- •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
8.7. The choice of the areas and wells for injectability profile enhancement technologies implementation.
The major prerequisites for the application of this technology in the areas with a significant degree of reserves depletion and high water cut level of output are the following conditions [20]:
1 . The presence of the distinct geological filtration heterogeneity of the reservoir profile (the prerequisite of the advanced reserves recovery of the definite interlayers). First of all the areas with the distinct heterogeneity are processed.
2 . The correspondence of the development degree of oil reserves to the production watering: the smaller the correspondence, the first the necessity of the work is considered (it indicates the presence of the trapped residual recoverable reserves).
3 . The ratio between the degree of pumping (in percents from the pore volume of the area) and initial recoverable reserves extraction (the efficiency of the reservoir pressure maintenance system). The higher the ratio, the lower the current efficiency of the reservoir pressure maintenance system, and the greater the volume of water without useful work on frontal oil displacement that is injected and recovered. This fact speaks about relative value of artificially trapped residual recoverable reserves. That’s why, it is necessary first of all to pay attention to the areas that have the greater ratio of the pumping degree and initial recoverable reserves extraction.
4. When all the other conditions are equal, first of all the areas of the production facility, corresponding to Kazemi model are processed. These are the areas, with high - and - low permeability interlayers.
5. In the conditions of the homogeneous geological structure, for example in the monolithic deposits, permabilities, defined on producing and injection wells, are compared respectively with pressure build-up curve (PBU) and pressure drawdown curve (PDD). The differences in the direction of greater permeability around the injection wells testify as "the reservoir breathes", i.e. the dependence of the reservoir properties on deformation processes occurring in the reservoir in the result of reservoir pressure differential. The greater the difference, the more vulnerable formations from injection wells stratification and washing that leads to the formation of channelized filtration. An indirect confirmation of the existing differences in the filtration properties of these formations is considered the average specific indices per 1 m3/ (days.MPa) on the injection wells intake capacity and on specific production rate of the surrounding producing wells.
CHAPTER 9. HYDRODYNAMIC ENHANCED OIL RECOVERY METHODS
Hydrodynamic methods are applied at the third and fourth stages of development of the production facilities, they are the secondary methods of oil production and are the most economical methods of enhanced oil recovery. Hydrodynamic EOR methods are divided into: the filtration flow direction change, cyclic flooding and forced fluid withdrawal. Their combined application should be defined as a combined non-stationary flooding, because all these methods are based on the non-stationary fluid filtration.