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Search Petrowiki: Gas lift equipment AND facilities
...Hydraulic pumping Hydraulic pumping is a proven artificial lift method that has been used since the early 1930s. It offers several different systems for handling a...able for wells with deviated or crooked holes that can cause problems for other types of artificial lift. The surface ...facilities can have a low profile and may be clustered into a central battery to service numerous wells. This ...
Hydraulic pumping is a proven artificial lift method that has been used since the early 1930s. It offers several different systems for handling a variety of well conditions. Successful applications have included setting depths ranging from 500 to 19,000 ft and production rates varying from less than 100 to 20,000 B/D. Surface packages are available using multiplex pumps ranging from 15 to 625 hp. The systems are flexible because the downhole-pumping rate can be regulated over a wide range with fluid controls on the surface.
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...Teflon ) rated up to 400 F. Lead barrier. In wells that have a damaging amount of hydrogen sulfide gas, the copper conductors can be attacked and destroyed. To protect against this, a thin layer of lead...able, it has the added function of providing additional containment protection for oil swelling and gas decompression. The armor is usually made of mild galvanized steel, which is applicable to non- to m...ion-tubing outside diameter (OD) is limited. Flat cable is not suitable for containing oil swell or gas decompression forces because of the interstices between the single conductors. If the insulation or...
Typically, it is banded or clamped to the production tubing from below the wellhead to the ESP unit because it is not designed to support its own weight. It is a specially constructed three-phase power cable designed specifically for downhole well environments. The cable design must be small in diameter, protected from mechanical abuse, and impervious to physical and electrical deterioration because of aggressive well environments. They are available in a wide range of conductor sizes or gauges. They can be manufactured in either round or flat configurations, using several different insulation and metal armor materials for different hostile well environments.
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...apacity and pressure capability to ensure that the pump can deliver the required fluid rate and net lift for the intended application. It is typical to select pumps with a design (i.e., theoretical) flow...e to reflect pump inefficiencies during production operations. Fluid slippage, inflow problems, and gas interference all contribute to reduced pump volumetric efficiency. Together, the design fluid rate ...ump at the lowest speed practical to increase the life of the pump, rod string, tubing, and surface equipment. However, consideration should also be given to the impact that the selection of larger-displacemen...
The key technical considerations and decisions involved in selecting a progressing cavity pump(PCP) for a particular application include pump displacement, pressure capability, geometric design,elastomer type, and rotor coating characteristics. Other factors, such as local vendor choice and economics can also affect pump selection.Figure 1 provides a flow chart of the key decisions. When selecting a PC pump, the two most critical requirements are adequate displacement capacity and pressure capability to ensure that the pump can deliver the required fluid rate and net lift for the intended application. It is typical to select pumps with a design (i.e., theoretical) flow rate that is somewhat higher than the expected fluid rate to reflect pump inefficiencies during production operations. Fluid slippage, inflow problems, and gas interference all contribute to reduced pump volumetric efficiency.
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...ing unit * Availability of field and/or service personnel capable of maintaining and repairing the equipment * Condition of the ...gas (sweet or sour) or availability now and in the future of the ...gas or liquids (i.e., propane or diesel) if an IC engine is used * Current and future expected cost fo...
