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
2.
OPTIMIZING STEAM AND SOLVENT INJECTION TIMING IN OIL PRODUCTION
A method for producing heavy oil, the method including testing a plurality of samples either from a reservoir play or simulating a reservoir play in a temperature and pressure controlled gravity drainage experiment. Test injection fluids are injected into the samples at a reservoir temperature and pressure and Cumulative Oil Production (COP) or Recovery Factor (RF) or similar feature measured over time. An injection profile is obtained by selecting n injection fluids based on a best COP or RF at a given time Tn, wherein n is a number of fluid injection stages and switching to an n+1 injection fluid when a rate of change (ROC) in the COP or RF drops at least 25%-75%, but preferably 40-60% or 50%. The injection profile is then implemented in the reservoir to produce heavy oil. Optimized injection profiles for certain reservoirs are also provided.
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E21B 43/24 - Procédés de récupération assistée pour l'extraction d'hydrocarbures utilisant la chaleur, p.ex. injection de vapeur
E21B 43/30 - Disposition particulière des puits, p.ex. disposition rendant optimum l'espacement des 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
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.
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 34/12 - 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 34/08 - 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
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
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.
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
7.
SOLVENT INJECTION FOR SOLIDS PREVENTION IN AN LNG PLANT
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 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
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
8.
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
9.
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.
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.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 47/26 - Stockage des données en fond de puits, p.ex. dans une mémoire ou sur un support d'enregistrement
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
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
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
G06F 30/20 - Optimisation, vérification ou simulation de l’objet conçu
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.
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.
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.
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 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 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
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.
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 41/00 - Matériel ou accessoires non couverts par les groupes
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
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 9/027 - 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
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 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 47/008 - Surveillance des systèmes de pompe de fond de trou, p.ex. pour la détection de conditions appelées "cognement sur le fluide"
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 47/06 - Mesure de la température ou de la pression
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
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 7/00 - Distillation des huiles d'hydrocarbures
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 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
25.
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 7/06 - Modification de la direction du trou de forage
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
26.
INVERTED SHROUD FOR STEAM ASSISTED GRAVITY DRAINAGE SYSYEM
Implementations described and claimed herein provide systems and methods for increasing production performance in a Steam Assisted Gravity Drainage system. In one implementation, an upper mating unit of an inverted shroud assembly is received with a lower mating unit of the inverted should assembly in a slidable relationship. The upper mating unit is coupled to a pump- intake assembly. The lower mating unit is coupled to a motor-seal assembly. The slidable relationship secures the pump-intake assembly to the motor-seal assembly. A motor of the motor-seal assembly is directly cooled by opening the motor to a production well based on an exterior attachment of the motor-seal assembly relative to an inverted shroud.
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.
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
F25J 3/00 - Procédés ou appareils pour séparer les constituants des mélanges gazeux impliquant l'emploi d'une liquéfaction ou d'une solidification
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
29.
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 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 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 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.
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
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.
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
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
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 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 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
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
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 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.
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 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
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 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 43/27 - Procédés pour activer la production par formation de crevasses ou de fractures par emploi de produits chimiques érosifs, p.ex. d'acides
E21B 47/06 - Mesure de la température ou de la pression
E21B 33/035 - Têtes de puits; Leur mise en place spécialement adaptées aux installations sous l'eau
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
47.
SYSTEMS AND METHODS FOR REMOVING NITROGEN DURING LIQUEFACTION OF NATURAL GAS
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
48.
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 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
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 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 1/44 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs et des récepteurs situés dans le même puits
49.
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 47/12 - 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
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, 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 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 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
53.
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 47/11 - Localisation des fuites, intrusions ou mouvements du fluide utilisant la radioactivité
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
54.
STANDALONE HIGH-PRESSURE HEAVIES REMOVAL UNIT FOR LNG PROCESSING
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.
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.
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
57.
MACHINE-LEARNING BASED SYSTEM FOR VIRTUAL FLOW METERING
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
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
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
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
61.
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.
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.
