Abstract: The present disclosure provides a method for determining an ore-forming environment of a porphyry deposit based on a tourmaline component, including the following steps: collecting a tourmaline-containing rock in the porphyry deposit to obtain a rock sample; performing pretreatment on the rock sample to obtain a treated sample; performing an in-situ tourmaline trace element test on the treated sample to obtain a test result; performing data processing and interpretation on the test result to obtain tourmaline trace element data; establishing a discrimination factor based on the tourmaline trace element data; and determining the ore-forming environment based on the discrimination factor. The present disclosure can quickly recognize a forming environment of a newly discovered porphyry deposit, thereby summarizing a rule and quickly giving guidance for a next prospecting direction.

Abstract: A device and a method for evaluating damage of high-temperature and high-humidity gas to a surrounding rock porous structure are provided. The device includes a rock sample clamper, a temperature control device, a pressurizing device, a gas mixing injection device, a CT scanning device and a low-temperature nitrogen adsorption device. By simulating the gas rock reaction under the conditions of in-situ temp., pressure and gas, using CT scanning device to visually monitor and analyze the reaction condition of gas and tunnel surrounding rock and the change condition of porous structure, and using low-temperature nitrogen adsorption test to obtain porous structure parameters change condition before and after reaction of gas and tunnel surrounding rock, and the damage evaluation index of the porous structure is established.

Abstract: Machine learning-based disaster modeling and high-impact weather event forecasting are provided herein. Embodiments herein provide a flexible machine-learning platform for providing skillful forecast of severe weather (tornadoes, damaging wind gusts, and hail), tropical cyclone activity, and precipitation, with skill potentially extending to 13 months or more.

Abstract: A system includes a processor and a memory. The memory includes instructions that are executable by the processor to access training data of a modern feature of interest from direct observations, remotely determined data, or a combination thereof. The instructions are also executable to compile parameter data from at least one model simulation that impacts the modern feature of interest. The instructions are executable to train a machine-learning model to generate a predictive model that matches the training data of the modern feature of interest using the compiled parameter data as input. Furthermore, the instructions are executable to predict a feature of interest in a past time period using the predictive model and at least one historical model simulation that impacts the feature of interest. Additionally, the instructions are executable to execute a processing operation for facilitating hydrocarbon exploration based on the predicted feature of interest from the predictive model.

Abstract: System and methods of petrophysical modeling are disclosed. Measurements of formation parameters are received from one or more measurement tools during a first stage of a downhole operation within a reservoir formation. A correlation between each of the formation parameters and a target parameter of the formation is determined based on the measurements. One or more formation parameters are selected as input parameters for a symbolic regression model, based on the correlation. A symbolic regression model is trained to generate candidate formation models representing the target parameter, based on the selected input parameters. One or more optimizations are applied to the candidate models to determine a target petrophysical model of the formation. Values of the target parameter are estimated for at least one formation layer, based on the target petrophysical model. A second stage of the downhole operation is performed within the formation layer(s) based on the estimated values.

Abstract: In contrast to existing methods wherein derived horizons are interpreted in isolation, the disclosure provides a process that does not interpret patches themselves but determines the relationships between patches, in order to associate and link patches to derive a holistic geological interpretation. Predefined patches, such as from a pre-interpreted suite, are received as inputs to determine the relationships and derive an interpretation for a complete volume. In one aspect the disclosure provides an automated method of generating a geological age model for a subterranean area. In one example, the automated method includes: (1) abstracting seismic data of a subsurface into a limited number of patches, (2) abstracting the patches by defining patch-links between the patches, and (3) generating a geological age model of the subsurface by solving for the relative geological age of each of the patches using the patch-links.

Abstract: A map having surfaces that are depicted at different levels that are not related to topography, with boundaries between the surfaces, where the boundaries are disposed at travel ways. The travel ways form cliff faces in the map between the surfaces, with information items disposed on the cliff faces at positions corresponding to items of interest at locations along the travel ways where the information items are disposed.

Abstract: A method may include determining a portion of a microscale fracture using a well log acquired for a stratigraphic interval of interest. The method may further include obtaining seismic data for the stratigraphic interval of interest. The method may further include determining a seismic attribute that correlates the microscale fracture to a subset of the seismic data. The method may further include generating an attribute volume using the seismic attribute with a seismic volume for a region of interest. The method may further include generating, using the attribute volume, a fracture image of the microscale fracture throughout the region of interest.

