can be harvested for human use.

About 2,900 kilometers (1,800 miles) below the Earth’s crust, or surface, is the hottest part of our planet: the core. A small portion of the core’s heat comes from the friction and gravitational pull formed when Earth was created more than 4 billion years ago. However, the vast majority of Earth’s heat is constantly generated by the decay of radioactive isotopes, such as potassium-40 and thorium-232.

Potassium, for instance, has 20 neutrons in its nucleus. Potassium-40, however, has 21 neutrons. As potassium-40 decays, its nucleus changes, emitting enormous amounts of energy (radiation). Potassium-40 most often decays to isotopes of calcium (calcium-40) and argon (argon-40).

Radioactive decay is a continual process in the core. Temperatures there rise to more than 5,000° Celsius (about 9,000° Fahrenheit). Heat from the core is constantly radiating outward and warming rocks, water, gas, and other geological material.

Earth’s temperature rises with depth from the surface to the core. This gradual change in temperature is known as the geothermal gradient. In most parts of the world, the geothermal gradient is about 25° C per 1 kilometer of depth (1° F per 77 feet of depth).

If underground rock formations are heated to about 700-1,300° C (1,300-2,400° F), they can become magma. Magma is molten (partly melted) rock permeated by gas and gas bubbles. Magma exists in the mantle and lower crust, and sometimes bubbles to the surface as lava.

Magma heats nearby rocks and underground aquifers. Hot water can be released through geysers, hot springs, steam vents, underwater hydrothermal vents, and mud pots.

These are all sources of geothermal energy. Their heat can be captured and used directly for heat, or their steam can be used to generate electricity. Geothermal energy can be used to heat structures such as buildings, parking lots, and sidewalks.

Most of the Earth’s geothermal energy does not bubble out as magma, water, or steam. It remains in the mantle, emanating outward at a slow pace and collecting as pockets of high heat. This dry geothermal heat can be accessed by drilling, and enhanced with injected water to create steam.

Many countries have developed methods of tapping into geothermal energy. Different types of geothermal energy are available in different parts of the world. In Iceland, abundant sources of hot, easily accessible underground water make it possible for most people to rely on geothermal sources as a safe, dependable, and inexpensive source of energy. Other countries, such as the U.S., must drill for geothermal energy at greater cost.

Almost anywhere in the world, geothermal heat can be accessed and used immediately as a source of heat. This heat energy is called low-temperature geothermal energy. Low-temperature geothermal energy is obtained from pockets of heat about 150° C (302° F). Most pockets of low-temperature geothermal energy are found just a few meters below ground.

Low-temperature geothermal energy can be used for heating greenhouses, homes, fisheries, and industrial processes. Low-temperature energy is most efficient when used for heating, although it can sometimes be used to generate electricity.

People have long used this type of geothermal energy for engineering, comfort, healing, and cooking. Archaeological evidence shows that 10,000 years ago, groups of Native Americans gathered around naturally occurring hot springs to recuperate or take refuge from conflict. In the third century BCE, scholars and leaders warmed themselves in a hot spring fed by a stone pool near Lishan, a mountain in central China. One of the most famous hot spring spas is in the appropriately named town of Bath, England. Starting construction in about 60 CE, Roman conquerors built an elaborate system of steam rooms and pools using heat from the region’s shallow pockets of low-temperature geothermal energy.

The hot springs of Chaudes Aigues, France, have provided a source of income and energy for the town since the 1300s. Tourists flock to the town for its elite spas. The low-temperature geothermal energy also supplies heat to homes and businesses.

Co-produced geothermal energy technology relies on other energy sources. This form of geothermal energy uses water that has been heated as a byproduct in oil and gas wells.

In the United States, about 25 billion barrels of hot water are produced every year as a byproduct. In the past, this hot water was simply discarded. Recently, it has been recognized as a potential source of even more energy: Its steam can be used to generate electricity to be used immediately or sold to the grid.

Newer technology has allowed co-produced geothermal energy facilities to be portable. Although still in experimental stages, mobile power plants hold tremendous potential for isolated or impoverished communities.

