The disclosure describes a BHA that generates electricity downhole. The generated electricity can then be utilized with an electric motor to turn the drive shaft and for drive shaft orientation. The disclosure also describes a more accurate MWD measurements by placing MWD sensors closer to drill bit.
E21B 4/16 - Moyens d'entraînement multiples au fond du trou, p.ex. pour le forage combiné par percussion et par rotation; Moyens d'entraînement pour unités de forage à plusieurs trépans
Method of decomposing high molecular weight polymer downhole to prevent chelation of iron by residual high molecular weight polymer thereby producing flowback without iron contamination as chelated iron. A secondary method is also described to treat iron chelated produced water with oxidants at surface conditions, utilizing aluminum electrolytes, specifically low basicity polyaluminum chloride, to either co-precipitate residual polymer and bound iron, or to substitute chelated iron with aluminum in the polymer-metal complex, resulting in liberating of iron to enable neutral pH oxidation and removal by precipitation, coagulation, flocculation and physical separation. The produced water with removed iron can be then stored or re-used for other oilfield applications.
The present disclosure generally relates to harvesting geothermal energy from mature and near end-of-life oil and gas reservoirs that have been subjected to secondary oil recovery steam processes like steam-assisted gravity drainage (SAGD), steamflood, etc. The geothermal potential of these mature SAGD reservoirs can be used to generate green electricity thus reducing the greenhouse gas (GHG) footprint of the oil production. Lateral spacing of injectors and producers, with closing of unused members of a well-pair for energy recovery is described.
F24T 10/30 - Collecteurs géothermiques utilisant des réservoirs souterrains pour l’accumulation des fluides vecteurs ou des fluides intermédiaires
F24T 10/20 - Collecteurs géothermiques utilisant un fluide vecteur injecté directement dans le sol, p.ex. utilisant des puits d’injection et des puits de récupération
F24T 10/10 - Collecteurs géothermiques avec circulation des fluides vecteurs dans des conduits souterrains, les fluides vecteurs n’entrant pas en contact direct avec le sol
Method of cleaning sucker rods using a portable cleaning tool containing a rotating brush assembly to remove scale and corrosion residue on the sucker rods is described herein. The brush is annular with an empty or hollow center, such that the rod can penetrate through the hole in the brush. The tool is powered by air compression, and also contains a mechanism of removing the collected debris for disposal. The cleaning tool assembly could be either a standalone device on site placed on a mounted rack, or could be attached to the rod to be cleaned.
A system and method for turning a well over to production. The method may include drilling a wellbore using a drillstring, casing the wellbore, fracturing a reservoir, drilling the wellbore to a plug back total depth using the drillstring to clean out the wellbore, and converting the drillstring from a drilling mode to a production mode.
Implementations described and claimed herein provide systems and methods for developing resources from a reservoir. In one implementation, obtaining nuclear magnetic resonance (NMR) log data is obtained for one or more wells of the reservoir. The NMR data is captured using one or more logging tools. An interpreted NMR log is generated by quantifying one or more fluid producibility parameters. The one or more fluid producibility parameters are quantified by processing the NMR log data using automated unsupervised machine learning. A production characterization of the reservoir is generated based on the interpreted NMR log, with the reservoir being developed based on the production characterization.
G01V 3/32 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant par résonance magnétique électronique ou nucléaire
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
G01R 33/50 - Systèmes d'imagerie RMN basés sur la détermination des temps de relaxation
G01R 33/44 - Dispositions ou appareils pour la mesure des grandeurs magnétiques faisant intervenir la résonance magnétique utilisant la résonance magnétique nucléaire [RMN]
7.
SYSTEMS AND METHODS OF GENERATING HIGH RESOLUTION SEISMIC USING SUPER RESOLUTION INVERSION
Systems and methods for reservoir modeling include a super resolution seismic data conversion platform for converting input seismic data into high resolution output seismic data. The super resolution seismic data conversion platform can perform a super resolution inversion on the input seismic data by imposing sparsity and/or coherency assumptions on geophysical parameters represented by wavelet information of the input seismic data. For instance, a seismic trace interval can be determined, and both a reflection coefficient and an acoustic impedance of the seismic trace interval can be constrained. An optimization problem, using the constrained reflection coefficient and the constrained acoustic impedance, can be generated and/or solved by a sparse inversion. As such, a vertical resolution, as well as a seismic bandwidth, of super resolution output seismic data can be increased, improving subterranean feature (e.g., sand and/or shale characteristics) interpretation and well planning and construction.
Aspects of the present disclosure relate generally to analyzing subterranean cylindrical structures using acoustic sensing. On example includes: sending first acoustic waves in the wellbore via a radial acoustic sensor; receiving first reflection waves associated with the first acoustic waves via the radial acoustic sensor; sending second acoustic waves in the wellbore via the radial acoustic sensor; receiving second reflection waves associated with the second acoustic waves via the radial acoustic sensor; processing recorded data associated with the first acoustic waves, the first reflection waves, the second acoustic waves, and the second reflection waves, wherein the first acoustic waves are associated with a first radial direction, and wherein the second acoustic waves are associated with a second radial direction, the second radial direction being opposite the first radial direction; and generating a plot for identification of one or more isolation regions in the wellbore based on the processing.
E21B 47/0224 - Détermination de l'inclinaison ou de la direction du trou de forage, p.ex. à l'aide de géomagnétisme utilisant des moyens sismiques ou acoustiques
E21B 47/085 - Mesure du diamètre ou des dimensions correspondantes des trous de forage utilisant des moyens de radiation, p.ex. des moyens acoustiques, radioactifs ou électromagnétiques
E21B 47/107 - Localisation des fuites, intrusions ou mouvements du fluide utilisant des moyens acoustiques
G01V 1/44 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs et des récepteurs situés dans le même puits
E21B 47/14 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques
Systems and methods for processing liquefied natural gas (LNG) can include an LNG production system with a methane refrigeration cycle downstream from an ethylene refrigeration cycle. The methane refrigeration cycle can be a closed loop methane refrigeration cycle that maintains a methane refrigerant separate from a natural gas feed, (e.g., compared to an open loop methane refrigeration cycle that extracts the methane refrigerant from the natural gas feed and recombines the methane refrigerant with the natural gas feed). The natural gas feed can be a medium or high nitrogen gas feed having a nitrogen content greater than 1.0% molarity.
Implementations described and claimed herein provide systems and methods for a scripting technique to clone equation-oriented models of a modeled system for parallel simulation of the modeled system. The multiple equation-oriented models may be solved in parallel to quickly create an optimized solution for different operating conditions by providing different input variable sets to the cloned equation-oriented models. The multiple equation-oriented models may provide real-time optimization of the modeled system to provide continuous optimization of all controls or handles of the system to help achieve a target performance of the system. The equation-oriented models may also provide a nomination tool to predict the output of the system over a nomination period with different input variables and performance monitoring capabilities of the system. Offline "what-if" simulations may also be executed on the equation-oriented modeling system to aid operators in predicting performance of the modeled system and troubleshoot potential problems.
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
G06Q 10/04 - Prévision ou optimisation spécialement adaptées à des fins administratives ou de gestion, p. ex. programmation linéaire ou "problème d’optimisation des stocks"
G06Q 50/06 - Fourniture d'électricité, de gaz ou d'eau
G06F 11/10 - Détection ou correction d'erreur par introduction de redondance dans la représentation des données, p.ex. en utilisant des codes de contrôle en ajoutant des chiffres binaires ou des symboles particuliers aux données exprimées suivant un code, p.ex. contrôle de parité, exclusion des 9 ou des 11
11.
TEMPORARY SUSPENSION OF COMPLETED HYDROCARBON WELLS
In the process of suspending a subsea hydrocarbon well (1) after finalizing the completion operation and prior to stimulation of the well and putting the well on production, preinstalled upper and lower glass plugs (11, 12) are used as temporary barriers in the tubing. The plugs allow various tests to be performed before the lower plug (12), below the production packer (10), is broken; the upper plug (11) located above the downhold safety valve (13) then forms one of the barriers required to suspend the well whilst the Blow Out Preventer (BOP) is removed and Xmas tree installed, at which point the upper plug (11) is broken.
E21B 23/01 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour ancrer les outils ou similaires
E21B 23/06 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour le montage des packers
E21B 23/00 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage
E21B 17/00 - Tiges ou tubes de forage; Trains de tiges souples; Tiges d'entraînement; Masses-tiges; Tiges de pompage; Tubages; Colonnes de production
Implementations described and claimed herein provide systems and methods for an integrated development optimization platform for well sequencing and unconventional reservoir management. The platform integrates key elements of unconventional development planning, such as production forecast, lease obligations, surface facilities, and economics and provides analysis and data associated with past and future field development and production. In addition, development optimization platform includes the parent-child relationship as one of the determining factors of production performance, which can provide valuable insights into the frac-hit impact and infill performance. The defensive re-fracs may also be incorporated to provide a more holistic view on project investment and field development. The development optimization platform is not only an optimization platform for well sequence and development planning, but also a reservoir management tool.