Abstract: Aspects described herein provide for methods and apparatus for characterizing azimuthal heterogeneities in a barrier installed outside an outer casing in a borehole traversing a formation in a cased hole configuration including an inner and outer casing. The approach is based on specific attributes in sonic signals acquired with an azimuthal and axial array receiver system located inside the inner casing. The methods include slowness-time-coherence (STC) processing based on specific arrivals identified in data acquired by axial arrays associated with multiple azimuthal sections of the receiver system. The specific arrivals contain STC signatures that can be examined in terms of coherence amplitude and localization within STC maps. Based on specific attributes in the sonic signals, an azimuthal coverage of the outer casing annular contents can be created.

Abstract: The present disclosure discloses a method for quantifying a bearing capacity of foundation containing shallow-hidden spherical cavities, comprising: in Step 1, constructing a spatial axisymmetric calculation model for stability analysis of the foundation containing shallow-hidden spherical cavities; in Step 2, solving the model to obtain a general solution which reflects the spatial stress distribution of surrounding rock containing shallow-hidden spherical cavities; in Step 3, obtain a mathematical expression by derivation for calculating the bearing capacity of the foundation containing shallow-hidden spherical cavities; and in Step 4: completing the determination of the foundation bearing capacity. Benefits: This method has many advantages such as comprehensive consideration, high accuracy and reliability of calculation results, and may provide the scientific basis for the development of prevention and control against the instability of the foundation containing shallow-hidden cavities.

Abstract: A system can receive seismic data that can correlate to a subterranean formation. The system can derive a set of seismic attributes from the seismic data. The seismic attributes can include discontinuity-along-dip. The system can determine parameterized results by analyzing the seismic data and the seismic attributes using a deep learning neural network. The deep learning neural network can include a dilation module. The system can determine one or more fault probabilities of the subterranean formation using the parameterized results. The system can output the fault probabilities for use in a hydrocarbon exploration operation.

Abstract: A method for analyzing a rock sample includes segmenting a digital image volume corresponding to an image of the rock sample, to associate voxels in the digital image volume with a plurality of rock fabrics of the rock sample. The method also includes identifying a set of digital planes through the digital image volume. The set of digital planes intersects with each of the plurality of rock fabrics. The method further includes machining the rock sample to expose physical faces that correspond to the identified digital planes, performing scanning electron microscope (SEM) imaging of the physical faces to generate two-dimensional (2D) SEM images of the physical faces, and performing image processing on the SEM images to determine a material property associated with each of the rock fabrics.

Abstract: A method includes receiving fluid property data of a fluid and receiving material property data for materials in the fluid. The method includes detecting material sensor data from at least one sensor and applying an inverse model and a forward model to the fluid property data and the material property data to provide at least in part synthetic spectral channel data for the materials.

Abstract: A method is provided for monitoring the occurrence of pressure anomalies due to FDI in near real time during a hydraulic fracturing operation carried out on an active well that is located near one or more passive monitoring wells. The method includes the steps of obtaining raw pressure sensor data from the one or more passive monitoring wells, processing the pressure sensor data with the FDI analysis module, and determining if the rate of change for averaged pressure sensor data exceeds a preset threshold value that indicates the likelihood of a pressure anomaly. The methods can be configured to autonomously alert an operator of the likelihood of a pressure anomaly and with guidance on resolving the anomalies.

Abstract: A drilling device may use a concurrent path planning process to create a path from a starting location to a destination location within a subterranean environment. The drilling device can receive sensor data. A probability distribution can be generated from the sensor data indicating one or more likely materials compositions that make up each portion of the subterranean environment. The probability distribution can be sampled, and for each sample, a drill path trajectory and drill parameters for the trajectory can be generated. A trained neural network may evaluate each trajectory and drill parameters to identify the most ideal trajectory based on the sensor data. The drilling device may then initiate drilling operations for a predetermined distance along the ideal trajectory.

Abstract: The present application relates to a permeability evaluation method for hydrate-bearing sediment, including a complex conductivity spectrum obtaining step, a hydrate saturation calculating step based on the spectrum, a formation factor calculating step based on Archie's first law or from the complex conductivity real part, imaginary part and a conductivity of pore water; and a permeability calculating step based on relaxation time, hydrate saturation, hydrate occurrence mode correction factor and formation factor, or based on the polarization amplitude, hydrate saturation, occurrence mode correction factor and formation factor, or based on the CEC, hydrate saturation and occurrence mode correction factor, or based on the pore radius, fractal dimension, hydrate saturation and occurrence mode correction factor.

