Abstract: A landscaping marking system comprising a plurality of individually selectively actuated pop up visible markers mounted adjacent subterranean features of interest, wherein each marker includes pop-up visible components moveable between a popped up deployed visible position and a stored non-visible position and that may be reset to the stored non-visible position; and a controller for selectively actuating each marker.

Abstract: A method for monitoring the production from different zones/sections along a well bore in a subsurface reservoir to draw inferences regarding production gases emerging from the subsurface reservoir, comprising: dividing the reservoir into a plurality of different zones/sections along the well bore; in a completion stage, deploying along the well bore in each such zone/section a release system for the release of at least one oil and/or water tracer material, such that a unique tracer formulation is provided in association with each respective such zone section; in a production stage, producing fluid from the reservoir, separating, sampling and testing liquids from the produced fluid and detecting the tracer materials in the produced liquids, drawing inferences from the detected levels of the tracer materials in the produced liquids regarding the production gases emerging from the subsurface reservoir.

Abstract: The present disclosure describes depth correlation tools and associated methods which do not require wireline depth correlation runs.

Abstract: A method includes deploying a downhole tool within a wellbore. While the downhole tool is within the wellbore, the method also includes slotting or perforating a casing of the wellbore at the target interval to expose formation surrounding the wellbore. Further, the method includes flushing the target interval to remove wellbore debris from the target interval. Furthermore, the method includes pacing a cement or sealant plug at the target interval.

Abstract: Systems, methods, and computer-readable medium for generating a three-dimensional fracture network model are provided. The method can include receiving reflected acoustic signal measurements acquired in response to emission of acoustic waves by one or more sensors disposed in a wellbore formed within a target region. Each reflected acoustic signal measurement represents a strength of a reflected acoustic wave as a function of time measured in at least one predetermined direction oriented with respect to an axis of the wellbore. A fracture extension estimate is generated for each of the reflected acoustic signal measurements. A three-dimensional fracture network model is generated corresponding to the fracture extension estimates generated for each of the plurality of reflected acoustic measurements. The generated fracture network model is output for display or use in modeling environments.

Abstract: A detector assembly of a logging tool for disposal within a wellbore penetrating a subterranean formation and comprising: a radiation detector disposed within a pressure housing including a window section and a remaining section, the window section including a window that provides a path for radiation from outside the pressure housing to the detector, wherein the window section and the remaining section of the pressure housing form a unitary, integral structure (i) providing no space between the window section and the remaining section of the pressure housing for an influx of fluid from the wellbore between the window section and the remaining section of the pressure housing, (ii) providing a fluid impermeable structural connection between the window section and the remaining section of the pressure housing, (iii) providing a monolithic structural interface between the window section and the remaining section of the pressure housing, or (iv) combinations thereof.

Abstract: Methods, systems, and computer-readable medium to perform operations including obtaining data identifying a time-lapse average pressure for each well of a plurality of wells of a reservoir; determining a plurality of homogenous trends of the data; clustering the data into a plurality of groups based on the homogenous trends, each group corresponding to a respective trend; and generating a connected reservoir region map that includes a plurality of connected reservoir regions (CRR) that each correspond to a group of the plurality of groups, each CRR includes a subset of the plurality of wells that corresponds to the respective group of the CRR, wherein each CRR is associated with a homogeneous pressure response.

Abstract: Proppant compositions for use in hydraulic fracturing and methods of using same are disclosed herein. The proppant compositions include a plurality of proppant particulates and at least one particulate of the plurality of proppant particulates containing at least one tracer, wherein the at least one tracer separates from the at least one particulate located inside a fracture of a subterranean formation after a period of time.

Abstract: A method of plugging a well in a plug and abandonment procedure includes providing a tubing in a wellbore, in a location for a well plug, the tubing is provided with an internal cable section placed inside of the tubing, and forming a plug in the well in said location for the well plug across the width of the tubing and a surrounding wellbore annulus to create a permanent barrier without pulling the tubing from the wellbore. The step of forming the plug includes substantially removing the internal cable section inside the tubing and forming a fluid-tight seal in the tubing where the internal cable section has been removed, for separating, on either side of the seal, first and second fluid volumes of the tubing.