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
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
A process is provided for the time dependent reduction and kill of cellular bacteria in a fluid by sequential exposure to nitrites and a low concentration of biocide. Oilfield water containing sulfate-reducing bacteria can be supplied with a timed sequential exposure of nitrite and biocide. The timed sequential addition of the biocide following exposure to the nitrite provides enhanced kill of the sulfate-reducing bacteria at concentrations of biocide that are lower than would be possible using simultaneous addition of these materials.
A61L 2/18 - Procédés ou appareils de désinfection ou de stérilisation de matériaux ou d'objets autres que les denrées alimentaires ou les lentilles de contact; Accessoires à cet effet utilisant des substances chimiques des substances liquides
67.
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.
An inexpensive electrically conductive carrier is added to well bore fluids thereby allowing for a closed loop real-time data communication system for topside management of all downhole equipment including drilling, completion, production, logging, and workover equipment. Conductive carrier fluid provides a "real-time" digital and analog bi-directional data and communication solution between the surface operations of a well-bore and downhole tools. Conductive carrier fluid provides for the application of more sophisticated software essential for exact control requirements of sophisticated downhole equipment, thereby achieving optimized tool performance as well as future downhole tools.
C09K 8/03 - Additifs spécifiques à usage général dans les compositions pour le forage des puits
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
C09K 8/32 - Compositions de forage non aqueuses, p.ex. à base d'huile
C09K 8/36 - Compositions de forage non aqueuses, p.ex. à base d'huile Émulsions eau-dans-l'huile
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 47/18 - 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 à travers le fluide du puits
G01V 3/00 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation
69.
SKID MOUNTED WELLHEAD DESANDERS AND FLOWBACK SYSTEMS
Small footprint, portable skid mounted wellhead desander systems are disclosed. In one version, two systems are mounted on the skid, one system being a single well system for testing various properties of well fluids, and the other being a combined bulk system for desanding comingled flow from a plurality of wells. In another version, the skid mounted system has three independent desanders together with all essential equipment, including e.g., plug catcher, hydrocyclone desander, solids accumulator, choke manifold, and all necessary sensors, valving and control equipment.
Methods of plugging a hydrocarbon well by using degradable plugs plus a degradable tape to ensure pressure testing to 10,000 psi. When the plug is no longer needed, a degradation fluid or fluids are pumped downhole and that fluid or fluids degrade the degradable plugs and degradable tape, thus avoiding the production of any solids large enough to clog or block equipment.
Reducing leak-off during acid stimulation with dissolvable material sized to preferentially block crevices and wormholes, thus allowing the acid to travel further down the fractures, etching deeper into the reservoir than a similar process not using such dissolvable materials. After stimulation, the materials dissolve and production can proceed and will be improved over what is possible without such dissolvable materials.
A system and method are provided to detect and avoid wellbore collision. The method may include receiving, by a processor, a path of a proposed wellbore. The processor then receives a boundary surrounding the path of the proposed wellbore. The processor then generates, automatically, a list of avoidance components within the boundary using an internal database. The proposed wellbore and avoidance components in the list are then displayed by a visualization system.
Implementations described and claimed herein provide systems and methods for recovering hydrocarbons from a subterranean formation. In one implementation, at least one drilling operation is executed at the subterranean formation according to at least one drilling parameter. High resolution geomechanical data is continuously captured in-situ during a duration of the at least one drilling operation. A geomechanical model of the subterranean formation is dynamically recalibrated as the high resolution geomechanical data is continuously captured during the at least one drilling operation. An integrity of caprock at the subterranean formation is determined based on the geomechanical model. The at least one drilling parameter is dynamically adjusted based on the integrity of caprock at the subterranean formation.
Method for characterizing subterranean formation is described. One method involves injecting a fluid into an active well of the subterranean formation at a pressure sufficient to induce one or more hydraulic fractures. Measuring, via a pressure sensor, a poroelastic pressure response caused by inducing of the one or more hydraulic fractures. The pressure sensor is in at least partial hydraulic isolation with the one or more hydraulic fractures.