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
G06F 30/20 - Optimisation, vérification ou simulation de l’objet conçu
Implementations described and claimed herein provide apparatus and techniques for providing a seal for a polished rod. One example apparatus is a stuffing box. The stuffing box generally includes: a first flange configured to surround a polished rod; a second flange configured to surround the polished rod; a seal package disposed between the first flange and the second flang, the seal package being configured to surround and connect to the polished rod; and a flexible membrane surrounding the seal package, the flexible membrane being connected to at least a portion of the seal package.
A method of fracturing a reservoir wherein the main fracture stimulation treatment is preceded by depositing non dissolving solids into fracture tips where excessive downward or upward fracture growth is not desired, thereby controlling fracture geometry. The method thereby increases production of a fluid, such as water, oil or gas, from said reservoir, and avoids fracture propagation out of the pay-zone into undesirable zones.
The invention relates to a method and apparatus for testing a lifeboat sprinkler system without launching the lifeboat. A tank (5) of freshwater is arranged adjacent the lifeboat (1) on a marine vessel or oil platform (2). A line (24) is connected from the tank (5) to the sprinkler system of the lifeboat (1). The pressure of the water supply is arranged by means of the location of the tank (5) and/or a regulating valve (23) to mimic the pressure of the seawater that the system would access from an inlet (14) in the lifeboat hull (15) if it were launched.
B63C 9/02 - Canots, radeaux ou analogues, spécialement conçus pour le sauvetage
A62C 37/50 - Dispositifs de test ou d'indication pour déterminer l'état de marche de l'installation
B63B 79/30 - Surveillance des caractéristiques ou des paramètres de fonctionnement des navires en opération pour le diagnostic, les essais ou la prévision de l’intégrité ou des performances des navires
16.
SYSTEMS AND METHODS FOR NUCLEAR MAGNETIC RESONANCE (NMR) WELL LOGGING
Systems and method for nuclear magnetic resonance (NMR) well logging use an inversion pulse sequence with a Carr-Purcell-Meiboom-Gill (CPMG) pulse sequence to improve spin magnetization calculations. Improved Bloch equation-based calculations consider conditions where a longitudinal relaxation time and a transverse relaxation time of the hydrogen nuclei (e.g., of a subterranean hydrocarbon pool and/or water) are within an order of magnitude of pulse durations for the inversion pulse sequence and the CPMG pulse sequence. Accordingly, an NMR response to the inversion pulse sequence and the CPMG pulse can be detected and used to calculate one or more spin magnetization values with higher accuracy amplitudes. Reservoir characteristics are determined based on the one or more spin magnetization values. As such, improved well operations (e.g., selecting a drilling site, determining a drilling depth, and the like) can be performed.
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
G01N 24/12 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance double
E21B 47/13 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio
G01V 3/32 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant par résonance magnétique électronique ou nucléaire
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
G01V 3/14 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation fonctionnant par résonance magnétique électronique ou nucléaire
17.
OPTIMIZING WELL SEQUENCES IN A WELL DEVELOPMENT ZONE
A computer-implemented method for optimizing a well development sequence for a development zone includes receiving one or more inputs based on the development zone. The method can also include generating a well development plan based on the development zone and the one or more inputs. Additionally, the method can also include calculating an expected value based on the well development plan. A system and a non-transitory computer-readable medium are also provided.
G06Q 10/06 - Ressources, gestion de tâches, des ressources humaines ou de projets; Planification d’entreprise ou d’organisation; Modélisation d’entreprise ou d’organisation
E21B 43/30 - Disposition particulière des puits, p.ex. disposition rendant optimum l'espacement des puits
G06F 30/20 - Optimisation, vérification ou simulation de l’objet conçu
Systems and methods for reservoir modeling use reservoir simulation and production data to predict future production for one or more wells. The system receives static data of a reservoir or well, receives dynamic data of the reservoir or well, and processes the static data and the dynamic data to generate a reservoir model. For instance, the static data and dynamic data can be used to generate a Voronoi grid, which is used to create a spatio-temporal dataset representing time steps for a focal well and offset wells. The reservoir model can predict reservoir performance, field development, production metrics, and operation metrics. By using one or more Machine Learning (ML) models, the systems disclosed herein can determined reservoir physics in minutes and replicate the physical properties calculated by more complex and computationally intensive reservoir modeling.
222S is captured via caustic cyanide solution and quantified by analytical methods and correspond to the concentration of elemental sulfur or amorphous dithiazine. The method has particular applicability to determine where best to drill and avoid locations of high sulfur.
G01N 35/00 - Analyse automatique non limitée à des procédés ou à des matériaux spécifiés dans un seul des groupes ; Manipulation de matériaux à cet effet
G01N 33/00 - Recherche ou analyse des matériaux par des méthodes spécifiques non couvertes par les groupes
20.
SYSTEMS AND METHODS FOR DETERMINING SURFACTANT IMPACT ON RESERVOIR WETTABILITY
Implementations described and claimed herein provide systems and methods for determining surfactant impact on reservoir wettability. In one implementation, a nuclear magnetic resonance T1 measurement of a sample is obtained before surfactant imbibition is applied to the sample, and a second nuclear magnetic T2 measurement of the sample is made after forced imbibition of the surfactant. Moreover, another nuclear magnetic resonance T1 measurement (e.g., omitting surfactant imbibition) can be obtained simultaneously with the nuclear magnetic resonance T2 measurement using a twin core sample. The nuclear magnetic resonance T1 measurement and the nuclear magnetic resonance T2 measurement are captured under simulated reservoir conditions. A fluid typing map is generated using the nuclear magnetic resonance T1 measurement and the nuclear magnetic resonance T2 measurement. An impact of the surfactant on fluid producibility is determined based on the fluid typing map.
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
G01N 13/00 - Recherche des effets de surface ou de couche limite, p.ex. pouvoir mouillant; Recherche des effets de diffusion; Analyse des matériaux en déterminant les effets superficiels, limites ou de diffusion
G01R 33/20 - Dispositions ou appareils pour la mesure des grandeurs magnétiques faisant intervenir la résonance magnétique
G01R 33/44 - Dispositions ou appareils pour la mesure des grandeurs magnétiques faisant intervenir la résonance magnétique utilisant la résonance magnétique nucléaire [RMN]
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
21.
METHOD AND APPARATUS FOR ALIGNING A SUBSEA TUBING HANGER
The invention relates to the alignment of a tubing hanger (14) when installed in a subsea wellhead (11). Sensors (39a,b; 40a,b) detect when the orientation is correct and send a signal to the surface to provide positive confirmation of correct orientation, before a XMT (15) is installed on the wellhead (11) and the HP riser (31) removed, etc.
E21B 33/043 - Têtes de tubage; Suspension des tubages ou des colonnes de production dans les têtes de puits spécialement adaptées aux têtes de puits sous l'eau
E21B 33/04 - Têtes de tubage; Suspension des tubages ou des colonnes de production dans les têtes de puits
E21B 41/08 - Bases de guidage sous l'eau, p.ex. gabarits de forage; Mise à niveau de celles-ci
22.
MACHINE LOGIC MULTI-PHASE METERING USING DISTRIBUTED ACOUSTIC SENSING DATA
A method for predicting fluid fractions is provided. The method includes building, from pressure, temperature, a fluid speed parameter, speed of sound, and fluid fractions of a first fluid flow, a machine learning model programmed to estimate fluid fractions of a fluid flow as a function of at least one Distributed Acoustic Sensing ("DAS") fluid flow parameter and at least one physical characteristic of the fluid flow; receiving at least one DAS fluid flow parameter and the at least one physical characteristic of a second fluid flow; and determining, using the machine learning model, fluid fractions of the second fluid flow from at least the at least one DAS fluid flow parameter for the second fluid flow and the at least one physical characteristic of the second fluid flow.
The invention relates to a method and apparatus for performing acid stimulation of a hydrocarbon well (1), especially in a multi-lateral branched well system. In the first lateral (8), after installation of the production liner (9) with ball-activated completion equipment (10), acid stimulation is performed through drill string (21) which is introduced into the well and which seals with the production liner (9) by means of a stinger (22) and polished bore receptacle (23) before introduction of acid.
E21B 43/14 - Extraction d'un puits à horizons multiples
E21B 43/01 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits spécialement adaptés à l'extraction à partir d'installations sous l'eau
24.
SYSTEMS AND METHODS FOR COMPLETION OPTIMIZATION FOR WATERFLOOD ASSETS
Implementations described and claimed herein provide systems and methods for a framework to achieve completion optimization for waterflood field reservoirs. The proposed methodology leverages adequate data collection, preprocessing, subject matter expert knowledge-based feature engineering for geological, reservoir and completion inputs, and state-of-the-art machine-learning technologies, to indicate important production drivers, provide sensitivity analysis to quantify the impacts of the completion features, and ultimately achieve completion optimization. In this analytical framework, model-less feature ranking based on mutual information concept and model-dependent sensitivity analyses, in which a variety of machine-learning models are trained and validated, provides comprehensive multi-variant analyses that empower subject-matter experts to make a smarter decision in a timely manner.
