|Development Geology Reference Manual|
|Series||Methods in Exploration|
|Part||Production engineering methods|
|Author||Stephen A. Holditch|
- 1 Purpose of well completions
- 2 Types of completions
- 3 Perforating
- 4 See also
- 5 External links
Purpose of well completions
The purposes of a well completion are to
- Connect the reservoir to the surface so that fluids can be produced from or injected into the reservoir
- Provide a conduit for well stimulation treatments
- Isolate the producing reservoir from other zones
- Protect the integrity of the reservoir, especially in unconsolidated formations
- Provide a conduit to measure the changes in flow rate and pressure needed to run a well test
The wellbore provides the only path from the surface to the reservoir. To a large extent, the successful production and depletion of a reservoir depends upon the successful completion and workover operations applied to a well. In most companies, the production engineer designs and supervises all completion and workover operations.
Types of completions
Completions can be divided into three categories: open hole completions, liner completions, and perforated casing completions. In most wells, conventional single perforated casing completions are used; however, multiple, alternate, or slim hole completions may be used under certain conditions. The choice of completion type should be closely coordinated with the development of the reservoir management plan. For example, the size, weight, and grade of the tubular goods will be determined based upon the ultimate use of a wellbore. An injection well may require stronger casing than a production well.
Open hole completions
Open hole completions were originally used in the early days of the petroleum industry when most wells were drilled with cable tools. Normally, casing was run as the hole was drilled. When the formation was penetrated and oil and gas began to flow, drilling ceased and the well was produced as an open hole completion. As rotary rigs began to drill a majority of the wells, it was still common to complete a well using an open hole completion. If the well needed to be stimulated, nitroglycerine was used to rubbleize the formation near the wellbore. Figure 1(a) illustrates a typical wellbore diagram for an open hole completion. Although not common in most areas, open hole completions are still used today in certain situations, such as the horizontal well completions in the Austin Chalk and in the Devonian shales in Appalachia. In a typical open hole completion, casing is set prior to drilling into the producing interval. A nondamaging fluid can then be used to drill into the pay section.
One important disadvantage of an openhole completion is that production casing must be set prior to drilling and logging the reservoir. If for some geological or engineering reason the target formation is not productive, then money has been spent to set casing in a well that may be plugged as a dry hole. Another disadvantage is the lack of control that occurs when an open hole completion is made. One cannot control the flow of fluids from the reservoir into the wellbore nor the injection profile in an open hole completion. In addition, if the formation is not competent, sloughing zones can cave into the wellbore and restrict flow to the surface.
Liner completions are similar to open hole completions in that casing must be set prior to drilling the producing interval. The advantage of a liner completion is that the drilling fluid system can be changed and a nondamaging fluid used to drill the pay interval. Several types of liner completions are commonly employed in well completions. These include
- Slotted liner
- Screen and liner
- Cemented liner
The slotted liner completion is similar to an open hole completion and has all the major advantages and disadvantages discussed for open hole completions. The only difference is that a slotted liner is hung in the open hole interval to minimize sloughing of the formation into the well bore (Figure 1b). A screen and liner completion is similar to the slotted liner completion in that a screen and liner is set in the open hole section of the wellbore. The difference is that gravel is sometimes placed behind the screen (Figure 2a). The advantages and disadvantages are the same as for open hole completions. The screen and liner completion is used primarily in unconsolidated formations to prevent the movement of formation materials into the wellbore, restricting the flow of reservoir fluids.
The cemented liner completion is used when intermediate casing is set in a well prior to reaching total depth (Figure 2b). Many times intermediate casing is used to isolate zones behind pipe such as low pressured intervals that tend to cause lost circulation problems or to isolate zones such as sloughing shales or salt layers. Intermediate casing is also set in transition zones between normally pressured intervals and geopressured intervals. After the casing is set, the weight or chemistry of the drilling fluid can be changed to continue drilling the well. The cemented liner completion is advantageous because the particular intervals behind the liner can be selectively perforated. This selection will allow one to control both the production and injection of fluids in those intervals. The main disadvantage of a cemented liner is the difficulty encountered in obtaining a good primary cement job across the liner. If a good cement job is obtained, then a cemented liner completion is very similar to a perforated casing completion.