Abstract: A communication system that is positionable in a wellbore can include a first transceiver positioned externally to a casing string. The first transceiver can be operable to detect a presence or an absence of a surface wave; determine a location of a fluid in the wellbore based on the presence or the absence of the surface wave; and transmit data indicative of the location to a second transceiver. The surface wave can include an electromagnetic wave that has a magnetic field or an electric field that is non-transverse to a direction of propagation of the surface wave. The communication system can also include the second transceiver, which can be positioned externally the casing string and operable to receive the data.

Abstract: Methods and systems for monitoring the oil to water ratio of a drilling fluid are disclosed. An example drilling fluid monitoring and handling system comprises a mud pit coupled to a fluid supply system and a fluid analysis system. The fluid supply system is coupled to the mud pit and the fluid analysis system. The fluid analysis system is coupled to the mud pit and the fluid supply system, wherein the fluid analysis system comprises a dielectric probe.

Abstract: A method for developing or maintaining a subterranean field includes: parameterizing seismic wave records for each identified seismic event to provide a parameter describing each seismic wave record used to identify each seismic event; generating a reference seismic event data base having the identified seismic events and the parameter; calculating a similarity value for new received seismic wave records with respect to each seismic event in the reference seismic event data base using the corresponding parameter to provide a plurality of similarity values; identifying a maximum similarity value from any of the similarity values in the plurality of similarity values that meets or exceeds a similarity threshold value; identifying a new seismic event at a location of the seismic event in the reference seismic event data base corresponding to the maximum similarity value; and modifying operation of subterranean field-related equipment in response to identifying the new seismic event.

Abstract: An illustrative method for estimating casing wear, including estimating, as a function of position along a casing string, a side force of a tubular string against the casing string, wherein said estimating accounts for a bending stiffness of the tubular string. The method further including determining, based at least in part on the side force, a casing string wear volume as a function of position along the casing string, and presenting the casing string wear volume to a user.

Abstract: A method for increasing efficiency in emulsion production for a steam-assisted gravity drainage (SAGD) oil well system includes generating a model of the SAGD oil well system and training the model of the SAGD oil well system utilizing historical time series data relating to one or more SAGD oil wells at one or more SAGD production sites of the SAGD oil well system. The historical time series data is obtained from a plurality of sensors in the SAGD oil well system. The method also includes determining an uncertainty of the model as a function of a control space of the model and utilizing the model to determine values for control variables associated with one or more of the SAGD production sites of the SAGD oil well system which reduce the model uncertainty while meeting one or more objectives subject to one or more constraints. The method further includes adjusting a set of controls of the SAGD oil well system based on the determined values for the control variables.

Abstract: Described herein are various embodiments of computer-implemented methods, computing systems, and program products for analyzing a flood operation on a hydrocarbon reservoir. For example, an embodiment of a computer implemented method of determining a value of injected fluid includes, for a first injection well of the hydrocarbon reservoir: receiving injection rate data for the first injection well and production rate data for at least one production well communicating with the injection well, running capacitance resistance modeling using the received data to generate an interwell connectivity for each injection well and production well pair, determining a value of injected fluid for each injection well and production well pair using the generated interwell connectivity for the well pair and an oil-cut value for the production well of the pair, and aggregating the generated values of injected fluid per pair to determine a value of injected fluid for the first injection well.

Abstract: A radio frequency antenna for radiating electromagnetic energy into a reservoir filled with a target material, the antenna being operatively connected to a feed transmission line. The antenna includes a waveguide, at least one slot formed in the outer waveguide layer, and a sleeve portion enclosing at least a portion of the waveguide. The sleeve portion comprises at least first and second dielectric layers where the permittivity of the second dielectric layer is higher than the permittivity of the first dielectric layer and the first dielectric layer is positioned in closer proximity to the waveguide than the second dielectric layer. When the antenna is inserted into the reservoir, the input impedance of the antenna remains matched to the feed transmission line for a wide range of target materials.

