Petroleum Analytics Learning Machine (or PALM) system is a machine learning based, “brutally empirical” analysis system for use in all upstream and midstream oil and gas operations. PALM system optimizes exploration, production and gathering from at least one well of oil and natural gas fields to maximize production while minimizing costs. Normalized data are processed to determine clusters of correlation in multi-dimensional space to identify a machine learned ranking of importance weights for each attribute. Predictive and prescriptive optimization on the normalized data is performed utilizing unique combinations of machine learning and statistical algorithm ensembles. The unstructured textual data are classified to correlate with optimal production to capture the dynamics of at least one or more wells of oil and natural gas fields and to provide categorization results from labeled data sets to identify patterns.
Please help me write a proper abstract based on the patent claims. CLAIM: 1. A method for optimizing exploration, production and gathering from at least one well of oil and natural gas fields using a petroleum analytics learning machine system to maximize production while minimizing costs, comprising the steps of: collecting structured digital data and unstructured textual data from geological, geophysical, reservoir modeling, drilling, completion and production of crude oil, natural gas, ethane, butane, propane and condensate; receiving incoming data over a communications network and storing the incoming data into a system integration database by a processor based server or cloud based distribution of servers to provide collected data, the incoming data comprises digital exogenous data, real-time and historical endogenous data, historical data from surrounding production wells, hydraulic fracture completion data, and progress, status and maintenance data from new vertical and horizontal wells, including kickoffs, sidetracks, step-outs, pipeline gathering systems, compressor stations, and oil and gas sensor data including from public and private data sources; recording a time and depth for each data point of the collected data; cleaning the collected data to eliminate extraneous and noisy data; normalizing and storing the clean data; processing the normalized data to determine clusters of correlation in multi-dimensional space to identify a machine learned ranking of importance weights for each attribute; ranking said importance weights, and identifying patterns to enhance production of said at least one well of oil and natural gas fields; performing predictive and prescriptive optimization on the normalized data utilizing unique combinations of machine learning and statistical algorithm ensembles, including at least two of the following: linear and non-linear support vector machines and regressions, decision trees, hidden Markov models, random forests, neural networks, deep learning networks, bagging, boosting, feature selection, clustering, approximate and dynamic programming; classifying unstructured textual data to correlate with optimal production by utilizing progressive clustering with learned seeds, information extraction and retrieval, image recognition, textual mining, keyword and keyphrase extraction, semantic and sentiment analysis, entity and pattern recognition and knowledge discovery processing to capture the dynamics of said at least one or more wells of oil and natural gas fields and provide categorization results from labeled data sets to identify patterns; displaying data and analyses, transmitting recommendations, and receiving actual field actions and reactions on a graphical user interface on a network-enabled processing device over the communications network, the recommendations being based on the collected data of one or more wells, or one or more predicted conditions, communications with the one or more of the field systems is autonomous and personalized to steer disparate data simultaneously to operators working on vertical and horizontal wells, hydraulic fractures, or other field operations that are needed to improve future production from of a well in response to one or more trends, said one or more predicted conditions, or recommendations displayed on the graphical user interface connected to the petroleum analytics learning machine system; and wherein the petroleum analytics learning machine system utilizes: an exploration and production synthesizer of available data from wells in an area or play, in order to score and rank the combined importance weights of attributes to predict maximum production at minimum costs when convolved with specific attributes of each well; a real-time synthesizer to optimize drilling to match a designed pathway of a drilled well including hitting one or more target landing zones, while minimizing sinuosity and missed targeting of horizontal, diagonal and vertical components of the drilled wells; a real-time processor to: convolve importance weight values of attributes received by the petroleum analytics learning machine system from historical data and attribute data from each new well as it progresses in real time to predict future production of said each new well before oil and gas are delivered to the surface; and to utilize time-series attributes during each hydraulic fracturing stage to automatically classify production effectiveness of said each hydraulic fracturing stage and provide recommendations to maximize future production of said each new well; and wherein the recommendations are directed autonomously to optimize the production of oil, natural gas, and natural gas liquids while minimizing water production over time. 2. The method of claim 1, further