Abstract: Examples described herein provide a method that includes performing a geomechanical analysis for a wellbore for each of a plurality of sand screens. The method further includes selecting a sand screen from the plurality of sand screens based at least in part on the geomechanical analysis. The method further includes deploying the selected sand screen in a tubular of the wellbore to filter particulate passing through an opening of the tubular.

Abstract: A method is offered to predict and prevent the event of fracture hit (direct fluid communication) between a parent well and a child (active) well. The growth of a child well creates 3D stress field in the vicinity of a parent well. The growth of a child well is simulated using the geomechanic-transport model. A model of interaction between the child well and parent well is provided. The simulations for different job designs create a set of pressure scenario in the parent both for the cases with and without fracture hit (fracture hit catalogue). Comparison (matching) of actual pressure data in the parent and child well with the pre-calculated pressure scenarios indicate the risk of fracture development with a fracture hit, which means a stop in fracturing stimulation.

Abstract: A method for determining change in stress in a reservoir formation includes inducing a pressure pulse in a first well hydraulically connected by a fracture to the reservoir formation. A stress-related attribute of the fracture is determined from reflection events detected in pressure measurement made in the first well as a result of the inducing the pressure pulse. The inducing and determining are repeated to estimate changes in the stress-related attribute with respect to time. A method for determining and localizing type of interaction between a treated well and an observation well by monitoring pressure and fracture changes in the observation well.

Abstract: Hydrocarbon wells include a wellbore, a fracture that extends from the wellbore, and an electromagnetic contrast material positioned within the fracture. The hydrocarbon wells also include a downhole electromagnetic transmitter, which is configured to direct an electromagnetic probe signal incident upon the electromagnetic contrast material, and a downhole electromagnetic receiver, which is configured to receive an electromagnetic resultant signal from the electromagnetic contrast material. Methods for monitoring fracture morphology of a fracture that extends from a wellbore of a hydrocarbon well include flowing an electromagnetic contrast material into a fracture and generating an electromagnetic probe signal. The methods also include modifying the electromagnetic probe signal with the electromagnetic contrast material to generate an electromagnetic resultant signal. The methods further include receiving the electromagnetic resultant signal and determining the morphology of the fracture.

Abstract: Closed loop wellbore configurations with unrestricted geometry for accommodating irregular or challenging thermal gradients within a thermally productive formation are disclosed. A working fluid is utilized in the loop for extraction of thermal energy there from. The loop and the unrestricted geometry are achieved using magnetic ranging of independent drilling operations which intersect from an inlet well and outlet well to form an interconnecting segment. In conjunction with the directional drilling, conditioning operations are incorporated to condition the rock face, cool the entire system, activate the wellbore for treatment to optimize thermal transfer inter alia. The significant degree of freedom in wellbore configuration is further optimized by the absence of mechanical impediments such as casing or liners in the heat transfer areas.

Abstract: Aspects of the subject technology relate to systems and methods for optimizing multi-unit pumping operations at a well site. Systems and methods are provided for receiving sensor data from a hydraulic fracturing fleet equipment at an equipment system, designating an event as being flagged based on the sensor data from the hydraulic fracturing fleet equipment, determining a physical action based on the flagged event and a priority list of actions, and providing instructions to a first pump of the hydraulic fracturing fleet equipment to perform the physical action based on the flagged event and the priority list of actions.

Abstract: The present disclosure relates to material for use in oil and gas well completion activities. More particularly, the present disclosure relates to diversion particles, along with methods for making and using the diversion particles. In an embodiment, a composite diversion material includes a non-degradable component comprising two or more non-degradable particulates, wherein the non-degradable particulates have a long term permeability at 7,500 psi of at least about 20 D. The composite diversion material includes a degradable component surrounding at least a portion of the non-degradable component. In another embodiment, a method of making a composite diversion material includes mixing non-degradable proppant particles with an aqueous solution containing a first degradable material to provide a mixture having a proppant concentration of at least about 20 volume percent. The method includes drying the mixture at a temperature of from about 25° C. to about 200° C. to provide the composite diversion material.