Abstract: A hydrocarbon production process comprising operating a first early stage hydrocarbon production process within a first communication domain with a first well pair, and operating a second early stage hydrocarbon production process within a second communication domain with a second well pair, such that an intermediate reservoir region including stranded bitumen becomes disposed between the first and second communication domains; wherein the first early stage hydrocarbon production process includes injecting a first production-initiating fluid via a first injection well of the first well pair into a first communication domain such that hydrocarbon material is mobilized and conducted to a first production well of the first well pair, and producing the received hydrocarbon material via the first production well; and wherein the second early stage hydrocarbon production process includes injecting a second production-initiating fluid via a second injection well of the second well pair into a second communication do

Abstract: Proppant compositions for use in hydraulic fracturing and methods of using same are disclosed herein. The proppant compositions include a plurality of proppant particulates and at least one particulate of the plurality of proppant particulates containing at least one tracer, wherein the at least one tracer separates from the at least one particulate located inside a fracture of a subterranean formation after a period of time.

Abstract: The system comprises a drilling apparatus comprising a first portion (111) and a second portion (116). In certain embodiments, the first portion may comprise a bottom hole assembly (BHA) or a drill string, and the second portion may comprise a sensor extension housing. The first portion (111) has a first diameter and the second portion (116) has a second diameter that is greater than the first diameter. The system includes a sensor pair 114) disposed within the second portion and proximate to an outer radial surface of the second portion. A processor is in communication with the sensor pair. The processor determines at least one gradient measurement based, at least in part, on outputs of the sensor pair.

Abstract: A method and apparatus for directional drilling using mechanical wave detectors and a drill string having a drill bit at a drill bit end of the drill string. During an underground drilling operation in an underground formation, a mechanical wave signal is transmitted using a mechanical wave transmitter carried at the drill bit end of the drill string. The mechanical wave signal is received by an array of mechanical wave receivers at a ground surface above the underground formation. The received mechanical wave signals are processed to determine at least the location of the drill bit in the underground formation. The position and direction of travel data is communicated to a drilling control unit.

Abstract: Specific embodiments of disclosed downhole telemetry systems and methods employ time-reversal pre-equalization. One downhole telemetry system embodiment includes an acoustic transducer and a digital signal processor. The acoustic transducer transmits an acoustic signal to a distant receiver via a string of drillpipes connected by tool joints. The digital signal processor drives the acoustic transducer with an electrical signal that represents modulated digital data convolved with a time-reversed channel response. Due to the use of time-reversal pre-equalization, the received signal exhibits substantially reduced intersymbol interference.

Abstract: An objective function is disclosed that extracts the velocity error information directly in the image domain without computing common-image gathers. Because of the dimensionality of the problem, gradient-based methods (such as the conjugate-gradient algorithm) are used in the optimization procedure. In order to include the full complexity of the wavefield in the velocity estimation algorithm, a two-way (as opposed to one-way) wave operator is considered, where the imaging operator is not linearized with respect to the model parameters (as in linearized wave-equation migration velocity analysis), and the gradient of the objective function is determined using the adjoint-state method. The velocity estimation methodology is illustrated with a few synthetic examples.

Abstract: Methods and apparatus for downhole monitoring are provided by interrogating an unmodified optic fiber (102) arranged along the path of a well bore (106) to provide a distributed acoustic sensor and sampling data gathered from a plurality of contiguous sensing portions of the fiber. The sampled data is processed to determine one or more well bore parameters. The well bore parameters may comprise a well condition profile, and may be obtained in response to an acoustic stimulus.

Abstract: A method for obtaining real-time data relating to a well construction activity includes locating wellbore-lining tubing comprising at least one non-magnetic tubing section in a wellbore of a well. At least one downhole parameter is measured at a location external of the wellbore-lining tubing using at least one sensor associated with the non-magnetic tubing section. A magnetic field generating device is positioned within the non-magnetic tubing section and the device is activated to inductively couple the device to the at least one sensor. Data relating to the at least measured parameter is then transmitted through the non-magnetic tubing section to the magnetic field generating device by means of the inductive coupling. The data retrieved from the at least one sensor may then be transmitted to surface using a fluid pressure pulse generating device associated with the magnetic field generating device.

Abstract: Various embodiments include apparatus and methods to conduct testing related to the disposition of measuring tools downhole in a borehole, where the measuring tools are deployed to perform testing to evaluate properties of regions in the borehole. A plurality of test analyses on data collected from operating a measuring device of a measuring tool in the borehole can be used to determine whether the measuring device is in casing or out of casing. Additional apparatus, systems, and methods are disclosed.