The prime mover (PM) rotates the gear-reducer gears through a V-belt drive. The two most common PMs are electric motors and internal combustion (IC) engines. The decision concerning which to use depends on a variety of considerations, which includes the following: * Availability of the power source (electricity or combustible fluid) * HP required to pump the well * Efficiency of the system * Ability to control the PM to match the on/off potential operation of the pumping unit * Availability of field and/or service personnel capable of maintaining and repairing the equipment * Condition of the gas (sweet or sour) or availability now and in the future of the gas or liquids (i.e., propane or diesel) if an IC engine is used * Current and future expected cost for the power source * Anticipated full-cycle total cost (including initial capital, operating, maintenance, downtime, and repairs) for the duration of the well These considerations, as well as other factors, have been discussed in numerous publications.[1][2][3][4][5][6][7][8][9][10] The characteristics of these engines are summarized here, and the detailed comparisons and field experiences have been published elsewhere.[11][12] Four-cycle, high-speed engines (greater than 750 rpm): * Best suited for portable test installations vs. permanent installations * Lower initial cost * Lower weight per HP * Wide speed and power range * Operates on a variety of fuels * Large speed variations occur during pumping cycle because of a small flywheel effect * Operates on a fixed throttle with the governor mechanism acting only as an overspeed device * Has relatively short life because of the fast moving parts and the close tolerances required * Requires frequent oil changes * Requires frequent maintenance * Major repairs require that the engine be removed from the pumping unit These test data should be requested and furnished to the purchaser from the manufacturer. The data should include the manufacturer's curves showing the torque, maximum brake HP, and the rated-brake HP vs. engine speed. These are important to know the speed range in which the engine would be able to operate. A general guide for installation and maintenance of gas engines is API RP 7C-11F,[14] which covers all three types of engines and includes a troubleshooting section. This practice should be used as a starting point for engines unless the specific manufacturer's operating manual details otherwise. Additionally, there are a number of published papers on installation, care, operation, and lubrication of engines as prime movers for pumping units.[15][16][17][18][19]
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...eas. New development challenges are in deep water and in marginal fields with smaller reserves. The facilities required in these new developments are similar in function to conventional processing ...facilities, but the packaging requirements can be quite different. Process ...facilities can now be placed literally anywhere between the reservoir and the product pipeline, including subs...
Introduction As easily accessible petroleum basins have matured, exploration and development have expanded farther offshore and to remote areas. New development challenges are in deep water and in marginal fields with smaller reserves. The facilities required in these new developments are similar in function to conventional processing facilities, but the packaging requirements can be quite different. Process facilities can now be placed literally anywhere between the reservoir and the product pipeline, including subsea and downhole. Obviously, minimizing surface equipment size and weight reduces costs for deepwater platforms. In addition, the trend of tying smaller fields to a larger processing facility, in a hub-and-spoke arrangement, has led to novel production approaches. Oil/water or liquid/gas can be partially separated closer to the reservoir to reduce the size of surface equipment, eliminate or reduce the size of flowlines, or to facilitate pumping.
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... The electrical submersible pump, typically called an ESP, is an efficient and reliable artificial-lift method for lifting moderate to high volumes of fluids from wellbores. These volumes range from a lo... company to REDA. In 1923, he immigrated to the United States and began looking for backers for his equipment. Initially, he approached Westinghouse but was turned down because their engineers thought it would...s retained the international segment of the Bakerlift business. Trico's product line was made up of equipment from Kobe Oiline, Standard Pump, WesTech, and Bakerlift Systems. It was renamed Trico Sub Services...
The electrical submersible pump, typically called an ESP, is an efficient and reliable artificial-lift method for lifting moderate to high volumes of fluids from wellbores. These volumes range from a low of 150 B/D to as much as 150,000 B/D (24 to 24,600 m3/d). Variable-speed controllers can extend this range significantly, both on the high and low side. The ESP's main components include: * Multistaged centrifugal pump * Three-phase induction motor * Seal-chamber section * Power cable * Surface controls The components are normally tubing hung from the wellhead with the pump on top and the motor attached below. There arespecial applications in which this configuration is inverted.
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...ing for pump replacement. Charge pumps and fluidizer pumps are currently being used to increase the gas- and solids-handling capabilities of PCP systems. The following sections provide a brief descriptio...ployed on a commercial basis.[1] Several major ESP vendors now market motors, gear boxes, and other equipment for DHD PCP systems. As a result, these systems have begun to see wider use. The entire surface uni...hole motor * Some size restrictions * Additional coordination between the ESP and PCP vendors for equipment design, supply, installation, and service(in most cases) In practice, these systems are normally u...