Abstract: Systems and methods provide for the reduction of motion at a ground layer of a site due to a seismic event. A predicted seismic motion is obtained for a geological layer at depth and properties of the layers between the ground layer and layer at depth are determined. A model is created using the layers and the predicted seismic motion. Iteratively for each layer, one or more properties of the layer is changed in the model and a site amplification is performed to determine a change or changes that result in an acceptable response at the ground layer. Subsequently, the in situ layer may be modified according to the modified property or properties to reduce motion at the site due to a seismic event.

Abstract: To estimate natural fracture properties based on production from hydraulically fractured wells, a computer system receives hydrocarbon reservoir production information associated with a naturally fractured hydrocarbon reservoir with entrapped hydrocarbons in which a wellbore has been formed to produce the hydrocarbons. The information includes a wellbore pressure measured over production time. From the wellbore pressure, the computer system determines a time rate of change of the wellbore pressure over the production time. From a plot of a logarithmic time rate of change of the wellbore pressure over logarithmic production time, the computer system identifies multiple plot sections, each representing a respective flow regime of a flow of the hydrocarbons from the reservoir.

Abstract: The invention relates to a dual detector comprising a detection head having: an inductive sensor which is mounted on the platform (11) and includes a transmitter coil (12) and a separate receiver coil (13), the transmitter coil (12) and the receiver coil (13) each forming a loop, a soil penetrating radar (60) comprising a transmitter antenna (61) and a receiver antenna (62), the transmitter antenna (61) and the receiver antenna (62) each being accommodated in the center of one of the loops of the transmitter and receiver coils (12) (13), the transmitter antenna (61) and the receiver antenna (62) having a maximum thickness (e) of one micron in order to limit interference with the inductive sensor (12).

Abstract: Methods and systems for assessing cross-well interference and/or optimizing hydrocarbon production from a reservoir by obtaining low frequency DAS and DTS data and pressure data from a monitor well, when both the monitor and production well are shut-in, and then variably opening the production well for production, and detecting the temperature and pressure fluctuations that indication cross-well interference, and localizing the interference along the well length based on the low frequency DAS data. This information can be used to optimize well placement, completion plans, fracturing plans, and ultimately optimize production from a given reservoir.

Abstract: A workflow for fracturing a subterranean formation includes providing fracturing databases or models for the hydrocarbon wellbore, selecting one or more fracturing fluid systems for fracturing the subterranean formation based on the fracturing databases or models and recommending at least one of the one or more selected fracturing fluid systems for fracturing the subterranean formation. Additionally, a workflow controller for fracturing a subterranean formation includes a workflow processing unit having fracturing models or databases to determine functional aspects of one or more fracturing fluid systems to provide a fracturing fluid system recommendation for the subterranean formation, and a fracturing fluid delivery unit that applies the fracturing fluid system recommendation to the subterranean formation. A hydrocarbon wellbore fracturing system for a subterranean formation is also provided.

Abstract: One embodiment of a wellbore to fracture connectivity apparatus comprises an opening portion representing an opening in a wellbore for receiving fluid, proppant, or any combination thereof to generate at least one fracture in a formation; a fracture portion representing the at least one fracture in the formation; and a coupling portion representing wellbore to fracture connectivity between the opening portion and the fracture portion. The coupling portion couples the opening portion and the fracture portion.

Abstract: An inexpensive electrically conductive carrier is added to well bore fluids thereby allowing for a closed loop real-time data communication system for topside management of all downhole equipment including drilling, completion, production, logging, and workover equipment. Conductive carrier fluid provides a “real-time” digital and analog bi-directional data and communication solution between the surface operations of a well-bore and downhole tools. Conductive carrier fluid provides for the application of more sophisticated software essential for exact control requirements of sophisticated downhole equipment, thereby achieving optimized tool performance as well as future downhole tools.

