Abstract: A method for evaluating a production potential for volume fracturing of a shale oil reservoir and determining a soaking time is discloses. The method may comprise: obtaining a core column; performing a saturated oil treatment on the core column; obtaining an initial fracture porosity parameter of the saturated oil-treated core column; soaking the core column after a CT scanning into a fracturing fluid to test the core mass increase amount at different immersion durations; obtaining the fracture porosity increase amount of the core column at different soaking times, and calculating a weight of newly added fracture porosity-fillable fracturing fluid; generating a curve of the core mass increase amount and a curve of the weight of the newly added fracture porosity-fillable fracturing fluid at different immersion durations; comparing a mass increase amount per volume unit of a core, and ranking a e mass increase amount per volume unit of the core to determine the production increase potential.

Abstract: Methods and systems for measuring cluster efficiency for stages of wellbores are provided herein. One method includes selecting a frequency band for generating broadband tube waves within the fluid column of the wellbore and generating the broadband tube waves within the fluid column of the wellbore using a pressure pulse generator that is hydraulically coupled to the wellbore. The method also includes recording data corresponding to the broadband tube waves and reflected broadband tube waves using pressure receivers that are hydraulically coupled to the wellbore. The pressure receivers are arranged into arrays with two or more pressure receivers in each array. The data recorded by the pressure receivers relate to characteristics of reflectors (including perforation cluster/fracture interfaces) within the wellbore.

Abstract: There is provided a fiber-reinforced brittle matrix composite. The fiber-reinforced brittle matrix composite comprises a brittle matrix material (for example, a cementitious or ceramics material) and a coated fiber embedded in the brittle matrix material, wherein the coated fiber comprises a fiber (for example, polyethylene fiber, glass fiber, silicon carbide fiber, alumina fiber, mullite fiber) and a coating material (for example, carbon nanofibers, carbon nanotubes), which is non-covalently disposed on the fiber. A method for producing the fiber-reinforced brittle matrix composite is also provided. The method comprises providing a fiber, disposing a coating material on the fiber to form a coated fiber, wherein the coating material is non-covalently disposed on the fiber, and embedding the coated fiber in a brittle matrix material to obtain the fiber-reinforced brittle matrix composite.

Abstract: A system and methods for quantitative hydraulic fracturing surveillance from fiber optic sensing using machine learning is described herein. An exemplary method provides capturing distributed acoustic sensing (DAS) data, distributed temperature sensing (DTS) data, and microseismic data over monitored stages. Operation states and variables at a respective stage are predicted, based on, at least in part, the DAS data, DTS data, or microseismic data. At least one event associated with the predicted operation states and variables is localized at the respective stage.

Abstract: Disclosed herein is an automated process of identifying shut-in parameters of a hydraulic fracturing operation from hydraulic fracturing treatment (HF) data. Also disclosed is a system and computer program product for automatically determining shut-in parameters from HF data. The HF data can be collected in real time during a HF from various sensors, equipment, or systems typically used in HFs or present at a well site. In one example, a method for automatically determining hydraulic fracturing parameters includes: (1) obtaining HF data, (2) determining a Rate Shut-In (RSI) time from the HF data, (3) determining a Well Shut-In (WSI) time using the RSI, and (4) calculating an Instantaneous Shut-In Pressure (ISIP) value based upon both the RSI and the WSI times, wherein determining the RSI time, the WSI time and calculating the ISIP value are automatically performed by one or more processors.

Abstract: In some examples, a system can include a computer-readable medium storing computer-executable instructions and one or more processors communicatively coupled to a computer-readable medium storing computer-executable instructions, which, when executed by the one or more processors cause the one or processors to receive data of a fracking stage, determine a penetration gradient of the fracking stage based on the data, and classify the fracking stage based on the penetration gradient.

Abstract: A system may have a built hydraulic fracturing system with a plurality of devices connected together and in fluid communication with one or more wells. The system may also include at least one continuous pumping operations for one or more wells and a fracturing pumping plan provided on a software application. The fracturing plan may include instructions to perform at least one continuous pumping operations for the one or more wells. The instructions may include a sequence of valve operations to direct fluid flow through a selected path into the one or more wells.

Abstract: A method for evaluating induced fractures in a wellbore includes obtaining a first set of data in a wellbore using a downhole tool. The method also includes pumping a first proppant into the wellbore after the first set of data is obtained. The first proppant includes a first tracer that is not radioactive. The method also includes pumping a second proppant into the wellbore. The second proppant includes a second tracer that is not radioactive. The second tracer is different than the first tracer. The first proppant and the second proppant flow into fractures in the wellbore. The method also includes obtaining a second set of data in the wellbore using the downhole tool after the first and second proppants are pumped into the wellbore. The method also includes comparing the first and second sets of data.

Abstract: Techniques for determining at least one rock property of a core sample include measuring a first nuclear magnetic resonance (NMR) spectrum signal of a test fluid enclosed at a particular pressure in a cylinder of an NMR pressure cell; measuring a second NMR spectrum signal of a core sample immersed in the test fluid; removing a background NMR spectrum signal from the first and second NMR spectrum signals to determine a bulk test fluid NMR spectrum signal and a combined test fluid and core sample NMR spectrum signal; determining a porosity of the core sample based on the bulk test fluid NMR spectrum signal, the combined test fluid and core sample NMR spectrum signal, a dimension of the core sample, and a dimension of the cylinder; and determining a fluid intake capacity of the core sample based on the porosity and the dimension of the core sample.

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 of mapping unknown well data channels involves generating, with a processor, summary statistics for unknown sequences of well data values where the well data values pertain to respective particular types of data and where each type belongs to a category of well data. The system processes the respective summary statistics with a trained super model to classify the respective sequences of well data values into categories of well data. The system then processes the summary statistics for a given sequence using a trained sub-model of the category to which the sequence belongs in order to further classify the sequence as to its particular type within the category thereby mapping originally unknown sequences of well data values to the correct category and type of well data.

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: 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: 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: 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: 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: 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: 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.