Abstract: Systems and methods for determining mechanical properties of anisotropic media are disclosed. A method for determining mechanical properties of an anisotropic media includes obtaining log data of the anisotropic media, the log data corresponding to measurements of the anisotropic media collected with a logging tool; determining values for a plurality of first stiffness components of a stiffness matrix based on horizontal and vertical velocities derived from the log data; determining an upper bound for a second stiffness component of the stiffness matrix based on the values for the plurality of first stiffness components; estimating a value for the second stiffness component based on the determined upper bound; determining a mechanical property of the anisotropic media based on the estimated value of the second stiffness component; and providing the determined mechanical property.

Abstract: Methods and systems are provided for characterizing a subterranean formation that involve the generation of four 3D geological model of the formation that are updated before and after an enhanced hydrocarbon production process.

Abstract: Systems and methods are provided for determining a formation body wave slowness from an acoustic wave. Waveform data is determined by logging tool measuring the acoustic wave. Wave features are determined from the waveform data and a model is applied to the wave features to determine data-driven scale factors The data-driven scale factors can be used to determine a body wave slowness within a surrounding borehole environment and the body wave slowness can be used to determine formation characteristics of the borehole environment.

Abstract: A device may determine a calibration value for a spectrometer using light from a first light source; deactivate the first light source after determining the calibration value; perform measurement with regard to a sample based on the calibration value, wherein the measurement of the sample is performed using light from a second light source; determine that the calibration value is to be updated; and update the calibration value using the light from the first light source.

Abstract: An example computer-implemented method for transmitting data from a downhole location to the earth's surface. The method includes sensing, with one or more sensors, sensor data downhole, the sensor data comprising a plurality of data value sets. The method further includes assigning at least one data value of each of the plurality of data value sets to each of a plurality of time levels or depth levels to generate a data block. The method further includes compressing, with a first processor in the drilling assembly, the data block by a block-based compression technique to generate compressed data. The method further includes transmitting, with a telemetry system, the compressed data from the downhole location to the surface. The method further includes decompressing, with a second processor at the surface, the compressed data to generate decompressed data values. The method further includes controlling the drilling assembly based on the decompressed data values.

Abstract: Method and system for developing reservoirs, such as hydrocarbon reservoirs or aquifers, including correcting pressure transient test data to account for variations of fluid density between a gauge depth and a mid-reservoir depth in a wellbore. Gauge depth pressure and temperature measurements, and density correlations are used to estimate mid-reservoir depth pressures, which can be used in a pressure transient analysis.

Abstract: Systems and methods include a method for providing an integrated advanced visualization tool for geosteering underbalanced coiled tubing drilling (UBCTD) operations. Drilling operation data is received from different sources in real time during a drilling operation. The drilling operation data includes geological formation information recorded during the drilling operation, micropalaeontological test results of the drilling operation, drilling parameters being used during the drilling operation, cumulative productivity index calculations, and reservoir pressure information of reservoirs encountered during the drilling operation. The drilling operation data is analyzed to correlate elements of the drilling operation data by time and cumulative depth. A graph is generated in real time that includes multiple plots correlated as a function of cumulative depth over time.

Abstract: A seismic monitoring system includes a plurality of seismic monitors and a processing device operatively coupled to the plurality of seismic monitors. The processing device receives recordings of waveforms of motion detected at the plurality of seismic detectors in a geographic area. The processing device applies the respective recordings to corresponding positions of the seismic detectors in a three-dimensional geological model that describes its elastic attributes and tests a plurality of moment tensors at a plurality of locations. Based on the testing, the processing device determines a globally convergent source location and moment tensor in the three-dimensional model based on the testing.

Abstract: Techniques for determining a fracture driven interaction include identifying pressure response data from one or more pressure sensors that are in direct fluid communication with a fluid at least partially enclosed within one or more monitor wellbores formed from a terranean surface to one or more subterranean formations; calculating at least one pressure response value from the pressure response data; determining the fracture driven interaction between the treatment wellbore and at least one of the one or more monitor wellbores based at least in part on the calculated at least one pressure response value; and preparing a graphic representation of the determined FDI for display on a graphical user interface.

