WELLHEAD TREE SYSTEM FOR TRANSITION BETWEEN ARTIFICIAL LIFT METHODS

Description

CROSS-REFERENCE SECTION

This application is a U.S. Non-Provisional Application claiming priority to U.S. Non-Provisional Application No. 63/711,902, filed on Oct. 25, 2024, which is incorporated by reference in its entirety.

FIELD OF THE DISCLOSURE

This application relates to wellhead tree systems, in particular for oil and gas production, specifically to a wellhead tree configuration that facilitates a transition between various artificial lift methods through minimal valve actuation.

BACKGROUND

In oil and gas extraction, various artificial lift methods, such as Conventional Gas Lift, Annular Gas Lift, and Electrical Submersible Pumps (ESP), are employed to maintain or enhance production. The ability to switch between these lift methods typically requires significant reconfiguration of the wellhead and wellhead tree system, resulting in increased downtime, prolonged setup time, and higher resource expenditure. Existing wellhead systems do not facilitate this transition between lift methods, often requiring valves and tree hardware to be manually reconfigured or replaced.

A new approach to addressing these issues is presented herein.

SUMMARY

According to some embodiments, the present disclosure relates to a wellhead tree configuration including: a tubing head fluidly connected to a first studded tee through a tubing head adaptor; the first studded tee fluidly connected to a tree cap; a studded cross fluidly connected to the first studded tee through a first spacer spool; a second studded tee fluidly connected to the studded cross through a first gate valve; a third studded tee fluidly connected to the second studded tee through a second spacer tool; and a fourth studded tee fluidly connected to: the third studded tree through a second gate valve; and the studded cross through a third gate valve and a fourth gate valve, wherein the third gate valve extends outward from the fourth studded tee, and wherein the fourth gate valve extends outward from the studded cross; and the tubing head through a fifth gate valve.

In some embodiments, the present disclosure relates to wellhead tree configuration including a tubing head fluidly connected to a first studded tee through a tubing head adaptor; the first studded tee fluidly connected to a tree cap; a studded cross fluidly connected to the first studded tee through a first spacer spool; a second studded tee fluidly connected to the studded cross through a first gate valve; a third studded tee fluidly connected to the second studded tee through a second spacer tool; and a fourth studded tee fluidly connected to: the third studded tree through a second gate valve; and the studded cross through a third gate valve and a fourth gate valve, wherein the third gate valve extends outward from the fourth studded tee, and wherein the fourth gate valve extends outward from the studded cross; and the tubing head through a fifth gate valve. The wellhead tree may be configured to function as a conventional gas lift by having each of the fourth gate valve and the second gate valve closed. The wellhead tree may be configured to function as an annular gas lift by having each of the first gate valve and the third gate valve closed. The wellhead tree may be configured to function as an electrical submersible pump by having each of the fourth gate valve, the second gate valve, and fifth gate valve closed.

The wellhead tree may be configured to function as a conventional gas lift by having each of the fourth gate valve and the second gate valve closed. The wellhead tree may be configured to function as an annular gas lift by having each of the first gate valve and the third gate valve closed. The wellhead tree may be configured to function as an electrical submersible pump by having each of the fourth gate valve, the second gate valve, and fifth gate valve closed. The fourth gate valve and the third gate valve may be connected by a third spacer spool. The third spacer spool may be connected to the third gate valve through a fourth studded tee. The tubing head may be fluidly connected to a WECO flange through a sixth gate valve. The first studded tee may be fluidly connected to the tree cap through a SWAB valve. The first studded tee may be fluidly connected to the tubing head adapter through a seventh gate valve and an eighth gate valve that are connected in line. The fifth gate valve may be fluidly connected to the fourth studded tee through a ninth gate valve. The wellhead tree may include a concentric wellhead adapter.

Additional features and advantages of the present disclosure are described in, and will be apparent from, the detailed description of this disclosure.

BRIEF DESCRIPTION OF THE DRAWINGS

The disclosure is illustrated by way of example, and not by way of limitation, in the figures of the accompanying drawings in which like reference numerals are used to refer to similar elements. It is emphasized that various features may not be drawn to scale, and the dimensions of various features may be arbitrarily increased or reduced for clarity of discussion.

FIG. 1 is a schematic diagram a wellhead tree system, in accordance with some embodiments.

FIG. 2A is a schematic diagram of a wellhead tree system configured as a conventional gas lift, in accordance with some embodiments.

FIG. 2B is a schematic diagram of a wellhead tree system configured as an annular gas lift, in accordance with some embodiments.

FIG. 2C is a schematic diagram of a wellhead tree system configured as an electrical submersible pump, in accordance with some embodiments.

