Abstract:
Method for increasing the recovery of crude oil from a reservoir containing at least one porous and permeable subterranean formation wherein the formation includes sandstone rock and at least one mineral that has a negative zeta potential under the reservoir conditions and wherein crude oil and connate water are present within the pores of the formation. The method is carried out by (A) injecting into the formation a slug of an aqueous displacement fluid that displaces crude oil from the surface of the pores of the formation wherein the pore volume (PV) of the slug of the aqueous displacement fluid is at least 0.2 and less than 1 and the aqueous displacement fluid has a total dissolved solids (TDS) content in the range of 200 to 10,000 ppm and the fraction of the total multivalent cation content of the aqueous displacement fluid to the total multivalent cation content of the connate water is less than 1, and (B) subsequently injecting into the formation a drive water of higher multivalent cation content and/or higher total dissolved solids content than the aqueous displacement fluid.
Abstract:
Wellbore fluid having a continuous aqueous phase, and comprising at least one polymer which has a number average molecular weight in the range of from 10,000 to less than 100,000, wherein the polymer is selected from a copolymer of at least one hydrophilic monomer and at least one hydrophobic monomer containing an alkyl group having at least 8 carbon atoms. The hydrophilic monomer is selected from acrylic acid, methacrylic acid, maleic acid, maleic anhydride, fumaric acid and itaconic acid, and sulfonate groups have been introduced into the copolymer by reaction of at least a portion of the carboxylic acid and/or anhydride groups with a compound of general formula R12N(CH2)nSO3X (I) or a compound of general formula HO(CH2)nSO3X (II). Each R1 is independently selected from hydrogen, methyl or ethyl, X is either H or a Group IA metal, and n is an integer of from 1 to 6. The combined molecular weight of the pendant alkyl groups that are introduced into the copolymer by the hydrophobic monomer is in the range of from 15 to 70% by weight based on the molecular weight of the polymer such that the polymer has a solubility of at least 2% in water at 20° C. The fluid further comprises at least one additive selected from additional fluid loss control agents, bridging particulate materials, finely dispersed additives for increasing the fluid density, thinners, and shale inhibitors.
Abstract translation:具有连续水相的井筒流体,并且包含数均分子量在10,000至小于100,000范围内的至少一种聚合物,其中所述聚合物选自至少一种亲水单体和至少一种亲水单体的共聚物 含有至少8个碳原子的烷基的疏水单体。 亲水性单体选自丙烯酸,甲基丙烯酸,马来酸,马来酸酐,富马酸和衣康酸,并且磺酸酯基已经通过至少一部分羧酸和/或酸酐基团与 通式R 12 N(CH 2)n SO 3 X(I)的化合物或通式为HO(CH 2)n SO 3 X(II)的化合物。 每个R 1独立地选自氢,甲基或乙基,X是H或IA族金属,n是1至6的整数。通过所述共聚物引入到共聚物中的侧基烷基的组合分子量 基于聚合物的分子量,疏水单体在15至70重量%的范围内,使得聚合物在20℃下在水中的溶解度至少为2%。流体还包含至少一种添加剂 来自额外的流体损失控制剂,桥接颗粒材料,用于增加流体密度的细分散添加剂,稀释剂和页岩抑制剂。
Abstract:
Wellbore fluid containing a base fluid and a particulate bridging agent comprised of melamine. A method is also described of forming a removable filter cake on the walls of a wellbore that penetrates a porous and permeable rock formation by placing in the wellbore a wellbore fluid containing a base fluid and melamine, and permitting the melamine to deposit from the wellbore fluid onto or into the walls of the wellbore to form the filter cake, whereby fluid loss to the formation through the removable filter cake is reduced.
Abstract:
A method and system for estimating reservoir pressure in a hydrocarbon reservoir from downhole pressure measurements of producing wells is disclosed. Pressure measurements are obtained from wells in the production field over time, and communicated to a server that applies the pressure measurements for a well to a model of that well. The server operates the model using the pressure measurements to determine an operating mode of the well, such as producing or shut-in. Upon detection of a change in operating mode indicative of an abrupt change in flow at the well, such as corresponding to a shut-in event, additional downhole pressure measurement data is acquired until a steady-state condition is reached. The pressure measurements are used to determine a reservoir pressure, which is transmitted to a responsible reservoir engineer or other user. Modification of the determined reservoir pressure value by the user can be received, and the stored reservoir pressure and well model are updated accordingly.