Abstract: Systems and methods are disclosed for identifying and displaying geostructural properties as a function of lithology, horizons, and faults interpreted from well and seismic data. Exemplary implementations may include obtaining an initial fracture distribution grid model; obtaining training structural deformation data; obtaining training subsurface lithology parameter data; obtaining training fracture attribute data; and training the initial fracture distribution grid model to generate a trained fracture distribution grid model.

Abstract: Methods and systems for determining wellpath tortuosity are disclosed. In accordance with an embodiment, a tortuosity of a borehole segment is determined and a tortuosity of a casing associated with the borehole segment is determined based, at least in part, on the tortuosity of the borehole segment and a path conformity characteristic of the casing. A tortuosity variation factor is generated based on a value of the tortuosity of the casing relative to a value of the tortuosity of the borehole segment.

Abstract: A method may include obtaining a request to determine automatically a depth of a formation top for a well in a geological region of interest. The method may include obtaining various well logs regarding the well and various wells in the geological region of interest. The method may include determining various depth values using the various well logs and a statistical interpolation method. The method may further include determining a final depth of the well using the various depth values and a searching method.

Abstract: An in-situ stress measurement method is provided. The method includes measuring a length of a maximum diameter at which an amount of distortion relative to a diameter of a standard circle of a measurement cross section of a boring core is largest and a length of a minimum diameter at which the amount of distortion relative to the diameter of the standard circle is smallest based on a shape of the measurement cross section of the boring core; measuring a length of a diameter in a vertical direction and a length of a diameter in a horizontal direction of the measurement cross section of a side-wall core acquired by hollowing ground in a well in an excavation direction thereof, based on a shape of the measurement cross section of the side-wall core; and calculating a maximum horizontal stress and a minimum horizontal stress by first and second equations.

Abstract: A method and apparatus of logging downhole formation and obtaining formation porosity using a pulsed neutron generator and multiple dual-function detectors that detect both neutrons and gamma rays. Ratios of thermal neutrons, epithermal neutrons, and capture gamma rays from multiple detectors are utilized to obtain neutron porosity, gamma porosity and formation porosity by using a trained neural network. The method can provide formation porosity measurements independent of environmental factors, such as borehole size, tool standoff, salinity, temperature, pressure, etc. Effects from environmental factors can be automatically corrected by employing multiple dual-function detectors that detect both neutrons and gamma rays.

Abstract: An acquisition system is configured to acquire seismic data representing a subsurface formation during a fracking process. The system includes at least one acoustic sensor that is configured to obtain vibration data representing vibrations relating to three orthogonal directions relative to the at least one acoustic sensor. The system is configured to receive the vibration data from the at least one acoustic sensor, identify one or more resonance frequencies represented in the vibration data, determine, based on the identified one or more resonance frequencies, a stage of a fracking process being performed, identify, based on the stage of the fracking process that is identified, a feature of one or more fractures in a borehole that is configured for the fracking process, and generate a seismic image of the subsurface formation based on the feature of the one or more fractures.

Abstract: A method of rock typing includes obtaining mercury injection capillary pressure (MICP) data regarding a region of interest. A distance matrix is computed for distributions determined from the MICP data using a statistical distance metric. A cluster tree of the distributions is generated using the distance matrix. The cluster tree is adjusted based on a petrographic characteristic to produce an adjusted cluster tree, which is used to determine a pore structure types of the region of interest.

Abstract: A method of predicting behavior or a degradable device of a borehole tool when deployed downhole including introducing a test mass of material identical to the material of the degradable device to the same general location and at a time near to when the degradable device is deployed, removing the test mass from downhole, determining characteristics related to degradation of the test mass, and predicting degradation behavior of the degradable device based on the determined characteristics.

Abstract: Drill strings with probe deployment structures, hydrocarbon wells that include the drill strings, and methods of utilizing the drill strings are disclosed herein. The drill strings include a pipe string and a drill bit attached to the pipe string. The drill strings also include a probe deployment structure attached to the pipe string and a downhole communication device attached to the pipe string. The probe deployment structure includes a probe and is configured to selectively insert the probe into a subterranean formation via a wellbore of the hydrocarbon well. The probe is configured to measure at least one property of the subterranean formation. The downhole communication device is configured to communicate with the probe. The hydrocarbon wells include a drill string support structure, which supports the drill string, a wellbore extending within a subsurface region, and the drill string extending within the wellbore.