Systems and method for predicting production decline for a target well include generating a static model and a decline model to generate a well production profile. The static model is generated with supervised machine learning using an input data set including historical production data, and calculates an initial resource production rate for the target well. The decline model is generated with a neural network using the input data and dynamic data (e.g., an input time interval and pressure data of the target well), and calculates a plurality of resource production rates for a plurality of time intervals. The system can perform multiple recursive calculations to calculate the plurality of resource production rates, generating the well production profile. For instance, the predicted resource production rate of a first time interval is used as one of inputs for predicting the resource production rate for a second, subsequent time interval.
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
G01V 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
Implementations described and claimed herein provide systems and methods for a data management tool for accessing various databases and data sources to collect or obtain data associated with a user of the tool or a member of an organization. The data management tool may include a user interface for receiving information or inputs from a user, such as a custodian of the data, to determine the various databases and/or systems from which user data may be available. To access the user data, the data management tool may communicate with various sources or gateways to sources, such as cloud-based data storage systems, operating system gateway programs, user hardware gateway programs, and the like. Various databases storing user data may be accessible through the systems or gateways and the data management tool may request such data in response to one or more instructions received via the user interface.
Systems and methods include a geological structure modeling tool for generating a geological facies model for a target well with decision tree-based models. The decision tree-based models use geographic facie class as a target variable and receives an input data set including well log data, core data, and geological facie class labels (e.g., generated by a subject matter expert (SME)). A predictive analytics model using the decision tree-based models generates, based on an input of target well data, the geological facies model to represent underlying geological structures at a candidate location (e.g., for drilling a well) or a section of a subsurface reservoir (e.g., for resource characterization). Vertical context data can be provided to the decision tree-based models and the input data set can be artificially boosted based on geological facies class label occurrences. A well development action is selected for the candidate location based on the geological facies model.
G01V 1/40 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage
G06F 30/27 - Optimisation, vérification ou simulation de l’objet conçu utilisant l’apprentissage automatique, p.ex. l’intelligence artificielle, les réseaux neuronaux, les machines à support de vecteur [MSV] ou l’apprentissage d’un modèle
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
28.
SYSTEMS AND METHODS FOR MODELING OF DYNAMIC WATERFLOOD WELL PROPERTIES
Implementations described and claimed herein provide systems and methods for dynamic waterflood forecast modeling utilizing deep thinking computational techniques to reduce the processing time for generating the forecast model and improving the accuracy of resulting forecasts. In one particular implementation, a dataset of a field may be restructured into the spatio-temporal framework and data driven deep neural networks may be utilized to learn the nuances of data interactions to make more accurate forecasts for each well in the field. Further, the generated model may forecast a single time segment and build the complete forecast through recursive prediction instances. The temporal component of the restructured data may include all or a portion of the production history of the field divided into spaced time intervals. The spatial component of the restructure data may include, within each epoch, a computed or estimated spatial relationships of all existing wells.
G06F 30/27 - Optimisation, vérification ou simulation de l’objet conçu utilisant l’apprentissage automatique, p.ex. l’intelligence artificielle, les réseaux neuronaux, les machines à support de vecteur [MSV] ou l’apprentissage d’un modèle
A downhole tubing rotator that has a housing configured into a production tubing string in a well in a reservoir, the housing being generally cylindrical with a hollow center and containing a two pole, three phase induction squirrel cage motor operatively connected to a tubing rotator configured to clamp onto a production tubing joint and rotate one or more production tubing joints (but not an entire production tubing string) when the motor is activated. An armor- protected insulated power and control cable connects the motor to a control box positioned at a surface of a reservoir and various sensors provide feedback for the unit. Methods of using this tool are also provided.
Method of monitoring produced water at each perforation or entry point by real time ion sensor deployed downhole to measure the content of water soluble ions. Methods of determining and differentiating nature of water breakthrough in oil production; such as between cycled injection water through a void space conduit, matrix swept injection water and formation water, especially as relates to offshore oil production. Real time ion sensors are deployed and when compared with known standards are used to monitor and remediate water breakthrough, prevent scale deposition, and the like.
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
E21B 43/119 - Perforateurs; Perméators - Parties constitutives, p.ex. pour localiser l'emplacement ou la direction de la perforation
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
Methods of determining if a test fluid is inert to reservoir oil at RTP, by assaying a composition, density and bubble or dew point of live oil to generate a first dataset, equilibrating a sample of live oil with a test fluid at RTP to generate an oil phase; assaying a composition, density and bubble or dew point of the oil phase to generate a second dataset; comparing the first and second datasets, wherein significant changes in the datasets indicate that the test fluid is not inert to reservoir oil at RTP. By contrast, if there are no significant changes, the test fluid is inert, and would therefore be suitable to collecting core samples at RTP. Various options for inert fluids are also provided.
Methods for reducing or reusing emissions and waste from oil and gas processing facilities are described. Specifically, emission and waste streams can be partially oxidized before being treated in a modified syngas fermentation process with parallel bioreactors to produce commodity chemicals of commercial importance while lowering greenhouse gas emissions. At least one bioreactor is online at all times, offline reactors being emptied to collect product and recharged for use.
Gravity driven reverse circulator tools are provided and methods of using same. One tool has nested pipes that when fully nested close a hole in one of the pipes, but when the drillstring is lifted, the pipes partially separate under the force of gravity to expose the hole. The other embodiment is similar, but the hole is hook shaped (hook on top as in a walking cane) and a protrusion from the other pipe fits in the hole. Thus, both lifting and rotation are needed open the tool.
E21B 21/10 - Aménagements des vannes dans les systèmes de circulation des fluides de forage
E21B 34/00 - Aménagements des vannes pour les trous de forage ou pour les puits
E21B 34/12 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des tubages ou des colonnes de production
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 37/00 - Procédés ou appareils pour nettoyer les trous de forage ou les puits
E21B 34/08 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits sensibles à l'écoulement ou à la pression du fluide obtenu
34.
FORMED PLATE CORE-IN-SHELL AND MULTI-PASS EXCHANGERS
A core-in-shell heat exchanger including a shell having an interior shell portion operable to receive a cooling fluid therein and at least one formed plate heat exchanger (FPHE) core operably arranged within the interior shell portion. The FPHE core includes an inlet coupled with a feed stream, a plurality of feed layers fluidly coupled with the inlet, and a plurality of cooling layers fluidly coupled with the interior shell portion and operable to receive at least a portion of the cooling fluid therein.
F28D 1/03 - Appareils échangeurs de chaleur comportant des ensembles de canalisations fixes pour une seule des sources de potentiel calorifique, les deux sources étant en contact chacune avec un côté de la paroi de la canalisation, dans lesquels l'autre source d avec des canalisations d'échange de chaleur immergées dans la masse du fluide avec des canalisations en forme de plaques ou de laminés
F28D 7/16 - Appareils échangeurs de chaleur comportant des ensembles de canalisations tubulaires fixes pour les deux sources de potentiel calorifique, ces sources étant en contact chacune avec un côté de la paroi d'une canalisation les canalisations étant espacées parallèlement
F28D 1/00 - Appareils échangeurs de chaleur comportant des ensembles de canalisations fixes pour une seule des sources de potentiel calorifique, les deux sources étant en contact chacune avec un côté de la paroi de la canalisation, dans lesquels l'autre source d
F28D 7/00 - Appareils échangeurs de chaleur comportant des ensembles de canalisations tubulaires fixes pour les deux sources de potentiel calorifique, ces sources étant en contact chacune avec un côté de la paroi d'une canalisation
F28D 9/00 - Appareils échangeurs de chaleur comportant des ensembles de canalisations fixes en forme de plaques ou de laminés pour les deux sources de potentiel calorifique, ces sources étant en contact chacune avec un côté de la paroi d'une canalisation
F28F 3/00 - Eléments en forme de plaques ou de laminés; Ensembles d'éléments en forme de plaques ou de laminés
35.
SYSTEMS AND METHODS OF PRESSURE TESTING COILED TUBING
Disclosed are systems and methods for pressure testing coiled tubing (CT) in a well. A CT pressure testing device may include a CT connector for attaching to a CT segment and a pressure test housing defining a pressure chamber. A rod may extend through a top opening of the pressure test housing and through the CT connector to the severed end of the CT segment. A sealing plug coupled to a bottom end of the rod may create an interface between the CT connector and the CT segment. A force activator may apply a force to a top end of the rod, causing the rod to push the sealing plug into the CT segment and tighten the interface. A pump may pressurize the pressure chamber to perform a pressure test on the sealing plug. Accordingly, the CT pressure testing device may establish a well control barrier for the well.
A solvent is dispersed into a natural gas feed at a solvent injection point to produce a mixed feed. The mixed feed contains heavy components with a potentially fouling portion that can cause obstructions in a heat exchanger. A fluid injection system can inject the solvent intermittently, for instance, based on an amount of accumulation or expected accumulation of heavy component solids in the heat exchanger. The solvent prevents the potentially fouling portion of the heavy components from freezing, melts or dissolves the accumulation, and reduces the obstructions in the heat exchanger. The fluid injection system includes a solvent supply, an optional atomizer, an injection controller, optionally one or more sensors, and/or optionally a heater. The solvent injection system can disperse the solvent onto a flow surface for the natural gas feed and/or mixed feed to form a solvent film which further reduces heavy component solids.