Abstract: A method for determining a location of a proppant in a subterranean formation includes obtaining a first set of data in a wellbore using a downhole tool. The proppant is pumped into the wellbore after the first set of data is obtained. The proppant is pumped while or after the subterranean formation is fractured. A second set of data is obtained in the wellbore using the downhole tool after the proppant is pumped into the wellbore. The first set of data and the second set of data include a gravitational field measurement. The first and second sets of data are compared, and in response to the comparison, the location of the proppant in the subterranean formation is determined.

Abstract: Embodiments of the present invention use radar technology to detect features or conditions in a well. A radar unit having an electronics subsystem and an antenna subsystem is positioned downhole in the well. The radar unit is coupled receive power from and communicate with to a surface system. The electronics subsystem generates RF signals which are provided to the antenna subsystem, generating radar wavefronts that are propagated toward areas of interest (e.g., farther downhole). The radar wavefronts may be electronically or mechanically steered in the desired direction. The antenna subsystem receives radar signals that are reflected back to the unit by features or conditions in the well. The received reflected signals are converted to electronic signals that are interpreted by the electronics subsystem of the radar unit or by the surface system to identify the features or conditions that caused the reflections.

Abstract: A well completion processing system to identify breakdown pressure, diverter events and offset pressure, in time sequenced fracture data, and use the identification of the same in the modification or adjustment of parameters associated with completion, as well as the display of information in a graphical form, such as an interface. In various examples, the processing system employs higher order channels in the processing of the same.

Abstract: An x-ray-based cement evaluation tool for determining whether a cement bond exists between the casing and cement of a cemented borehole is provided, the tool including at least: an internal length comprising a sonde section, wherein said sonde section further comprises an x-ray source; a radiation shield for radiation measuring detectors; arrayed pixelated detectors; sonde-dependent electronics; and a plurality of tool logic electronics and PSUs. A method of using an x-ray-based cement evaluation tool for measuring a cement bond between a casing and the cement of a cemented borehole is also provided, the method including: producing x-ray in a conical beam to illuminate a well casing; measurement of the returning photons as a function of radial and axial offset; remapping the intensity of returning photons to a geometric response within the casing and cement; and determining whether an annulus is present between the casing and cement.

Abstract: A method, system and apparatus of optimizing operation of one or more tubing strings in a hydrocarbon well are provided. Each tubing string is located in a hydrocarbon well and has a plurality of valves. Each valve is actuatable between a fully open position and a fully closed position and is in communication with a respective zone of a formation defining a reservoir containing hydrocarbon material. The method includes characterizing an injectivity of one or more zones of the formation and determining an optimal operating schedule in accordance with the characterization. The optimal operating schedule comprises one or more valve configurations and an operating duration for each of the one or more valve configurations.

Abstract: Use of traceable micro-electro-mechanical systems (“MEMS”) in subterranean formations. A method may comprise introducing a treatment fluid comprising a traceable micro-electro-mechanical system into a wellbore, wherein the traceable micro-electro-mechanical system comprises a micro-electro-mechanical system and a tagging material.

Abstract: Methods may include emplacing a resistivity logging tool in a borehole; stimulating an interval of the formation in the borehole; obtaining at least one resistivity log of the interval of the formation, wherein the resistivity log comprises a survey of one or more depths into the formation; determining a radial invasion of the stimulating fluid into the interval of the formation; and inverting the radial invasion to obtain an input and entering the input into an effective medium model; solving the effective medium model and generating an effective wormhole radius profile and thickness for the interval of the formation.

Abstract: Systems and methods for generating candidate designs and selecting a fracturing position design scheme for a horizontal well to be fractured based on fracturing potential are disclosed. A fracturing potential value of each designed fracturing point or each fracturing point is calculated using obtained values of various indexes of various depth points. A first corresponding relation between fracture conductivity value and the fracturing potential value and a second corresponding relation between a fracture half length and the fracturing potential value is determined. Corresponding first simulated production data for each candidate design is generated, and the candidate design with a highest predicted net present value is selected as the fracturing position design scheme which provides higher rationality and practicability to better guide development.

Abstract: A method includes acquiring data associated with a field operation of equipment in a geologic environment; filtering the data using a filter where the filter includes, along a dimension, a single maximum positive value that decreases to a single minimum negative value that increases to approximately zero; and, based on the filtering, issuing a control signal to the equipment in the geologic environment.

