Completion , in petroleum production, is a ready-to-produce (or injection) manufacturing process. This primarily involves preparing the bottom of the hole as required, running on the production tubing and associated bottom hole tool and perforating and stimulating as needed. Sometimes, the process of running in and cementing the casing is also included.
Video Completion (oil and gas wells)
Graduation is lower
This refers to parts of wells throughout the production zone or injection. A good designer has many tools and options available to design a lower settlement according to the reservoir conditions. Usually, a lower settlement is set in the productive zone using a liner hanger system, which anchors a lower finish to the production casing strings. Lower coverage area categories are listed below.
Non-footwear settlement
This type is the most basic, but can be a good choice for hard rock, multi-lateral and underbalance drilling. This involves leaving a productive reservoir section without any tubulars. This effectively removes fluid flow control from the formation; not suitable for weaker formations that may require sand control, as well as for formations that require selective isolation of oil, gas and water intervals. However, advances in interventions such as tubing and circular tractors mean that barefoot wells can be produced successfully.
Open the Hole
The production casing is set above an attractive zone before drilling zone. Open zone for drilled wells. In this case small costs are generated by interpretation of uncritical log perforations. The well can be deepened easily and easily converted to screen and liner. However, excessive gas and water production is difficult to control, and may need frequent cleaning. Also the interval can not be selectively stimulated.
Open hole completion
This designation refers to various settlements where no casing or liner is cemented in place in the production zone. In a competent formation, zones may be left completely empty, but a kind of sand-and/or flow control tool is usually included.
Open pit openings have seen significant uptake in recent years, and there are many configurations, often developed to address specific reservoir challenges. There are many recent developments that have driven the successful completion of openhole, and they also tend to be popular in horizontal wells, where cement installations are more expensive and technically more difficult. Common options for openhole completion are:
Pre-perforated plates
Often also called pre-drilled liners . Liners are prepared with several small drill holes, then arranged in production zones to provide wellbore stability and intervention lines. Pre-holed liners are often combined with openhole packing, such as swelling elastomers, mechanical packing or external casing packers, to provide zonal separation and isolation. It is now very common to see combinations of pre-sealing liners, solid liners and swellings of the elastomer to provide the initial isolation of unwanted water or gas zones. Some shear sleeves can also be used in conjunction with openhole packaging to provide sufficient flexibility in zonal flow control for wellbore life.
This type of settlement is also being adopted in some water injection wells, although this requires a much larger performance envelope for openhole packing, due to the considerable pressure and temperature changes that occur in the water injector.
Open pit opening (compared to cemented pipe) requires a better understanding of formation damage, drilling of wellbore and fluid loss control. The main difference is that perforating penetrates through the first formation of 6-18 inches (15-45 cm) around the wellbore, while completion of the open pit requires a liquid reservoir to flow through all filtrate-invaded zones around the wellbore and takeoff. from a mud filter cake.
Many openhole settlements will incorporate a fluid loss valve at the top of the liner to provide good control while completion of over run.
There are more and more ideas coming to the market to expand the options for openhole completion; for example, electronics may be used to drive the valve opening or valve closure. It may be used in the open-hole completion to improve cleaning, by bringing the well into production from the ends of the foot for 100 days, then opening the heel's own end. Intelligent flow control and settlement control devices are also installed as openhole completion.
Pre-shielded coatings may provide some of the basic controls of solid production, where wellbore is considered to be a failure in aggregate collection, but is not usually considered a sand control solution.
Slotted liner
Slotted liners can be selected as alternatives to pre-cross liners, sometimes as personal preferences or from established practices in the field. It can also be selected to provide low cost control of sand/solid production. The slotted liner is worked with several longitudinal slots, for example 2 mm x 50 mm, spread along the length and periphery of each connection. The latest advances in laser cutting mean that slotting can now be done much cheaper to a much smaller slot width and in some situations slotted liners are now used for the same function as a sand control screen.
Openhole sand control
This is selected where the liner is required to mechanically resist the formation sand movement. There are many variants of openhole sand controls, three popular options are stand-alone screens, openhole gravel packages (also known as external gravel packages, where sand sized 'gravel' is placed as annulus around a sand control screen) and expandable screens. The main screen design is a wire wrap or premium; screen wires use a spiral-welded corrosion-resistant wire wrapped around a basepipe drilled to provide a consistent small helical slit (such as 0.012 inches (0.30 mm), called 12 gauge). The premium screen uses a woven metal fabric that encloses the basepipe. The expandable screen runs into depth before being swung mechanically to a larger diameter. Ideally, the expandable screen will be swaged until they reach the wellbore wall.