comprising the steps of receiving data from digital field devices into the system integration database; combining the received data with real time exogenous data comprising weather forecasts; feeding the historical data and the real-time data into a data cleaning system to recognize a quality of the combination with the received data from a comparison with historical performance of at least one of each digital field device and a data stream; and wherein the system integration database retrieves, compares and combines geology and geophysics, reservoir modeling, rock properties, drilling, completion, hydraulic fracturing, production and pipeline gathering data into a uniform data repository by linking heterogeneous data sources with normalization based on common unique identifiers, the common unique identifiers comprising at least one of a well name, a well number, a region and geological location of a well, a well depth, time, and a physical property number or API number, and the geology and geophysics, reservoir modeling, rock properties, drilling, hydraulic fracturing, completion, production, and pipeline gathering data. 3. The method of claim 1, further comprising the steps of: determining clusters of like correlations in one or more well conditions that will likely result in a productive well using the petroleum analytics learning machine system; generating from machine learning predicted production volumes of hydrocarbon liquids, gases, and water for each well over time; displaying identified trends and predicted production conditions; alerting an operator when an anomaly between the predicted production conditions and observed field conditions arise to modify and report a modification of an estimated ultimate recovery from the petroleum analytics learning machine system; and wherein the petroleum analytics learning machine system has a coverage of multiple aspects in the analytics, including: at least one of the following regressions: linear regression, support vector regression, classification, regression trees and random forests; at one of the following classification: logistic regression, support vector machine and support vector regression, nearest neighbors, decision trees and random forest, neural networks and deep learning networks; at least one of the following clustering methods: k-means, k-medoids, expectation-maximization, agglomerative clustering, and nonparametric Bayesian models; at least one of the following feature selection and feature engineering processes: information gain, chi-square, principle component analysis, and filter and wrapper feature selection methods; at least one the following ensemble methods and models: bagging, boosting, gradient boosting machine, and random forests; at least one of the following time series analyses: autoregressive integrated moving average (ARIMA), generalized autoregressive conditional heteroskedasticity (GARCH), multivariate time series analysis, hidden Markov models, nonparametric Bayesian models; and at least one of the following large-scale or big data analyses: MapReduce, approximation, and locality sensitivity hashing. 4. The method of claim 3, further comprising the step of recommending a shut-in, cessation or abandonment of a well in response to a determination by the petroleum analytics learning machine system that anomalous conditions cannot be economically corrected. 5. The method of claim 1, further comprising the steps of receiving at least one of historical exogenous data, real-time exogenous data and the real-time endogenous data of said each well over a secure wireless or wired network, and wherein the historical exogenous data and the real-time exogenous data include at least one of historical weather data, forecast weather data, and production data from surrounding wells under similar historical conditions; and computing forecast of future product for said each well. 6. The method of claim 5, further comprising querying one or more system integration databases of multiple surrounding wells in an area or querying one integrated master system integration database comprising regionally relevant geologic and geophysical data, reservoir models, drilling data, hydraulic fracturing data, the historical exogenous data, the real-time exogenous data, and the real-time endogenous data to forecast production of said each well. 7. The method of claim 1, wherein the exploration and production synthesizer of the petroleum analytics learning machine system independently computes at least one of the following actions: steering of a new horizontal well within a preferred geological landing zone target, planning and execution of each stage and perforation density and spacing, and a hydraulic fracturing design and sand proppant volume over time that positively affects production decisions using real-time decision trees and random forests during each hydraulic fracture. 8. The method of claim 7, wherein the exploration and production synthesizer of the petroleum analytics learning machine system utilizes a support vector regression to estimate relative importance weights of attributes inputted into the petroleum analytics learning machine system and a linear regression to assign a positive or negative correlation sign to product for each weight; and wherein the attributes comprise: relevant geological and geophysical data; reservoir modeling results and calculations, including correction factors and assumptions; rock property measurements including poisons ratio, young's module, gamma ray radioactivity, organic and BTU content; and combining parameters of the support vector regression and linear regression to enable construction of tornado diagrams representing visually the importance weights of each attribute that correlates with a positive production prediction result and the importance weights of each attribute that correlates with a negative production prediction result for all wells in the area or play. 9. The method of claim 8, wherein the real-time processor convolves f and g, where f is the importance weight values of attributes computed by the petroleum analytics learning machine system from historical data from all the wells in the area or play and g is each attribute value specific to a well as it progresses; and wherein f * g is an integral transform of a product of two functions as attributes specific to said well, and the integral transform predicts the future production of said well before the oil and gas are delivered to the surface. 