Abstract: Method for characterizing subterranean formation is described. One method involves simulating a poroelastic pressure response of known fracture geometry utilizing a geomechanical model to generate a simulated poroelastic pressure response. Compiling a database of simulated poroelastic pressure responses. Measuring a poroelastic pressure response of the subterranean formation during a hydraulic fracturing operation to generate a measured poroelastic pressure response. Identifying a closest simulated poroelastic pressure response in the library of simulated poroelastic pressure response. Estimating a geometrical parameter of a fracture or fractures in the subterranean formation based on the closest simulated poroelastic pressure response.

Abstract: A spoolable array of sensors may be deployed within a wellbore and external a tubular string for measuring properties of a fluid in the central flow passage of the tubular string. A flow port may be made in the tubular string passing from the central flow passage to the external surface. Sensors of the spoolable array of sensors may be covered with a shroud and placed proximate the flow port, or such sensors may be isolated in a zone with packers along with the flow port. The spoolable array of sensors may additionally obtain pressure data to calculate a flow rate from a production zone. The spoolable array of sensors may also be employed in a non-flowing wellbore for monitoring nearby wellbores.

Abstract: A system includes a processing device and a non-transitory computer-readable medium having instructions stored thereon that are executable by the processing device to cause the system to perform operations. The operations include generating and running a reservoir simulation model. The reservoir and simulation model includes representative natural fracture or secondary porosity attributes for an area of interest for one or more wells. The operations also include generating a synthetic G-function response using results of the reservoir simulation model. Additionally, the operations include calibrating the synthetic G-function response from the reservoir simulation model to a field G-function response generated using results of a field diagnostic fracture injection test by changing natural fracture characteristics of the reservoir simulation model.

Abstract: A method for the stimulation of a hydrocarbon-bearing formation, said method comprising the steps of: providing a wellbore in need of stimulation; inserting a plug in the wellbore at a location slightly beyond a predetermined location; inserting a perforating tool and a spearhead or breakdown acid into the wellbore; positioning the tool at said predetermined location; perforating the wellbore with the tool thereby creating a perforated area; allowing the spearhead acid to come into contact with the perforated area for a predetermined period of time sufficient to prepare the formation for stimulation; removing the tool form the wellbore; and initiating the stimulation of the perforated area using a stimulation fluid. Also disclosed is a corrosion inhibiting composition for use with the acid composition.

Abstract: This document relates to energetic salts that contain an organic cation and an oxidizing anion and methods of using the energetic salt compositions, including methods of hydraulic fracturing, pressure pulse fracturing, formation damage removal, and lowering the viscosity of heavy oil.

Abstract: Various embodiments of the present disclosure are directed to systems and methods for data collection using fiber-optic cable in a well, and analysis of the data to determine instantaneous frequency, instantaneous phase, instantaneous amplitude, and/or dominant frequency. These measures can be used to determine parameters associated with the operation of the well. The parameters can be used to control the operation of the well and/or the fracturing process.

Abstract: The disclosure presents a process for calibrating a diversion model for a treatment stage of a hydraulic fracturing well site. The process can pump a portion of the proppant into the wellbore, flush the wellbore with clean HF fluid, and then perform a diagnostic test to determine a near-wellbore (NWB) flow resistance parameter. Next, diverter material can be distributed into the wellbore and the amount of diverter material delivered to each active perforation cluster can be estimated. A second diagnostic test can be performed followed by computing diversion model parameters such as a near-wellbore zone length parameter for perforation clusters capable of receiving HF fluid. In another aspect, a system is disclosed that can direct operations of a well site pump and collect data from surface and downhole diagnostic sensors, and then use the collected data for the diversion model calibration process.

Abstract: A method for fracturing a formation is provided. Real-time fracturing data is acquired from a well bore during fracturing operation. The real-time fracturing data is processed using a recurrent neural network trained using historical data from analogous wells. A real-time response variable prediction is determined using the processed real-time fracturing data. Fracturing parameters for the fracturing operation are adjusted in real-time based on the real-time response variable prediction. The fracturing operation is performed using the fracturing parameters that were adjusted based on the real-time response variable prediction.