Abstract: An apparatus disclosed herein includes a downhole tool having a body defining an interior bore and an exterior surface. The example apparatus also includes first and second fluid ports to provide respective fluid paths between the exterior surface and the interior bore. The first fluid port is to receive wellbore fluid from an annulus of a wellbore in which the downhole tool is to be disposed and the second fluid port is to receive formation fluid extracted from a subterranean formation. The formation fluid is to mix with the wellbore fluid to form an output mixture in the interior bore. The example apparatus also includes a controller to control a concentration of the formation fluid in the output mixture.

Abstract: In one aspect, a method of performing a wellbore operation is disclosed that in one embodiment may include: deploying a device in the wellbore containing a conductive fluid, wherein the device is configured to disintegrate upon application of electrical current thereto; and applying current to the device in the wellbore using a tool to controllably disintegrate the device. In another aspect, an apparatus for use downhole is provided that in one embodiment may include a device placed at a selected location in a wellbore, wherein the device is made from a material that disintegrates when electric current is induced in to device and a tool placed proximate to the device configured to induce electric current into the device to cause the device to disintegrate.

Abstract: A method includes lowering a downhole tool via a pipe into a wellbore drilled through a formation via the pipe and establishing a fluid communication between the downhole tool and the formation at a location in the wellbore. The method also includes extracting from the formation a first fluid stream through the fluid communication and passing the first fluid stream through the downhole tool for a first duration. The method further includes breaking the fluid communication between the downhole tool and the formation, moving the pipe in the wellbore, and reestablishing the fluid communication between the downhole tool and the formation essentially at the location in the wellbore subsequent to moving the pipe in the wellbore.

Abstract: A method and apparatus configured to perform an interference test while drilling, including the steps of computing a pressure history response at a monitoring well from a pulsing of a well remote to the monitoring well, determining a time interval and a location for conducting a pressure test along a monitoring well trajectory based on the computing of the pressure history response, initiating a pulsing of the well remote to the monitoring well, determining whether pressure data should be taken at the monitoring well, estimating a near wellbore pressure effect at the monitoring well if the pressure data is taken, adjusting a mud circulation flow rate in the monitoring well if the pressure data is taken, and measuring at least one pressure value at the monitoring well if the pressure data is taken.

Abstract: The invention relates to a device for determining the depth and orientation of a feature in a wellbore, and to a corresponding method. It also relates to a downhole apparatus for performing an operation in a well comprising a device for determining the depth and orientation of a feature in a wellbore and a device for performing the operation. In an embodiment, a downhole device (42) for determining the depth and orientation of a feature (24, 26, 28) in a wellbore (12) containing a ferrous tubing (14) is disclosed, the device comprising: at least one magnetic field sensor (44) for monitoring the inherent magnetic field of the ferrous tubing so that the presence of the feature can be detected; and at least one orientation sensor (48) for determining the orientation of the device within the wellbore.

Abstract: In one example of a rotationally independent wellbore ranging system, a housing attached to a rotary component is positioned in a first wellbore and remains substantially stationary relative to the first wellbore when the rotary component rotates in the first wellbore. Multiple sensors affixed to the housing are operable to receive multiple ranging signals from a second wellbore while the rotary component rotates in the first wellbore, and provide the multiple ranging signals to a processor to determine a position of the first wellbore relative to the second wellbore.

Abstract: Embodiments of a bottomhole assembly BHA for completion of a wellbore are deployed on electrically-enabled coiled tubing (CT) and permit components of the BHA to be independently electrically actuated from surface for completion of multiple zones in a single trip using a single BHA having at least two electrically-actuated variable diameter packers. One or both of the packers may be actuated to expand or retract for opening and closing off a variety of flowpaths between the BHA and the wellbore, in new wellbores, old wellbores, cased wellbores, wellbores with sleeves and in openhole wellbores. Additional components in the BHA, which may also be electrically-actuated or powered, permit perforating, locating of the BHA in the wellbore such as using casing collar locators and microseismic monitoring in real time or in memory mode.

Abstract: A method for determining along a length of a wellbore situated in an underground hydrocarbon-containing formation, regions within the formation where injection of a fluid at a pressure above formation dilation pressure may be advantageous in stimulating production of oil into the wellbore. An initial information-gathering procedure is conducted prior to formation dilation/fracturing, wherein fluid is supplied under a pressure less than formation dilation or fracture pressure, to discrete intervals along the wellbore, and sensors measure and data is recorded regarding the ease of penetration of such fluid into the various regions of the formation. Regions of the formation exhibiting poor ease of fluid penetration or regions of higher oil saturation, are thereafter selected for subsequent stimulation or dilation, at pressures above formation dilation pressures. Where initial fluid pressures and/or formation dilation pressures are provided in cyclic pulses, as novel downhole tool is disclosed for such purpose.

