
- •Physical foundations of oil fields development and enhanced oil recovery methods
- •Introduction
- •1.2 Pool-reservoir properties.
- •1.3. Heterogeneity and anisotropy of reservoirs
- •2.1. Rock pressure and effective pressure.
- •2.2. Reservoir energy types.
- •2.3. The main sources of reservoir energy.
- •2.4. Operation modes of oil deposits.
- •2.5. Elastic-water drive
- •2.6. Dissolved gas drive
- •2.7. Gas cap drive.
- •2.8. Gravity drive
- •3.1. Productive formation.
- •3.2. The reservoir recovery and oil recovery factor (orf).
- •3.3. The well patterns - development systems of production facilities on natural recovery modes.
- •3.4. Enhanced recovery systems
- •3.5. Field development systems
- •3.5.1. Simultaneous production facilities development
- •3.5.2. Successive development systems.
- •3.6. Oil fields development parameters
- •3.6.1. Technological development parameters
- •3.6.2. Borehole grid. Wells’ density.
- •3.6.3. Krylov’s parameters. Compensation factor. Water cut factor.
- •3.6.4. Oil fields development rates.
- •3.6.5. Development stages of the production facilities (oil fields)
- •3.7. Types of water flooding
- •3.7.1. Edge water flooding.
- •3.7.2. Boundary water flooding
- •3.8. Circle water flooding.
- •3.8.1. Direct line drive systems. Their varieties – block systems.
- •3.8.2. Grid water flooding systems.
- •3.8.3. Selective and Spot water flooding.
- •3.8.4. Barrier water flooding system.
- •4.1. Porous formation models.
- •4.1.1. Deterministic model
- •4.1.2. Stochastic-statistical model.
- •4.2.4. Pollard model.
- •4.2.5. Models use peculiarities of the reservoirs of complex structure.
- •4.3. Water saturation and watering.
- •4.4. Reciprocating and non-reciprocating oil displacement.
- •4.4.1. Reciprocating displacement.
- •4.5. Displacement characteristics.
- •5.2. Project documentation.
- •5.3. Field-geologic characteristic of the deposit.
- •5.4. Rational development system.
- •6.1. Geological peculiarities reservoir structure with high-viscosity oil.
- •6.2. The deposit Russkoye
- •6.3. Katangli deposit.
- •6.4. Canada high-viscosity oil deposits.
- •6.5. The main peculiarities of high-viscosity oil deposits development.
- •7.1. Enhanced oil recovery methods classification.
- •7.2. Production stimulation methods (psm)
- •7.3. Enhanced oil recovery methods (eorm)
- •7.4. The forms of residual oil condition.
- •7.5 The reasons of residual oil condition.
- •7.6. The conditions of effective enhanced oil recovery methods use.
- •7.7. Oil deposits management and enhanced oil recovery methods.
- •8.1. Oil displacement by water solutions of surface-active reagents (sar)
- •8.2. Sar adsorption
- •8.3. Sar (surface-active reagent) composition.
- •8.4. Polymer oil displacement.
- •8.5. Micellar-polymer flooding method.
- •8.6. Conformance change or control (straightening the injectivity profile) (cc)
- •8.7. The choice of the areas and wells for injectability profile enhancement technologies implementation.
- •9.1. Filtration flows’ direction changing.
- •9.2. Forced fluid withdrawal (ffw)
- •9.3. Cyclic water flooding.
- •9.4. Combined non-stationary water flooding.
- •10.1. Oil displacement by carbon dioxide (co2).
- •10.2. Oil displacement by hydrocarbon gas
- •10.3. Water-alternated-gas cyclic injection.
- •11.1. Physical processes, happening during oil displacement by heat-transfer agents.
- •11.2. Oil displacement by hot water and steam.
- •11.3. The method of heat margins.
- •11.4. Combined technologies of enhanced oil recovery of high-viscosity oil deposits.
- •11.5. Thermal-polymer reservoir treatment (tpt)
- •11.6. Cyclic steam treatment of producing wells
- •Disp-lace-ment front
- •Ther-mal front
- •Combustion front
- •Disp-lace-ment front
- •Ther-mal front
- •Injection temperature
- •11.8. Thermal-gas method of treatment.
- •12.1. Formation hydraulic fracturing (fhf)
- •12.2. Well operation with horizontal end.
- •12.3. Acoustic methods.
- •Conclusion.
- •The list of symbols and abbreviations.
- •Content
- •Introduction 3
- •4.1. Porous formation models………………………………………………..38
- •4.1.1. Deterministic model……………………………………………………38
Disp-lace-ment front
Ther-mal front
T C0
Combustion front
Fig. 11.3. The scheme of wet-situ combustion
Reference representations: а - air; б -water; в – steam and air mixture; г - oil; д – steam and combustion gases mixture; е – combustion gases .
The zones of: 1 – the injected water and air filtration; 2,4 – superheated steam; 5 – saturated steam; 6 – oil displacement by hot water; 7 – oil displacement by water under the reservoir temperature conditions; 8 – oil filtration at the original conditions; 3 – combustion front.
Heat transfer to the region ahead of the combustion front is carried out during wet combustion mainly by convection by the flows of evaporated injected water and combustion products, and thermal conductivity. In the front of the combustion front there is formed several temperature zones. The zone of superheated steam, where the temperature decreases from the combustion front temperature to the steam condensation temperature, joints directly to the combustion front The size of this area is relatively small, because the heat loss in the surrounding reservoir rocks leads to rapid cooling of filtering gaseous water steam and combustion products, characterized by low heat capacity.
The main share of the transferred heat to the zone in front of the combustion front is concentrated in the zone of saturated steam – the zone of steam plateau, where the heat loss in the surrounding rocks accompanied by steam condensation of steam in the transition temperature zone - the zone of hot water, generated in the result of the condensation of saturated steam. The temperature in the zone of saturated steam mainly depends on the level of the reservoir pressure with a glance of steam share in the gas flow. Usually within the limits of this zone, it changes slightly and is approximately 80-90 % from the temperature of the saturated steam. The temperature in the transition zone changes from the temperature of steam condensation to the initial reservoir temperature.
Finally, ahead of the transition zone there is situated an area not covered by thermal stimulation, corresponding to the original reservoir temperature. The amount of the formation heating zone in front of the combustion front is largely determined by the rate of heat generation at the combustion front and, (consequently, the rate of air injection) and water-air factor. With the increasing of water-air factor the size of the formation heating zone increases. If the wet combustion process is carried out with the maximum possible value of water-air factor or close to it, almost all the accumulated heat in the reservoir will be located in the area ahead of the combustion front, and the size of this area will be the maximum.
The distribution of temperature field in wet-situ combustion is determined mainly by steam generating at the combustion front and heating by the steam of the area of the reservoir ahead the combustion front. So, temperature conditions, ahead the combustion front during wet-situ combustion, are very similar to the temperature distribution during steam injection to the reservoir (fig. 11.4.).