Cenovus Energy Inc.

Conocophillips Company

Amos Ben-Zvi

Simon D Gittins

Michael Patrick McKay

Prince Azom

Ryan Miller

Paulina Morasse

Michael Miller

Trenton M Schrader

Amin Fardi

Thomas James Wheeler

Subodh Gupta

Harbir Chhina

Siluni L Gamage

Ishan Deep Singh Kochhar

Jason Abbate

Brent D Seib

Ashley Leroux

Juliana Y Leung

Seyide Hunyinbo

Ishan Deep S Kochhar

Alexander E Filstein

Sam Chen

Brent Donald Seib

Kenneth Switala

Mazda Irani

Alexander Filstein

Kirsten Amy Yeates Pugh

Rosana Patricia Bracho Dominguez

Methods are provided for sequestering a pollutant gas of carbon dioxide (CO) gas and/or hydrogen sulfide (HS) gas in a subterranean reservoir. In one method, a carrier gas containing pollutant-sorbent particles (e.g., nanoparticles) is pumped into the subterranean reservoir, the pollutant-sorbent particles attach to the subterranean reservoir, the pollutant gas is pumped into the subterranean reservoir, and the pollutant-sorbent particles attached to the subterranean reservoir adsorb the pollutant gas. In another method, pollutant gas is introduced into a carrier liquid containing pollutant-sorbent particles to produce a pollutant-rich carrier liquid, the pollutant-rich carrier liquid is pumped into the subterranean reservoir, and the pollutant-rich carrier liquid is allowed to remain in the subterranean reservoir. A modifier gas or modifier liquid may be injected into the subterranean reservoir to modify a condition in the subterranean reservoir and thereby cause the pollutant-sorbent particles to release the sequestered pollutant gas.

Methods for carbon dioxide or hydrogen sulfide sequestration in a subterranean reservoir using sorbent particles

A method and apparatus for forecasting oil production from an oil well in a geological formation includes receiving a plurality of sets of predicted geological data, for each of the plurality of sets of predicted geological data, determining a probability for the predicted geological data of the formation, iteratively selecting one of the plurality of sets of predicted geological data using Monte Carlo sampling based on the determined probabilities, assigning the selected set of predicted geological data to a cluster of historical data, and for each set of historical data of the cluster generating a predicted oil production rate as a function of time utilizing a machine learning based oil model, generating, based on the predicted oil production rates, a forecasted oil production rate, determining, based on the forecasted oil production rate, a preferred operating parameter for the well, and operating based on the preferred operating parameter.

Apparatus and method for oil production forecasting

A method is provided for producing hydrocarbons from a subterranean reservoir. A mixture of steam and HS-sorbent particles (e.g., nanoparticles) is injected into the subterranean reservoir. This may be performed during the steam phase of a steam injection operation, such as steam assisted gravity drainage (SAGD), steam flooding, or cyclic steam stimulation, which is performed on the reservoir. The injected steam reduces the viscosity of the hydrocarbons in the subterranean formation. The injected HS-sorbent particles attach to the subterranean reservoir and adsorb HS therein. The hydrocarbons are produced to the surface, without producing the HS-sorbent particles with adsorbed HS that remain attached to the subterranean reservoir.

Steam-enhanced hydrocarbon recovery using hydrogen sulfide-sorbent particles to reduce hydrogen sulfide production from a subterranean reservoir

Method for carbon dioxide or hydrogen sulfide sequestration in a subterranean reservoir via pumping using sorbent particles in a carrier gas

Methods for producing hydrocarbons from subterranean reservoirs utilizing a production well having a plurality of fluid-inlet components spaced apart to define a plurality of production-well fluid-inlet zones. An injection fluid comprising a solvent is injected into the reservoir, resulting in a drainage fluid with a liquid phase and a gas phase occupying one or more of the production-well fluid-inflow zones. The production fluid is produced at a production-flow rate via a pump, and the gas phase:liquid phase ratio of the production fluid is modulated by orchestrating variations in the pump speed and one or more of the plurality of fluid-inlet components to prioritize hydraulic communication with a subset of the plurality of production-well fluid-inlet zones.

