Showing papers on "Annulus (oil well) published in 2012"

Stage tool for wellbore cementing

Abstract: A stage tool and a method for stage cementing a wellbore annulus. The method includes: running into a wellbore toward bottom hole with a tubing string to a position in the wellbore; setting the tubing string in the wellbore to create the wellbore annulus between the tubing string and a wall of the wellbore; opening a cementing port through a side pocket structure positioned alongside the tubing string; pumping cement through the cementing port; and closing the cementing port to hold the cement in the annulus.

Methods for evaluating inflow and outflow in a subterraean wellbore

Abstract: A method for evaluating inflow or outflow in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured during static conditions or while drilling and may be further processed to compute a density of an inflow constituent in the annulus. Changes in the computed interval density with time may be used as an indicator of either an inflow event or an outflow event.

Method for combined cleaning and plugging in a well, a washing tool for directional washing in a well, and uses thereof

Abstract: Method and washing tool (24; 24') for combined cleaning of an annulus (10) in a well (2) across a longitudinal section (L1) of the well (2), and subsequent plugging of the longitudinal section (L1), wherein the method comprises the following steps: (A) conducting a perforation tool (18; 18') into a casing (8) to said longitudinal section (L1); (B) forming holes (22) in the casing (8) along the longitudinal section (L1); (C) by means of a washing tool (24; 24') conducted into the casing (8) on a tubular work string (16), pumping a washing fluid (26) through the tubular work string (16) and out into the casing (8) via the washing tool (24; 24'); (D) by means of a directional means associated with the washing tool (24; 24'), conducting the washing fluid (26) out into the annulus (10) via at least one hole (22) at a first location within the longitudinal section (L1), after which the washing fluid (26) will flow via the annulus (10) and onward into the casing (8) via at least one hole (22) formed in at least one second location within the longitudinal section (L1); (E) pumping a fluidized plugging material (50) out into the casing (8) at the longitudinal section (L1); and (F) placing the plugging material (50) in the casing (8) and in the annulus (10) along the longitudinal section (L1) so as to plug the casing (8) and the annulus (10).

Telemetry operated circulation sub

Abstract: A method of drilling a wellbore includes drilling the wellbore by injecting drilling fluid through a drill string extending into the wellbore from surface and rotating a drill bit of the drill string. The drill string further includes a circulation sub having a port closed during drilling. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The drilling fluid and cuttings (returns) flow to the surface via an annulus formed between an outer surface of the tubular string and an inner surface of the wellbore. The method further includes after drilling at least a portion of the wellbore: halting drilling; sending a wireless instruction signal from the surface to a downhole portion of the drill string by articulating the drill string, acoustic signal, or mud pulse, thereby opening the port; and injecting drilling fluid through the drill string and into the annulus via the open port.

Cement oil-based mud spacer formulation

Abstract: A spacer fluid made of a viscosity thinner, a weighting agent, an antifoaming agent, and a non-ionic surfactant in a base aqueous fluid. In some instances, the viscosity thinner is a sulfomethylated tannin, the weighting agent is barium sulfate, the antifoaming agent is a silicone, and the non-ionic surfactant is an ethoxylated alcohol. A method of treating a well bore annulus in preparation of introducing water-based cement slurry into a well bore using the spacer fluid. A method of using the spacer fluid to position a first fluid into a well bore annulus of a well bore containing a second fluid. A method for fluidly isolating at least a portion of a well bore annulus in a well bore containing an oil-based drilling fluid using water-based cement slurry and the spacer fluid.

Pressure and Flow Control in Drilling Operations

Abstract: A well drilling system includes a flow control device regulating flow from a rig pump to a drill string, the flow control device being interconnected between the pump and a standpipe manifold, and another flow control device regulating flow through a line in communication with an annulus. Flow is simultaneously permitted through the flow control devices. A method of maintaining a desired bottom hole pressure includes dividing drilling fluid flow between a line in communication with a drill string interior and a line in communication with an annulus; the flow dividing step including permitting flow through a flow control device interconnected between a pump and a standpipe manifold.