Abstract: A coaxial ground heat exchanger and installation method are disclosed where the heat exchanger has a central core tube that can be provided with a thermally insulating casing and an outer tube that delimits an annular gap which extends radially outwards from the core tube. The core tube and the annular gap can be configured such that a flowable heat transfer medium can flow through. The outer tube is formed by a tubular expandable cover that directly adjoins a wall of a ground heat exchanger borehole when the heat exchanger is installed.

Abstract: Provided are a system and method for identifying planned markers while drilling a borehole. In one example, the method includes obtaining a plan containing planned markers that each corresponds to a baseline marker from an existing well. Each of the baseline markers corresponds to a waveform from a log file obtained from the existing well and is associated with a waveform representation of the corresponding waveform. Each of the planned markers is associated with an estimated true vertical depth (TVD) value. A second log file corresponding to the borehole is obtained that contains waveforms representing formation information detected within the borehole. The second log file is scanned for a planned marker based on the estimated TVD value and the waveform representation of the baseline marker corresponding to the planned marker. At least one match may be identified and reported for the planned marker.

Abstract: Systems and methods for optimal positioning of drilling pads for horizontal well field development considering the location and spacing of each horizontal well, boundaries and surface/subsurface hazards.

Abstract: According to aspects of the present disclosure, a magnetic ranging system is described herein. The magnetic ranging system may comprise a downhole apparatus tool (350) that is sized to couple to a drill string (375). The downhole apparatus (350) may be included, for example, near-bit within the bottom assembly (BHA). A transmitter (302) and a receiver (304) may be coupled to the downhole apparatus (350). The system may also comprise a power management system (308) coupled to the downhole apparatus (350). In certain embodiments, the power management system (308) may selectively provide power to the transmitter (302) from a first power source (316) or a second power source (318) based, at least in part, on an estimated distance to a target well.

Abstract: Systems and methods for accessing and/or harvesting hydrocarbons from a wellbore. A method may include modeling a well to determine a length of a stimulation zone in the production interval, wherein the model is based, at least in part, on a reaction time for a stimulation process. Packers are placed in the well to fluidically isolate the stimulation zone from other zones in the well. The targeted zone is stimulated, such as by acid treatment. Hydrocarbons may be recovered from the stimulation zone.

Abstract: A downhole tools deployment apparatus is disclosed. In an embodiment, the apparatus includes at least an in-ground well casing, a housing providing a hermetically sealed electronics compartment, a tool attachment portion, and a first flow through core. The housing is preferably configured for sliding communication with the well casing. The hermetically sealed electronics compartment secures a processor and a location sensing system, which communicates with the processor while interacting exclusively with features of the well casing to determine the location of the housing within the well casing. The embodiment further includes a well plug affixed to the tool attachment portion, the well plug includes a second flow through core capped with a core plug with a core plug release mechanism, which upon activation provides separation between the second flow through core and the core plug, allowing material to flow through said first and second flow through cores.

Abstract: The methods described are for determining distribution, orientation and dimensions of networks of hydraulically-induced fractures within a subterranean formation containing fluids. Micro-seismic events are generated, after cessation of fracturing and establishment of fracture networks, by particles introduced into the fractures which are capable of explosive or chemical reaction. In one method, attachment site particles are positioned within the formation during fracturing and additional reactive particles are later introduced. The reactive particles attach to the attachment sites and, upon a triggering event, react to produce micro-seismic events. The waves generated by the micro-seismic events are used to provide mapping of the effective fracture space. Additionally, time-lapse mapping is provided with use of “species” of attachment sites and reactive particles.

Abstract: A method of estimating fractures in an earth formation includes: disposing an acoustic tool in a cased borehole in an earth formation, the acoustic tool including a multipole acoustic transmitter and an acoustic receiver; transmitting an acoustic signal into the borehole; measuring deep shear wave (DSW) signals generated from shear body waves reflected in the formation in a far-field region of the formation around the borehole; and estimating at least a location and an orientation of a fracture in the formation based on the DSW signals.