Gas-phase solvent management during production of in-situ hydrocarbons

Disclosed are methods for producing hydrocarbons from a subterranean reservoir. The methods comprise penetrating the subterranean reservoir with a plurality of well pairs that are laterally displaced across a well pad in an array. The methods further comprise operating the plurality of well pairs under a first set of conditions that induce a solvent-concentration gradient, a temperature gradient, or a combination thereof within the subterranean reservoir by: (i) injecting varying concentrations of steam, solvent, or combinations thereof across the array, and (ii) producing hydrocarbons from the reservoir via the plurality of well pairs. The methods further comprise operating the plurality of well pairs under a second set of conditions that delocalize the solvent-concentration gradient, the temperature gradient, or the combination thereof across the array to enhance hydrocarbon production.

Hydrocarbon-production methods employing multiple solvent processes across a well pad

Methods are provided for producing hydrocarbons and recovering solvent from a subterranean reservoir that is penetrated by an injection well and a production well, in which a production phase involves injecting solvent (and optionally steam) to mobilize viscous hydrocarbons and a solvent-recovery phase involves non-condensable gas injection. The production phase and the solvent-recovery phase are each defined by an injection profile. The solvent-recovery-phase injection profile is selected: (i) based on the production-phase injection profile, and (ii) to ensure the pressure/temperature conditions in proximity to the production well favor gas-phase solvent recovery.

Methods for recovering solvent and producing hydrocarbons from subterranean reservoirs

Methods for producing hydrocarbons from subterranean reservoirs utilize a production well having a plurality of individually-actuatable fluid-inlet components that are spaced apart to define a plurality of production-well fluid-inlet zones. An injection fluid including a non-condensable gas (NCG) is injected into the reservoir, such that a drainage fluid including at least a portion of the NCG occupies the production-well fluid-inlet zones. The gas phase:liquid phase ratio of a production fluid is modulated by identifying at least one of the production-well fluid-inlet zones as having a gas content above a threshold and thus being a higher-gas zone, and actuating variations in pump speed and the flow states of the plurality of fluid-inlet components adjacent and corresponding to the higher-gas zone to prioritize hydraulic communication with a subset of the plurality of production-well fluid-inlet zones spaced apart from the higher-gas zone.

Non-condensable gas management during production of in-situ hydrocarbons

Disclosed herein are methods for producing hydrocarbons from a subterranean reservoir that is penetrated by an injection well and a production well. The methods comprise operating the injection well under a set of injection parameters and operating the production well under a set of production parameters to produce a production fluid that has an API gravity that changes over time (&#x394;API) as the method is advanced towards an ultimate recovery factor (RF) for the reservoir. The methods further comprises modulating the injection parameters, the production parameters, or a combination thereof to decrease or increase the API gravity of the production fluid depending on whether &#x394;API and RFsatisfy a set of requirements as disclosed herein.

Methods of hydrocarbon production enhanced by in-situ solvent de-asphalting

Methods are provided that facilitate the production of hydrocarbons from subterranean formations, involving the mobilization of an immobile heavy oil in situ by gravity displacement. In effect, heavy oil is mobilized by dense aqueous gravity displacement (DAGD), in a process that generally involves injecting a dense, heated aqueous injection fluid into the formation into an injection zone that is in fluid communication with immobile heavy oil. The injection well is operated so that the injection fluid mobilizes and displaces the immobile heavy oil, to produce an expanding upper zone of mobilized heavy oil amenable to production.

Dense aqueous gravity displacement of heavy oil

A method and system in which foams are used (instead of, or in addition to, NCG) to maintain pressure in a mature chamber during blowdown operations of a SAGD process or other enhanced oil recovery process. The foam occupies the depleted void space within the mature chamber after injection ceases, maintaining pressure, and improving blowdown performance. This use of the foam in the method and system also improves the performance of less mature chambers that are being operated at higher pressure adjacent to the mature chamber in blowdown. Foaming agents, such as metal carbonates, bicarbonates, and hydroxides, surfactants or any other colloidal foams, aerosols, hydrosols, emulsions or dispersions can be utilized. The method and system can be utilized in conjunction with other known art, such as heat scavenging in the chamber, or enhanced oil recovery utilizing foams, to displace oil in the chamber.

Blowdown pressure maintenance with foam

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Calgary, Canada

Amos Ben-Zvi