10 components of wellhead

casing spools

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casing hangers

choke manifold

packoffs (isolation) seals

test plugs

mudline suspension systems

tubing heads

tubing hangers

tubing head adapter

oilfield christmas tree and wellhead components    

The oilfield christmas tree is an assembly of valves and accessories, used for fluid control of oil and gas wells, and provides access to the production tubing string. It includes all the equipment on the upper flange of the tubing head. The oilfield christmas tree assembly can be used in many different combinations to meet the needs of any special purpose. According to different functions, the oilfield christmas tree is divided into special wellhead devices for oil production (self-injection, artificial lift), gas production (natural gas and various acid gases), water injection, thermal production, fracturing, acidification, etc. And form series according to different pressure levels.    oilfield christmas tree and wellhead components are mainly used for gas production and gas injection. Because the relative density of natural gas is low, the pressure of gas injection is low, regardless of whether the gas production or gas injection wellhead pressure is high, the flow rate is high, and it is easy to leak. Sometimes there are corrosive media such as H2S and CO2 in the natural gas, which is harmful to the tree. Tightness and its material must have stricter requirements. Sometimes for safety, double valves are used for oil and casing. For some high-pressure and ultra-high-pressure gas wells, the valves are integrally forged with high-quality steel.     The main pressure-bearing parts of the company’s Christmas tree and tubing head cross are made of forgings or specially smelted castings, so they have the characteristics of high pressure bearing, safety and reliability. 

Function

1. It is the base of the oilfield christmas tree. ⒉Hanging and fixing the oil pipe hanger. 3. Pack the casing annular space. 4. It is the casing operation window. 5. Provide a control channel for the downhole safety valve and a penetration channel for the electric pump cable.

10 wellhead components

The casing head is a kind of part connecting casings and wellheads. It provides a transition joint for the tubing head.Christmas tree and other wellheads.Both top and bottom connections are API 6A flanged, and the flanges are provided with locking bolts.  Casing Heads have a straight bore bowl with 45 C landing shoulder design which avoids damage to sealing areas by drilling tools and prevents test plug and bowl protector wedging problems when pressure is applied.  Casing Heads are normally furnished with threaded outlets and studded outlets are available upon request. Bottom connections can be furnished threaded or slip-on for welding.

casing spools feature a versatile straight bore design that can accept a wide variety of slip and mandrel type casing hangers, minimizes risk of damage to sealing areas by drilling tools, and prevents test-plug and bow-protector wedging problems when pressure is applied.

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Casing hanger is used for supporting the casing loads, and sealing the annular space between casing and tubing

Throttle and killing manifold is indispensable well control equipment for implementing the new process of
balanced drilling.

test plugs

Choose from our selection of expansion plugs, inflatable plugs, expansion plugs for tubing, and more. In stock and ready to ship.

Tubing head is an equipment attached to the casing spool used to hang the tubing and seal the annulus between the tubing and casing, consisting of tubing head spool and tubing hanger.

tubing hangers

Casing hanger is used for supporting the casing loads, and sealing the annular space between casing and tubing

Drilling spool and adapter flange can be designed with different combination and dimensions according to the
different users' needs, meeting the scene operation to a great extent.

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1. Introduction

2,3,

So far, acid gas reinjection flooding has been widely used in North American oilfields. Acid gas flooding has become an efficient means of achieving a double gain in economic development and environmental protection. For one thing, acid gases bring the greenhouse effect, acid rain, and environmental damage if they are directly discharged into the atmosphere. Another thing is the acid gases corrode pipelines and equipment, leading to the cost of acid gas treatment being extremely high. However, acid gas is injected directly into the formation, which can avoid greenhouse gases and reduce the cost of the purification plant [ 1 4 ]. In addition, sour gas is an effective displacement agent that can bring crude oil into the formation to the production well. In spite of all this, some problems remain to be solved in acid gas reinjection floods, in particular in the selection of oil and gas well materials.

