Energy reservoir

Once injection water treatment requirements have been established, process equipment must be sized to deal with the anticipated throughput. In a situation where water injection is the primary source of reservoir energy it is common to apply a voidage replacement policy, i.e. produced volumes are replaced by Injected volumes. An allowance above this capacity would be specified to cover equipment downtime. 

Program DAV08 is an 18 reservoir energy balance climate model... 

Program DAV10 is an 18 reservoir energy balance climate using the long wave radiation formulation of Kuhn et al. (1989) in LWFLUX Albedo formulation of Thompson and Barron in SWALSEDO with land and sea ice. 

The fundamental phases of petroleum production include (1) the initial exploration required to find heretofore undiscovered oil and gas reservoirs (2) primary and secondary recovery methods, which make use of both naturally occurring (or primary) reservoir energy and the application of secondary energy sources, such as the injection of gas or water and (3) enhanced oil recovery used to increase ultimate oil production beyond that achievable with primary and secondary methods. Enhanced oil recovery (EOR) methods increase the proportion of the reservoir by improving the sweep efficiency, reducing the amount of residual oil in the swept zones (increasing the displacement efficiency), and reducing the viscosity of thick oils. 

Kg. 24. Enhanced oil recovery techniques employ heat, gases, chemicals, and water—singly or in combinations—to reduce the factors that inhibit oil recovery and to augment reservoir energy. (Exxon Corp)... 

Then it is natural to use the expansion of around the maximum value of the reservoir energy, Ej, ... 

ENHANCED OIL RECOVERY refers to the process of producing liquid hydrocarbons by methods other than the conventional use of reservoir energy and reservoir repressurizing schemes with gas or water. On the average, conventional production methods will produce from a reservoir about 30% of the initial oil in place. The remaining oil, nearly 70% of the initial resource, is a large and attractive target for enhanced oil recovery methods. 

The reaction of the microorganisms with the reservoir fluids may also produce gases, such as CO2, N2, H2, and CH4. The production of these gases will result in an in-erease in reservoir pressure, which will thereby enhance the reservoir energy. 

Once produced, this singlet state of oxygen can be transported for considerable distances even at moderately high pressures, as the radiative lifetime is 64 min and 02(a A) is very resistant to collisional deactivation. Thus, 02(a A) is ametastable energy reservoir. Energy densities of 10-20 kJ/m are typically attained. 

The production of petroleum from a reservoir may be divided into different phases. The, first stage of oil recovery is where the flow is under the reservoir pressure. Very early in the life of a reservoir, energy must usually be supplied to the porous medium, which bears the crude oil so that it continues to flow to the producing wells. This energy is brought into the reservoir by injection of water or gas (nitrogen, methane, COj) (Tunio et al., 2011). With these secondary recovery methods, about 30%-40% of the original oil in place may be recovered, while the rest may be left in the earth. 

A polymer flood is being proposed for a thin reservoir that contains a 20-cp oil. Table 5.72 summarizes properties of the reservoir, rock, and fluids. The reservoir energy was limited, and primary recovery was negligible. Because of the high oil viscosity, a polymer flood is under consideration. Laboratory tests indicate that a polymer concentration of 300 ppm will increase the viscosity of field brine to 5 cp at the frontal-advance rates expected in the reservoir. Polymer retention at the 300-ppm injected polymer concentration is 20 mg/g, and the density of the rock matrix is 2.65 g/cm. IPV is 0.20. Estimate the oil recovery for a linear polymer flood in this reservoir as a function of PV s of polymer injected to a WOR ratio of 20. Plot oil recovery vs. PV s of polymer injected. Eqs. 3.14 through... 

Primary development of the subject reservoir at Vernon began in 1953 and continued intermittently until 20 wells had been drilled by mid-1963. Initial production rates ranged from 10 to 75 BOPD/well. Due to limited solution gas reservoir energy associated with the viscous 24 to 26° API reservoir oil, production declines were rapid. Production usually decreased to 3 to 5 B/D within a month and reached a relatively stable rate of from 1 to 2 B/D/well within a year after completion. 

The pilot area was essentially depleted of reservoir energy at the time of flood installation. Production rates averaged slightly more than 1 BOPD/well. The 60 bbl/ acre-ft cumulative production amounts to an economic primary recovery of approximately 5 per cent of the oil in place. Reservoir void space at the beginning of injection operations is represented by primary production since the reservoir does not have a gas cap or water drive. 

BP participated in the development of a new biphase turbine that converts reservoir energy to shaft power by passing reservoir fluid through a multistage turbine. It saves 10% in weight and area in cramped offshore platforms. 

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