Method for characterizing subterranean formation is described. One method involves simulating a poroelastic pressure response of known fracture geometry utilizing a geomechanical model to generate a simulated poroelastic pressure response. Compiling a database of simulated poroelastic pressure responses. Measuring a poroelastic pressure response of the subterranean formation during a hydraulic fracturing operation to generate a measured poroelastic pressure response. Identifying a closest simulated poroelastic pressure response in the library of simulated poroelastic pressure response. Estimating a geometrical parameter of a fracture or fractures in the subterranean formation based on the closest simulated poroelastic pressure response.
A method of optimizing production of a hydrocarbon-containing reservoir by measuring low-frequency Distributed Acoustic Sensing (LFDAS) data in said well during a time period of constant flow and during a time period of no flow and during a time period of perturbation of flow and simultaneously measuring Distributed Temperature Sensing (DTS) data from said well during a time period of constant flow and during a time period of no flow and during a time period of perturbation of flow. An initial model of reservoir flow is provided using the LFDAS and DTS data; the LFDAS and DTS data inverted using Markov chain Monte Carlo method to provide an optimized reservoir model, and that optimized profile utilized to manage hydrocarbon production from said well and other asset wells.
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
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
Method of detecting malware in a computer storage medium is described. The method involves connecting the computer storage medium to an air-gapped anti-malware device. Scanning the computer storage medium for malware.
G06F 21/50 - Contrôle des usagers, programmes ou dispositifs de préservation de l’intégrité des plates-formes, p.ex. des processeurs, des micrologiciels ou des systèmes d’exploitation
G06F 21/55 - Détection d’intrusion locale ou mise en œuvre de contre-mesures
G06F 21/56 - Détection ou gestion de programmes malveillants, p.ex. dispositions anti-virus
H04L 9/28 - Dispositions pour les communications secrètes ou protégées; Protocoles réseaux de sécurité utilisant un algorithme de chiffrement particulier
78.
DATA STREAM CONTROLLER WITH CONFIGURABLE BARRIER FOR JOIN AND AGGREGATION
A method, system, and apparatus are provided for a configurable streaming operator to join or aggregate input data streams in a streaming application topology. The configurable operator may include a configuration data stream that allows for the selection of a varying number of input streams to join or aggregate. Introducing the configuration stream into a streaming operator allows the underlying operator to selectively use the remaining input streams based on the configuration stream as well as influencing the resulting output stream as defined by the configuration stream to provide flexibility in handling various configurations with a minimum and/or maximum of input streams.
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
G06F 3/048 - Techniques d’interaction fondées sur les interfaces utilisateur graphiques [GUI]
A system and method to conform data flow are provided. The system includes a queue configured to receive at least one data stream, and a processor configured to convert the at least one data stream to a continuous data stream, and output the continuous data stream at a constant rate.
H04L 47/21 - Commande de flux; Commande de la congestion en utilisant un seau troué
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
A method of assessing cross-well interference and/or optimizing hydrocarbon production from a reservoir by obtaining low frequency DAS and DTS data and pressure data from a monitor well, when both the monitor and production well are shut-in, and then variably opening the production well for production, and detecting the temperature and pressure fluctuations that indication cross-well interference, and localizing the interference along the well length based on the low frequency DAS data. This information can be used to optimize well placement, completion plans, fracturing plans, and ultimately optimize production from a given reservoir
E21B 47/06 - Mesure de la température ou de la pression
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
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
A process for removing metals and chelators from SAGD liner flowback that can be implemented at the wellhead using temporary tankage and equipment. In the first step, caustic is added to the flowback until the concentration of hydroxyl ion is high enough for the metals (Fe, Ca, Mg) to dissociate from the metal-chelate complexes and precipitate as hydroxides. In the second step, hydrogen peroxide is added and allowed to react until all of the chelator molecules are oxidized and decomposed. Once treated, the flowback can proceed to the CPF.
A system and method to identify a dysfunction of a drill-string within a wellbore are provided. The system includes a sensor positioned proximate to a drill-string and proximate to a surface of the wellbore. The sensor is configured to sense a surface condition and generate measurement data. The system also includes a transmitter in communication with the sensor and configured to transmit the measurement data. The system also includes a receiver configured to receive the measurement data from the sensor. The system also includes a processor configured to calculate a downhole measurement based on the measurement data and analyze the downhole measurement to identify the dysfunction.
