Patent Grant
10927654
This disclosure relates to hydrocarbon production.
In hydrocarbon production, wells are drilled to penetrate target reservoirs which usually include different geological layers. All the reservoir layers can be produced simultaneously during the life time of the well, resulting in more production from dominant layers while production from the less prolific layers. For vertical wells, casings can be run across the wellbore with sequential perforations starting from the deepest layers to ensure better sweep efficiency across all layers; however, this is not applicable in horizontal wells. Typically, the wells are connected to a topside facility where it the hydrocarbons can be processed for transportation and refinement. In some instances, the wells could be re-completed to target unswept reservoir zones or abandoned after a period of time when its drainage area is depleted.
This disclosure describes technologies relating to depleting reservoirs with coiled tubing.
An example implementation of the subject matter described within this disclosure is a method of producing from a multi-layered reservoir. The method has the following features. A first layer of the multi-layered reservoir is produced through a coiled tubing production string. The coiled tubing production string is located within a wellbore that includes a first horizontal section within the first layer. The coiled tubing production string includes a packer at a downhole end of the coiled tubing production string. The packer seals an annulus that is defined by an outer surface of the coiled tubing production string and an inner surface of the wellbore. The annulus is sealed from the first layer. The coiled tubing is retracted from the first layer of the multi-layered reservoir to a second layer of the multi-layered reservoir. The second layer is uphole of the first layer. The first layer is sealed from the second layer. The second layer produced through the coiled tubing production string. The coiled tubing production string is located within the wellbore that includes a second horizontal section within the second layer.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. The packer is unsealed prior to retracting the coiled tubing from the first layer to the second layer. The packer is retracted with the coiled tubing. The packer is retrieved from the wellbore. A second packer is installed and resealed after retracting the coiled tubing from the first layer to the second layer. The second packer seals the annulus from the second layer.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. The coiled tubing is retracted from the second layer of the multi-layered reservoir to a third layer of the multi-layered reservoir. The third layer is uphole of the second layer. The second layer is sealed from the third layer. The third layer is produced from through the coiled tubing production string.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. Retracting the coiled tubing includes using a coiled tubing truck.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. Sealing the first layer from the second layer includes installing a plug.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. The plug includes a cement plug or an expandable plug.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. The first horizontal section includes an open-hole completion.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. The second horizontal section includes an open-hole completion after retracting the coiled tubing to the second layer.
An example implementation of the subject matter described within this disclosure is a well-system with the following features. A wellbore is formed in a layered reservoir. The wellbore includes a first horizontal section within a first layer of the reservoir and a second horizontal section within a second layer of the reservoir. The second horizontal section is uphole of the first horizontal section. A length of coiled tubing extends through the wellbore from a topside facility to the first horizontal section. An annular packer is positioned at a downhole end of the length of coiled tubing. The annular packer seals an annulus defined by an outer surface of the length of coiled tubing and an inner surface of the wellbore. The annular packer seals the annulus from the first horizontal section.
Aspects of the example system, which can be combined with the example system alone or in combination, include the following. The wellbore further includes a third horizontal section within a third layer of the reservoir. The third horizontal section is uphole from the second horizontal section.
Aspects of the example system, which can be combined with the example system alone or in combination, include the following. The first layer is stratigraphically lower than the second layer, and the second layer is stratigraphically lower than the third layer.
Aspects of the example system, which can be combined with the example system alone or in combination, include the following. The second horizontal section and the third horizontal section are connected by a vertical section or a deviated section.
Aspects of the example system, which can be combined with the example system alone or in combination, include the following. The annular packer is a retrievable annular packer.
Aspects of the example system, which can be combined with the example system alone or in combination, include the following. The first horizontal section and the second horizontal section are connected by a vertical section or a deviated section.
Aspects of the example system, which can be combined with the example system alone or in combination, include the following. The first horizontal section includes an open-hole completion.