F25J 3/02 - Procédés ou appareils pour séparer les constituants des mélanges gazeux impliquant l'emploi d'une liquéfaction ou d'une solidification par rectification, c. à d. par échange continuel de chaleur et de matière entre un courant de vapeur et un courant de liquide
F25J 1/02 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux nécessitant l'emploi d'une réfrigération, p.ex. de l'hélium, de l'hydrogène
37.
PASSIVE PRODUCTION LOGGING INSTRUMENT USING HEAT AND DISTRIBUTED ACOUSTIC SENSING
A system for measuring fluid flow in a wellbore is provided. A probe includes at least a heater. A fiber optic cable is connected to the probe. The system is programmed to perform operations including: changing an output of the heater to thereby change a temperature of drilling fluid moving over a fiber optic cable; measuring a strain on the fiber optic cable caused by changing the temperature of the drilling fluid; preliminarily determining a velocity of the drilling fluid from the measured strain; measuring at least a second parameter of the drilling fluid; adjusting the preliminary determined velocity based on the measured at least a second parameter to yield an adjusted velocity; and determining a flow rate of the drilling fluid based on the adjusted velocity.
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
G01F 1/68 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en utilisant des effets thermiques
E21B 36/04 - Aménagements pour le chauffage, le refroidissement, l'isolation, dans les trous de forage ou dans les puits, p.ex. pour être utilisés dans les zones de permagel utilisant des réchauffeurs électriques
38.
SYSTEMS AND METHODS FOR MAPPING SEISMIC DATA TO RESERVOIR PROPERTIES FOR RESERVOIR MODELING
Implementations described and claimed herein provide systems and methods for reservoir modeling. In one implementation, an input dataset comprising seismic data is received for a particular subsurface reservoir. Based on the input dataset and utilizing a deep learning computing technique, a plurality of trained reservoir models may be generated based on training data and/or validation information to model the particular subsurface reservoir. From the plurality of trained reservoir models, an optimized reservoir model may be selected based on a comparison of each of the plurality of reservoir models to a dataset of measured subsurface characteristics.
A method of predicting production characteristics of a hydrocarbon well using time lapse geochemistry fingerprinting and using machine learning to train a reservoir model to accurately predict production characteristics. The method involves obtaining a plurality of samples from a well in a reservoir over a period of time and assigning both a time and a location identifier to each of said plurality of samples. Each of the plurality of samples is chemically fingerprinting to obtain time lapse fingerprint data and each is assessed for one or more production characteristics to obtain time lapse production characteristics.
G06F 30/13 - Conception architecturale, p.ex. conception architecturale assistée par ordinateur [CAAO] relative à la conception de bâtiments, de ponts, de paysages, d’usines ou de routes
40.
UNCONVENTIONAL WELL GAS TO OIL RATIO CHARACTERIZATION
A method of reducing gas flaring through modelling of reservoir behavior using a method of optimizing oil production from one or more well (s) in a reservoir, the method providing a model of the well, inputting well data for a one or more well(s) into the model, the well data selected from geological layers, reservoir properties, fracturing data, completion data, permeability data, geochemistry, and combinations thereof Inputting historical production data from one or more well(s) into the model, the historical data selected from PVT data, BHP, oil production rates, gas production rates and water production rates, or combinations thereof.
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 43/01 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits spécialement adaptés à l'extraction à partir d'installations sous l'eau
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
The invention relates to the use of a sleeve (9) installed in a liner or casing (1) prior to a cementing operation. Completion equipment in the liner/casing creates an irregular inner profile which can cause cement to get trapped. A wiper dart (3) passed down the casing/liner (1) may have difficulty removing all residual cement (5). By using a sleeve or insert (8) in the liner/casing (1), a smooth inner profile (9) may be created which can be cleaned relatively easily by a wiper dart. Once cementing and cleaning are complete, the sleeve (9) may be removed by acid if it is made from a dissolvable material such as aluminium.
The invention relates to a system and method for analyzing drilling fluid from a drilling rig for accessing subterranean hydrocarbons. The system and method involve analysis for chloride by replacing conventional chemical titration with electrical conductivity titration.
Disclosed are systems and methods for processing liquefied natural gas (LNG). A LNG production system may include a contaminant removal process with one or more sets of sorbent beds co-loaded with a metal sulfide sorbent and/or metal oxide sorbent. In some examples, the contaminant removal process may include one or more molecular sieve dehydrators co-loaded with a 3A or 4A sieve and a 3A or 4A sieve impregnated with silver. The one or more sets of sorbent beds may be arranged at various locations throughout the LNG production system including upstream of or downstream of heavy component removal beds having activated carbon. In some instances, the LNG production system may include a regeneration process for moving heated fluid, typically feed gas, through a first heavy component removal bed while maintaining other heavy component removal beds online to reduce downtime for the LNG production system, increase production efficiency, and decrease an amount of greenhouse gases released from defrost and flare-offs.
C10L 3/10 - Post-traitement de gaz naturel ou de gaz naturel de synthèse
B01D 53/02 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par adsorption, p.ex. chromatographie préparatoire en phase gazeuse
Methods of plugging a hydrocarbon well by using degradable plugs are provided. When the plug is no longer needed, a degradation fluid or fluids are pumped downhole under high pressure, typically via jet, such that the degradation fluid provides an erosive force to the degradable plug, thus both speeding its degradation and preventing or minimizing the leaving of solid plug material remnants in the well.
E21B 31/00 - Repêchage ou dégagement d'objets dans les trous de forage ou dans les puits
E21B 37/06 - Procédés ou appareils pour nettoyer les trous de forage ou les puits utilisant des moyens chimiques pour empêcher ou limiter le dépôt de paraffine ou de substances analogues
E21B 29/02 - Découpage ou destruction de tubes, packers, bouchons ou câbles, situés dans les trous de forage ou dans les puits, p.ex. découpage de tubes endommagés, de fenêtres; Déformation des tubes dans les trous de forage; Remise en état des tubages de puits sans les retirer du sol au moyen d'explosifs ou par des moyens thermiques ou chimiques
Method of making and using a proppant from captured carbon in either a carbon mineralization process or in a carbon nanomaterial manufacturing process, followed by treatments to ensure the quality control of the proppants so that they are suitable for use in hydraulic and other reservoir fracturing methods.
A method to reduce slugging in a pipeline, including flowing a fluid flow through a pipeline having a fluid flow path extending therethrough and determining a presence of a slug within the fluid flow path of the pipeline. Launching a chokeable pig into the fluid flow path, anchoring the chokeable pig at a predetermined location within the fluid flow path, and adjusting the pressure drop through the pipeline.
B08B 9/055 - Nettoyage de conduites ou de tubes ou des systèmes de conduites ou de tubes Élimination des bouchons utilisant des dispositifs de nettoyage introduits dans et déplacés le long des tubes déplacés le long des tubes par un fluide, p.ex. par pression de fluide ou par aspiration les dispositifs de nettoyage ayant, ou pouvant épouser, la forme de la section des tubes, p.ex. hérissons ou chariots
B08B 9/02 - Nettoyage de conduites ou de tubes ou des systèmes de conduites ou de tubes
B08B 9/027 - Nettoyage de conduites ou de tubes ou des systèmes de conduites ou de tubes Élimination des bouchons
B08B 9/04 - Nettoyage de conduites ou de tubes ou des systèmes de conduites ou de tubes Élimination des bouchons utilisant des dispositifs de nettoyage introduits dans et déplacés le long des tubes
F16L 55/34 - Moyens de propulsion autonomes portés par le hérisson ou le chariot le hérisson ou le chariot étant déplacé pas à pas
F16L 101/00 - Utilisation ou application des hérissons ou des chariots
47.
SYSTEMS AND METHODS FOR PREDICTIVE RESERVOIR DEVELOPMENT
Implementations described and claimed herein provide systems and methods for predictive reservoir development. In one implementation, asset data is received for a particular asset, with the particular asset corresponding to a particular reservoir. A model of the particular asset is generated based on the asset data. Asset intelligence is generated for the particular asset at an asset life cycle stage based on the model, and development of the particular reservoir is optimized using the asset intelligence.
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
48.
METHOD AND APPARATUS FOR USE IN PLUG AND ABANDON OPERATIONS
The invention relates to the use of a casing or liner (3) with pre-formed, selectively openable apertures (5), in plug and abandon operations at the end of life of a hydrocarbon well. The casing or liner (3) is installed at the start of the well's life and the apertures (5) are provided over a length of the casing/liner above the reservoir where a permanent plug would normally be formed when the well is abandoned at the end of its life. Associated with the apertures are sliding sleeve closure members (6) which are designed to remain operational over the 20-30 year lifetime of the well.
C09K 8/42 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits
Implementations described and claimed herein provide systems and methods for increasing accuracy of firing perforating charges in an oil well casing. In one implementation, a body of an orientation device has a first portion and a second portion. An opening extends through a center of the body from a first lateral surface to a second lateral surface, and the opening is configured to receive a perforating gun string. An outer perimeter surface extends about the center of the body from the first lateral surface to the second lateral surface. The outer perimeter surface has a first shape associated with the first portion and a second shape associated with the second portion. The second shape forms a base portion configured to maintain the perforating gun string in an orientation by preventing rotation of the perforating gun string. The orientation corresponds to a predetermined perforating charge direction of the perforating gun string.