Horizontal open pit fittings
This is the most common open pit settlement currently used. It is essentially the same as described on the completion of the vertical open hole but on the horizontal well enlarged significantly in contact with the reservoir, increasing the production or the level of injection of your well. The sand controls on the horizontal wells are completely different from the vertical wells. We can no longer rely on gravity for gravel placement. Most service companies use the design of alpha and beta waves to cover the total length of horizontal wells with gravel. It is known that very long wells (about 6000 feet) have been packaged in many occasions, including a marine reservoir in Brazil.
Liner Completions
In this case the casing is set above the main zone. A non-cemented screen and liner assembly is installed throughout the payment section. This technique minimizes formation damage and provides the ability to control the sand. It also makes cleaning easy. The cost of perforation is also low to none. However, the formation of gas and water is difficult to control and selective stimulation is unlikely that the well can not be easily deepened and additional rig time may be required.
Perforated Liner
The casing is set above the production zone, drilled zone and cement liner cemented in place. The liner is then perforated for production. This time the additional cost to perforate the casing takes place, also the log interpretation is very important and it may be difficult to get a good quality cement job.
Casings Perforated
Production cement is cemented through the zone and the payment portion is selectively hollowed out. Gas and water are easily controlled like sand. Formations can be selectively stimulated and wells can be deepened. This option can be customized with other completion configurations and logs available to assist casing decisions. The main casing is much better. However it can cause damage to the zone and requires good log interpretation. The cost of perforation can be very high.
Charge hole casing
This involves running the casing or liner down through the production zone, and cementing in place. Connection between wellbore and formation made with perforantes. Because the perforation interval can be positioned appropriately, this type of settlement provides good fluid flow control, although it depends on the quality of the cement to prevent fluid flow behind the liner. Because it is the most common form of settlement...
Conventional completion
- Casing Flow : means the fluid flow that produces only has one path to the surface through the casing.
- Casing and tubing flow : means there is tubing inside the casing that allows the liquid to reach the surface. This pipe can be used as a killer string for chemical injection. Tubing may have a "no-go" nipple at the end as a means of pressure testing.
- Pumping flow : tubes and pumps run down to the depths below the working fluid. Pumps and rod strings are installed concentrically in the tubing. An anchor tubing prevents the movement of the tube while pumping.
- Tubing stream : tube strings and production packs are installed. The packer means all the streams pass through the pipe. Inside the tubing you can install a combination of tools that will help control the flow of fluids through the pipes.
- Gas is well lifted : gas is inserted into the valve installed in mandril on the tube strip. The hydrostatic head is lowered and the gas liquid is lifted to the surface.
- Single-good alternative solution : in this case there is a well with two zones. To produce from both isolated zone with packing. Blast joints can be used on tubing in the perforated area. It is a thick-walled sling that can withstand abrasion of liquids from the production zone. This setting can also work if you have to generate from a higher zone due to the depletion of the lower zone. Tubing may also have a flow control mechanism.
- String kills with good single concentration : inside the well, a small circle containing concentric cord is used to circulate the killing fluids when needed.
- 2-tube single well-settlement : in this example 2 strings of the pipe are inserted well below 1. They are connected at the lower end by a circulating head. Chemicals can be circulated to a single tube and their production can continue to another.
Maps Completion (oil and gas wells)
Completion component
The top finish refers to all the components from the bottom of the upward tubing production. The precise design of this "string completion" is important to ensure wells flow well in the condition of the reservoir and to allow any operations deemed necessary to improve production and safety.
Wellhead
This is the pressure that contains equipment on the surface of the well where the suspended casing strings and the blast prevention or Christmas tree are connected.
Christmas tree
It is a valve main assembly that controls the flow from the well to the process plant (or vice versa for injection wells) and allows access to good chemical and intervention rationing.
Tubing hanger
It is a component, which is above the wellhead and serves as the main support for the production tube.
Production tube
The production tube is the main conduit for transporting hydrocarbons from the reservoir to the surface (or other injection materials). It runs from the tubing hanger at the top of the wellhead to the point that is generally just above the top of the production zone.
Downholes safety valve (DHSV)
This component is intended as a last-resort method to protect the surface from uncontrolled release of hydrocarbons. This is a cylindrical valve with a ball closing mechanism or flapper. These are installed in the production tubing and held in open position by a high pressure hydraulic channel from the surface contained in a 6.35 mm (1/4 ") control line attached to the DHSV hydraulic chamber and terminated on the surface for hydraulic actuators. High pressures are required to overcome the production pressure on the pipe in the upstream choke on the tree, The valve will operate if the HPH line is cut or the well head is destroyed.
This valve allows the liquid to be passed or pumped into a production tube. When closing DHSV forms a barrier in the direction of the hydrocarbon stream, but the liquid can still be pumped down for a good killing operation. These are placed well below the surface as they are considered safe from possible surface disturbances including craters caused by platform removal. Where hydrates may be formed (most of the production is at risk), the depth of SCSSV (below-ground subsurface under control valve) may be as much as 1 km: this will allow for geothermal temperatures. become high enough to prevent the hydrate from blocking the valve.