Abstract: Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations. The methods can include injecting an aqueous pressure protection composition into an unconventional subterranean formation via an existing wellbore in fluid communication with a rock matrix of the unconventional subterranean formation prior to and/or during injection of a fracturing fluid into the unconventional subterranean formation via a new wellbore in fluid communication with the rock matrix of the unconventional subterranean formation; and producing a hydrocarbon from the existing wellbore during and/or after the injection of the fracturing fluid into the unconventional subterranean formation via the new wellbore.

Abstract: A sequence of stimuli produced by an electric frac pump can be generated by a treatment optimization system. Well environment responses to the sequence of stimuli may be measured by sensors and respective sensor data may be received. The sensor data may be used to select a representative system model which can then be used to control the electric frac pump. The representative system model may be used to achieve well stage objectives such as particular cluster efficiencies, complexity factors, or proximity indices.

Abstract: A device and method for evaluating fracture initiation and propagation, and a stress sensitivity of a propped fracture is provided. The device includes a core part, a confining pressure loading part, a fracturing fluid pumping part, a stress sensitivity testing part and a fracture monitoring part. The method evaluates fracture initiation and propagation, and a stress sensitivity of a propped fracture using the above device and is reliable and simple to operate and guides optimization of construction parameters of hydraulic fracturing, thus achieving improvement in productivity of an oil and gas well.

Abstract: Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of solid surfactant composites in well cementing operations.

Abstract: The present invention discloses a method for evaluating and preventing creep damage to conductivity of hydraulic fracture in gas reservoirs, comprising: (1) selecting a rock sample of target reservoir for creep experiment, and plotting ?-t curve of the rock sample during creep; (2) fitting the fractional Kelvin model with the ?-t curve of the rock sample during creep; (3) calculating the conductivity and permeability of hydraulic fracture considering creep damage; (4) numerically solving the productivity model, calculating the cumulative gas production of the gas well produced up to time t, and calculating the creep damage rate for cumulative production of the gas well; (5) repeating Steps (3) to (4), calculating the creep damage rate for cumulative production for the cases of hydraulic fracture sanding concentration N of 5 kg/m2, 7.5 kg/m2, 10 kg/m2, 12.5 kg/m2 and 15 kg/m2 respectively, plotting the creep damage chart of cumulative production.

Abstract: A method evaluating borehole subsurface geologies can include receiving a total response signal by a sensor array disposed in a borehole, the response signal represents a pressure wave propagating in the borehole. A secondary signal can be extracted from the total response signal and a depth location for at least one secondary source that corresponds to the secondary signal is determined. An estimated reflectivity response for the secondary signal as a function of frequency is determined and the estimated reflectivity response is inverted to determine the secondary source includes at least one of a potential fracture or a potential washout. The at least one of a fracture conductivity or a washout volume for the secondary source is compared to one or more borehole images corresponding to the depth location of the secondary source to determine the potential fracture is an actual fracture or the potential washout is an actual washout.

Abstract: A data acquisition program, which includes core, image log, microseismic, DAS, DTS, and pressure data, is described. This program can be used in conjunction with a variety of techniques to accurately monitor and conduct well stimulation.

Abstract: An apparatus for detecting a position of a moveable component of a valve disposed in a borehole penetrating the earth includes a radioactive marker disposed on the moveable component and a radiation detector configured to detect radiation emitted by the radioactive marker. The apparatus also includes a controller configured to receive radiation detection information from the radiation detector and to correlate the radiation detection information to the position of the moveable component.

Abstract: An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor, a centrifugal pump mechanically coupled to the electric motor, and a probe mechanically coupled to the electric motor and extending upstream of the electric motor, comprising a plurality of sensor bundles distributed axially along the probe wherein each sensor bundle comprises at least one sensor.