DETAILED DESCRIPTION

The present disclosure relates to a wellhead tree for transitioning between artificial lift methods. Disclosed wellhead trees may switch between multiple lift methods, including, but not limited to, a conventional gas lift, an annular gas lift, and an electrical submersible pump, through a simple action (e.g., opening or closing) of opening or closing some of the valves. In contrast, existing wellhead systems do not facilitate transitioning between lift methods, often requiring valves and tree hardware to be manually reconfigured or replaced. Disclosed wellhead trees advantageously eliminate a need for extensive reconfiguration or introduction of additional equipment, thereby minimizing downtime and reducing operation costs. Additionally, when used in conjunction with other known concentric wellhead adapters (e.g., SCP10000), system versatility increases to accommodate Plunger lift and Rod Lift methods without requiring any significant reconfiguration or installation of new hardware.

In some embodiments, disclosed wellhead trees include a configuration incorporating strategically placed gate valves, tees, flow lines, and other hardware to permit these seamless transitions between artificial lift methods. The wellhead trees disclosed herein may facilitate seamless transition between at least three artificial lift methods, including Conventional Gas Lift, Annular Gas Lift, and Electrical Submersible Pump (ESP), wherein the transition is achieved by actuating (i.e., opening or closing) no more than three valves.

FIG. 1 is a schematic diagram a wellhead tree system 100. Disclosed wellhead trees 100 may include a tubing head 102 fluidly connected to a first studded tee 106 through a tubing head adaptor 104. The first studded tee 106 may be fluidly connected to a tree cap 165. As shown in FIG. 1, the wellhead tree 100 may include a studded cross 110 fluidly connected to the first studded tee 106 through a first spacer spool 108, a second studded tee 112 fluidly connected to the studded cross 110 through a first gate valve 114, and a third studded tee 116 fluidly connected to the second studded tee 112 through a second spacer tool 118. The wellhead tree 100 may include a fourth studded tee 118 fluidly connected to the third studded tree 116 through a second gate valve 120. The fourth studded tee 118 may be connected to the studded cross 110 through a third gate valve 122 and a fourth gate valve 124, where the third gate valve 122 extends outward from the fourth studded tee 118, and where the fourth gate valve 124 extends outward from the studded cross 110. The fourth studded tee 116 may also be fluidly connected to the tubing head 102 through a fifth gate valve 130. Fluidly connected may include any mechanical connection that allows a substance, like a liquid, gas, solid, or combination thereof, to flow or move between two or more components of a disclosed wellhead tree system 100. The fluid connection may involve a metal and/or plastic component to facilitate said fluid connection.

According to some embodiments, as shown in FIG. 1, a disclosed wellhead tree 100 may include a fourth gate valve 124 and a third gave valve 122 connected by a third spacer spool 126. The third spacer spool 126 may be connected to the third gate valve 122 through a fourth studded tee 128. A tubing head 102 may be fluidly connected to a flange 140 through a sixth gate valve 135. The flange 140 may include a WECO flange, or any other flange known in the art. A first studded tee 106 may be fluidly connected to a tree cap 165 through a valve 145. The valve 145 may include a SWAB valve. As shown in FIG. 1, the first studded tee 106 may be fluidly connected to a tubing head adapter 104 through a seventh gate valve 150 and an eighth gate valve 155 that are connected in line. In some embodiments, a fifth gate valve 130 of the wellhead tree 100 may be fluidly connected to the fourth studded tee 118 through a ninth gate valve 160.

Each gate valve disclosed herein may include any known disk type, including a solid wedge, a flexible wedge, a split wedge, parallel disks, and more. Each gate valve disclosed may include any known stem type, including a rising stem, a non-rising stem, and more. Each disclosed gate valve may include any known body-bonnet connection, including a screwed bonnet, a bolted bonnet, a welded bonnet, and a pressure-seal bonnet.

FIG. 2A is a schematic diagram of a wellhead tree system 100 configured as a conventional gas lift. As shown in FIG. 2, a produced fluids may flow from the tubing head 102 through seventh gate valve 150 and eight gate valve 155, through first studded tee 106, tenth gate valve 132, first spacer spool 108, studded cross 110, first gate valve 114, and second studded tee 112, and then through second spacer spool 118 and third studded tee 116. As shown in FIG. 2A, the conventional gas lift configuration includes having fourth gate valve 124 and second gate valve 120 closed. As shown in FIG. 2A, a high pressure gas lift is found in fourth studded tee 128, third gate valve 122, fourth studded tee 118, ninth gate valve 160, fifth gate valve 160, and going down tubing head 102.