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 47/12 - 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
A method is provided to determine and mitigate one or more downhole events of a drill string in a wellbore. The method includes receiving, via a processor, drilling data from one or more surface sensors. The drilling data is processed into a plurality of segments. Each of the plurality of segments are processed by a pre-trained model such that one or more labels are determined. The one or more labels are relating to one or more downhole events corresponding to each of the plurality of segments.
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
A method of characterizing a subterranean formation using a plurality of seismic acquisitions includes obtaining a first seismic acquisition of the subterranean formation, wherein the first seismic acquisition is a baseline survey. Injecting a gas fluid into the subterranean formation, wherein the gas fluid at least partially fills a portion of a fracture network of the subterranean formation. Obtaining a second seismic acquisition of the subterranean formation. Calculating a time-lapse difference in the plurality of seismic acquisitions.
G01V 1/32 - Transformation d'un mode d'enregistrement en un autre
G01V 1/34 - Représentation des enregistrements sismiques
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/37 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie spécialement adaptés aux systèmes sismiques utilisant une agitation continue du sol
G01V 1/38 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées aux zones recouvertes d'eau
85.
DEGAUSSING FERROUS MATERIAL WITHIN DRILLING FLUIDS
A method of demagnetizing well fluid to improve measurements in a well bore. A demagnetization apparatus for coupling to a well pipe is provided, the demagnetization unit having a demagnetizer or degausser that can be attached to a well pipe. The demagnetizing unit configured to demagnetize well fluid as it passes through a pipe as it is conveyed to the well bore.
H01F 13/00 - Appareils ou procédés pour l'aimantation ou pour la désaimantation
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forage; Protection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
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
86.
SYSTEM AND METHOD FOR STICK-SLIP VIBRATION MITIGATION
A stick-slip vibration mitigation system and a method of using the system are provided. The system includes a sensor, a processor, a non-transitory storage medium, and a controller. The system is operable to be used with a drill-string in a wellbore during a drilling process to mitigate stick-slip vibration of the drill-string.
E21B 44/08 - Commande automatique de l'avance de l'outil en réponse à l'amplitude du mouvement de l'outil à percussion, p.ex. sa course ou son recul
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
A method of plugging a hydrocarbon well includes deploying a downhole tool to remove at least a portion of a casing at a section of well to be plugged. Deploying a blocking device downhole to block a bottom of the section of well to be plugged. Deploying a plugging material downhole onto the blocking device to fill an area to be plugged. Deploying an exothermic fluid downhole, wherein activation of the exothermic material liquefies the plugging material. Allowing the plugging material and the exothermic fluid to solidify form a cast-in-place plug that fills the section of well to be plugged.
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
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
88.
METHOD AND APPARATUS FOR CEMENTING AND CLEANING A RESERVOIR LINER
A procedure and apparatus for cementing and cleaning a reservoir liner (3) comprises installing a reservoir liner using a drill string (4) which extends only as far as the distal end of a cased part (2) of the well, then, using the drill string, displacing cement into the reservoir liner using completion fluid whereby, when the cement is in place in the annulus around the reservoir liner, the reservoir liner is already clean and filled with completion fluid. A ball valve (6) at the top of the reservoir liner (3) is then closed before the cased part (2) of the wellbore is cleaned, to avoid debris entering the reservoir liner.
E21B 21/10 - Aménagements des vannes dans les systèmes de circulation des fluides de forage
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 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
89.
METHOD AND APPARATUS FOR WASHING AN UPPER COMPLETION
The invention relates to the cleaning of a wellbore including a reservoir liner 3 and an upper portion 2 of the wellbore, by running in only one string into the wellbore and performing a reservoir liner cementing operation, displacing the cement 7 with completion fluid 8, followed using the same string to circulate mud in the upper completion, perform an inflow test on the reservoir liner 3, wash the upper completion and displace it to completion fluid 8.