Abstract: Method for characterizing subterranean formation is described. One method involves injecting a fluid into an active well of the subterranean formation at a pressure sufficient to induce one or more hydraulic fractures. Measuring, via a pressure sensor, a poroelastic pressure response caused by inducing of the one or more hydraulic fractures. The pressure sensor is in at least partial hydraulic isolation with the one or more hydraulic fractures.

Abstract: A method of assessing cross-well interference and/or optimizing hydrocarbon production from a reservoir by obtaining low frequency DAS and DTS data and pressure data from a monitor well, when both the monitor and production well are shut-in, and then variably opening the production well for production, and detecting the temperature and pressure fluctuations that indication cross-well interference, and localizing the interference along the well length based on the low frequency DAS data. This information can be used to optimize well placement, completion plans, fracturing plans, and ultimately optimize production from a given reservoir.

Abstract: Systems and methods of hydraulically fracturing subterranean formations include modifying a completion operation parameter for hydraulic fracturing a target well, the target well extending through a subterranean formation and a fracture extending from the target well as a result of the hydraulic fracturing. The modification to the completion operation is responsive to detection of a response of a monitor well extending through the subterranean formation, where the response of the monitor well resulting from interactions between the monitor well and the fracture extending from the target well.

Abstract: A perforating system and method includes a perforating gun with shaped charges and an orientation device. The orientation device provides an orientation datum. Sensors associated with the perforating gun detect relative alignment of each perforating gun as compared to the orientation datum. A detonation signal can be either sent or not sent to the perforating gun in response to the signal received from the orientation sensor.

Abstract: A method of controlling a high-pressure system having an engine, and a hydraulic pump having a swashplate includes inputting a maximum discharge pressure, a maximum allowable equipment pressure, a pressure relief valve (PRV) setting, a flowrate, and a maximum positive and negative rate of change of pressure; setting a work value to full power; setting a first position of the swashplate based on flowrate; determining: (a) if a discharge pressure is greater than the PRV setting; (b) if the discharge pressure is greater than the maximum allowable equipment pressure; and (c) if a rate of change of pressure is greater than the maximum positive rate of change of pressure or the maximum negative rate of change of pressure; and upon the occurrence of any of steps (a)-(c): (d) activating a PRV in the system; (e) setting the swashplate position to neutral; and (f) reducing the power to zero.

Abstract: A system for deploying sensors throughout a vertical section and a horizontal section of an unconventional well comprises a mandrel comprising a set of extendable arms; a conductivity sensor mounted on a first predetermined subset of the set of movable arms; a strain sensor mounted on a second predetermined subset of the set of movable arms; a first downhole tool configured to be placed in the horizontal section of the unconventional well; a second downhole tool placed in a vertical section of the well, the first downhole tool and the second downhole tool adapted to operate simultaneously; a navigation package; a real time communications short hop data communicator; a data communicator; a downhole power source; and a surface system configured to collect and process data obtained in the well. The system can be used to provide data to evaluate conditions in the well and its reservoirs as well as frac height and frac width.

Abstract: A system and method for isolating a zone in a wellbore having a sand screen including applying hydrogel into an annulus between the sand screen and the geological formation to form a hydrogel packer in the annulus.

Abstract: The disclosure improves the analysis of the hydraulic fracturing (HF) break down process of a well system. The analysis can use as inputs collected HF data such as the HF fluid pressure, HF fluid flow rate, and HF fluid composition over one or more time intervals. In some aspects, the perforation parameters and stratigraphic well placement can also be used as inputs. The analysis can also use as inputs the HF model inputs that were used in collecting the HF data. The analysis can determine an effectiveness parameter of the received inputs. HF model inputs can be selected that would best fit a HF job plan goal for the current well system. In some aspects, the HF model inputs can be communicated to a well system controller of the current well system to further direct HF job plan operations.

Abstract: A multivariate analysis may be used to correlate seismic attributes for a subterranean formation with petrophysical properties of the subterranean formation and/or microseismic data associated with treating, creating, and/or extending a fracture network of the subterranean formation.

Abstract: A system for determining a fingerprint of a structure is provided.