An example implementation of the subject matter described within this disclosure is a method of completing a well within a multilayered reservoir. The method include the following features. A wellbore is formed. The wellbore includes a first horizontal section within a first layer of the reservoir and a second horizontal section within a second layer of the reservoir. The second horizontal section is uphole of the first horizontal section. A coiled tubing string is inserted such that a downhole end is within the first horizontal section. A packer is seated at a downhole end of the coiled tubing string. The packer seals an annulus defined by an outer surface of the coiled tubing string and an inner surface of the wellbore. The packer seals the annulus from the first horizontal section.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. Fluid is produced through the coiled tubing from the first horizontal section.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. The first horizontal section and the second horizontal section are connected by a vertical section or a deviated section.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. The first horizontal section is completed with an open-hole completion.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. Forming the wellbore further includes forming a third horizontal section within a third layer of the reservoir. The third horizontal section is uphole from the second horizontal section.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. The second horizontal section and the third horizontal section are connected by a vertical section or a deviated section.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. The first layer is stratigraphically lower than the second layer, and the second layer is stratigraphically lower than the third layer.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. Forming the wellbore includes using a drilling rig.
Aspects of the example method, which can be combined with the example method alone or in combination, include the following. Completing the wellbore in the second layer does not require using a drilling rig.
Particular implementations of the subject matter described in this disclosure can be implemented so as to realize one or more of the following advantages. The recovery factor for hydrocarbon production is increased as individual layers are fully produced before moving on to subsequent layers avoiding dominant effect of a prolific layer. As open-hole completions can be used, oil production can be accelerated. Deployment of coiled tubing will take care of dog-leg severity due to their flexibility, and take care of the well-bore size adaptation due to their wide range of sizes. As well, the coil-tubing can be re-used elsewhere when the reservoir is depleted. No drill rig is needed for subsequent stages of re-completion.
The details of one or more implementations of the subject matter described in this disclosure are set forth in the accompanying drawings and the description. Other features, aspects, and advantages of the subject matter will become apparent from the description, the drawings, and the claims.
Like reference numbers and designations in the various drawings indicate like elements.
During hydrocarbon production, there are often hydrocarbons left in place, as they cannot be economically or technically produced. A goal of developing a production plan for a given hydrocarbon reservoir involves determining how to extract as much hydrocarbon out of the reservoir. Often times this is referred to as the “recovery factor” of the reservoir. The goal is generally to have the recovery factor be as high as is feasible.
This disclosure relates to a method of producing a multilayered reservoir with coiled tubing. One horizontal well is drilled step wisely (stair-way) through many overlying production layers. The horizontal is a continuity of horizontal sections drilled at the top of each producing layer simultaneously crossing vertically or slanted from one layer to the next one forming a step design single wellbore. The well might be drilled with a coiled tubing drilling stringer or with regular drilling pipe. The length of coiled tubing is extended through the wellbore to the bottom layer, where the annulus between the coiled tubing and the wall of the wellbore is sealed with a packer. The lower level is produced until the water-cut is too substantial, then the coiled tubing is retracted to the next layer. The packer is then re-seated, and the lower layer is abandoned. The process is repeated for each subsequent layer. Such a process allows a greater total hydrocarbon recovery from the reservoir by reducing the effect of more prolific production layers.
The wellbore 102 passes through the first layer 104a, the second layer 104b, and the third layer 104c. As illustrated, the wellbore 102 includes a first horizontal section 102a within a first layer 104a of the reservoir 104. A second horizontal section 102b is located within a second layer 104b of the reservoir 104. The second horizontal section 102b is uphole of the first horizontal section 102a. The second horizontal section 102b is connected to the first horizontal section 102a by a first deviated or vertical section 102d. The first deviated or vertical section 102d connects a downhole end of the second horizontal section 102b to an uphole end of the first horizontal section 102a. As illustrated, the wellbore 102 includes a third horizontal section 102c within a third layer 104c of the reservoir 104. The third horizontal section 102c is uphole of the second horizontal section 102b. The third horizontal section 102c is connected to the second horizontal section 102b by a second deviated or vertical section 102e. The second deviated or horizontal section 102e connects a downhole end of the third horizontal section 102c to an uphole end of the second horizontal section 102b. In general, the wellbore 102 forms a step pattern through the various layers of the layered reservoir 104, and the wellbore 102 includes a horizontal section within each layer.