A method of plugging a hydrocarbon well by a through-tubing technique allows the tubing to be left in place. Only a short section is cut, milled, perforated, ruptured and expanded, or combinations thereof. A blocking device is sent downhole to block a bottom of the plug section, and bismuth alloy pellets dropped onto the blocking device. A heater is deployed to melt the bismuth alloy pellets. Next, the alloy liquid is allowed to cool and solidify. During solidification, the alloy expands and fills the section of well to be plugged or a portion thereof. Once primary and secondary barriers are in place, the well can be closed and the Christmas tree removed. A rock-to-rock plug can be set by removing or partially removing the tubular and outer casing, or just inner casing/tubulars can be removed if the exterior cement and casing are of sufficient quality.
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
Monitoring and diagnosing completion during hydraulic fracturing operations provides insights into the fracture geometry, inter-well frac hits and connectivity. Conventional monitoring methods (microseismic, borehole gauges, tracers, etc.) can provide a range of information about the stimulated rock volume but may often be limited in detail or clouded by uncertainty. Utilization of DAS as a fracture monitoring tool is growing, however most of the applications have been limited to acoustic frequency bands of the DAS recorded signal. In this paper, we demonstrate some examples of using the low-frequency band of Distributed Acoustic Sensing (DAS) signal to constrain hydraulic fracture geometry. DAS data were acquired in both offset horizontal and vertical monitor wells. In horizontal wells, DAS data records formation strain perturbation due to fracture propagation. Events like fracture opening and closing, stress shadow creation and relaxation, ball seat and plug isolation can be clearly identified. In vertical wells, DAS response agrees well with co-located pressure and temperature gauges, and illuminates the vertical extent of hydraulic fractures. DAS data in the low-frequency band is a powerful attribute to monitor small strain and temperature perturbation in or near the monitor wells. With different fibered monitor well design, the far-field fracture length, height, width, and density can be accurately measured using cross-well DAS observations.
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
G01V 1/42 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs dans un puits et des récepteurs dans un autre endroit ou vice versa
A new water treatment system for SAGD operations is disclosed. Instead of treating both produced water and recycled water using warm lime softening systems, the recycled water is combined with saline water in a cold lime softening system. This results in slightly warmed reactions that require less chemicals during the lime softening process while also allowing for larger volumes of treated produced water to be generated by the warm lime softening system.
C02F 9/00 - Traitement en plusieurs étapes de l'eau, des eaux résiduaires ou des eaux d'égout
C02F 1/42 - Traitement de l'eau, des eaux résiduaires ou des eaux d'égout par échange d'ions
C02F 1/52 - Traitement de l'eau, des eaux résiduaires ou des eaux d'égout par floculation ou précipitation d'impuretés en suspension
C02F 1/66 - Traitement de l'eau, des eaux résiduaires ou des eaux d'égout par neutralisation; Ajustage du pH
C02F 5/00 - Adoucissement de l'eau; Prévention de l'entartrage; Addition à l'eau d'agents antitartre ou détartrants, p.ex. addition d'agents séquestrants
C02F 5/06 - Adoucissement de l'eau par précipitation des substances qui rendent l'eau dure en utilisant des composés du calcium
E21B 43/24 - Procédés de récupération assistée pour l'extraction d'hydrocarbures utilisant la chaleur, p.ex. injection de vapeur
E21B 43/40 - Séparation associée à la réinjection de matériaux séparés
Described herein is a coagulant blend for use in SAGD water treatment systems. Specifically, a blend of high charge density polyamine and low charge density poly(diallylmethyl ammonium chloride (poly-DADMAC) is used in the warm lime softening treatment process to coagulate and flocculate solids.
Methods, systems and designs are provided for removing mercury from crudes. Crude oil containing a synthetic reducing agent is heated to a temperature above 100°C and held at that temperature for a specified period of time to convert all of the forms of mercury in the oil into the elemental mercury form. The elemental mercury is then stripped from the crude oil by e.g., flashing the hot oil and/or contacting it with a gas phase.