Abstract: Electrically conductive proppants and methods for detecting, locating, and characterizing same are provided. The electrically conductive proppant can include a substantially uniform coating of an electrically conductive material having a thickness of at least 500 nm. The method can include injecting a hydraulic fluid into a wellbore extending into a subterranean formation at a rate and pressure sufficient to open a fracture therein, injecting into the fracture a fluid containing the electrically conductive proppant, electrically energizing the earth at or near the fracture, and measuring three dimensional (x, y, and z) components of electric and magnetic field responses at a surface of the earth or in an adjacent wellbore.

Abstract: A method may include forming a borehole in a subterranean formation, lining at least part of the borehole with an electrically conductive casing, and injecting a fracturing fluid, a proppant, and a sensing additive into the borehole to form a propped fracture pattern. The method may further include driving the electrically conductive casing so that the sensing additive generates an electromagnetic (EM) field, sensing the EM field, and mapping the propped fracture pattern based upon the sensed EM field.

Abstract: The present invention relates to a production system (1) for producing hydrocarbons from a well (2).

Abstract: An electrically conductive proppant coating and a method for applying the coating to the proppant, whereby the coated electrically conductive proppant can determine formation characteristics, such as dimensions, orientation, and conductivity.

Abstract: Techniques for recovering hydrocarbons, such as heavy hydrocarbons or bitumen, from a cellar region below a horizontal production well can include providing a cellar well section that extends from the horizontal production well into the cellar region. The horizontal production well can be part of a Steam-Assisted Gravity Drainage (SAGD) in situ recovery system, which forms a hydrocarbon depleted region and a hydrocarbon bearing cellar region. The cellar region includes hydrocarbons that have been pre-heated by SAGD operations. One or more cellar well sections are provided from the SAGD production well to extend into the cellar region, in order to form a branched production well. A pressurizing gas can be injected into the hydrocarbon depleted region from a SAGD injection well, in order to provide sufficient pressure to promote production of pre-heated hydrocarbons from the cellar region through the cellar well section.

Abstract: Provided are a system and method for identifying planned markers while drilling a borehole. In one example, the method includes obtaining a plan containing planned markers that each corresponds to a baseline marker from an existing well. Each of the baseline markers corresponds to a waveform from a log file obtained from the existing well and is associated with a waveform representation of the corresponding waveform. Each of the planned markers is associated with an estimated true vertical depth (TVD) value. A second log file corresponding to the borehole is obtained that contains waveforms representing formation information detected within the borehole. The second log file is scanned for a planned marker based on the estimated TVD value and the waveform representation of the baseline marker corresponding to the planned marker. At least one match may be identified and reported for the planned marker.

Abstract: Methods and related systems are described for measuring and analyzing refracted acoustic energy. A plurality of receivers mounted are on a downhole tool, and are arranged and adapted to receive refracted acoustic energy from a downhole formation. Measurements of refracted acoustic energy is analyzed such that information relating to an azimuthal direction relative to the downhole tool of an interface within the downhole formation can be estimated. The receivers can be mounted on a drill collar as part of a LWD tool and steering of the drilling trajectory can be based in part on the estimated formation information.

Abstract: Methods and related systems are described for use for determining orientation of a measurement tool in a cased borehole. The measurement tool is deployed in a cased section of a borehole. The tool includes a volume containing a reference fluid having a first density, and a marker within the fluid having a different density. The position of the marker within volume containing the reference fluid is senses, and orientation information of the measurement tool is determined based at least in part on combining information relating to the position of the marker with prior recorded data representing orientation measurements made while the section of the borehole was not yet cased.

Abstract: Systems and methods of detecting an intersection between a wellbore and a subterranean structure that includes a marker material. The systems and methods include drilling the wellbore and determining that the wellbore has intersected a portion of the subterranean structure that includes the marker material by detecting the marker material. The systems and methods also may include distributing the marker material within the subterranean structure, aligning the marker material within the subterranean structure, determining one or more characteristics of the marker material, ceasing the drilling, repeating the method, and/or producing a hydrocarbon from the subterranean structure. The systems and methods further may include forming an electrical connection between an electric current source and a granular resistive heater that forms a portion of the subterranean structure, forming the granular resistive heater, and/or forming the subterranean structure.