Several nonstandard Progressing cavity pumping systems have been developed by various companies to improve pumping capacity, performance, and serviceability for certain applications. Disadvantages * 1.4 Rod insert PCPs * 1.5 Tubing driven PCP systems * 1.6 Charge pump systems * 1.7 Fluidizer pumps * 1.8 Water reinjection systems * 2 Industry standards * 3 References * 4 Noteworthy papers in OnePetro * 5 External links * 6 See also * 7 Page champions * 8 Category These nonstanard PCP systems includes a number of different downhole drive systems that inherently eliminate tubing wear problems and reduce fluid flow losses. Rod-insert PC pump designs are available that preclude the need to pull the tubing string for pump replacement. Charge pumps and fluidizer pumps are currently being used to increase the gas- and solids-handling capabilities of PCP systems. The following sections provide a brief description of the rationale for developing each hybrid system and a description of the basic operating principles of the product where applicable.
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...cation Information Petroleum Engineering Handbook Larry W. Lake, Editor-in-Chief Volume III โ Facilities and Construction Engineering Kenneth E. Arnold, Editor Copyright 2006, Society of Petroleum Eng...on's Pipeline Group Pgs. 317-394 ISBN 978-1-55563-116-1 Get permission for reuse Once oil and gas are located and the well is successfully drilled and completed, the product must be transported to ...ducing "wing(s)" of the wellhead tree and includes the well "flowline," production/treating/storage equipment, custody-transfer measurement ...
Once oil and gas are located and the well is successfully drilled and completed, the product must be transported to a facility where it can be produced/treated, stored, processed, refined, or transferred for eventual sale.Figure 1.1 is a simplified diagram that illustrates the typical, basic "wellhead to sales" concept. The typical system begins at the well flow-control device on the producing "wing(s)" of the wellhead tree and includes the well "flowline," production/treating/storage equipment, custody-transfer measurement equipment, and the gathering or sales pipeline. Information and detailed discussions concerning petroleum production, treating, storage, and measurement equipment are located in various chapters of thisHandbook. The piping and pipeline systems typically associated with producing wells include, but are not limited to, the well flowline, interconnecting equipment piping within the production "battery," the gathering or sales pipeline, and the transmission pipeline.
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...n is key to success. The following all affect how well downhole separation will work: * separation equipment operating ranges * wellbore design * reservoir geology The economics are often determined by the...overs, gel polymer treatments, cement squeezes, and so on. The following discussion applies to both gas/liquid and water/oil processing, followed by sections that discuss screening criteria specific to e...ach. Contents * 1 Overall considerations * 2 Gas/liquid situations * 3 Oil/water situations * 4 Engineering and design issues * 4.1 Tubing/casing...
As with most technology, proper candidate selection is key to success. The economics are often determined by the number of and locations of the wells and by the overall geographical development plan. It is important to recognize that downhole processing is not a substitute for prudent profile control of wells through workovers, gel polymer treatments, cement squeezes, and so on. The following discussion applies to both gas/liquid and water/oil processing, followed by sections that discuss screening criteria specific to each. From an equipment standpoint, gas/liquid separation is much easier than oil/water separation. This generally means that it is a more robust application. All separation and pump equipment has an expected lifetime that is typically much shorter than the lifetime of the well. The cost of replacing or repairing the equipment must be considered as well as the initial capital cost. Some equipment can be placed through tubing by wireline or coiled tubing, which is usually most cost-effective.
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...78-1-55563-108-6 Get permission for reuse Contents * 1 History of Produced Water in Oil and Gas Fields * 1.1 Produced Water Is Important * 1.2 Where Does the Water Come From? * 2 Primary Produ...enclature * 19 References * 20 SI Metric Conversion Factors History of Produced Water in Oil and Gas Fields Early U.S. settlements commonly were located near salt lakes that supplied salt to the po...early efforts to acquire salt by digging wells were rewarded by finding unwanted amounts of oil and gas associated with the saline waters. In the Appalachian Mountains, saline water springs commonly occu...
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