Geothermal heat pumps (GHPs) take advantage of the Earth’s heat, and can be used almost anywhere in the world. GHPs are drilled about 3 to 90 meters (10 to 300 feet) deep, much shallower than most oil and natural gas wells. GHPs do not require fracturing bedrock to reach their energy source.

A pipe connected to a GHP is arranged in a continuous loop—called a "slinky loop"—that circles underground and above ground, usually throughout a building. The loop can also be contained entirely underground, to heat a parking lot or landscaped area.

In this system, water or other liquids (such as glycerol, similar to a car’s antifreeze) move through the pipe. During the cold season, the liquid absorbs underground geothermal heat. It carries the heat upward through the building and gives off warmth through a duct system. These heated pipes can also run through hot water tanks and offset water-heating costs.

During the summer, the GHP system works the opposite way: The liquid in the pipes is warmed from the heat in the building or parking lot, and carries the heat to be cooled underground.

The U.S. Environmental Protection Agency has called geothermal heating the most energy-efficient and environmentally safe heating and cooling system. The largest GHP system was completed in 2012 at Ball State University in Indiana. The system replaced a coal-fired boiler system, and experts estimate the university will save about $2 million a year in heating costs.

In order to obtain enough energy to generate electricity, geothermal power plants rely on heat that exists a few kilometers below the surface of the Earth. In some areas, the heat can naturally exist underground as pockets steam or hot water. However, most areas need to be “enhanced” with injected water to create steam.

Dry-steam power plants take advantage of natural underground sources of steam. The steam is piped directly to a power plant, where it is used to fuel turbines and generate electricity.

Dry steam is the oldest type of power plant to generate electricity using geothermal energy. The first dry-steam power plant was constructed in Larderello, Italy, in 1911. Today, the dry-steam power plants at Larderello continue to supply electricity to more than a million residents of the area.

There are only two known sources of underground steam in the United States: Yellowstone National Park in Wyoming and The Geysers in California. Since Yellowstone is a protected area, The Geysers is the only place where a dry-steam power plant is in use. It is one of the largest geothermal energy complexes in the world, and provides about a fifth of all renewable energy in California.

Flash-steam power plants use naturally occurring sources of underground hot water and steam. Water that is hotter than 182° C (360° F) is pumped into a low-pressure area. Some of the water “flashes,” or evaporates rapidly into steam, and is funneled out to power a turbine and generate electricity. Any remaining water can be flashed in a separate tank to extract more energy.

Flash-steam power plants are the most common type of geothermal power plants. The volcanically active island nation of Iceland supplies nearly all its electrical needs through a series of flash-steam geothermal power plants. The steam and excess warm water produced by the flash-steam process heat icy sidewalks and parking lots in the frigid Arctic winter.

The islands of the Philippines also sit over a tectonically active area, the "Ring of Fire" that rims the Pacific Ocean. Government and industry in the Philippines have invested in flash-steam power plants, and today the nation is second only to the United States in its use of geothermal energy. In fact, the largest single geothermal power plant is a flash-steam facility in Malitbog, Philippines.

Binary cycle power plants use a unique process to conserve water and generate heat. Water is heated underground to about 107°-182° C (225°-360° F). The hot water is contained in a pipe, which cycles above ground. The hot water heats a liquid organic compound that has a lower boiling point than water. The organic liquid creates steam, which flows through a turbine and powers a generator to create electricity. The only emission in this process is steam. The water in the pipe is recycled back to the ground, to be re-heated by the Earth and provide heat for the organic compound again.

The Beowawe Geothermal Facility in the U.S. state of Nevada uses the binary cycle to generate electricity. The organic compound used at the facility is an industrial refrigerant (tetrafluoroethane, a greenhouse gas). This refrigerant has a much lower boiling point than water, meaning it is converted into gas at low temperatures. The gas fuels the turbines, which are connected to electrical generators.