Electrical Capacitance Volume Tomography Imaging of Three-Dimensional Flow Structures and Solids Concentration Distributions in a Riser and a Bend of a Gas–Solid Circulating Fluidized Bed

Abstract: Electrical capacitance volume tomography (ECVT) is a newly developed imaging technique that can quantify three-dimensional (3D) multiphase flows in a complex, geometric flow field. In this study, the 3D phase distribution images inside a gas–solid circulating fluidized bed (CFB) are obtained using ECVT. Specifically, measurements are made at a riser section and a 90° bend-shape riser exit section of the CFB. Inside the vertical riser, a symmetric core–annulus structure with a low solids holdup in the riser center along with a high solids holdup near the riser wall is observed. The average volume solids holdup and the thickness of the annulus decrease with the superficial gas velocity. A core–annulus flow structure is formed both in the vertical and horizontal parts of the bend. The annulus structure is noncentro-symmetric in the horizontal part of the bend. The solids holdup in the annulus near the top wall area in the bend is higher than that in other locations of the annulus. At a higher superficial gas...

Method of drilling and running casing in large diameter wellbore

Abstract: A well is drilled and casing installed utilizing a casing drilling technique. A bottom hole assembly having a drill bit and a fluid diverter is secured to a string of drill pipe and installed within a casing string. Drilling fluid is pumped down the drill pipe string to cause the drill bit to rotate and drill the well while the fluid diverter is in a drilling mode position. At the total depth for the casing string, the operator moves the fluid diverter to a cementing position and pumps cement down the drill pipe and up the casing string annulus. After cementing, the operator moves the fluid diverter to a packer set position and again pumps drilling fluid down the drill string to set the packer.

Horizontal and vertical well fluid pumping system

Abstract: A pump system for producing fluids from a reservoir using a wellbore having a vertical section with a casing defining an annulus, a transitional section and a horizontal section, and a production tubing having a vertical section and a horizontal section, wherein the system includes a completion with an isolation device in the annulus near the bottom of the vertical section, a gas/liquid separator for receiving produced fluids from the horizontal section, and a vertical lift pump; a continuous flow path from the terminus of the production tubing to the vertical section; a plurality of horizontal pumps in the horizontal section, each having an intake exposed to the reservoir and an outlet in the continuous flow path. The horizontal length of the production tubing is closed to the reservoir except through the horizontal pumps. A method of producing fluids includes isolating a vertical section of a wellbore from a horizontal section; isolating the production tubing from the reservoir; pumping fluid from the reservoir adjacent a toe segment into a production tubing toe segment and towards the heel segment; and pumping fluid from the reservoir adjacent a heel segment into the production tubing heel segment and towards the vertical section, and pumping fluid up the vertical section to the surface. Also disclosed is a diaphragm pump.

Methods for evaluating cuttings density while drilling

Abstract: A method evaluating a cuttings density while drilling a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured while drilling and may be further processed to compute a cuttings density in the annulus. Moreover, changes in the computed interval density with time while drilling may be used as an indicator of a change in cuttings density.

The stress and strain states of the posterior annulus under flexion.

Abstract: STUDY DESIGN Experimental measurement of bovine caudal annulus fibrosus (AF) biaxial stress-strain states for unloaded motion segments and those loaded in flexion combined with axial compression. OBJECTIVE To measure AF biaxial stress-strain states for motion segments free of external loads and those loaded in flexion combined with axial compression. SUMMARY OF BACKGROUND DATA In vitro, cyclically loaded flexion is associated with the complete rupture of the AF in acute cases. However, currently little is known about the tissue-level stress and strain states in this damaging load configuration. METHODS Surface strains of the posterior annulus were measured, during loading of intact bovine caudal motion segments in flexion combined with axial compression, using the unloaded motion segment as a reference. Planar annulus specimens were excised from the motion segments, and the measured strains from the unloaded and flexed intact discs were applied to the excised specimens in a planar biaxial stress-strain device to determine the stress state in each condition. The annulus strain state of the flexed disc was input into a previously developed nonlinear strain energy function with additive terms that directly represent the structural features of the AF. RESULTS The AF posterior surface strain for motion segments in flexion combined with compression was -0.1087 (circumferential) and 0.1051 (axial) on average. This strain state corresponded to average biaxial stresses in the annulus of 0.046 MPa (circumferential) and 0.224 MPa (axial). The planar AF specimens contracted after sectioning, resulting in small negative strains. In the absence of external loads on a motion segment, the annulus was approximately in a state of equibiaxial tensile stress. The theoretical analysis indicated that collagen crosslinks store a greater portion of the strain energy than the matrix or collagen fibers. CONCLUSION In flexion combined with compression, the posterior AF stress state is biaxial and is much larger in the axial direction in bovine caudal discs.