B01D 53/34 - Epuration chimique ou biologique des gaz résiduaires
B01D 53/64 - Métaux lourds ou leurs composés, p.ex. mercure
C10G 17/02 - Raffinage des huiles d'hydrocarbures, en l'absence d'hydrogène, avec des acides, des composés libérant un acide ou des liquides contenant un acide, p.ex. avec une boue acide avec des acides ou des liquides contenant un acide, p.ex. avec une boue acide
C10G 17/095 - Raffinage des huiles d'hydrocarbures, en l'absence d'hydrogène, avec des acides, des composés libérant un acide ou des liquides contenant un acide, p.ex. avec une boue acide avec des "acides solides", p.ex. avec l'acide phosphorique déposé sur un support
C10G 27/02 - Raffinage des huiles d'hydrocarbures, en l'absence d'hydrogène, par oxydation avec un halogène ou des composés donneurs d'halogène; Acide hypochloreux ou ses sels
C10G 31/06 - Raffinage des huiles d'hydrocarbures, en l'absence d'hydrogène, par des méthodes non prévues ailleurs par chauffage, refroidissement ou traitement par la pression
A data acquisition and signal detection through radio frequency identification (RFID) system and a method of using the system are provided. The system includes a base station, a receiver, and an RFID device. The system is operable to be used with a wellbore and a drill string during a drilling process to obtain data regarding properties of the wellbore and/or the drill string.
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
96.
IN-SITU SURFACTANT RETENTION EVALUATION USING SINGLE WELL CHEMICAL TRACER TESTS
The present disclosure provides methods for determining surfactant retention values m subterranean reservoirs. In particular, the methods comprise conducting at least one single well chemical tracer test and performing a straight line analysis on a saturation profile of the subterranean reservoir.
C09K 8/584 - 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 caractérisées par l'utilisation de tensio-actifs spécifiques
C09K 8/588 - 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 caractérisées par l'utilisation de polymères spécifiques
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
97.
POROMECHANICAL IMPACT ON YIELD BEHAVIOR IN UNCONVENTIONAL RESERVOIRS
A method for obtaining hydrocarbon from a reservoir in a subterranean formation is described. The method includes measuring a poromechanic pressure change due to lithostatic load sharing in the subterranean formation. Mapping the poromechanic pressure change to one or more locations in the subterranean formation. Identifying one or more local pressure peaks in the poromechanic pressure change, wherein the one or more local pressure peaks are each marked by a pressure escalation and subsequent pressure depletion. Determining one or more regions in the reservoir exhibiting single phase hydrocarbon production.
E21B 47/06 - Mesure de la température ou de la pression
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
E21B 43/30 - Disposition particulière des puits, p.ex. disposition rendant optimum l'espacement des 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
G01V 1/00 - Séismologie; Prospection ou détection sismique ou acoustique
98.
DRAINED RESERVOIR VOLUME DIAGNOSTICS FROM MANDEL-CRYER PRESSURE SIGNAL
A method for obtaining hydrocarbon from a reservoir in a subterranean formation is described. The method includes measuring a poromechanic pressure change due to lithostatic load sharing in the subterranean formation. Mapping the poromechanic pressure change to one or more locations in the subterranean formation. Identifying one or more local pressure peaks in the poromechanic pressure change, wherein the one or more local pressure peaks are each marked by a pressure escalation and subsequent pressure depletion. Determining a drained reservoir volume in the hydrocarbon reservoir based on the pressure escalation.
Described herein are methods for accelerating the start-up in SAGD type processes wherein the volume between the injector and the producer is preheated utilizing open-holes drilled between wells. The recovery of hydrocarbons is also improved due to a viscous fluid drive in the open-holes during SAGD operations.
A delayed fin deployment wiper plug has a tubular body, which has a closed top and a piston therein. The piston is supported at one or more locations inside the tubular body by one or more sets of shear pins or spring clips or some equivalent device. The piston is connected to or abutted to a sleeve that covers an upper portion of the tubular body, containing therein one or more sets of deployable fins that are not exposed for use unless the piston is activated and raises the sleeve.
brevets