10. The method of claim 7, further comprising step of managing one or more prescriptive analytics calculations to maximize production of liquids, and gases and to minimize production of water while minimizing the costs by the exploration and production synthesizer by: computing multiple learning models operatively coupled to the system integration database and receiving collected data from the field in real time in an exit poll like voting procedure by the petroleum analytics learning machine system; generating at least one predicted condition by the petroleum analytics learning machine system; and storing resulting changes in operations in the system integration database from field operations in response to a recommended action. 11. The method of claim 1, wherein the real-time synthesizer of the petroleum analytics learning machine system independently monitors drilling data comprising the following: at least one of the following surveys: measured depth, inclination, azimuth, total vertical depth, vertical steering, azimuthal departure and dog-leg severity, build rate and turn; at least one of the following parameters: weight on bit, rotary torque, circulation rate, measurement while drilling logs such as gamma ray, density and electrical resistivity, differential pounds per square inch, choke position, hook load, flow, alarm states, pump rates, pump strokes, inclination, rotary revolutions per minute, mud viscosity, mud weight, and deviation from a plan; at least one of the following wellbore schematics: conductor casing depth, water casing depth, minimum casing depth, surface casing depth, production casing depth, float subs, float collars, float shoes, marker joints, cement design, mud displacement volume, additive types, and additive volumes; and further comprises the step of providing real-time recommendations to minimize sinuosity of horizontal wells while maintaining a position within selected landing zones for predetermined distances. 12. The method of claim 1, further comprising the steps of: independently monitoring the completions data by the real-time processor, the completions data comprising perforation depths and time, completions tool use and choke setting, and at least one of the following: time series hydraulic fracture data including surface and downhole pressures, slurry compositions and water mixes, sand volumes, breakdown pressure, proppant concentrations and shut-in pressure for each hydraulic fracture; optimizing a maximum possible production from one or more hydraulic fracturing stages while minimizing its costs by a real-time processing and generation of a predictive machine learning model based on classification of following key attributes determined by the petroleum analytics learning machine system: a time of a density drop that ends a first sand injection; a pressure percentile at the time of the first density drop; a time of a density drop that ends a second sand injection with sand heavier than the sand used in the first sand injection; a pressure percentile at the time of the second density drop; a time of a pressure drop at an end of a shut-in; a pressure percentile at the time of the pressure drop at the shut-in; a time of a beginning of a sand change from a light to a heaviest sand; a pressure percentile at beginning of a heaviest sand density increase; a time of a highest pressure after the sand change to the heaviest sand; a pressure percentile of a maximum heaviest sand change; a slope of a linear regression of a pressure from beginning to end of the second sand injection; an intercept of the linear regression of pressure from the beginning of the second sand injection to the highest pressure; a scatter of the linear regression of the pressure from the beginning of the second sand injection to the highest pressure; generating one or more real-time executable recommendations to a hydraulic fracturing control center by the real-time processor, the real-time executable recommendations comprising at least one of the following: a recommended down-hole pressure, a proppant concentration, slurry rate and volume, and a water/sand mix based on at least trends in one or more hydraulic fracturing decision tree and random classifications of historical, highly productive versus low producing stages; and generating one or more conditions to change real time decisions in the hydraulic fracturing control center based on updated decision trees and random forest predictions that can steer in real time towards a high producing fracture versus a low producing fracture stage. 