Pipe system with annulus utilization and monitoring

Abstract: A system for monitoring leakage in a pipe system including a pipe, a flexible tube extending through an inside of the pipe, an end fitting assembly connecting each end of the tube to a corresponding end of the pipe which creates an annulus and a monitoring system for detecting leakage from the tube into the annulus. A method for creating multiple flow paths in an existing pipe is also provided.

Comprehensive simulation experimental device of drilling circulation system

Abstract: The invention relates to a comprehensive simulation experimental device of a drilling circulation system The comprehensive simulation experimental device of the drilling circulation system comprises a drilling liquid circulation loop, a rock debris circulation branch, an air injection branch and a data collection system The drilling liquid circulation loop is formed by an annulus testing section, a Parshall flume, a vibration screen, a liquid storage pool and a frequency changing pump The rock debris circulation branch is formed by sequentially connecting an air propeller, a rock debris collection tank, a packing tank and a screw pump through pipelines, wherein the air propeller is arranged on the vibration screen, and the screw pump is connected to the position of an inlet of the annulus testing section through a pipeline The air injection branch is formed by connecting an air storage tank and an air compressor through a pipeline, wherein the compressor is connected with a tee joint through a pipeline By means of the comprehensive simulation experimental device of the drilling circulation system, the migration rule of annulus rock debris under different hole drift angles can be observed, and radial concentration of the annulus rock debris under different hole drift angles and grain composition of the annulus rock debris in different river basins can be quantitatively measured

Multi-Zone Screened Fracturing System

Abstract: A multi-zone formation treatment assembly has sections disposed on a tubular structure in a borehole An isolation element disposed on the tubular structure that isolates a borehole annulus around the section from the other sections, and a flow valve disposed on the tubular structure is selectively operable between opened and closed conditions permitting and preventing fluid communication between the through-bore and the borehole annulus A screen disposed on the tubular structure communicates with the borehole annulus, and a closure disposed on the tubular structure at least prevents fluid communication from the through-bore to the screen A workstring of the assembly can be manipulated in the tubular structure relative to each section in the same trip to: open the flow valve, position in the through-bore relative to the open flow valve, deliver the treatment from an outlet to the section through the open flow valve, and close the flow valve

Estimating flow rates from multiple hydrocarbon reservoir layers into a production well

Abstract: There is provided a computer-implemented method for estimating flow of fluid into a production well extending into a reservoir comprising fluid, the well comprising a central tubing and an annulus surrounding the central tubing. The annulus is connected to the reservoir so as to receive fluid at one or more inflow locations. The central tubing has at least one inlet, arranged to allow fluid to flow from the annulus into the central tubing, and is located downstream of the one or more inflow locations. The production well further comprises one or more devices arranged to measure a temperature of fluid within the annulus at a plurality of points along the length of the annulus. The method comprises: receiving temperature data from the one or more devices indicative of a temperature of fluid at a plurality of points along the length of the annulus; identifying a change in temperature of fluid flowing within the annulus on the basis of the received temperature data at the plurality of points; using a model to estimate heat transfer from the central tubing to fluid flowing within the annulus, said model being configured such that the heat transfer is assumed to be substantially constant along the length of the tubing; and estimating a rate at which fluid flows into the annulus from the reservoir at a first inflow location on the basis of the identified change in temperature between the points and the estimated heat transfer.

Pressure balanced valve

Abstract: The disclosed embodiments include a pressure balance valve that solves one or more problems associated with existing designs. For example, in one embodiment, a pressure balancing valve assembly is disclosed that provides a low cost frictionless assembly that is constructed to not seal the leak path between an inlet port and an outlet port. Instead, this leak path is minimized with small angle tapered plunger and a precision bored annulus to provide a defined area for the pressure drop to occur and to limit the flow from the inlet to the outlet.

Turbine stage for a turbomachine

Abstract: Turbine stage for a turbomachine comprising a guide vanes assembly (112) and an impeller mounted inside a segmented annulus (118) worn by a casing (114), the guide vanes assembly being attached to the casing and held axially in the downstream direction by resting against an annular ring (136), the annulus segments comprising, at each of their upstream ends, a member (144) of C-shaped cross section which is fitted over the casing rail and holds the ring radially in position, characterized in that the radially internal wall (148) of the C-shaped member of each annulus segment extends on the inside of the ring over the entire axial dimension thereof and its upstream end part fits into at least one recess (160, 162) of the guide vanes assembly.