The invention relates to an improved method for installing a dual/multiple lateral well where the overburden casing is relatively narrow. A tapered liner is employed for the first lateral. The liner has a narrow production section (109) and a larger diameter section (104) allowing a liner (116) for Lateral B to be run through it, after a window (114) has been milled. The system saves a drilling run and a liner installation run, as well as avoiding the need to set a liner hanger in Lateral A.
Water hammer is oscillatory pressure behavior in a wellbore resulting from the inertial effect of flowing fluid being subjected to an abrupt change in velocity. It is commonly observed at the end of large-scale hydraulic fracturing treatments after fluid injection is rapidly terminated. Factors affecting treatment-related water hammer behavior are disclosed and field studies are introduced correlating water hammer characteristics to fracture intensity and well productivity.
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
G01V 1/137 - Production d'énergie sismique en utilisant des fluides comme moyens d'entraînement hydrauliques, p.ex. en utilisant des fluides à haute pression dont les fluides s'échappent du générateur d'une manière pulsée, p.ex. pour produire des explosions
An economical process in which cement sheath integrity, perforation cluster spacing and frac plug integrity can be assessed for every frac stage, potentially leading to improvements in stimulation, completion, cementing and drilling practices. It is based on analyzing wellbore pressure responses occurring at key segments of the wireline pump-down and perforating operation and correlating the results among multiple frac stages and wells in a field or play. A special requirement is that the frac ball (ball check) is inserted in the frac plug and pumped to seat prior to performing perforating operations. A complementary benefit of this process is that selectively establishing injectivity in the most distant perforation cluster can be used to establish inhibited HCl acid (wireline acid) coverage across all perforation intervals for uniform reduction in near-wellbore tortuosity.
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 47/008 - Surveillance des systèmes de pompe de fond de trou, p.ex. pour la détection de conditions appelées "cognement sur le fluide"
E21B 47/06 - Mesure de la température ou de la pression
A uniform oleophobic or oleo- and hydrophobic film is applied to equipment used in the petroleum industry. The methods can be applied to new equipment or equipment pulled from service, with the application process being performed in a controlled environment or the field. Applicator tools for efficient delivery and application of cleaners, solvents, and films used in the coating process are also described.
C10G 45/02 - Raffinage des huiles d'hydrocarbures au moyen d'hydrogène ou de composés donneurs d'hydrogène pour éliminer des hétéro-atomes sans modifier le squelette de l'hydrocarbure mis en œuvre et sans craquage en hydrocarbures à point d'ébullition inférieur; Hydrofinissage
C10G 7/00 - Distillation des huiles d'hydrocarbures
C10G 75/04 - Inhibition de la corrosion ou des salissures dans des appareils de traitement ou de conversion des huiles d'hydrocarbures, en général par addition d'agents antisalissures
54.
METHOD AND APPARATUS FOR MILLING A WINDOW IN CASING
A process is described for milling a window in the casing (2) of an oil or gas producing well, for example in order to drill a lateral well branching off from the main well. A wireline milling tool is first used, in a relatively low cost operation, to create a small window (14) or notch in the casing (2). Provided a small window (14) or notch can be created successfully, an expensive heavy duty coil tubing milling operation can then be conducted to create the full window, some 4-6 feet in length. Previous attempts to create a full window using wireline tools have encountered difficulties due to there being no circulating drilling fluid to remove metal swarf and due to the need for the tool to be supported by casing during the milling operation, when the integrity of the casing is being compromised by drilling the window. The proposed wireline tool has an actuator (4) with relatively small stroke length and a relatively small container (8) to manage the swarf produced by the milling process.
E21B 29/06 - Découpage de fenêtres, p.ex. découpage directionnel de fenêtres en vue d'opérations impliquant des sifflets-déviateurs
E21B 23/00 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage
E21B 23/01 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour ancrer les outils ou similaires
E21B 29/00 - Découpage ou destruction de tubes, packers, bouchons ou câbles, situés dans les trous de forage ou dans les puits, p.ex. découpage de tubes endommagés, de fenêtres; Déformation des tubes dans les trous de forage; Remise en état des tubages de puits sans les retirer du sol
E21B 7/00 - Procédés ou matériels particuliers pour le forage
A method for improving the efficiency of liquefied natural gas (LNG) liquefaction including receiving a gas feed stream at an LNG facility, condensing the gas feed stream into an LNG product stream, removing nitrogen from the LNG product stream via a nitrogen rejection unit coupled with the LNG facility to produce a final LNG product stream, analyzing one or more process samples taken throughout the liquefaction and nitrogen removal processes via mass spectrometry, and adjusting one or more aspects of the LNG processing system based on the analysis.
F25J 3/00 - Procédés ou appareils pour séparer les constituants des mélanges gazeux impliquant l'emploi d'une liquéfaction ou d'une solidification
C01B 3/32 - Production d'hydrogène ou de mélanges gazeux contenant de l'hydrogène par réaction de composés organiques gazeux ou liquides avec des agents gazéifiants, p.ex. de l'eau, du gaz carbonique, de l'air
C07C 7/12 - Purification, séparation ou stabilisation d'hydrocarbures; Emploi d'additifs par adsorption, c. à d. purification ou séparation d'hydrocarbures à l'aide de solides, p.ex. à l'aide d'échangeurs d'ions
Methods for preventing elemental sulfur deposition from a hydrocarbon fluid is disclosed. A mercaptan is added to a hydrocarbon fluid that has elemental sulfur and reacted with the elemental sulfur to produce a disulfide and hydrogen sulfide. Amines and/or surfactants can assist with the process. Secondary reactions between the disulfide and the elemental sulfur result in a polysulfide and a solvated sulfur- disulfide complex. The disulfide, hydrogen sulfide, polysulfide and solvated sulfur- disulfide complex do not deposit, and can optionally be removed.
C23F 11/00 - Inhibition de la corrosion de matériaux métalliques par application d'inhibiteurs sur la surface menacée par la corrosion ou par addition d'inhibiteurs à l'agent corrosif
C23F 14/02 - Prévention de l'entartrage ou des incrustations dans les appareils destinés à chauffer des liquides à des fins physiques ou chimiques par des moyens chimiques
C23G 5/024 - Nettoyage ou dégraissage des matériaux métalliques par d'autres méthodes; Appareils pour le nettoyage ou le dégraissage de matériaux métalliques au moyen de solvants organiques au moyen de solvants organiques contenant des hydrocarbures
The invention relates to the drilling of subsurface oil and gas wells and the installation of subsurface equipment (11). A lifting vessel 7 brings heavy equipment such as Xmas trees or manifolds and wet parks this equipment (11) on the seafloor (5) during good weather when the significant wave height is low. The equipment (11), once it is underwater, has much lower weight and may easily be moved into place onto a wellhead (10) at an appropriate time using lower capacity lifting gear. The timing of this operation is much less sensitive to weather conditions because the equipment does not need to pass through the splash zone (sea surface). This makes for efficient use of expensive drilling rig time, and allows for acceleration of production of first wells on the template as critical heavy lifts could not else be done until rig has left the location.
E21B 19/00 - Manipulation de tiges, tubages, tubes ou autre objets analogues à l'extérieur du trou de forage, p.ex. dans la tour de forage; Appareils pour faire avancer les tiges ou les câbles
58.
METHOD FOR THE DISSOLUTION OF AMORPHOUS DITHIAZINES
The invention relates to the dissolution of amorphous dithiazine (a-DTZ)or polythioformaldehyde or other polymeric by-products of the treatment of hydrocarbon products (a-DZT) to remove them from surfaces. These are solids that build up on surfaces of processing plant and are resistant to most chemical treatment. The treatment requires treating the surface with an effective amount of a mercaptan or an amine. Surfactants to keep the dissolved a-DTZ or other components from redepositing elsewhere are also described, as is the use of hydrogen sulfide to add in removal by mercaptans.
A method of raising the pressure of a natural gas stream (9) on an oil or gas producing installation (1) comprises using an existing high pressure gas stream (13) at the installation to drive the turbine (12) of a turbo-compressor unit (10). It is common on oil and gas producing installations to require the pressure of a gas stream to be increased by a small amount, e.g. to allow flare gas to be fed to the production gas train thereby avoiding flaring. This system may replace the current practice of using ejectors for this purpose since ejectors are very inefficient. However, it can be advantageous to feed the output of the turbine side (12) of the turbo-compressor (10) to an ejector which can give a small pre-boost to the low pressure natural gas (9) before it enters the compressor side (11) of the turbo-compressor (10).
C07C 2/80 - Procédés faisant intervenir des moyens électriques
C07C 2/76 - Préparation d'hydrocarbures à partir d'hydrocarbures contenant un plus petit nombre d'atomes de carbone par condensation d'hydrocarbures avec élimination partielle d'hydrogène
Production equipment and methods which reduce "gray" or off-specification production and improve central processing facility (CPF) efficiency. The process is a combination of unit operations (heat exchange, pumping, and separation) to produce an on-spec gas product, an on-spec condensate product, and/or on-spec oil product. It does so by placing the feed under pressure and heating it to the point that it can be vaporized and separated. The blended components are modulated dependent upon the composition of the produced fluids, produced gas, and off-specification fluid to efficiently produce on-specification products.