Abstract: A method of geosteering in a wellbore construction process uses an earth model that defines boundaries between formation layers and petrophysical properties of the formation layers in a subterranean formation. Sensor measurements related to the wellbore construction process are inputted to the earth model. An estimate is obtained for a relative geometrical and geological placement of the well path with respect to a geological objective using a trained stochastic clustering and pattern matching agent. An output action based on the sensor measurement for influencing a future profile of the well path with respect to the estimate.

Abstract: An elemental analysis of rock samples from outcrop sections or wells is performed. Data quality checks, data analysis, and filtering are performed on the rock samples, including de-spiking of elemental profiles and elemental ratios. First and second derivatives for the elemental profiles and the elemental ratios are calculated. Samples and depths that exceed thresholds are determined. The process is repeated for the elemental profiles and the elemental ratios that are related with boundary determination and carbonate or siliciclastic sediments. Additional filters are applied to at least a subset of the elemental profiles and elemental ratios that are related with boundary determination and carbonate or siliciclastic sediments to enhance the boundary identification. Possible boundaries in depths of the outcrop sections or wells are determined by summarizing the additionally filtered elemental profiles and the additionally filtered elemental ratios.

Abstract: A method, including disposing a probe of a sensor system in a wellbore to interact with a formation fluid that includes a mud filtrate and a clean fluid that includes one of a formation water, or a formation hydrocarbon fluid including at least one hydrocarbon component. The method includes collecting multiple measurements of a formation fluid from a wellbore, the formation fluid comprising a mud filtrate and a clean fluid, is provided. The clean fluid includes at least one hydrocarbon component, and the method also include identifying a concentration of the mud filtrate and a concentration of the clean fluid in the formation fluid for one of the measurements, and determining at least one hydrocarbon composition and at least one physical property of the clean fluid based on a measurement fingerprint of the hydrocarbon components. A sensor system configured to perform a method as above is also provided.

Abstract: A downhole gauge device for use in a well is described. The downhole gauge device includes one or more electrical systems including at least one measurement means for obtaining measurement data and a data transmitting means configured to transmit measurement data to a receiving station; a first power supply configured to supply a first amount of power to any of the one or more electrical systems; a second power supply configured to supply a second amount of power that is greater than the first amount of power to any of the one or more electrical systems; and means for selectively enabling one or both of the first and second power supply.

Abstract: Systems and methods for machine-learning-based additive manufacturing use a machine-learning model to process an input vector describing a new part transaction, thereby providing part optimization outputs and command initiation outputs to configure additive manufacturing of a new part. The machine-learning model is trained based on entries in a user experience database, each entry in the user experience database including data defining requirements for an additively manufactured part previously fabricated or attempted to be fabricated, specifications describing an additive manufacturing fabrication device, a selection of a raw material type fed to the fabrication device for fabrication of the additively manufactured part, a fabrication spatial orientation of the additively manufactured part within the fabrication device, a fabrication slicing resolution of the additively manufactured part, and a toolpath taken by the fabrication device in fabricating the additively manufactured part.

Abstract: Computing system assessment of geological similarity of wells employing well-log data includes receiving logs with chronostratigraphic markers, and extracting signatures from the logs using the chronostratigraphic markers. A distance matrix is generated from the signatures using dynamic time warping. Using the distance matrix, a set of clusters are generated. The set of clusters are presented with an image.

Abstract: The disclosure relates generally to the inversion of geophysical and/or logging measurements for formation evaluation and monitoring. The disclosure may be related to methods of deconvolution and/or inversion of piecewise formation properties. A method for formation evaluation from a downhole tool may comprise disposing a downhole tool into a wellbore, broadcasting a signal into a formation penetrated by the wellbore, recording the signal from the formation with at least one receiver disposed on the downhole tool, computing an objective function, and determining formation properties by minimizing the objective function.

Abstract: A method includes receiving a first transition probability matrix (TPM) of a subsurface region, wherein the TPM defines, for a given lithology at a current depth sample (or micro-layer), a probability of particular lithologies at a next depth sample (or micro-layer), receiving seismic data for the subsurface region, utilizing the first TPM and the seismic data to generate first pseudo wells, calculating a second TPM from the first pseudo wells, determining whether the second TPM is consistent with the first TPM, and utilizing the first pseudo wells to characterize a reservoir in the subsurface region when the second TPM is determined to be consistent with the first TPM.