The Earth has virtually endless amounts of energy and heat beneath its surface. However, it is not possible to use it as energy unless the underground areas are "hydrothermal." This means the underground areas are not only hot, but also contain liquid and are permeable. Many areas do not have all three of these components. An enhanced geothermal system (EGS) uses drilling, fracturing, and injection to provide fluid and permeability in areas that have hot—but dry—underground rock.

To develop an EGS, an “injection well” is drilled vertically into the ground. Depending on the type of rock, this can be as shallow as 1 kilometer (0.6 mile) to as deep as 4.5 kilometers (2.8 miles). High-pressure cold water is injected into the drilled space, which forces the rock to create new fractures, expand existing fractures, or dissolve. This creates a reservoir of underground fluid.

Water is pumped through the injection well and absorbs the rocks’ heat as it flows through the reservoir. This hot water, called brine, is then piped back up to Earth’s surface through a “production well.” The heated brine is contained in a pipe. It warms a secondary fluid that has a low boiling point, which evaporates to steam and powers a turbine. The brine cools off, and cycles back down through the injection well to absorb underground heat again. There are no gaseous emissions besides the water vapor from the evaporated liquid.

Pumping water into the ground for EGSs can cause seismic activity, or small earthquakes. In Basel, Switzerland, the injection process caused hundreds of tiny earthquakes that grew to more significant seismic activity even after the water injection was halted. This led to the geothermal project being canceled in 2009.

Geothermal energy is a renewable resource. The Earth has been emitting heat for about 4.5 billion years, and will continue to emit heat for billions of years into the future because of the ongoing radioactive decay in the Earth’s core.

However, most wells that extract the heat will eventually cool, especially if heat is extracted more quickly than it is given time to replenish. Larderello, Italy, site of the world’s first electrical plant supplied by geothermal energy, has seen its steam pressure fall by more than 25% since the 1950s.

Re-injecting water can sometimes help a cooling geothermal site last longer. However, this process can cause “micro-earthquakes.” Although most of these are too small to be felt by people or register on a scale of magnitude, sometimes the ground can quake at more threatening levels and cause the geothermal project to shut down, as it did in Basel, Switzerland.

Geothermal systems do not require enormous amounts of freshwater. In binary systems, water is only used as a heating agent, and is not exposed or evaporated. It can be recycled, used for other purposes, or released into the atmosphere as non-toxic steam. However, if the geothermal fluid is not contained and recycled in a pipe, it can absorb harmful substances such as arsenic, boron, and fluoride. These toxic substances can be carried to the surface and released when the water evaporates. In addition, if the fluid leaks to other underground water systems, it can contaminate clean sources of drinking water and aquatic habitats.

There are many advantages to using geothermal energy either directly or indirectly:Geothermal energy is renewable; it is not a fossil fuel that will be eventually used up. The Earth is continuously radiating heat out from its core, and will continue to do so for billions of years.

Using geothermal energy is relatively clean. Most systems only emit water vapor, although some emit very small amounts of sulfur dioxide, nitrous oxides, and particulates.

Geothermal power plants can last for decades and possibly centuries. If a reservoir is managed properly, the amount of extracted energy can be balanced with the rock’s rate of renewing its heat.

Unlike other renewable energy sources, geothermal systems are “baseload.” This means they can work in the summer or winter, and are not dependent on changing factors such as the presence of wind or sun. Geothermal power plants produce electricity or heat 24 hours a day, 7 days a week.

The space it takes to build a geothermal facility is much more compact than other power plants. To produce a GWh (a gigawatt hour, or one million kilowatts of energy for one hour, an enormous amount of energy), a geothermal plant uses the equivalent of about 1,046 square kilometers (404 square miles) of land. To produce the same GWh, wind energy requires 3,458 square kilometers (1,335 square miles), a solar photovoltaic center requires 8,384 square kilometers (3,237 square miles), and coal plants use about 9,433 square kilometers (3,642 square miles).

Harvesting geothermal energy still poses many challenges:The process of injecting high-pressure streams of water into the Earth can result in minor seismic activity, or small earthquakes.

Geothermal plants have been linked to subsidence, or the slow sinking of land. This happens as the underground fractures collapse upon themselves. This can lead to damaged pipelines, roadways, buildings, and natural drainage systems.