Circular safety valve
On wells with gas lifting capabilities, many operators consider it wise to install valves, which would isolate the annulus for the same reason as DHSV might be needed to isolate the production pipeline to prevent the inventory of natural gas downhole from being a hazard while in Piper Alpha.
Mandrel pocket side
This is a welded/machine product containing "pocket sides" next to the main tubular channel. Side pockets, usually 1 "or 1Ã,½" in diameter are designed to contain gas lifting valves, allowing high pressure gas flow into the tube there by reducing tube pressure and allowing the hydrocarbon to move upward.
Electric submersible pump
This device is used for artificial lifting to help provide energy to move hydrocarbons to the surface if reservoir pressure is insufficient.
Nipple landings
The finished component is made as a short section of heavy wall tubular with an internal surface of the machine providing seal area and locking profile. Landing nipples are included in most of the settlements at predetermined intervals to enable the installation of flow control devices, such as plugs and chokes. The three basic types of landing nipples are commonly used: nipple no-go, selective landing nipples, and ported nipples or safety valves.
Slide arm
The shear arm is hydraulically or mechanically moved to allow communication between tubing and annulus 'A'. They are often used in some reservoir wells to regulate flow to and from the zone.
Production packer
Packer isolates the annulus between the tubing and the inner casing and the well foot. This is to stop the liquid reservoir from flowing into the entire casing and damage it. These are generally placed close to the tube feet, long above the production zone.
Downhole gauge
It is an electronic or fiberoptic sensor to provide continuous monitoring of downhole pressure and temperature. A good gauge uses a 1/4 "line of control to clamp onto the outside of the tube string to provide electrical or fiberoptic communications to the surface, or transmit measurable data to the surface by an acoustic signal on the tubing wall Information obtained from this monitoring device can be used to model the reservoir or predicting life or problems in special boreholes.
Perforated joint
This is the length of the tubing with the hole being perforated. If used, it will usually be positioned under the packer and will offer an alternate entrance for the liquid reservoir into the tube if the shoe becomes obstructed, for example, with a stuck perforated gun.
Formation isolation valve
This component, placed towards the foot of the completion string, is used to provide two-way insulation from the formation for the completion operation without the need to kill the weight of the liquid. Its use is sporadic because they do not enjoy the best reputation for reliability when it comes to opening it at the end of the settlement process.
Centralizer
In a very distorted well, this component can be inserted into the foot of the settlement. It consists of a large collar, which makes the completion string centered inside the hole.
Wireline entry guide
This component is often installed at the end of the tube, or "shoe". This is intended to make withdrawal wireline tools easier by offering a guide surface for the tool strap to reinsert the tube without getting caught on the side of the shoe.
Perforating and stimulating
In the completion of the cased holes (mostly wells), once the string is completed in place, the final stage is to make connections between the wellbore and the formation. This is done by running a perforated weapon to blow a hole in the casing or liner to make the connection. Modern perforations are made using explosive charge shaped, similar to the charge of penetrating armor used on anti-tank rockets (bazooka).
Sometimes after the well is complete, further stimulation is required to achieve planned productivity. There are a number of stimulation techniques.
Acidification
It involves the injection of chemicals to eat away at any skin damage, "clean up" the formation, thereby increasing the flow of the reservoir fluid. Strong acids (usually hydrochloric acid) are used to dissolve rock formations, but these acids do not react with hydrocarbons. As a result, hydrocarbons are more accessible. Acid can also be used to clean the wellbore of several scales formed from mineral-containing water.
Fracture
This means creating and expanding fractures from the deeper perforated tunnels to formation, increasing the surface area for formation fluid flowing into the well, as well as extending the passage of possible damage near the wellbore. This can be done by injecting fluids at high pressure (hydraulic fracturing), injecting liquids mixed with round material (proppant fracture), or using explosives to produce high pressure and high-speed gas flow (TNT or PETN up to 1,900,000 psi) 13,000. 000 kPa)) and (propellant stimulation up to 4,000 psi (28,000 kPa)).
Acidification and fracture (combined method)
This involves the use of explosives and chemical injections to increase the acid-rock contact.
Nitrogen circulation
Sometimes, productivity may be hampered by residual fluid settlement, heavy brine, in wellbore. This is particularly a problem in gas wells. In this case, the rolled tube can be used to pump nitrogen at high pressure to the bottom of the borehole to circulate the brine.
See also
- Oil well
- Intervention well
External links
- Intelligent troubleshooting technology
Source of the article : Wikipedia
0 Comments