While generally described as a step pattern, a serpentine pattern can be used to similar effect without departing from this disclosure. In some implementations, a serpentine pattern can be combined with a step pattern depending on the topology of the individual reservoir. While the reservoir 104 and wellbore 102 are described within this disclosure as having three layers with three horizontal sections, greater or fewer layers and subsequent horizontal sections can be used without departing from this disclosure.
At an uphole end of the wellbore 102, a topside facility 106 is positioned to receive production fluid from the wellbore. The topside facility can include separators, pumps, compressors, amine units, glycol units, storage tanks, or any other equipment to assist in hydrocarbon production, hydrocarbon processing, or both. Extending into the wellbore 102 from the topside facility is a length of coiled tubing 108. The length of coiled tubing 108 extends though the wellbore 102 into the first horizontal section 102a. The length of coiled tubing 108 fluidically connects the first horizontal section 102a to the topside facility for production. While primarily described as using a length of coiled tubing, any downhole-type tubular (production string, liner, casing, etc.) can be used without departing from this disclosure. An annular packer 110 is positioned at a downhole end of the length of coiled tubing 108. The annular packer seals an annulus 112 defined by an outer surface of the length of coiled tubing 108 and an inner surface of the wellbore 102. The annular packer 110 seals the annulus 112 from the first horizontal layer 104a. “Seal” in the context of this disclosure refers to completely blocking fluid flow or partly blocking fluid flow. In some implementations, the annular packer 110 is a retrievable annular packer. The illustrated implementation shows an open-hole completion within the first horizontal section 102a. Other well completions can be used depending on wellbore stability, production zone length, production rate, well economics, any combination of these reasons, or any other reason.
Once the well is completed, the first layer 104a of the multi-layered reservoir 104 is produced through the coiled tubing length 108. That is, the coiled tubing length 108 acts as a production string. In the context of this disclosure, the terms “coiled tubing length” and “production string” may be used interchangeably. Producing from the first horizontal section 102a refers to directing production fluid from the first horizontal layer 104a, through the first horizontal section 102a, and up the length of coiled tubing 108 to the topside facility 106. Production fluid can include liquid hydrocarbons, water, gaseous hydrocarbons, or any combination and ratio of these. Production from the first horizontal section 102a continues until the ratio of hydrocarbons to other production fluids, such as water, decreases to be less than a specified threshold. Once the water cut becomes too great (hydrocarbon ratio becomes too small), an operator may move on to a second stage of production.
As previously stated, the packer 110 is unsealing prior to retracting the coiled tubing 108 from the first layer 104a to the second layer 104b. In some implementations, the packer 110 is retracted with the coiled tubing 108. In some implementations, the packer 110 is retrieved from the wellbore 102, and a second packer is installed and resealed at a downhole end of the coiled tubing 108 after retracting the coiled tubing from the first layer 104a to the second layer 104b. In some implementations, the same packer 110 can be refurbished and reused. In some implementations, the original packer is not retrieved, and is instead abandoned within the wellbore 102. The newly seated packer 110 seals the annulus 112 from the second layer 104b.
Prior to producing the second layer 104b, a plug 202 is installed between the first horizontal section 102a and the second horizontal section 102b. As illustrated, the plug 202 is installed within the first vertical section 102d, but can be installed anywhere along the wellbore 102 such that the first layer 104a is fluidically isolated from the second layer 104b. The plug 202 can include an expandable plug, a cement plug, or any other plug appropriate for abandoning a section of a well.
Once the second layer 104b is isolated from the first layer 104a, production is flowed from the second layer 104b. Producing from the second layer 104b is substantially similar to producing from the first layer 104a with the exception of any differences described within this disclosure. The second layer 104b is produced through the coiled tubing 108 until the ratio of hydrocarbons to other production fluids, such as water, decreases to a value less than a specified threshold. Once the water cut becomes too great (hydrocarbon ratio becomes too small), an operator may move on to a third stage of production.
Prior to producing the second layer 104c, a plug 204 is installed between the second horizontal section 102b and the third horizontal section 102c. As illustrated, the plug 204 is installed within the first vertical section 102e, but can be installed anywhere along the wellbore 102 such that the second layer 104b is fluidically isolated from the third layer 104c. The plug 204 can include an expandable plug, a cement plug, or any other plug appropriate for abandoning a section of a well.