C10G 67/16 - Traitement des huiles d'hydrocarbures, uniquement par au moins un procédé d'hydrotraitement et au moins un procédé de raffinage en l'absence d'hydrogène uniquement par plusieurs étapes en parallèle
C10G 69/00 - Traitement des huiles d'hydrocarbures par au moins un procédé d'hydrotraitement et au moins un autre procédé de conversion
The invention relates to a method of conducting a perf wash cement ("P/W/C") abandonment job in an offshore oil or gas well annulus, in particular the washing or cementing operation using a rotating head with nozzles dispensing wash fluid or cement at pressure. A new design of bottom hole assembly is proposed in which the cementing tool has a relatively large diameter in order to optimize pressure whilst the wash tool has a relatively small diameter. The wash process, for a number of reasons, appears to be less sensitive to tool diameter and making the wash tool smaller reduces the overall risk of stuck pipe. (Figure 2(a))
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
E21B 33/10 - Etanchement ou bouchage des trous de forage ou des puits dans le trou de forage
E21B 37/00 - Procédés ou appareils pour nettoyer les trous de forage ou les puits
E21B 37/08 - Nettoyage sur place des filtres de fond de trou, des tamis, ou des filtres à gravier
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
The invention relates to a cementing tool for use in oil and gas well decommissioning operations, in particular so called perforate, wash and cement procedures. The tool (1) is designed for running in a well on drill string and for jetting cement through previously formed perforations in the casing (10) to fill the outer annulus (9) with cement. The tool (1) has a cylindrical wall (3) which is formed from steel (11) and elastomeric (5) elements, whereby it is expandable between a first diameter in which it may be run down the well and a second, larger diameter deployed during cementing operations. (Figure 2).
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
E21B 33/05 - Têtes de cimentation, p.ex. comportant des aménagements pour introduire les bouchons de cimentation
E21B 33/127 - Packers; Bouchons à manchon gonflable
E21B 33/128 - Packers; Bouchons avec un organe dilaté radialement par pression axiale
E21B 33/138 - Plâtrage de la paroi du trou de forage; Injections dans la formation
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
The invention relates to a cementing tool and method for setting a cement plug. Instead of the conventional "balanced plug", the technique involves pumping cement whilst pulling and rotating the tool. The cementing tool includes nozzles for jetting cement which are located in a relatively narrow region of the tool and a larger diameter choke region proximal of the nozzles. The end of the tool is closed off and tapered. The tool is passed down the well to a location where it is desired to set a plug, then cement is injected whilst rotating and withdrawing the tool. The jets of cement help displace existing fluid in the well thereby reducing mixing of the existing fluid with the cement. The choke region increases the flow energy, whilst the tapered end helps prevent disruption to the cement as the tool is withdrawn.
E21B 33/16 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage utilisant des bouchons pour isoler la charge de ciment; Bouchons à cet effet
The invention relates to a method and apparatus for remediating damaged casing or liner in a hydrocarbon well, e.g. caused by collapsed formation. Damaged liner is milled away and a straddle joint (20) located in the exposed ends of liner (8,9), bridging the gap between them and restoring most of the inner diameter. The straddle joint (20) includes cement ports (25) through which cement may be injected into any cavity (4) in the rock surrounding the straddle joint (20), thereby supporting the rock and helping to prevent further collapse.
Implementations described and claimed herein provide systems and methods for extending reach in a wellbore in oil well operations. In one implementation, a first coiled tubing string has a first coil interior surface, and a second coiled tubing string is disposed within the first coiled tubing string and has a second coil exterior surface. An annulus is defined by the first coil interior surface and the second coil exterior surface. The annulus is sealed proximal to a top end of the first coiled tubing string via a first seal and sealed proximal to a bottom end of the first coiled tubing string via a second seal. A fluid is sealed within the annulus at a pressure.
Scavenging chemicals used in mitigation treatments of hydrogen sulfide in hydrocarbon streams often continue to react and form polymers that foul the processing system. Disclosed herein are methods for determining if a scavenging chemical mitigator, or its reaction or degradation product, will polymerized during or after mitigation treatments. This information allows for the optimization of mitigation treatments that pre-emptively control or prevent polymer formation. Such pre-emption measures reduce the cost and time related to remedial actions to treat polymer-fouled equipment.
A high pressure core chamber for use in collecting pressurized core samples from a reservoir is equipped with at least two high pressure access valves, allowing the core chamber to also function as a vessel for various high pressure experiments. In some embodiments, the core chamber is also equipped with a heater, allowing high pressure, high temperature experiments, and thus duplicating reservoir conditions. Various assays using the core chamber are also described.
E21B 25/02 - Appareils pour recueillir ou retirer des carottes intactes, p.ex. tubes carottiers, extracteurs de carottes le réceptacle de la carotte pouvant être introduit dans le trou de forage ou en être enlevé sans retirer le tube de forage
E21B 25/10 - Moyens de retenue ou de sectionnement des carottes une fois formées
Implementations described and claimed herein provide systems and methods for monitoring real-time drilling parameters. In one implementation, one or more measured parameters including at least a mud weight (MW) of a drilling fluid within a wellbore are received. At least one of a coefficient of performance (COP) cuttings transport ratio, a COP bit equivalent circulation density (ECD), a COP Wilcox ECD, a reverse circulation ECD, or a COP kill mud density (KMD) are determined from the one or more measured parameters. The at least one of the coefficient of performance (COP) cuttings transport ratio, the COP bit equivalent circulation density (ECD), the COP Wilcox ECD, the reverse circulation ECD, or the COP KMD are displayed. An alert is generated when the at least one of the COP cuttings transport ratio, the COP bit ECD, the COP Wilcox ECD, the reverse circulation ECD, or the COP KMD exceeds a predetermined threshold.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 45/00 - Mesure du temps de forage ou de la vitesse de pénétration
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
Implementations described and claimed herein provide systems and methods for breaking cement within an annulus of a wellbore. In one implementation, an annulus cement breaking system includes a cement compression tool operable to be disposed within an inner bore of a casing having a longitudinal length. The casing is disposed within a wellbore formed in a subterranean formation having a cement layer disposed within an annulus formed between the casing and the subterranean formation. One or more actuation elements are coupled with the cement compression tool, and the one or more actuation elements are operable to engage the inner bore. The one or more actuation elements are transitionable between an unactuated state and an actuated stated. The actuated state operable to engage the inner bore of the casing, thereby radially expanding the casing and compressing the cement layer.
E21B 29/02 - Découpage ou destruction de tubes, packers, bouchons ou câbles, situés dans les trous de forage ou dans les puits, p.ex. découpage de tubes endommagés, de fenêtres; Déformation des tubes dans les trous de forage; Remise en état des tubages de puits sans les retirer du sol au moyen d'explosifs ou par des moyens thermiques ou chimiques
E21B 29/10 - Remise en état des tubages de puits, p.ex. redressage
E21B 43/10 - Mise en place de tubages, filtres ou crépines dans les puits
E21B 43/112 - Perforateurs avec organes de perforation extensibles, p.ex. actionnés par des moyens fluides
E21B 43/116 - Perforateurs à balles ou à charge profilée
A drill string system includes a drill bit disposed at a distal end of a drill string. A clutch is coupled with the drill bit. A mud motor is coupled to the clutch, and the mud motor is operable to receive a drilling fluid therein and transfer torque to the drill bit through the clutch. The clutch disengages upon application of a torque exceeding a predetermined threshold.
A suspension head (11) is provided for connection between a high pressure riser (8) and a subsea wellhead (9), for use in drilling and completion operations in which a jack-up rig (1) is employed and a blowout preventer (7) is installed on the jack-up rather than on the wellhead. The use of the suspension head (11) offers improved safety and convenience, allowing the riser (8) to be isolated from the wellhead (9) in emergencies or for carrying out certain operations which would otherwise require the installation of a temporary plug.
The invention relates to a method and system for monitoring strain data on a subsea wellhead and associated tubing especially during a drilling or completion operation when the wellhead is connected via a riser to a drilling rig. The bending stresses on the wellhead assembly can be modelled and monitored, based on strain data from strain gauges attached to the conductor, surface casing and possibly also inner tubing. The strain gauges are located where maximum bending stresses occur, at around seafloor level. Data from the strain gauges is transmitted by radio to a receiver unit on the template, from which it may either be transmitted to the surface or stored and retrieved by divers or subsea vehicles.
The invention relates to the checking of pressure in various void or cavities of a wellhead or Xmas tree of an active hydrocarbon well. Pressure sensing plugs (51) are provided at various points in the wellhead/Xmas tree (50). Each plug incudes a pressure transducer (39) and associated electronics allowing the pressure to be read by a hand held reader device. Alternatively, the plugs may include a radio transmitter for transmitting sensed data to a monitoring system via a wifi network or similar to a central control room on a hydrocarbon producing platform. In this way, the pressure at the various point in the wellhead/Xmas tree may be checked without exposing the cavity or void.
E21B 34/02 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits
E21B 47/06 - Mesure de la température ou de la pression
E21B 47/13 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio
74.