Perforated casing completions
A perforated casing completion, illustrated in Figure 3a, is the most commonly used completion technique today. The main advantage of this type of completion is that the well can be drilled and logged to total depth prior to running and cementing production casing. By obtaining cores and logs of the potential producing interval, one can estimate the economic value of that wellbore prior to committing funds to complete the well. Another advantage of a perforated casing completion is that it is easier to obtain a good cement job, compared to a liner completion. If the primary cementing job is properly performed, one can selectively produce from and inject into the reservoir and isolate intervals as required. The production of an unconsolidated formation can be accomplished by performing an inside gravel pack. Finally, the perforated casing completion is quite adaptable to multiple completions and alternate completions.
Once the decision has been made to either complete a well using an open hole completion, liner completion or perforated casing completion, a decision must be made on how many different intervals will be produced. The most common method is the single completion in which only one interval is produced at a time (Figure 3b). A single completion is simple and results in fewer operating problems and less cost than multiple completions. Single completions are common on land where the reservoirs are either shallow or very deep. If the formation is very shallow, then drilling costs are minimal and single completions are usually best. In very deep wells, single completions are preferred because of the complexity and expense involved with a dual or triple completion in reservoirs deeper than 10,000 ft3,048 m.
In certain cases, multiple completions may provide the best control of reservoir operations. Multiple completions include the tubing-casing dual, dual tubing strings, and the typical triple completion consisting of three tubing strings. Figures 4 and 5 illustrate these multiple completions.
The more complex the completion, the more trouble one can expect in both completion operations and in subsequent workover operations. Multiple completions should be considered only in special situations. These situations include areas where drilling costs are very high or where the area allocated for drilling wells is at a premium. Such areas include offshore areas, highly populated areas, and remote land locations.
The main advantage of multiple completions is that two or more reservoirs can be simultaneously produced from a single wellbore. If all goes properly, the economics of using multiple completions can be attractive; however, operating and workover costs can be quite high. These operational factors must be considered when considering multiple completions.
Alternate completions are used to allow inexpensive recompletions. Normally, a single interval is completed and produced to abandonment and then, using wireline tools, the lower interval is isolated and the upper interval opened to production (Figure 6). Alternate completions eliminate the need for costly workovers using rigs. It is possible to have a dual well with two alternate completions; however, as the completion gets more complex, more problems will occur. Alternate completions are used in areas where workover costs by conventional methods can be quite high. The most common use of alternate completions is offshore.
Slim hole completions
In certain reservoirs, the economic value of the reserves does not justify the expenditures of normal completion methods. An example of such a reservoir would be a series of thin, small lenticular dry gas intervals. Under certain conditions, the reservoir might not warrant the use of large production casing and tubing to produce the gas. For such reservoirs, slim hole completion techniques might be justified in which small pipe, such as 4-1/2-in. or 2–7/8-in. casing, is run and cemented in the wellbore. This small casing serves as the tubing and casing for the wellbore. This completion practice is used to minimize completion costs and should be used only for wells that are expected to have short producing lives and that do not require artificial lift.
Special considerations for producing and injection wells
The completion technique applied to a well depends on whether the well is a producing well or an injection well. For a producing well, the number of different reservoirs that may eventually be produced is significant. A decision must be made on whether a single or multiple completion will be made. One should be aware of stimulation treatments that may be required or the possible need for artificial lift equipment to produce fluids from the wellbore. Information on Christmas trees, tubing spools, packers, and downhole equipment needed to produce the well should be carefully designed and included in the completion program.
If a well is to be an injection well, one should be aware of the intervals that will require completion for the injection of fluids. The engineer should have an idea of the anticipated injection rates and pressure that will influence the design of the completion program. Extra effort should be made to ensure that the casing, tubing, wellhead, and cement programs are carefully designed and that the mechanical condition of the well during completion is excellent.
The major purpose of perforations is to provide effective flow communication between the wellbore and the reservoir. To create a perforation, a perforating gun is used to “shoot” a hole through the casing and cement. The hole is called a perforation tunnel and provides a pathway for fluid flow from the reservoir to the wellbore.