The third layer 104c is produced through the coiled tubing 108 until the ratio of hydrocarbons to other production fluids, such as water, decreases to a value less than a specified threshold. Once the water cut becomes too great (hydrocarbon ratio becomes too small), an operator may move on to a fourth stage of production (not illustrated).
In this instance, as there are three production layers illustrated, the fourth stage of production includes abandonment. Once the wellbore is abandoned according to local guidelines (plugging, cementing, etc.), the coiled tubing 108 can be moved to another production location and installed into a new wellbore. In some implementations, a sidetrack can be formed within the original wellbore and production can continue in a different section of the reservoir 104. While described in the context of three production layers, greater or fewer production layers can be included in each individual reservoir. In some implementations, multiple wellbores can radiate from a single, central, or vertical wellbore to produce multiple sections of a reservoir simultaneously. In such an implementation, flows can be comingled from different sections of the reservoir, or they can be fluidically isolated prior to processing at the topside facility 106. Aspects of this disclosure are applicable to both onshore and offshore production.
After the first layer has been sufficiently produced, the packer is unsealed. In some implementations, the packer is retracted with the coiled tubing. In some implementations, the packer is retrieved from the wellbore. At 504, the coiled tubing is retracted from the first layer of the multi-layered reservoir to a second layer of the multi-layered reservoir. Next, a second packer is installed and sealed. The same packer used in the previous layer can be refurbished and reused, or a new packer can be installed. At 506, the first layer is sealed from the second layer. That is, the second packer seals the annulus from the second layer. At 508, fluid is produced from the second layer through the coiled tubing production string.
In some instances, more than two production layers are present in the reservoir. In such instances, subsequent layers can be produced. For example, after the second layer has been sufficiently produced, the coiled tubing is retracted from the second layer of the multi-layered reservoir to a third layer of the multi-layered reservoir. In some implementations, the third layer is uphole of the second layer. The second layer is then sealed from the third layer, and the third layer is produced through the coiled tubing production string.
In some implementations, retracting the coiled tubing includes using a coiled tubing truck. In some implementations, a drill rig can be used to retract the coiled tubing. In some implementations, sealing the first layer from the second layer comprises installing a plug, for example, a cement plug. In some implementations, other sealing systems can be used, for example, a permanently installed packer. In some implementations, the first horizontal section and the second horizontal section each include open-hole completions. While primarily described as using open-hole completions, other completion methods can be used in any section of the wellbore without departing from this disclosure.
At 604, a coiled tubing string is inserted into the wellbore such that a downhole end is within the first horizontal section. At 606, a packer is seated at a downhole end of the coiled tubing string. The packer is positioned such that it seals an annulus defined by an outer surface of the coiled tubing string and an inner surface of the wellbore. The packer seals the annulus from the first horizontal section. After the annulus is sealed, fluid is produced through the coiled tubing from the first horizontal section.
While this disclosure contains many specific implementation details, these should not be construed as limitations on the scope of any inventions or of what may be claimed, but rather as descriptions of features specific to particular implementations of particular inventions. Certain features that are described in this disclosure in the context of separate implementations can also be implemented in combination in a single implementation. Conversely, various features that are described in the context of a single implementation can also be implemented in multiple implementations separately or in any suitable subcombination. Moreover, although features may be described previously as acting in certain combinations and even initially claimed as such, one or more features from a claimed combination can in some cases be excised from the combination, and the claimed combination may be directed to a subcombination or variation of a subcombination.
Similarly, while operations are depicted in the drawings in a particular order, this should not be understood as requiring that such operations be performed in the particular order shown or in sequential order, or that all illustrated operations be performed, to achieve desirable results. Moreover, the separation of various system components in the implementations described previously should not be understood as requiring such separation in all implementations, and it should be understood that the described components and systems can generally be integrated together in a single product or packaged into multiple products.
Thus, particular implementations of the subject matter have been described. Other implementations are within the scope of the following claims. In some cases, the actions recited in the claims can be performed in a different order and still achieve desirable results. In addition, the processes depicted in the accompanying figures do not necessarily require the particular order shown, or sequential order, to achieve desirable results.
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