FIG. 2B is a schematic diagram of a wellhead tree system 100 configured as an annular gas lift. As shown in FIG. 2B, the wellhead tree system 100 has produced fluids flowing from tubing head 102 through fifth gate valve 130, ninth gate valve 160, fourth studded tee 118, and finally through third studded tee 116. The wellhead tree system 100, as shown in FIG. 2B, has high pressure gas lift flowing through fourth studded tee 128, third spacer spool 126, fourth gate valve 124, and studded cross 110, through first spacer spool 108, tenth gate valve 132, first studded tree 106, eighth gate valve 155, seventh gate valve 150, ESP tubing head adapter 104, and finally through tubing head 102. As shown in FIG. 2B, the wellhead tree configured to function as an annular gas lift may have each of the first gate valve 114 and the third gate valve 122 closed.

FIG. 2C is a schematic diagram of a wellhead tree system 100 configured as an electrical submersible pump. As shown in FIG. 2C, the wellhead tree system 100 with the electrical submersible pump configuration may have each of the fourth gate valve 124, the second gate valve 120, and fifth gate valve 130 closed. In some embodiments, the wellhead tree system 100 may include a produced fluids may flow from the tubing head 102 through seventh gate valve 150 and eight gate valve 155, through first studded tee 106, tenth gate valve 132, first spacer spool 108, studded cross 110, first gate valve 114, and second studded tee 112, and then through second spacer spool 118 and third studded tee 116.

According to some embodiments, disclosed wellhead tree systems may have a modular design. For example, the wellhead tree systems may be pre-assembled in two sections so that they may easily be assembled on site or near the site of production, allowing for rapid deployment and reducing setup time. Each of the two sections may be pre-tested for immediate functionality upon installation, thus reducing deployment time, the need for extensive reconfiguration, or the addition of new components during transitions between lift methods. In some embodiments, a first section may include components including a tubing head adapter 104, a seventh gate valve 150, an eights gate valve 155, a first studded tee 106, a gate valve 145, a tree cap 165, and a tenth gate valve 132. In some embodiments, the first section may or may not include a first spacer spool 108. The second section may include components including a studded cross 110, a first gate valve 114, a second studded tee 112, a fourth gate valve 124, a second spacer spool 118, a second gate valve 120, a third studded tee 115, a fourth studded tee 118, a ninth gate valve 160, a fourth studded tee 128, a third spacer spool 126, and a fourth gate valve 124. The connectivity of the first section and the second section components may be arranged as shown in FIG. 1.

The figures and descriptions provided herein may have been simplified to illustrate aspects that are relevant for a clear understanding of the herein described devices, systems, and methods, while eliminating, for the purpose of clarity, other aspects that may be found in typical similar devices, systems, and methods. Those of ordinary skill may recognize that other elements and/or operations may be desirable and/or necessary to implement the devices, systems, and methods described herein. But because such elements and operations are well known in the art, and because they do not facilitate a better understanding of the present disclosure, a discussion of such elements and operations may not be provided herein. However, the present disclosure is deemed to inherently include all such elements, variations, and modifications to the described aspects that would be known to those of ordinary skill in the art.

The terminology used herein is for the purpose of describing particular example embodiments only and is not intended to be limiting. For example, as used herein, the singular forms “a”, “an” and “the” may be intended to include the plural forms as well, unless the context clearly indicates otherwise. The terms “comprises,” “comprising,” “including,” and “having,” are inclusive and therefore specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof. The method steps, processes, and operations described herein are not to be construed as necessarily requiring their performance in the particular order discussed or illustrated, unless specifically identified as an order of performance. It is also to be understood that additional or alternative steps may be employed.

Although the terms first, second, third, etc., may be used herein to describe various elements, components, regions, layers and/or sections, these elements, components, regions, layers and/or sections should not be limited by these terms. These terms may be only used to distinguish one element, component, region, layer or section from another element, component, region, layer or section. That is, terms such as “first,” “second,” and other numerical terms, when used herein, do not imply a sequence or order unless clearly indicated by the context.

Reference in the specification to “one implementation” or “an implementation” means that a particular feature, structure, or characteristic described in connection with the implementation is included in at least one implementation of the disclosure. The appearances of the phrase “in one implementation,” “in some implementations,” “in one instance,” “in some instances,” “in one case,” “in some cases,” “in one embodiment,” or “in some embodiments” in various places in the specification are not necessarily all referring to the same implementation or embodiment.

Additionally, the above descriptions of the implementations of the present disclosure have been presented for the purposes of illustration and description. It is not intended to be exhaustive or to limit the present disclosure to the precise form disclosed. Many modifications and variations are possible in light of the above teaching. It is intended that the scope of the present disclosure be limited not by this detailed description, but rather by the claims of this application. As will be understood by those familiar with the art, the present disclosure may be embodied in other specific forms without departing from the spirit or essential characteristics thereof. Accordingly, the present disclosure is intended to be illustrative, but not limiting, of the scope of the present disclosure, which is set forth in the following claims.