The way of the oil field development

 

(57) Abstract:

The invention relates to the oil industry and can be used to optimize oil production field, in particular for the development of the field by programming the injection for the directional displacement of oil. The technical result of the invention is to optimize the oil production fields by controlling the energy state of the Deposit without measurement of pore pressure. The method includes drilling, the calculation of the current reservoir pressure Ptechreservoir as a whole and in each well of the PSLE.techin accordance with the dependencies. Then, in accordance with the mathematical formulas build graphics Rtech=f(ln(Vtechand RSLE.tech=f(ln(Qtech). The graphs are slope coefficients for reservoir I and for each well i. Calculate the ratio i/i, and wells with i/i>l are used as injection wells, and wells with i/Il use as mining. When this injection wells consistently develop, starting from the wells with the maximum values of i/I to wells with minimum values is greater than 1 the value of i/I. 1 C.p. f-crystals, 1 record oil field in particular for the development of the field by programming the injection for the directional displacement of oil.

The closest way to develop oil fields to the invention is a method described in patent RU 2044870 from 27.09.1995.

This method of field development involves the drilling of production and injection wells, monitoring the power state of the Deposit, and each well by determining the current ratio of the energy recovery (KEN), water injection and oil extraction, thus limiting the selection of fluid through at least one production well and at the same time increase the sampling fluid, at least one of the wells with the current KEN, great value CAN only field.

This method allows to optimize field development and increased oil recovery through the use of reservoir energy and improve the drainage of stagnant zones in the selection of a product from production wells.

The disadvantages of this method include the fact that the question remains, what wells can be used as an injection, and which as mining, because when developing qui the program is to eliminate the above disadvantages, as well as controlling the energy state of the Deposit without measurement of pore pressure calculated on the basis of the material balance method with 100% coverage calculations on producing and injection wells.

The problem is solved in that in the method of field development, including drilling, control the energy state of the Deposit, and each of the wells, water injection into injection wells and extraction of oil from production wells, monitoring energy state is carried out by calculating the current reservoir pressure reservoir as a whole in accordance with addiction

Ptech=[ln(Vtech-Vn-Vin+VZack)/In(Vtech)]P, Art. C

and on each well in accordance with addiction

PSLE.tech=[ln(Qtech-Qn-Qin+QZack)/In(Qtech)]P, senior SLE,

where Vn- the cumulative oil production in the total deposits, m3;

Vin- the cumulative water production in the total deposits, m3;

Vtech- movable oil reservoir, m3;

VZack- the cumulative water injection in the total deposits, m3;

Qgine, m3;

Qin- the cumulative water production in the well, m3;

QZack- the proportion of injected water per each production well, m3;

P, Art. C- the average hydrostatic pressure on deposits, MPa;

P, senior SLE- hydrostatic pressure on the well, MPa,

then, in accordance with specified formulas, build graphs of Ptech=f(In(Vtech)) and Rtech.SLE=f(In(Qtech)), the graphs are slope coefficients for deposits and for each well, respectively:

;

,

where Rtech.prog- pressure reservoir, recovered to a value close to R, Art. C.;

PSLE.prog- pressure on the well recovered to a value close to R, senior SLE,

calculate the ratio i/i, and wells with i/i > 1 is used as injection wells, and wells with i/i l is used as mining.

Preferably injection wells to consistently develop, starting from the wells with the maximum values of i/I to wells with minimum values is greater than 1 the value of i/I.

The essence of the method consists in tomodem constant control over its energy state, which is estimated by measuring the formation pressure in the well. Direct measurement of formation pressure in the wells with the help of underlying instruments is possible only in wells operated by flush method. In wells operated by mechanical means (using the downhole pump), direct measurement is impossible because of the presence in the borehole of the downhole pump. In these wells reservoir pressure is determined by calculation according to the depth static level. This method has large errors.

The Foundation of mechanized wells, for example, in the fields of Western Siberia is more than 80% of the total Fund wells. Under these conditions control the energy state of the Deposit is seriously complicated.

The proposed method allows to solve problems of control the energy state of the Deposit without measurement of pore pressure calculated on the basis of the material balance method with 100% coverage calculations on producing and injection wells.

For calculation of the required following initial data:

1. Measured by known methods:

Vn- the cumulative oil production in the total deposits;

scrap reservoir;

Qn- the cumulative oil production through the borehole;

Qin- the cumulative water production for the well.

2. Known values:

Vbeg- initial geological reserves of oil reservoir;

Pbegthe initial reservoir pressure prior to the opening of a Deposit (usually equal to the average hydrostatic pressure reservoir R, Art. C);

P, senior SLE- hydrostatic pressure on the well.

As a result of exposure to the reservoir by a selection of oil and water injection it produces the current reservoir pressure Ptech:

where

Vbeg- initial geological reserves of oil deposits, m3.

The current reservoir pressure for each of the production well is determined by the formula:

where

where

QZack- the proportion of injected water allocated for each production well.

Modeling development process

For solving the problem of directional effects of the injection of water to displace oil from subversively zones development process deposits is modeled as follows.

Me is moving oil reserves Vtechas in the whole Deposit, and on each well at the same time.

Modeling the process as a whole reservoir, at the same time by changing parameters in formulas (3) and (4) modeled the process for each hole.

Having a slope coefficients for each well

and total deposits

compare them with the attitude of i/I, which allows us to determine the priority for the division of wells for injection and production.

The criterion is:

i/i > 1-candidate wells in injection;

i/i l-candidate wells in the producing.