Water that flows through underground reservoirs can pick up trace amounts of toxic elements such as arsenic, mercury, and selenium. These harmful substances can be leaked to water sources if the geothermal system is not properly insulated.

Although the process requires almost no fuel to run, the initial cost of installing geothermal technology is expensive. Developing countries may not have the sophisticated infrastructure or start-up costs to invest in a geothermal power plant. Several facilities in the Philippines, for example, were made possible by investments from American industry and government agencies. Today, the plants are Philippine-owned and operated.

Geothermal energy exists in different forms all over the Earth (by steam vents, lava, geysers, or simply dry heat), and there are different possibilities for extracting and using this heat.

In New Zealand, natural geysers and steam vents heat swimming pools, homes, greenhouses, and prawn farms. New Zealanders also use dry geothermal heat to dry timber and feedstock.

Other countries, such as Iceland, have taken advantage of molten rock and magma resources from volcanic activity to provide heat for homes and buildings. In Iceland, almost 90% of the country’s people use geothermal heating resources. Iceland also relies on its natural geysers to melt snow, warm fisheries, and heat greenhouses.

The United States generates the most amount of geothermal energy of any other country. Every year, the U.S. generates at least 15 billion kilowatt-hours, or the equivalent of burning about 25 million barrels of oil. Industrial geothermal technologies have been concentrated in the western U.S. In 2012, Nevada had 59 geothermal projects either operational or in development, followed by California with 31 projects, and Oregon with 16 projects.

n: a record showing variations in wellbore diameter by depth, indicating undue enlargement due to caving in, washout, or other causes. The caliper log also reveals corrosion, scaling, or pitting inside tubular goods.

n: a specially designed, self-propelled workover or drilling rig that is driven directly to the well site. Power from a carrier rig"s hoist engine or engines also propels the rig on the road. A carrier rig may be a back-in type or a drive-in type.

n: 1. steel pipe placed in an oil or gas well to prevent the wall of the hole from caving in, to prevent movement of fluids from one formation to another and to aid in well control.

v: to obtain cuttings for geological information as formations are penetrated by the bit. The samples are obtained from drilling fluid as it emerges from the wellbore or, in cable-tool drilling, from the bailer.

n: a powder consisting of alumina, silica, lime, and other substances that hardens when mixed with water. Extensively used in the oil industry to bond casing to the walls of the wellbore.

n: the adherence of casing to cement and cement to formation. When casing is run in a well, it is set, or bonded, to the formation by means of cement.

n: an acoustic survey or sonic-logging method that records the quality or hardness of the cement used in the annulus to bond the casing and the formation. Casing that is well bonded to the formation transmits an acoustic signal quickly; poorly bonded casing transmits a signal slowly. See acoustic survey, acoustic well logging.

n: an accessory attached to the top of the casing to facilitate cementing of the casing. It has passages for cement slurry and retainer chambers for cementing wiper plugs. Also called retainer head.

n pl: a slurry of cement and water and sometimes one or more additives that affect either the density of the mixture or its setting time. The cement used may be high early strength, common (standard), or slow setting. Additives include accelerators (such as calcium chloride), retarders (such as gypsum), weighting materials (such as barium sulfate), lightweight additives (such as bentonite), or a variety of lost circulation materials.

n: a tool set temporarily in the casing or well to prevent the passage of cement, thereby forcing it to follow another designated path. It is used in squeeze cementing and other remedial cementing jobs.

n: a pump with an impeller or rotor, an impeller shaft, and a casing, which discharges fluid by centrifugal force. An electric submersible pump is a centrifugal pump.

n: when casing is being cemented in a borehole, the cement slurry can fail to rise uniformly between the casing and the borehole wall, leaving spaces, or channels, devoid of cement. Ideally, the cement should completely and uniformly surround the casing and form a strong bond to the borehole wall. See cement channeling.

n: a method of severing pipe in a well by applying high pressure jets of a very corrosive substance against the wall of the pipe. The resulting cut is very smooth.