Abstract:
A method of recovering hydrocarbons from a porous subterranean hydrocarbon-bearing formation comprising the steps of: a) feeding to at least on reverse osmosis unit of a desalination assembly a high salinity water feed stream having a total dissolved solids content (total salinity) of at least 10,000 ppm; b) driving a portion of the high salinity water feed stream across a membrane in the reverse osmosis unit of the desalination assembly at a pressure above the osmotic pressure of the high salinity water feed stream while excluding at least a portion of the dissolved solids from crossing said membrane to produce a treated low salinity water product stream having a total salinity of less than 5,000 ppm and a concentrated waste brine stream wherein the hydrostatic head exerted by the high salinity water feed stream on the feed side of the membrane provides at least a major component of the pressure required to overcome the osmotic pressure; c) injecting the low salinity water product stream into the hydrocarbon-bearing formation from an injection well; d) displacing the hydrocarbons with the low salinity water product stream toward an associated production well; and e) recovering hydrocarbons from the formation via the production well.
Abstract:
A continuous process for regasifying a feed stream comprising (i) a slurry phase comprising gas hydrate particles suspended in a produced liquid hydrocarbon and optionally free produced water and (ii) optionally a gaseous phase comprising free produced gaseous hydrocarbon thereby generating a regasified multiphase fluid and for separating the regasified multiphase fluid into its component fluids, comprising the steps of: (a) heating the feed stream to above the dissociation temperature of the gas hydrate thereby regasifying the feed stream by converting the gas hydrate particles into gaseous hydrocarbon and water; (b) separating a gaseous hydrocarbon phase from the regasified multiphase fluid thereby forming a gaseous hydrocarbon product stream and a liquid stream comprising a mixture of liquid hydrocarbon and water; (c) separating the liquid stream comprising a mixture of the liquid hydrocarbon and water into a liquid hydrocarbon phase and an aqueous phase; and (d) removing the liquid hydrocarbon phase as a liquid hydrocarbon product stream.
Abstract:
A method of treating a subterranean formation, the method comprising: (A) injecting down a well bore into the formation an admixture of (a) an emulsion having an internal aqueous phase comprising a water-soluble oil or gas field chemical or an aqueous dispersion of a water-dispersible oil or gas field chemical and an external oil phase comprising a liquid hydrocarbon and an oil-soluble surfactant and (b) a demulsifier comprising a solution of a surfactant having a cloud point temperature of above 40° C.; or (B) separately injecting down a well bore into the formation emulsion (a) and demulsifier (b) and generating an admixture of emulsion (a) and demulsifier (b) within the formation.
Abstract:
A composition for reducing deposition of a mineral salt from an aqueous supersaturated solution onto a solid surface in contact with the aqueous supersaturated solution which composition comprises a dispersion of either (i) seed crystals of the mineral salt in an aqueous solution of the mineral salt or (ii) seed crystals of a salt isomorphous with the mineral salt in an aqueous solution of the isomorphous salt wherein the dispersed seed crystals are of Mean particle size of less than 2.5 microns.
Abstract:
A process for the conversion of synthesis gas into higher hydrocarbon products in a system comprising a high shear mixing zone and a post mixing zone wherein the process comprises: a) passing a suspension of catalyst in a liquid medium through the high shear mixing zone where the suspension is mixed with synthesis gas; b) discharging a mixture of synthesis gas and suspension from the high shear mixing zone into the post mixing zone; c) converting at least a portion of the synthesis gas to higher hydrocarbons in the post mixing zone to form a product suspension comprising catalyst suspended in the liquid medium and the higher hydrocarbons; d) separating a gaseous stream comprising uncoverted synthesis gas from the product suspension; e) recycling the separated gaseous stream to the high shear mixing zone; and f) recycling at least a portion of the product suspension to the high shear mixing zone.
Abstract:
An end effector for an automated electric vehicle charging system includes a chassis including a chassis connector for coupling the end effector to an end of a robotic arm; and a support rail unit coupled to the chassis and including an elongate support rail, a carriage slidably coupled to the support rail and including a carriage connector configured to couple to an electric distributor charging connector of the electric vehicle charging system, and a carriage actuator coupled between the support rail and the carriage for transporting the carriage along the support rail.