IMPROVED HYDROCARBON PRODUCTION THROUGH ACID PLACEMENT
The invention relates to the completion of hydrocarbon wells using acid. It is known to create cavities in the formation using acid, which then collapse to leave a highly permeable region for production of hydrocarbons. An issue with this technique can be that the wellbore/tubing adjacent the cavity is damaged. The invention involves passing thin conduits through the formation transversely of the main wellbore, through which conduits acid is delivered to create unstable cavities at a distance from the main wellbore thereby stimulating production without risking instability of the main wellbore.
C09K 8/68 - Compositions à base d'eau ou de solvants polaires contenant des composés organiques
C09K 8/70 - Compositions pour la formation de crevasses ou de fractures caractérisées par leur forme ou par la forme de leurs composants, p.ex. mousses
C09K 8/80 - Compositions pour renforcer les fractures, p.ex. compositions pour agents de soutènement utilisés pour maintenir les fractures ouvertes
The invention relates to the drilling of wells in rock and hydrocarbon formations. Drilling is performed with a drill string having a bottom hole assembly (BHA) and drill bit. Drilling mud is circulated during drilling. A valved inlet port is provided in the BHA which, in the event of a pack-off, opens and allows drilling mud to enter an internal space in the BHA to relieve pressure. An outlet port at the proximal end of the BHA may be provided to allow he mud to flow back into the annulus around the drill string. In this way, rapid build-up of pressure is avoided and the driller has more time to respond to the pack-off.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 17/18 - Tubes comprenant plusieurs passages pour les fluides
E21B 21/10 - Aménagements des vannes dans les systèmes de circulation des fluides de forage
E21B 21/12 - Procédés ou appareils pour nettoyer les trous de forage par jet de fluide, p.ex. en utilisant l'air d'échappement du moteur utilisant des tubes de forage comprenant plusieurs passages pour les fluides, p.ex. systèmes en circuit fermé
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 34/08 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits sensibles à l'écoulement ou à la pression du fluide obtenu
The invention relates to the monitoring of pressure in production tubing (3) and/or annuli (7, 9) of an oil or gas well. Patterns of pressure in tubing and/or annuli may be indicative of a fault or a condition which requires attention. Patterns may also be recognized that, e.g. based in rates of change, may indicate that a fault may be going to occur in the future. Pressure differences between tubing and annuli or between different annuli may be monitored in the same way.
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
The invention relates to the introduction of pressurized fluid, e.g. acid, into a subsea well directly from a vessel (33). A fluid injection assembly (20) is fitted to the top of a subsea Xmas tree (3), the assembly (20) including fail safe closed valve (21) which is controlled via a hydraulic line (31) from the vessel. The hose and assembly and valve are designed with an internal bore allowing a large diameter ball to be dropped (required for acid stimulation). The subsea control module (8) on the Xmas tree is controlled from the producing platform.
E21B 43/27 - Procédés pour activer la production par formation de crevasses ou de fractures par emploi de produits chimiques érosifs, p.ex. d'acides
E21B 33/076 - Têtes de puits; Leur mise en place comportant des dispositions pour introduire des objets dans les puits ou pour les en retirer, ou pour y introduire des fluides spécialement adaptés aux installations sous l'eau
E21B 33/068 - Têtes de puits; Leur mise en place comportant des dispositions pour introduire des objets dans les puits ou pour les en retirer, ou pour y introduire des fluides
The invention relates to the fluid treatment, such as acid stimulation, of a subsea hydrocarbon well via a subsea wellhead/Christmas tree. Fluid is delivered directly to the subsea wellhead from a pumping vessel. Control of the delivery of fluid is from the pumping vessel via a fail-safe close valve in the delivery line. The Christmas tree subsea module is controlled directly from a host platform via a subsea cable, whilst a radio data link between the vessel and host platform provides communication of downhole data to the pumping vessel during the operation.
Implementations described and claimed herein provide systems and methods for removing nitrogen during liquefaction of natural gas. In one implementation, a nitrogen rejection unit is used in an LNG facility to remove nitrogen from natural gas during an LNG liquefaction process. The nitrogen rejection unit contains at least two columns and at least one 3-stream condenser, 2-stream condenser or a two 2-stream condenser.
F25J 3/06 - Procédés ou appareils pour séparer les constituants des mélanges gazeux impliquant l'emploi d'une liquéfaction ou d'une solidification par condensation partielle
F25J 3/00 - Procédés ou appareils pour séparer les constituants des mélanges gazeux impliquant l'emploi d'une liquéfaction ou d'une solidification
F25J 3/02 - Procédés ou appareils pour séparer les constituants des mélanges gazeux impliquant l'emploi d'une liquéfaction ou d'une solidification par rectification, c. à d. par échange continuel de chaleur et de matière entre un courant de vapeur et un courant de liquide
80.
INTEGRATED MACHINE LEARNING FRAMEWORK FOR OPTIMIZING UNCONVENTIONAL RESOURCE DEVELOPMENT
Implementations described and claimed herein provide systems and methods for developing resources from an unconventional reservoir. In one implementation, raw reservoir data for the unconventional reservoir is obtained. The raw reservoir data includes geology data, completion data, development data, and production data. The raw reservoir data is transformed to transformed data. The raw reservoir data is transformed to the transformed data based on a transformation from a set of one or more raw variable to a set of one or more transformed variables. The set of one or more transformed variables is statistically uncorrelated. Resource development data is extracted from the transformed data. Performance analytics are generated for the unconventional reservoir using the resource development data. The performance analytics are generated through ensemble machine learning. The unconventional reservoir is developed based on the performance analytics.
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
G01V 1/44 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs et des récepteurs situés dans le même puits
81.
NEUTRON ABSORBER-DOPED DRILLING MUD AND CHARACTERIZATION OF NATURAL FRACTURES
Gadolinium- or boron-doped drilling mud is used during drilling so that it will penetrate all natural cracks in the formation that intersect with the wellbore. Once cased, cemented and washed, die doped mud will only be in the fractures. Pulsed neutron logging is performed, and natural fractures thereby characterized.
G01V 5/10 - Prospection ou détection au moyen de radiations nucléaires, p.ex. de la radioactivité naturelle ou provoquée spécialement adaptée au carottage en utilisant des sources de radiation nucléaire primaire ou des rayons X en utilisant des sources de neutrons
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
E21B 47/11 - Localisation des fuites, intrusions ou mouvements du fluide utilisant la radioactivité
82.
SYSTEMS AND METHODS FOR ANALYZING CASING BONDING IN A WELL USING DIFFERENTIAL SENSING
Implementations described and claimed herein provide systems and methods for isolation detection. In one implementation, an acoustic signal is obtained. The acoustic signal is captured at a set of acoustic receivers deployed in a structure in a subterranean surface. A differential acoustic signal is produced from the acoustic signal captured at the set of acoustic receivers. A symmetry within a portion of the structure is determined based on a value of the differential acoustic signal. At least one isolation region is detected within the structure based on the symmetry.
G01V 1/44 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs et des récepteurs situés dans le même puits
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
G01V 1/00 - Séismologie; Prospection ou détection sismique ou acoustique
G01V 1/40 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage
Implementations described and claimed herein provide systems and methods for isolation detection. In one implementation, an axial acoustic signal is obtained. The axial acoustic signal is captured using an axial sensor deployed in a structure in a subterranean surface. The axial acoustic signal is separated into a first wave region and a second wave region by applying velocity filtering. An axial symmetry of a portion of the structure is determined based on at least one of the first wave region or the second wave region.
Implementations described and claimed herein provide systems and methods for isolation detection. In one implementation, recorded data is obtained. The recorded data includes radial acoustic waves transmitted and received using a radial sensor of an acoustic logging tool deployed in a wellbore. Clockwise waves are separated from counterclockwise waves by converting the recorded data from a time domain to a frequency domain. The clockwise waves are shifted into shifted clockwise waves, and the counterclockwise waves are shifted into a shifted counterclockwise waves. A forward wave is generated by combining the shifted clockwise waves, and a reflected wave is generated by combining the shifted counterclockwise waves. One or more isolation regions are identified in the wellbore using the forward wave and the reflected wave.
E21B 47/14 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
85.
SYSTEMS AND METHODS FOR DETERMINING WELL CASING ECCENTRICITY
Implementations described and claimed herein provide systems and methods for isolation detection. In one implementation, a radial acoustic log is obtained. The radial acoustic log is captured using a radial sensor of an acoustic logging tool deployed within a first structure. The first structure disposed within a second structure in a subterranean environment. A radial symmetry is determined using the radial acoustic log. An eccentricity of the first structure relative to the second structure is determined based on the radial symmetry.
Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a dry feed gas is received. The dry feed gas is chilled with clean vapor from a heavies removal column to form a chilled feed gas. The chilled feed gas is partially condensed into a vapor phase and a liquid phase. The liquid phase retains freezing components. The freezing components are extracted using a reflux stream in the heavies removal column. The freezing components are removed as a condensate. The vapor phase is compressed into a clean feed gas. The clean feed gas is free of the freezing components for downstream liquefaction.