Abstract: A method and system for processing a slowness profile. A method may comprise disposing a geophone array into a borehole, positioning the geophone array at a first location within the borehole; discharging a seismic source; positioning the geophone array at a second location within the borehole; discharging the seismic source, wherein the seismic source produces an acoustic wave; recording a vertical seismic profiling dataset, wherein vertical seismic profiling comprises a dataset of recorded acoustic waves by the geophone array at the first location within the borehole and the second location within the borehole; picking a first gap travel time from the vertical seismic profiling dataset; and determining the slowness profile, wherein the slowness profile comprises determining a slowness of the acoustic wave through a formation by the geophone arrays. A well system may comprise a geophone array, comprising a plurality of geophones, and an information handling system.

Abstract: Well logs can be automatically correlated using dynamic warping with descriptors. For example, a computing device can receive user input indicating a manual correlation between a first node in a first well-log and a second node in a second well-log. The computing device can use the manual correlation to automatically determine a combination of descriptors usable to correlate the first node to the second node. The computing device can then perform dynamic warping on other well logs using the combination of descriptors determined by using the first well log and the second well log. This may provide more accurate correlations between well logs.

Abstract: Methods may include calculating a formation permeability for a subterranean formation from a combination of dielectric measurements and acoustic measurements, wherein the formation permeability is calculated according to the formula: kg=a(Vx?w/?r)b, where Vx is either Vp, Vs, or Vp/Vs, ? is formation conductivity, Øw is water-filled porosity, and a and b are constants that are empirically determined for the frequency selected with respect to Vx; and creating a design for a wellbore operation from the calculated formation permeability. Methods may also include obtaining a dielectric measurement from a downhole formation; obtaining an acoustic measurement from a downhole formation; and calculating a formation permeability from a combination of the dielectric measurement and the acoustic measurement.

Abstract: Methods and devices for estimating at least one property of a volume of interest of an earth formation from a radiation based measurement. Methods include using an optimization procedure to determine an optimal mineralogical model in dependence upon a secondary dependence relation between tool measurements, the mineralogical model including a mineralogical composition of the volume. The secondary dependence relation may include a relation between a plurality of estimated elemental concentrations for the volume. The mineralogical composition may include a concentration of each mineral of a plurality of minerals of the volume. The relation may include a ratio of a first elemental concentration of the plurality of estimated elemental concentrations and a second elemental concentration of the plurality of estimated elemental concentrations. Methods may include using at least one cost function to determine the optimal mineralogical model, wherein the at least one cost function is determined using the relation.

Abstract: For a specified stratigraphic interval, well data is received for a plurality of wells. An average grain size for each of the plurality of wells is determined based on the received data. A location or multiple locations of a grain source is determined based on the average grain sizes for the stratigraphic interval.

Abstract: Systems, devices, and methods for generating steering instructions to directing the operation of a drilling system are provided. The systems, devices, and methods may include determining an optimized path to navigate a Bottom Hole Assembly (BHA) to a steering target using one or more steering methods, such as straight line projections, rotary drilling projections, True Vertical Depth, Inclination, and Azimuth (TIA) calculations, and three dimensional “J” (3DJ) calculations, and driving the BHA to the steering target using the optimized path.

Abstract: A method includes operating a downhole acquisition tool in a wellbore in a geological formation and performing formation testing to determine at least one measurement associated within the formation, the wellbore, or both. The tool may include sensors to detect measurements including, for example, formation pressure and/or wellbore pressure. The tool may also include a processor to obtain at least one spectral characteristic associated with the measurement, which may include frequencies of oscillation. The processor may also determine one or more parameters, associated with an oscillation suppression process, based on the spectral characteristic and remove oscillations, including noise associated with fluctuations of a fluid level in the wellbore, in the measurement based on the parameters. Petrophysical parameters may be estimated based on the modified measurement.

Abstract: A system and method for facilitating a user to initiate and accept an assistance request through a chat session is disclosed. Controls may be provided in a graphical chat interface to enable the user to specify inputs to request assistance from other users participating in the chat session. An assistance request may be generated and communicated to those users through the chat session. Graphical representation for the assistance request and controls that facilitate the users to accept the assistance request may be provided in the graphical chat interface. Upon an acceptance to the assistance request by a responding user through the graphical chat interface, an assistance command may be generated and executed in the virtual space.