13. The method of claim 12, further comprising the step of executing automated time series classification by the real-time processor using a machine learning feature recognition to develop clusters of hydraulic fracture classes, and to correlate stages of each class to an average highest production of historical wells, the automated time series classification comprising the following hydraulic fracture classifications: FracClass 1 is a failure to fracture due to surface equipment failures resulting in no hydraulic fracture and no input to a well production; FracClass 2 is a hydraulic fracture but a subsequent equipment failure either on the surface or down-hole resulting in a minimal sand displacement and an operator decision to cut a hydraulic fracture short, and cancel a current stage and move on to a next stage in the well production plan; FracClass 3 is a successful fracture at extended time and cost, a rapid sand injection resulting in the well being accidentally packed-off to the surface by an excessive sand buildup, then a wellbore cleanup with water, and re-perforation to allow a formation to take scheduled proppant sands; FracClass 4 is a successful fracture and injection of a full planned for amount of sand, but a late sand placement at an end of a proppant injection resulting in a pressure surge, the sand placement only packing-off locally to a near wellbore annulus of perforations of the current stage, and a subsequent water cleanout failing to washout the near wellbore sand placement away from the annulus; and FracClass 5 is a perfect hydraulic fracture wherein the full planned amount of the sand was emplaced in a scheduled time, and a subsequent water wash successfully washed the sand from the drill pipe and the near wellbore; and wherein the real-time processor performs the automated time series classification by modeling sequential patterns and interactions among time series variables utilizing at least one of the following: autoregressive integrated moving average (ARIMA), a multivariate time series analysis, a hidden Markov model, an autoregressive conditional heteroskedasticity (ARCH), an exponentially weighted moving average and a generalized autoregressive conditional heteroskedasticity (GARCH). 14. The method of claim 13, further comprising the steps of generating one or more executable recommendations to proceed to a productive hydraulic fracture class mixture based on tornado diagrams by the real-time processor utilizing the machine learning to match clusters of attributes of the hydraulic fracture classes that correlate with a maximum production; generating recommended actions to control the FracClasses 3 and 4 occurrences as a percentage of the FracClass 5 of perfect factures; and automatically updating the decision trees to estimate limits of combination of the down-hole pressure, the proppant concentration, the slurry volume and rate, and a sand volume and size based on trends in one or more historical hydraulic fracture successes and failures that occur in each well stage-by-stage and conveyed automatically and autonomously to the hydraulic fracturing control center. 15. The method of claim 12, further comprising the step of storing the hydraulic fracture classes from each new well in the system integration database by the real-time processor, thereby enabling subsequent production of liquids, gas and water to be tested against stored hydraulic fracture class mixtures, real-time conditions, and performance measurements as fractures unfold in real-time. 16. The method of claim 12, further comprising the step of generating one or more hydraulic fracturing conditions by the real-time processor of the petroleum analytics learning machine system that minimizes ideal hydraulic fracturing conditions comprised by at least reducing costs of a service company's time and energy, and determining a water consumption and decision to proceed or stop said each hydraulic fracturing stage. 17. The method of claim 12, wherein the real-time processor comprises a memory to store computer-executable instructions and is coupled to at least one transmitter to communicate with the hydraulic fracturing control center via a bi-directional messaging interface; and further comprising the step of executing the computer-executable instructions by the real-time processor to cause the hydraulic fracturing control center to: receive recommendations from the petroleum analytics learning machine system; generate at least one recommendation to increase production or cut costs of a well in progress by controlling a mix of the hydraulic fracturing class outcome using decision trees of the petroleum analytics learning machine system to maximize an overall ell production; and store data from actions undertaken based on said at least one recommendation in the system integration database to provide a feedback to the petroleum analytics learning machine system about its recommendations based on the future production. 18. The method of claim 1, further comprising the steps of computing a forecast for production of oil, natural gas, gas liquids, and water by the real-time processor of the petroleum analytics learning machine system for a duration of a productive history of a well, before delivery of the oil and gas to the surface; continuously monitoring and updating the production as the well ages by the real-time processor; and providing an estimated ultimate recovery modification recommendations by the real-time processor when a deviation from a forecasted, estimated ultimate recovery is predicted. 19. The method of claim 1, further comprising the steps of analyzing a pipeline gathering system monitoring data from the system integration database by the real-time processor of the petroleum analytics learning machine system, the monitoring data comprises at least one of the following: time series of nodal pressure, liquids and gas compositions and volumes, maintenance records; and identifying correlation clusters to predict pigging schedules and looping directions for an optimal performance of a pipeline gathering system.