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Search Petrowiki: Gas lift installation design methods
... Get permission for reuse This chapter provides an overview of the primary categories of natural gas compressor services and a description of the different classifications and types of compressors ava...r components and construction features of centrifugal and reciprocating compressors are emphasized. Installation, safety, and maintenance considerations also are discussed. For centrifugal compressors, the perfo...Major Components * 4.2 Compressor Performance * 4.3 Surge * 4.4 Stonewall (Choke) * 4.5 Process Installation * 4.6 Maintenance * 5 Reciprocating Compressors * 5.1 Major Components * 5.2 Compressor Perform...
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...affect how well downhole separation will work: * separation equipment operating ranges * wellbore design * reservoir geology The economics are often determined by the number of and locations of the well...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 ...
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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...ct flow from the reservoir, but the larger wellbore pressure provides additional inflow pressure to lift fluids to the surface. Cased-hole gravel packs that have not been prepacked are usually damaged. Th...e conditions. If the perforation filling is indeed critical for cased-hole gravel packs, completion methods that focus on filling perforations should prove superior to those that sacrifice perforation fillin... because it is less expensive and time consuming. There are proponents of both fracture prepacking methods. Some prefer the frac packs because they believe that the longer, wider fractures provide less risk...
Prepacking can be defined as any method that intentionally places gravel into the perforation tunnels. Filling of perforation tunnels can be accomplished either with a dedicated operation before performing the gravel pack or simultaneously with it. The technique used is normally dictated by well parameters. Gravel packing cased-hole completions in vertical and deviated wells are more common than openhole completions, particularly in shaley reservoirs. However, cased-hole gravel packs have an important requirement that is easily overlooked.
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...wnhole hydraulic pump types There are two types of pumps used in hydraulic pumping for artificial lift purposes. These are reciprocating pumps and jet pumps. This page discusses each pump type along wit...he pump can be either single-acting or double-acting. A single-acting pump closely follows rod-pump design practices and is called single-acting because it displaces fluid on either the upstroke or downstro...ing pump (model 220). * Fig. 2-Hydraulic piston double-acting pump. Back to top In a sucker-rod installation, the rod that actuates the pump plunger extends to the surface of the well and connects to the pump...
There are two types of pumps used in hydraulic pumping for artificial lift purposes. These are reciprocating pumps and jet pumps. The pump end of a hydraulic downhole pump is similar to a sucker-rod pump because it uses a rod-actuated plunger (also called the pump piston) and two or more check valves. The pump can be either single-acting or double-acting. A single-acting pump closely follows rod-pump design practices and is called single-acting because it displaces fluid on either the upstroke or downstroke (but not both). An example is shown schematically inFigure 1. Figure 1 shows a double-acting pump that has suction and discharge valves for both sides of the plunger, which enables it to displace fluids to the surface on both the upstroke and downstroke.
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...* 4.4.1 Retrieval * 4.5 Dual-string packers * 4.6 Permanent and retrievable sealbore packers * 5 Methods of conveyance * 5.1 Landing conditions * 5.2 Through-tubing operations * 5.3 Casing cleanup oper...d well-servicing fluid (kill fluids, packer fluids) in the casing annulus. * Facilitate artificial lift, such as continuous ...gas lifting through the A-annulus. Packer components Packers have four key features: * Slip * Cone...
The packer (more accurately described as the'upper completion production packer') is a key piece of downhole equipment in many completions - a sealing device that isolates and contains produced fluids and pressures within the tubing string; it is a well barrier element, usually part of the well's primary well barrier, protecting the casing and creating an A-annulus. The packer is essential to the basic functioning of most wells, injectors or producers. Alternatives to using a production packer include a dynamic seal assembly, a cemented completion and a packerless completion. Advantages and application * 4.3 Retrievable tension/compression set--versatile landing * 4.4 Retrievable hydraulic-set single-string packer * 4.4.1 Retrieval * 4.5 Dual-string packers * 4.6 Permanent and retrievable sealbore packers * 5 Methods of conveyance * 5.1 Landing conditions * 5.2 Through-tubing operations * 5.3 Casing cleanup operations * 5.4 Other casing considerations * 6 Packer rating envelopes * 6.1 Rating envelope * 7 References * 8 Noteworthy papers in OnePetro * 9 External links * 10 General references * 11 See also * 12 Category In addition to providing a seal between the tubing and casing, other aspects of a packer are as follows: * Prevent downhole movement of the tubing string, generating considerable axial tension or compression loads on the tubing string. Packers have four key features: * Slip * Cone * Packing-element system * Body or mandrel. The slip is a wedge-shaped device with wickers (or teeth) on its face, which penetrate and grip the casing wall when the packer is set. The cone is beveled to match the back of the slip and forms a ramp that drives the slip outward and into the casing wall when setting force is applied to the packer. Once the slips have anchored into the casing wall, additional applied setting force energizes the packing-element system and creates a seal between the packer body and the inside diameter of the casing. Production packers can be classified into two groups: * Retrievable * Permanent. Permanent packers can be removed from the wellbore only by milling.
