- •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
3.5. Field development systems
3.5.1. Simultaneous production facilities development
A. Independent development.
It is used for multi-layer deposits, when each production facility is operated by an independent grid. It requires a large number of the wells, as a result, it leads to high capital costs. This system is used in the development of high-productive objects with large oil reserves.
B. Joint development.
This development system considers the combination of two or more layers into a single production facility that are developed by uniform grid of producing and injection wells. Each well at the same time operates two layers that are combined into one production facility. Its advantage is the provision of high current production rate at a given number of wells. However, in general, it is observed an uncontrolled reservoir development; it is difficult to establish the quantity of the extracted oil from each formation, remaining recoverable reserves, production and wells’ injection capacity each stratum separately. This system is used for layers with the same geological structure and similar pool-reservoir properties.
C. Joint-independent development.
This system is used when two layers are combined into one production facility; the producing wells are equipped with installations for dual completion, injection wells – are equipped with installations for dual water injection.
3.5.2. Successive development systems.
1. The up-bottom development is the development system when the underlying object is operated after the overlying. Currently, this system is considered to be irrational, because it retards the prospecting and development of the underlying objects, increases the drilling volume and metal consumption that are used for well casing.
2. The bottom-up development is the development system when objects from the bottom (base, a base object) are started to develop first, and then the upper (return) layers are developed. When there are many layers as a basic one is chosen the most productive, more studied objects with a sufficiently large oil reserves, as the return ones – the other objects are used.
3.6. Oil fields development parameters
3.6.1. Technological development parameters
We consider technological development parameters as a set of field, commercial and other measurements of a production facility, determined on particular date, that characterize the development condition. The technological development parameters are current production rate, cumulative stock-tank oil and fluid production, oil and fluid production rates, a number of active, abandoned, step-out, producing and injection wells, water cut, current ORF, production rates of initial and residual recoverable reserves, etc.
There are more than 50 parameters. They are usually represented in the form of a table, where the time (in years) is illustrated from the beginning of development of the production formation to the last one of the current year and annual development parameters. To analyze the changes of development parameters of during the time the graphs are built (for example, fig. 3.4., 3.5, see below) or the histogram, of the corresponding parameters. In this case we speak about the dynamics, the development parameters changing during the time.
The development parameters changes are necessary to analyze the current state of development, to compare real and project figures, to control reserve recovery, to manage the development process.
The difference of real and project figures indicates either incomplete fulfillment of project decisions, or lack of geological knowledge about the object, or incorrect chosen development system. It means that we need to make changes, corrections of project documents, geological and hydrodynamic models, the choice of activities for regulation of the development of production facility.