Patent Application
20150176378
1. Field of the Disclosure
This disclosure relates generally to wellbore systems, including multilateral wellbore systems that inhibit flow of particles over a certain size from one wellbore to another wellbore.
2. Background of the Art
Wells or wellbores are drilled in subsurface formations for the production of hydrocarbons (oil and gas). In some cases, multilateral wells are formed, wherein one or more wells are formed from a main wellbore. Sometimes lateral wellbores are also formed from one or more of the other lateral wellbores. Such a wellbore system is generally referred to a “multilateral wellbore” or a “multilateral wellbore system.” Typically, the main wellbore is a cased wellbore, in that, it is lined with a metal casing (typically a jointed metallic tubular). In some cases the lateral wellbore is not lined with a casing, i.e., it is left as an open hole. Sand control and other flow control devices are installed at locations from which the formation fluid is extracted into the lateral wellbore. However, in open hole lateral wellbores, the junction between the main wellbore and the lateral wellbore includes no sand control devices that prevent the flow of particles, such as sand, from entering into the main wellbore from the lateral wellbore. Excessive sand production is detrimental to the equipment in the wellbores. This problem can be exacerbated when the open hole is formed in an unconsolidated formation, as such formations can produce excessive amounts of sand.
The disclosure herein provides wellbore systems that include sand control apparatus that inhibit or prevent flow of particles above a certain size from the junctions and the lateral wellbores into the main wellbore and methods of installing such apparatus.
In one aspect, a wellbore system is disclosed that in one non-limiting embodiment includes a first wellbore capable of producing a fluid from a first formation, a second wellbore intersecting the first wellbore at a junction, wherein the second wellbore is an open hole and capable of producing a fluid from a second formation and a sand screen at the junction configured to inhibit particles larger than a selected size from flowing from the second wellbore and the juncture into the first wellbore.
In another aspect, a method of forming a wellbore is disclosed that in one non-limiting embodiment includes: forming a first wellbore capable of producing a fluid from a first formation; forming a second wellbore from a junction in the first wellbore; and placing a sand screen at or proximate to the junction to inhibit and/or prevent particles larger than a selected size from flowing from the second wellbore and the junction into the first wellbore.
Examples of the more important features of the apparatus and methods of the disclosure have been summarized rather broadly in order that the detailed description thereof that follows may be better understood, and in order that the contributions to the art may be appreciated. There are, of course, additional features that will be described hereinafter and which will form the subject of the claims.
For a detailed understanding of the apparatus and methods disclosed herein, reference should be made to the accompanying drawing and the detailed description thereof, wherein:
The lateral wellbore 180 includes inflow devices, such as a sand screen 184 and other devices, such as flow control devices (valves, pressure drop devices, etc. known in the art), collectively referred to by numeral 186. Fluid 188 from a production zone 190 may flow into the lateral wellbore 180 via devices 184 and 186, as shown by arrows 188a. The fluid 188 flows into the wellbore 180 and then into the main wellbore 110 at the junction 130, as shown by arrows 188b. As noted earlier, fluid 132 from the formation proximate the junction 130 also may flow into the main wellbore 110 as shown by arrows 133. In one non-limiting embodiment, a lateral liner 140 (sometimes referred to in the industry as “lateral hook liner”) extends from a location 140a in the main wellbore 110 uphole (or above) of the junction 130 to a location 140b downhole (or below) of the junction 130 proximate to the screen 184 in the lateral well bore 180. The lateral liner 140 includes a through passage 144 that provides a through opening in the main wellbore 110 across the junction 130. The fluid 132 from the junction 130 flows or is directed to flow into the main wellbore 110 via fluid path 134 between the lateral liner 140 and the casing 104. The fluid 188, however, will generally flow into the main wellbore 110 from inside of the lateral liner 140, as shown by arrows 188b. Alternatively, the lateral liner may be located at any other suitable location in the wellbore system 100 so as to direct the fluid 132 from the junction toward the sand screen 160.
Still referring to
In one non-limiting embodiment, a flow control device, such as a sand screen 160 of sufficient length and size is placed in the production tubular 114 to inhibit or prevent flow of solid particles above a certain (selected) size in the fluid 132 and fluid 188b from entering the production tubing 114. In one aspect, the sand screen 160 may extend from a location 160a above the junction 130 to a location 160b below the junction 130. In one non-limiting embodiment, the sand screen 160 may be placed in a tubing 170 and placed inside the production tubing 114. Alternatively, the sand screen 160 may be placed in the lateral wellbore 180 or partially in the main wellbore 101 and partially in the lateral wellbore 180, each such screen adapted to or configured to inhibit or prevent solid particles above a size from entering the flow of the fluid toward the surface. In one non-limiting embodiment, the production tubing 114 includes an inward profile (also referred as indentations) 116 and the tubing 170 includes a collet 172 that is configured to engage with (mate with) the profile 116, so that when the collet 172 engages with the profile 116, the tubing 170 will securely hang inside the production tubing 114. In one embodiment, the tubing 170 also included another profile 176. To install or place the screen 160 in front of the junction 130, collet 175a on a run-in tool 175 is engaged with the profile 176 on the tubing 170 at the surface. The run-in tool 175 carrying the tubing 170 and the sand screen 160 is moved into the production tubing 114 until the collet 172 engages with the profile 116. In aspects, the force (pull force) required to dislodge the collet 172 from the profile 116 is greater than the pull force required to dislodge the collet 175a from the profile 176 and thus the run-in tool 175 from the profile 116. Once the tubing 170 has been placed in the production tubing 114, the run-in tool 175 is pulled out of the tubing 114, leaving the sand screen 160 in front of the junction 130. Seals 162a and 162b are provided between the tubing 170 and the production tubing 114 to prevent flow of the fluid from the lateral wellbore 180 or the junction 130 to bypass the sand screen 160. In other aspects, devices in addition to the sand screen may also be placed outside the screen (198) r inside the screen (189). For example, a flow control device, such as sliding sleeve valve, may be placed inside the sand screen 160 to control the flow of the fluid from the lateral wellbore 180. In another aspect, a flow control device that discriminates flow of one type of fluid against another type of fluid may be placed inside the sand screen 160. Such devices are known in the art and may include, but are not limited to, device having a tortuous fluid flow path; a device that inhibits flow of water compared to the flow of oil or gas; and a flow that created a greater pressure drop for water compared to oil or gas. Also, the sand screen may be any suitable sand screen.
The foregoing disclosure is directed to certain exemplary embodiments and methods. Various modifications will be apparent to those skilled in the art. It is intended that all such modifications within the scope of the appended claims be embraced by the foregoing disclosure. The words “comprising” and “comprises” as used in the claims are to be interpreted to mean “including but not limited to”. Also, the abstract is not to be used to limit the scope of the claims.