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...78-1-55563-118-5 Get permission for reuse There are many completion options available to oil and gas producers. Today's cased-hole completion systems vary from relatively simple single-zone low-pressu...icient and cost-effective to achieve production and financial goals. A key factor in the completion design is the production rate; see other chapters in this section of the Handbook for additional informati...gle-String Packer * 1.6 Dual-String Packers * 1.7 Permanent and Retrievable Sealbore Packers * 2 Methods of Conveyance * 2.1 Landing Conditions * 2.2 Through-Tubing Operations * 2.3 Casing Cleanup Oper...
There are many completion options available to oil and gas producers. Many of the basic components appear similar to those used in the past, yet they have been vastly improved, and their performance has been optimized to suit numerous environments. There are several keys to designing a successful completion system and selecting components that are fit for purpose for both the downhole environment and application. Consideration must be given to the various modes under which the completion must operate and the effects any changes in temperature or differential pressure will have on the tubing string and packer. Ultimately, the system must be both efficient and cost-effective to achieve production and financial goals. A key factor in the completion design is the production rate; see other chapters in this section of the Handbook for additional information on this topic. The intention of this chapter is to familiarize the reader with the common components that make up the completion ...
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...PCP system operations The following topic describes the installation, monitoring, troubleshooting and failure analysis of the Progressive Cavity Pumping systems (PCP) u...sed in the oil and gas industry. Contents * 1 PCP system ...installation and startup * 2 PCP system monitoring and automation * 2.1 Automated Monitoring and Control Syste...
The following topic describes the installation, monitoring, troubleshooting and failure analysis of the Progressive Cavity Pumping systems (PCP) used in the oil and gas industry. Adherence to proper installation procedures for both downhole and surface equipment is key to the successful operation and performance of aPCP system. Given the many different types of equipment available and the number of system configuration alternatives, it is advisable to review the product manuals provided by PCP equipment vendors to obtain detailed installation instructions and system operating information for specific installations. The well-servicing guide books available from some service companies also provide useful information. Although the following list highlights a few key system installation and startup considerations, it is not intended to be comprehensive, and the appropriate equipment manuals should be consulted in all cases: * Confirm that the equipment at the wellsite is configured properly for making the following connections: stator to tubing, tubing to drive head, rotor to sucker rods, and sucker rods to drive shaft or polished rod. Ensure that the stator outside diameter (OD) is sufficiently under the casing drift diameter and that the rotor major diameter is less than the tubing-string drift diameter.
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...um Engineers Chapter 14 โ Hydraulic Pumping in Oil Wells James Fretwell, Weatherford Artificial Lift Systems Pgs. 41-103 ISBN 978-1-55563-118-5 Get permission for reuse Introduction Hydraulic pum...ping 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 servi...
Introduction 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. Chemicals to control corrosion, paraffin, and emulsions can be injected downhole with the power fluid, while fresh water can also be injected to dissolve salt deposits. When pumping heavy crudes, the power fluid can serve as an effective diluent to reduce the viscosity of the produced fluids. The power fluid also can be heated for handling heavy or low-pour-point crudes. Hydraulic pumping systems are suitable for wells with deviated or crooked holes ...
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...ottom hole pressure (BHP) requirements * Identify the drilling fluid options * Establish the well design and perform flowing modeling * Select the surface equipment. This article discusses the first two... of foam drilling * 2.4 Gasified systems * 2.4.1 Characteristics of gasified-fluid systems * 2.5 Gas/liquid ratios * 2.6 Single-phase fluids * 2.7 ...Gas lift systems * 3 Injection ...
A basic four-step process can be applied to determine the options and requirements for drilling underbalanced: * Determine bottom hole pressure (BHP) requirements * Identify the drilling fluid options * Establish the well design and perform flowing modeling * Select the surface equipment. Disadvantages * 2.2 Mist systems * 2.3 Foam systems * 2.3.1 Characteristics of foam drilling * 2.4 Gasified systems * 2.4.1 Characteristics of gasified-fluid systems * 2.5 Gas/liquid ratios * 2.6 Single-phase fluids * 2.7 Gas lift systems * 3 Injection methods * 3.1 Drillpipe injection * 3.1.1 In overbalanced drillng (OBD), a mud weight is selected that provides a hydrostatic pressure of 200 to 1,000 psi above the reservoir pressure. In UBD, we select a fluid that provides a hydrostatic pressure of around 200 psi below the initial reservoir pressure. This provides a good starting point for the selection of a fluid system.
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...eld 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...4][5][6][7][8][9][10] Contents * 1 Engines * 2 Electric motors * 2.1 Common motors * 2.2 NEMA design standards * 2.3 Power factors * 2.4 Cyclic-load factor * 2.5 Motor enclosures * 2.6 Motor insul...
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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