Methods of isolating annular areas formed by multiple casing strings in a well

Abstract: A method of isolating annular areas formed by multiple well casings can include providing fluid communication through a wall of one of the casings at a location where another one of the casings outwardly surrounds the first casing, then flowing a cement into an annulus formed radially between the first and second casings, then providing fluid communication through the wall of the first casing and a wall of the second casing, and then flowing another cement into another annulus external to the second casing. A method of abandoning a well can include perforating a casing at a location where another casing outwardly surrounds the first casing, flowing a cement into an annulus formed radially between the first and second casings, the cement including a tracer, perforating the first and second casings, and flowing another cement into another annulus external to the second casing, the second cement including a second tracer.

Preemptive setpoint pressure offset for flow diversion in drilling operations

Abstract: A method of controlling pressure in a well can include transmitting an instruction to change flow through an annulus formed radially between a drill string and a wellbore, and adjusting a pressure setpoint in response to the transmitting. A well drilling system can include a flow control device which varies flow through a drill string, and a control system which changes a pressure setpoint in response to an instruction for the flow control device to change the flow through the drill string. A method of controlling pressure in a well can include transmitting an instruction to divert flow from a drill string, and adjusting a pressure setpoint in response to the transmitting.

Method for automatic pressure control during drilling including correction for drill string movement

Abstract: A method for determining annulus/wellbore fluid pressure, which is corrected for movement of a pipe string into or out of a wellbore, includes determining an initial annulus fluid pressure in the wellbore. Determining the initial annulus fluid pressure may include measuring a fluid flow rate into the wellbore and/or measuring a fluid pressure in the annulus proximate the surface. A rate of movement of a pipe string into or out of the wellbore is also determined. The initial annulus fluid pressure is adjusted to a corrected annulus fluid pressure by an amount which is a function of the rate of motion of the pipe string, a surface area of the outer wall of the pipe string and a surface area of the inner wall of the wellbore.

System and method for monitoring a subsea well

Abstract: A system for monitoring a subsea well is presented. The system includes the subsea well, where the subsea well includes a production tube, an annulus A co-axial to the production tube and positioned exterior to the production tube, an annulus B co-axial to the annulus A and positioned exterior to the annulus A, and a casing wall disposed between the annulus A and annulus B. Furthermore, the system includes a first sensor disposed on or about the production tube, the annulus A, the casing wall, or combinations thereof and configured to measure a first parameter. The system also includes a controller coupled to the subsea well and configured to analyze the first parameter measured by the first sensor and detect an anomaly in one or more components of the subsea well. Methods and non-transitory computer readable medium configured to perform the method for monitoring a subsea well are also presented.

Device and method for controlling return flow from a bore hole

Abstract: There is provided a device and method for control of return flow from a borehole (18) where drill fluid is supplied from a surface rig (16) via a multi section drill string (4) to a bottom hole assembly (18), the drill pipe sections (6) having tool joints (8) that include an enlarged outer diameter portion (9), and where an annulus (12) is formed between a pipe (2) and the drill string (4), and where the annulus (12) is in fluid communication with or forms part of a return path (40) for the drill fluid, and where a choke (1) is positioned in the annulus (12), and where the length (L) of the choke (1) exceeds the distance (M) between the enlarged outer diameter portion (9) of two adjacent tool joints (8).

Downhole diverter gas separator

Abstract: An oil and gas well downhole gas separator defines an outer annulus between the well casing and a separator tube having a lower end fluid inlet, and an inner annulus with a fluid conduit disposed inside. An inlet fitting and an outlet manifold route the fluids, liquids, and gases through a gravity separation sequence. A liquid outlet at the upper end is coupled to a downhole pump. A draw tube is coupled to the inlet fitting at the lower end. The draw tube also supports a casing flow diverter that slideably engages the well-bore casing so as to resist the movement of well fluids thereby while allowing the separator to move along a longitudinal axis of the well-bore casing, facilitating insertion into and removal from the well casing, and allowing for well tubing stretch during operation.

Systems and methods for co-production of geothermal energy and fluids

Abstract: Systems include a well having a production casing and a production tubing positioned therein, forming an annulus there between. A packer is positioned in the annulus at a position sufficient to separate the annulus into a first portion and a second portion. The well further includes a tie-back conduit positioned in the first portion of the annulus and configured to allow heat transfer between a working fluid flowing through the first portion of the annulus and a production fluid flowing through the production tubing, thus separating the circulating working fluid from fluids in the second portion of the annulus. A working fluid loop is fluidly connected to the first portion of the annulus. Co-production methods, methods of modeling, and computer-readable media including the methods of modeling are disclosed.