For quick effect, choose the following sequence of translation wells under pressure: the maximum values of i/i to the minimum is greater than 1 the value of i/i, depending on the development of reserves. Sequence control of translation by profile design, develop and build a map of current saturation.

For convenience, the choice of the well under pressure map construction and relationship of the angular coefficients.

The definition of additional oil wells and volume of injected water into the reservoir

technical progand movable oil in wells ABOUTtechat the current reservoir:

The volume of injected water into the reservoir QZackis the sum of the predicted share of the injected waterZack.progattributable to each well after increasing reservoir pressure in the transfer of production wells under pressure:

Example

As an example, consider the application of the method on the site of the reservoir And 1-3 of the Samotlor field within the boundaries of OJSC “TNK-Nizhnevartovsk”.

For this object:

Vbeg= 250392085 m3

Vn= 125061065 m3

Vin= 106196616 m3

VZack= 146081072 m3

P, Art. C=17.6 MPa

Cumulative production of oil, water and hydrostatic pressure in the well is given in table:

The calculation of the residual oil reservoir

Vbeg- Vn-250392085-125061065 = 125331020 m3.

The calculation of the current reservoir pressure reservoir Rtech(1)

The calculation of the predicted reservoir pressure reservoir Rtech.progin the second restoring pressure - The ARCS on deposits).

To the current pressure Ptechrecovered to values close to the average hydrostatic pressure reservoir R, Art. C=17,7 MPa (according to the ARC), recoverable reserves Vtechmust be equal:

Vtech.progestimated recoverable reserves of oil reservoir after increasing reservoir pressure in the transfer of production wells under pressure.

In accordance with the formula (1)

where VN. prog- the cumulative oil production at a pressure Ptechnical prog.

Then:

The calculation of the predicted reservoir pressure Ptech.prog:

The calculation of the angular coefficient for deposits of:

Well 16033

The calculation of the current reservoir pressure PSLE.techwell 16033 (2):

The calculation of the predicted reservoir pressure for the well 16033 PSLE.prog, recovered to levels close to the hydrostatic pressure (in accordance with the recovery curve - ARC well):

where Qtech.prog- forecast mobile C fraction of injected water, per well with a formation pressure PSLE.prog

The angular coefficient of the i well 16033:

The calculated ratio i/I for a well 16033:

The value of i/I is less than 1, therefore, the well 16033 operate as mining.

Well 16036

The calculation of the current reservoir pressure PSLE.techwell 16086 (2):

The calculation of the predicted reservoir pressure for the well 16086 PSLE.prog, recovered to levels close to the hydrostatic pressure (in accordance with the recovery curve - ARC well):

The angular coefficient of the i/I in well 16086:

The calculated ratio i/I for a well 16033:

The value of i/I is less than 1, therefore, the well 16086 operate as mining.

Well 18311

The calculation of the current reservoir pressure PSLE.techwell 18311 (2):

The calculation of the predicted reservoir pressure for the well 18311 PSLE.pravlenie - ARC well):

The angular coefficient of the i well 18311:

The calculated ratio i/I for a well 18311:

The value of i/i is greater than 1, therefore, the well 18311 should be converted from production to injection.

The calculation of the additional oil production (accumulated) Qnaccording to wells (5):

SLE. 16033 QH1= 723578-232218 = 491360 m3;

SLE. 16086 QH2= 233091-74806 = 158285 m3;

SLE. 18311 QH3= 403995-129654=274341 m3.

Total additional oil production at the site of the reservoir A1-3 of the Samotlor field by increasing the reservoir pressure after transfer well 18311 in the discharge will be:

Injected volume on the specified area of the reservoir A1-3 is determined in accordance with formula (6) as follows:

1. The method of field development, including drilling, control the energy state of the Deposit, and each of the wells, water injection into injection wells and extraction of oil from producing wells, characterized in that the control energy state is carried out by calculation of the current stratum d is>VZack)/In(Vtech)]P, Art. C

and on each well in accordance with addiction

PSLE. tech=[ln(Qtech-Qn-Qin+QZack)/In(Qtech)]P, senior SLE ,

where Vn- the cumulative oil production in the total deposits, m3;

Vin- the cumulative water production in the total deposits, m3;

Vtech- movable oil reservoir, m3;

VZack- the cumulative water injection in the total deposits, m3;

Qtech- moving the oil through the borehole, m3;

Qn- the cumulative oil production at the well, m3;

Qin- the cumulative water production in the well, m3;

QZack- the proportion of injected water per each production well, m3;

P, Art. C- the average hydrostatic pressure on deposits, MPa;

P, senior SLE- hydrostatic pressure on the well, MPa,

then, in accordance with specified formulas, build graphs of Ptech=f(In(Vtech)) and RSLE.tech=f(In(Qtech)), the graphs are the angular coefficients

for deposits and

for each well,

PSLE.prog- pressure on the well recovered to a value close to R, senior SLE,

calculate the ratio i/i, and wells with i/i>1 is used as injection wells, and wells with i/i l is used as mining.

2. The method according to p. 1, characterized in that the injection wells consistently develop, starting from the wells with the maximum values of i/I to wells with minimum values is greater than 1 the value of i/I.

 

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FIELD: oil and gas production.

SUBSTANCE: groups of high intake- and low intake-capacity injecting wells are chosen in a single hydrodynamic system and, for each well, oil reservoir properties and permissible degree of pollution of fluid received by high intake-capacity wells are determined. When fluid from low-permeable oil reservoir flows off through high intake-capacity wells, this fluid is cleaned to permissible degree of pollution.

EFFECT: reduced losses in intake capacity of formations and increased time between treatments of wells.

1 dwg

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