2 and H2S [6,2-H2S environment [9,10,13,14,3 formation was encouraged at high pH and 120 °C, while FeS structures were dominant at 90 °C [2S. Without H2S, a stable and denser film of FeCO3 was created. With H2S, the FeS film decreased the corrosive effect of CO2 and delayed the precipitation of FeCO3 [2-H2S environment. Cr(OH)3 and FeS were competitively deposited on the surface of 3Cr steel. The FeS preferentially accumulates to form the inner layer and inhibit precipitation of Cr(OH)3, whereas Cr(OH)3 deposits away from the surface to form the outer layer [2 and H2S corrode tubing in such severe environments. Therefore, it is necessary to test the corrosion of tubing in such a harsh environment to understand the corrosion risk of tubing during operation.

It is crucial to inject acid gas into training safely because of the high corrosivity of COand HS [ 5 7 ]. Researchers have also conducted thorough research on the corrosion of steel in the CO-HS environment [ 8 11 ] and proposed lots of corrosion mechanism models [ 12 15 ]. Santos et al. noted that FeCOformation was encouraged at high pH and 120 °C, while FeS structures were dominant at 90 °C [ 16 ]. Souza et al. also observed that protective corrosion conditions were reached at 120 °C with and without HS. Without HS, a stable and denser film of FeCOwas created. With HS, the FeS film decreased the corrosive effect of COand delayed the precipitation of FeCO 17 ]. Dong et al. explained the process of producing 3Cr steel corrosion product film in the CO-HS environment. Cr(OH)and FeS were competitively deposited on the surface of 3Cr steel. The FeS preferentially accumulates to form the inner layer and inhibit precipitation of Cr(OH), whereas Cr(OH)deposits away from the surface to form the outer layer [ 18 ]. However, the tubing is faced with high temperature and high pressure and the total pressure even exceeds 50 MPa due to the fact that the acid gas is compressed in acid reinjection. Unfortunately, it is rarely reported that COand HS corrode tubing in such severe environments. Therefore, it is necessary to test the corrosion of tubing in such a harsh environment to understand the corrosion risk of tubing during operation.

2 flooding and compared corrosion inhibitors and corrosion-resistant alloys with an economic model [22,23,26,27,

In addition, the material selection of well facilities, such as a wellhead, wellbore, and packers, also needs further exploration. Dong et al. analyzed the main influencing factors of tubing corrosion in COflooding and compared corrosion inhibitors and corrosion-resistant alloys with an economic model [ 19 ]. Moreover, they also analyzed the failure of the acid gas wells and selected suitable materials for these gas wells [ 20 ]. Although many scholars have put forward different anti-corrosion measures for different environments [ 21 24 ], acid gas reinjection flooding still lacks corresponding anti-corrosion scheme. Due to the service, the environment is extremely severe, and only suitable materials should be selected to be tubing [ 25 28 ]. Oilfield companies try to use alloy steel as tubing to reduce the risk of corrosion, but it is difficult to effectively control the production cost of tubing [ 29 30 ]. What is more, it is necessary to reduce the cost of casing materials through wellbore design. It is the most important route to reduce the cost of tubing through reasonable wellbore design. Unfortunately, there is still a lack of relevant literature to integrate wellbore design methods and material selection.

In order to ensure the safe implementation of acid reinjection flooding, it is necessary to select appropriate materials for wellhead, wellbore, and downhole tools, combined with wellbore design, to form the best material selection scheme. In this paper, firstly, a trace of the literature is investigated to determine the steel used for wellhead, wellbore, and packer in an acid environment. Then, a weight-loss test is used to simulate the acid reinjection flooding environment for evaluating the steel corrosion, and surface characterization techniques are carried out to understand the corrosion risk in the production process. According to the residual tensile strength and internal pressure strength, the corrosion life of tubing is predicted, combing the economic model to calculate the cost of tubing. A new design scheme of a downhole string is proposed to control the cost of oil well string. Finally, the materials suitable for the wellhead, wellbore, and packer of reinjection acid gas drive wells are selected, and a new method of combining wellbore and materials is designed, which is beneficial to reducing costs.

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