Over 90% of wells are perforated using a shaped charge perforating system. The shaped charge, or jet charge, came into use in the oil field shortly after World War II. The perforating shaped charge is a derivative of the charge used to construct a bazooka. The shaped charge has essentially replaced the bullet gun, which was the main perforating tool prior to World War II.
Figure 7 illustrates the components of the shaped charge. The main characteristic of the shaped charge is the cone-shaped cavity. To fire the shaped charge, the primer cord ignites the primer charge, which in turn ignites the main explosive charge. As the powder burns, it reaches the apex of the cone. The cone collapses and creates a jet stream that is capable of penetrating the steel casing, cement, and formation. Figure 8 illustrates the formation of the jet stream from a shaped charge.
Types of guns
All perforating guns can be classified into three broad categories:
- Expendable gun
- Semi-expendable gun
- Retrievable, hollow carrier gun
An expendable gun is one in which all parts of the gun below the collar locator are either destroyed during the perforation explosion or left in the well as debris in the rathole. Expendable guns are used in shallow wells and usually cost less than other types of guns. Expendable guns allow the use of larger jet charges; however, the guns can cause casing damage in unsupported casing.
A semi-expendable gun has a metal bar that holds the shaped charges. After firing, some of the gun disintegrates, part of the jet charges fall to the bottom of the hole, and the metal bar is recovered. The semi-expendable gun costs slightly more that an expendable gun with comparable shot density. Like the expendable gun, the semi-expendable gun can use larger jet charges than the hollow carrier guns, and the possibility of casing damage exists.
Retrievable hollow carrier gun
A retrievable hollow carrier gun is the most widely used gun because it
- Is highly reliable
- Is mechanically rugged and strong
- Can be used in high temperature and pressure environments
- Leaves no debris in the hole
- Eliminates casing damage
- Offers high charge performance
The hollow carrier gun contains all parts inside a steel tube that is resistant to wellbore fluids. When the gun is fired, most debris remains inside the tube and is retrieved at the surface.
Gun size and method of conveyance
Perforating guns also come in different sizes and can be run using a wireline or tubing.
Typical casing guns range from 3–1/8 to 5 in.0.127 m
0.417 ft outside diameter. These large diameter guns have to be run inside casing with tubing out of the hole. Casing guns are advantageous because maximum size jet charges can be used, resulting in maximum hole size and penetration.
A tubing conveyed gun is a large diameter casing gun (3–1/8 to 5 in.) that is run on the end of tubing. This arrangement allows one to use a large diameter gun and to perforate the well with tubing in the hole and the wellhead installed. The gun can be fired by dropping a bar inside the tubing.
The guns that are run inside the tubing to perforate the casing are called thru-tubing guns. Typical thru-tubing guns range in diameter from 1–3/8 to 2–3/8 in. Because thru-tubing guns are much smaller than casing guns, smaller jet charges must be used; therefore, the resulting perforations are smaller in diameter and length, compared to a casing gun.
A well can be perforated three different ways:
- Overbalanced using a casing gun
- Underbalanced using a tubing-conveyed gun
- Underbalanced using a thru-tubing gun
When the well is overbalanced, the pressure in the wellbore is greater than the reservoir pressure. After firing the gun, the wellbore fluids will flow into the perforations. If mud is used, the solids in the mud will plug the perforations; therefore, clean wellbore fluids are preferred when perforating overbalanced. In contrast, when the pressure in the wellbore is less than the formation pressure, the situation is called underbalanced perforating. To perforate underbalanced, one should use either a tubing-conveyed gun or a thru-tubing gun. Also, the wellhead should be installed and a pressure-tested lubricator should be on the wellhead.
Figure 9 illustrates the two methods: (1) overbalanced perforating with a casing gun and (2) underbalanced perforating with a thru-tubing gun. Figure 10 shows qualitatively the difference in hole size and hole penetration for the two methods. The selection of the perforating method is influenced by the depth of the zone, the temperature, the pressure, the need for well stimulation, and the need for sand control procedures.
- Production testing
- Production histories
- Artificial lift
- Surface production equipment
- Introduction to production engineering methods
- Pressure transient testing
- Production logging
- Production problems