F25J 1/00 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux
F25J 3/00 - Procédés ou appareils pour séparer les constituants des mélanges gazeux impliquant l'emploi d'une liquéfaction ou d'une solidification
F25J 3/06 - Procédés ou appareils pour séparer les constituants des mélanges gazeux impliquant l'emploi d'une liquéfaction ou d'une solidification par condensation partielle
F25J 5/00 - Aménagements des échangeurs de froid ou accumulateurs de froid dans les installations de séparation ou de liquéfaction
Disclosed herein are systems and processes for removing heavies during the liquefaction of a natural gas. The processes include dissolving the heavies in the natural gas by adding external natural gas liquid (NGL), followed by a staged removal of the natural gas liquid (NGL) and dissolved heavies.
B01D 3/26 - Colonnes de fractionnement dans lesquelles vapeur et liquide s'écoulent au contact l'un de l'autre, ou dans lesquelles le fluide est pulvérisé dans la vapeur, ou dans lesquelles un mélange de deux phases est admis à passer dans un seul sens
B01D 3/34 - Distillation ou procédés d'échange apparentés dans lesquels des liquides sont en contact avec des milieux gazeux, p.ex. extraction avec une ou plusieurs substances auxiliaires
Robust methods for quantitating the amount of elemental sulfur in a fluid whereby a caustic solution is mixed with the fluid, and the elemental sulfur present in the fluid reacts to form a colored solution that can be compared to a series of standards. The methods can be performed in a laboratory or the field and allow for real time feedback. Once the concentration of the elemental sulfur is known, appropriate methods of treatment can proceed. Test kits for performing the methods in the field are also described.
Various aspects described herein relate to a system that utilized deep learning and neural networks to estimate/predict an amount of natural resource production in a well given a set of parameters indicative of physical changes to the well. In one aspect, a virtual flow meter includes memory having computer-readable instructions stored therein and one or more processors configured to execute the computer-readable instructions to receive one or more input parameters indicative of physical changes to at least one well; apply the one or more input parameters to a trained neural network architecture; and determine one or more outputs of the trained neural network architecture, the one or more outputs corresponding to predicted fluid output of the at least one well.
Methods of assessing internal features of oilfield equipment including elbows, connections, valves, branches, olets, and other structures include the methods and apparatus for determining the physical geometric boundaries of oilfield structures using an automated articulating arm with an external laser scanner and an ultrasonic probe.
A system and method of detecting subsurface karst features includes receiving surface mapping data. A potential surface pad location can be identified in view of the surface mapping data. A resistivity survey for the potential surface pad location can be designed. The resistivity survey can include at least one long line extending through a surface hole for each of one or more wellbores in the potential surface pad location, and a short line extending through the surface hole of one of the one or more wellbores, each short line intersecting the long line substantially at the surface hole of one of the one or more wellbores. High resistivity areas exceeding approximately 150 Ohm per meter can be identified as sub surface karst features within the resistivity survey.
G01V 11/00 - Prospection ou détection par des méthodes combinant des techniques spécifiées dans les groupes
G01V 1/00 - Séismologie; Prospection ou détection sismique ou acoustique
G01V 3/08 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation fonctionnant au moyen de champs magnétiques ou électriques produits ou modifiés par les objets ou les structures géologiques, ou par les dispositifs de détection
G01V 7/00 - Mesure de champs ou d'ondes de gravitation; Prospection ou détection gravimétrique
G01S 17/88 - Systèmes lidar, spécialement adaptés pour des applications spécifiques
G01S 17/89 - Systèmes lidar, spécialement adaptés pour des applications spécifiques pour la cartographie ou l'imagerie
92.
DETERMINATION OF RHEOLOGY OF FLUID IN AN OIL OR GAS WELL
The invention relates to the measurement of the rheology of drilling fluid down a hydrocarbon well in real time during operations. A sensor device comprising a pipe rheometer with multiple diameters is installed in a bottom hole assembly tool, such that a portion of the total flow of drilling fluid passes through it. In this way the rheological properties of the drilling fluid can be determined under the high pressures and elevated temperatures encountered downhole.
A method and system for removing wax deposits from a wellbore and other oil production and processing equipment using a wax removal surfactant having at least 1% alkyl poly glycoside (APG), at least 0.5% ethoxy lated alcohol (AE) or alcohol ethoxy sulfates (AES), and at least 1% saturated alcohol, and optionally comprising D-Limonene, wherein the wax removal surfactant solution forms a Winsor Type III or Type IV microemulsion with water and wax.
C09K 8/28 - Compositions aqueuses pour le forage des puits Émulsions huile-dans-l'eau contenant des additifs organiques
C09K 8/52 - Compositions pour éviter, limiter ou éliminer les dépôts, p.ex. pour le nettoyage
C09K 8/524 - Compositions pour éviter, limiter ou éliminer les dépôts, p.ex. pour le nettoyage les dépôts organiques, p.ex. paraffines ou asphaltènes
E21B 37/06 - Procédés ou appareils pour nettoyer les trous de forage ou les puits utilisant des moyens chimiques pour empêcher ou limiter le dépôt de paraffine ou de substances analogues
Method of condition monitoring an industrial asset is described. The method involves collecting one or more of process variables associated with the industrial asset. Determining abnormal operating conditions for the one or more process variables. Providing a graphic monitoring of the industrial asset, wherein the graphic monitoring visually represents part or portion of the industrial asset operating in abnormal operating conditions.
G06F 19/00 - Équipement ou méthodes de traitement de données ou de calcul numérique, spécialement adaptés à des applications spécifiques (spécialement adaptés à des fonctions spécifiques G06F 17/00;systèmes ou méthodes de traitement de données spécialement adaptés à des fins administratives, commerciales, financières, de gestion, de surveillance ou de prévision G06Q;informatique médicale G16H)
The invention relates to injection of water into a hydrocarbon reservoir to assist recovery of the hydrocarbons. It is often desirable to use produced water (PW) for injection, often there is insufficient PW and the supply of PW needs to be supplemented. It is also often desirable to reduce the salinity of the PW. The invention contemplates an osmotic process in which the high salinity PW acts as a draw solution and lower salinity seawater is used as a feed. The PW supply may be pressurized in preparation for injecting it into the reservoir and then passed through an osmotic membrane element, whilst low pressure seawater is passed through the osmotic membrane element on the other side. The lower salinity of the seawater leads to an osmotic pressure difference across the membrane causing a pure water permeate to enter the PW stream, whilst maintaining the pressure of the PW stream.
C02F 1/44 - Traitement de l'eau, des eaux résiduaires ou des eaux d'égout par dialyse, osmose ou osmose inverse
C02F 103/08 - Eau de mer, p.ex. pour le dessalement
C09K 8/58 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement
Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a feed gas is received and partially condensed into a two-phase stream by expanding the feed gas. A liquid containing fouling components is removed from the two-phase stream. A vapor generated from the two-phase stream is compressed into a compressed feed gas. The compressed feed gas is directed into a feed chiller heat exchanger. The compressed feed gas is free of the fouling components.
Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a solvent is injected into a feed of natural gas at a solvent injection point. A mixed feed is produced from a dispersal of the solvent into the feed of natural gas. The mixed feed contains heavy components. A chilled feed is produced by chilling the mixed feed. The chilled feed includes a vapor and a condensed liquid. The condensed liquid contains a fouling portion of the heavy components condensed by the solvent during chilling. The liquid containing the fouling portion of the heavy components is separated from the vapor. The vapor is directed into a feed chiller heat exchanger following separation of the liquid containing the fouling portion of the heavy components from the vapor, such that the vapor being directed into feed chiller heat exchanger is free of freezing components.
F25J 1/00 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux
F25J 1/02 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux nécessitant l'emploi d'une réfrigération, p.ex. de l'hélium, de l'hydrogène
Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a solvent is injected into a feed of natural gas at a solvent injection point. A mixed feed is produced from a dispersal of the solvent into the feed of natural gas. The mixed feed contains heavy components. A chilled feed is produced by chilling the mixed feed. The chilled feed includes a vapor and a condensed liquid. The condensed liquid contains a fouling portion of the heavy components condensed by the solvent during chilling. The liquid containing the fouling portion of the heavy components is separated from the vapor. The vapor is directed into a feed chiller heat exchanger following separation of the liquid containing the fouling portion of the heavy components from the vapor, such that the vapor being directed into feed chiller heat exchanger is free of freezing components.
F25J 1/00 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux
F25J 1/02 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux nécessitant l'emploi d'une réfrigération, p.ex. de l'hélium, de l'hydrogène
99.
MACHINE-LEARNING BASED FRACTURE-HIT DETECTION USING LOW-FREQUENCY DAS SIGNAL
Various aspects described herein relate to a machine learning based detecting of fracture hits in offset monitoring wells when designing hydraulic fracturing processes for a particular well. In one example, a computer-implemented method includes receiving a set of features for a first well proximate to a second well, the second well undergoing a hydraulic fracturing process for extraction of natural resources from underground formations; inputting the set of features into a trained neural network; and providing, as output of the trained neural network, a probability of a fracture hit at a location associated with the set of features in the first well during a given completion stage of the hydraulic fracturing process in the second well.
A system and method for creating a subsea well for the production or injection of hydrocarbons, fluids, or gases which can include installing an assembly having a subsea template and at least one conductor housing installed in a slot in the template. A drill string can be passed through the at least one conductor housing and drill directly into the seafloor to create a first bore associated with the slot in the template. The bore can be of a diameter suitable for a surface casing and the surface casing can be passed through the conductor housing and into the bore.
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