n: a method of improved oil recovery in which chemicals dissolved in water are pumped into a reservoir through injection wells to mobilize oil left behind after primary or secondary recovery and to move it toward production wells.

n: a device with an orifice installed in a line to restrict the flow of fluids. Surface chokes are part of the Christmas tree on a well and contain a choke nipple, or bean, with a small-diameter bore that serves to restrict the flow. Chokes are also used to control the rate of flow of the drilling mud out of the hole when the well is closed in with the blowout preventer and a kick is being circulated out of the hole. See choke manifold.

n: a line, or pipe, that runs from the blowout preventer stack to the choke manifold through which fluid from the hole is flowed when the well is shut in with the blowout preventer.

n: the control valves, pressure gauges, and chokes assembled at the top of a well to control flow of oil and/or gas after the well has been drilled and completed. It is used when reservoir pressure is sufficient to cause reservoir fluids to rise to the surface.

v: to pass from one point throughout a system and back to the starting point. For example, drilling fluid is circulated out of the suction pit, down the drill pipe and drill collars, out the bit, up the annulus, and back to the pits while drilling proceeds.

n: the movement of drilling fluid out of the mud pits, down the drill stem, up the annulus, and back to the mud pits. See normal circulation, reverse circulation.

n: a coupling used to connect and disconnect a driving and a driven part of a mechanism, especially a coupling that permits the former part to engage the latter gradually and without shock. In the oil field, a clutch permits gradual engaging and disengaging of the equipment driven by a prime mover. v: to engage or disengage a clutch.

n: a continuous string of flexible steel tubing, often hundreds or thousands of feet long, that is wound onto a reel, often dozens of feet in diameter. The reel is an integral part of the coiled tubing unit, which consists of several devices that ensure the tubing can be safely and efficiently inserted into the well from the surface. Also called reeled tubing.

n: the equipment for transporting and using coiled tubing, including a reel for the coiled tubing, an injector head to push the tubing down the well, a wellhead blowout preventer stack, a power source (usually a diesel engine and hydraulic pumps), and a control console. A unique feature of the unit is that it allows continuous circulation while it is being lowered into the hole. A coiled tubing unit is usually mounted on a trailer or skid.

n: a workover performed with a continuous steel tube, normally 0.75 inch to 1 inch (1.9 to 2.54 centimeters) outside diameter, which is run into the well in one piece inside the normal tubing. Lengths of the tubing up to 16,000 feet (4,877 meters) are stored on the surface on a reel in a manner similar to that used for wireline. The unit is rigged up over the wellhead. The tubing is injected through a control head that seals off the tubing and makes a pressure-tight connection.

n: 1. a coupling device used to join two lengths of pipe, such as casing or tubing. A combination collar has left-hand threads in one end and right-hand threads in the other. 2. a drill collar.

n: a logging device used to determine accurately the depth of a well; the log measures and records the depth of each casing collar, or coupling, in a well.

v: to pull the drill stem out of the wellbore to change the bit, to change from a core barrel to the bit, to run electric logs, to prepare for a drill stem test, to run casing, and so on. Also called trip out, tripping out (TOH).

n: an employee of an operating company who supervises the operations at a drilling site or well site and who may coordinate the hiring of logging, testing, service, and workover companies. Also called company hand, operator"s representative, or company man.

n: low-solids fluid or drilling mud used when a well is being completed. It is selected not only for its ability to control formation pressure, but also for the properties that minimize formation damage.

n: 1. a mechanism used to transmit power from the engines to the pump, the drawworks, and other machinery on a drilling rig. It is composed of clutches, chains and sprockets, belts and pulleys, and a number of shafts, both driven and driving. v: to connect two or more power producing devices, such as engines, to run driven equipment, such as the drawworks.

n: a diesel engine; an engine in which the fuel/air mixture inside the engine cylinders is ignited by the heat that occurs when the fuel-air mixture is highly compressed by the engine pistons.

n: a device that raises the pressure of a compressible fluid such as air or gas. Compressors create a pressure differential to move or compress a vapor or a gas.

n: 1. the ability to transmit or convey (as heat or elec