scholarly journals THE DEPENDENCE OF HOT WATER FLOODING EFFICIENCY ON THE FILTRATION-CAPACITIVE PROPERTIES FOR DOUBLE PERMEABILITY RESERVOIR OF HIGH-VISCOSITY OIL DEPOSITS

2019 ◽  
Vol 17 (4) ◽  
pp. 32
Author(s):  
E.M. Almukhametova ◽  
I.V. Vladimirov
Keyword(s):  
High Viscosity ◽  
Hot Water ◽  
Water Flooding ◽  
Capacitive Properties ◽  
Oil Deposits ◽  
High Viscosity Oil ◽  
Double Permeability

RESPONSE TO THE APRIL 1988 OIL SPILL AT MARTINEZ, CALIFORNIA

1989 ◽  
Vol 1989 (1) ◽  
pp. 65-69 ◽  
Author(s):  
J. P. Fraser ◽  
J. R. Mortenson ◽  
D. P. Montoro ◽  
M. E. Rugg
Keyword(s):  
Oil Spill ◽  
High Viscosity ◽  
Hot Water ◽  
Complex Part ◽  
Sorbent Materials ◽  
Saltwater Marshes ◽  
High Viscosity Oil ◽  
Oil Company ◽  
Suisun Bay ◽  
Spilled Oil

ABSTRACT A spill of approximately 9,400 bbl of San Joaquin Valley crude oil (13.5 API gravity) occurred on April 23, 1988, from the Shell Oil Company Martinez Manufacturing Complex. Part of the high-viscosity oil eventually reached Carquinez Strait and Suisun Bay. Areas initially affected by the spill included a 103-acre freshwater marsh, the shorelines of Carquinez Strait and Suisun Bay, saltwater marshes associated with both the strait and the bay, three marinas, two local parks, and waterfront properties in Benicia. To aid in the cleanup, Shell used the facilities of the local oil spill cooperative, Clean Bay, Inc., four oil spill contractors, and U.S. Navy skimmers. Two local organizations were actively involved in caring for birds and other widlife oiled by the spill. Within four weeks, over 90 percent of the spilled oil was judged by the federal On-Scene Coordinator to have been recovered. Cleanup of floating oil involved use of skimmers and vacuum trucks. Sorbent materials were used extensively for shoreline cleanup, and a substantial amount of vegetation was removed to reduce the risk of wildlife contamination. High-pressure hot water was used to clean some rocky shorelines.

scholarly journals Enhanced oil recovery from high-viscosity oil deposits by acid systems based on surfactants, coordining solvents and complex compounds

Georesursy ◽  
2019 ◽  
Vol 21 (4) ◽  
pp. 103-113 ◽  
Author(s):  
Lyubov K. Altunina ◽  
Vladimir A. Kuvshinov ◽  
Lyubov A. Stasyeva ◽  
Ivan V. Kuvshinov
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
High Viscosity ◽  
Complex Compounds ◽  
Natural Mode ◽  
Inorganic Acid ◽  
Acid Oil ◽  
Oil Displacement ◽  
Oil Deposits ◽  
High Viscosity Oil

Physicochemical aspects of enhanced oil recovery (EOR) from heavy high-viscosity deposits, developed in natural mode and combined with thermal methods, using systems based on surface-active substances (surfactants), coordinating solvents and complex compounds are considered, which chemically evolve in situ to acquire colloidal-chemical properties that are optimal for oil displacement. Thermobaric reservoir conditions, interactions with reservoir rock and fluids are the factors causing the chemical evolution of the systems. To enhance oil recovery and intensify the development of high-viscosity deposits, acid oil-displacing systems of prolonged action based on surfactants, inorganic acid adduct and polyatomic alcohol have been created. As a result of experimental studies of acid-base equilibrium in the systems with donor-acceptor interactions – polybasic inorganic acid and polyol, the influence of electrolytes, non-electrolytes and surfactants, the optimal compositions of the systems were selected, as well as concentration ranges of the components in the acid systems. When the initially acid system interacts with the carbonate reservoir to release CO2, the oil viscosity decreases 1.2-2.7 times, the pH of the system rises and this system evolves chemically turning into an alkaline oil-displacing system. As a result it provides effective oil displacement and prolonged reservoir stimulation. The system is compatible with saline reservoir waters, has a low freezing point (minus 20 ÷ minus 60 oC), low interfacial tension at the oil boundary and is applicable in a wide temperature range, from 10 to 200 oC. In 2014-2018 field tests of EOR technologies were successfully carried out to intensify oil production in the test areas of the Permian-Carboniferous deposit of high-viscosity oil in the Usinsk oil field, developed in natural mode and combined with thermal-steam stimulation, using the acid oil-displacing system based on surfactants, coordinating solvents and complex compounds. The pilot tests proved high efficiency of EOR technologies, as far as the oil production rate significantly increased, water cut decreased to intensify the development. The EOR technologies are environmentally safe and technologically effective. Commercial use of the EOR is promising for high-viscosity oil deposits.

Analysis of solutions of the Muskat — Leverett non-isothermal model for different types of oils

2020 ◽  
pp. 26-37
Author(s):  
O. B. Bocharov ◽  
I. G. Telegin
Keyword(s):  
Oil Recovery ◽  
High Viscosity ◽  
Oil Field ◽  
Hot Water ◽  
Oil Viscosity ◽  
Isothermal Model ◽  
Total Heat Loss ◽  
Low Viscosity ◽  
Different Types ◽  
High Viscosity Oil

In this article, numerical methods are used to analyze the features of solutions to the non-isothermal Muskat — Leverett two-phase filtration model. The structure of solutions to thermal waterflooding problems for low-viscosity and high viscosity types of oil is considered. Typical solutions for different types of functional parameters of the model are shown. The simulations show that hot water displacement of high-viscosity oil is an effective method of increasing oil recovery. In particular, if in the case of thermal flooding the reservoir with low-viscosity oil, recovery increases by only a few percent, then for a field with high viscosity oil, thermal flooding increases oil recovery by tens of percent. It is shown that in order to increase the efficiency of the thermal flooding it is necessary to pump hot water with the minimum possible capillary parameter. High total filtration rate reduces total heat loss through the roof and sole of the formation. Numerical experiments have shown that for an adequate simulation of thermal flooding, in addition to taking into account changes in oil viscosity, it is necessary to take into account the action of capillary forces and the variation of relative phase permeability during the operation of the oil field.

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