Leak-tightness determination method for underground gas storage facilities with water drive operation mode

FIELD: oil and gas industry.

SUBSTANCE: stratum is impact cyclically, at that each cycle of impact includes gas injection to the stratum with further gas extraction. The stratum is impacted during 10 cycles at least. In each cycle current formation pressure as well as gas extraction (or injection) volume is measured simultaneously in gas- ( P t ' ' ф ' ' ) and water-bearing ( P t ' ' ф в ' ' ) zone of the storage facility, then considering the measured parameters the design pressure in the underground storage facility ( P t ' ' P ' ' ) is defined for the facility operation mode without gas losses and operation mode with gas losses. Then function (F) is defined as arithmetic mean value of deviations ( P t ' ' P ' ' ) from ( P t ' ' ф ' ' ) , which are received for each ith measurement for the facility operation mode without gas losses and the function (Fy) for the facility operation mode with gas losses and when inequality Fy<F is satisfied the summary is made about available gas leaks in the storage facility.

EFFECT: simplifying control of gas leak-tightness, improving reliability and safety of the underground storage facilities made in the water-bearing strata.

1 tbl

 

The invention relates to oil and gas industry and can be used to control the safe operation of underground gas storages (UGS) with water mode of operation.

Known hydrogeochemical method of determining inter-layer flows of gas in gas fields (Agishev A. P. Cross flows of gas at the development of gas fields. Moscow: Nedra, 1966, S. 79-88), which is in the exploration stage define constant hydrogeochemical background around the vertical incision. Then the accumulated data on the geochemical environment of the studied section intervals compare with the natural background of the field and identify emerging trends change on a particular area. The disadvantage of this method is the complexity of its implementation due to the need to study the initial hydrochemical background prior to injection of gas into storage. In addition, the application of the above method for UGS is associated with significant costs for the drilling of monitoring wells, because hydrogeochemical studies should be carried out in specially drilled test wells located in the path of the gas reservoir, and water samples should be selected in a well-isolated wells, retaining reservoir conditions (temperature and pressure), which leads to caribcan when determining the tightness of UGS.

The closest to the proposed method (prototype) is a method for studying dynamic processes gas environment UGS (RF patent No. 2167288, E21B 47/00, publ. 20.05.2001), including the introduction into the reservoir through different injection wells indicators in gas media, sampling of gas from the producing wells and the determination of concentrations of indicators over time in the production wells. In the period of maximum gas pressure chosen by the Central injection well, located in one or more operational levels, based on the location of production wells by area, using the indicators of multiple colors, and upload the indicator of the same color in the form of a gas-filled micro granules with the degree of dispersion of 0.5-0.6 μm, consisting of a mixture of polycondensation resins and organic luminescing substances in the estimated quantity. During the pressure reduction to the minimum weighted average by area size at the same time take samples of gas from wells located in one or more operational levels, and determine the time variation of the concentration of indicators of each color and volume rate of all gas production wells are the total number of the indicator of each color received in each production well, for the Anna formula. Build maps and largest share of migrating gas identify areas in-situ casting and cross flows and framing gazodinamichesky different zones. The disadvantage of this method is the need for identification of indicators by five parameters, which complicates the implementation of the method and reduces the reliability of the study of dynamic processes of the gas environment.

The task to be solved by the invention, is to develop a method for determining the integrity UGS created in the aquifer, the water mode of operation that enables to determine the leakage of gas from underground storage facilities during the entire period of operation.

The technical result, which directed the present invention is to simplify the control of the leak, which leads to increased reliability and safety of operation of UGS, created in aquifers.

This technical result is achieved due to the fact that in the proposed method of determining the tightness of UGS carry out cyclical effects on the reservoir, wherein each cycle includes a gas injection through wells into the reservoir until the value of the reservoir pressure not exceeding the maximum allowable design value, with subsequent OTB is rum gas until the value of the reservoir pressure is not below the minimum allowable design value. The stimulation is carried out, at least for 10 cycles, with each cycle periodically simultaneously measure the current pressure in the gas(Ptf)and aquifer(Ptfin)the storage zone, and the amount of selection (or injection) gas (qt). Then taking into account the measured parameters determine the design pressure in underground gas storage(PtP)for the operation mode storage without leakage of gas from the relationship

(Ωo-qin)Ptp/Zt-ΩoPo/Zo=0tqtdt, (1)

where Ωo- gas-saturated pore volume UGS,

Pothe initial reservoir pressure,

PtP - estimated reservoir pressure at the time t,

Zo- the initial factor sverkhlineinoi gas

Ztis the coefficient of sverkhlineinoi gas at time t,

qt- volume injection (or selection) of gas at time t;

qin- volume pushed (or established) produced water in the gas storage zone at time t, with

qin=Cin(PtP-Ptfin), (2)

where Cinis the coefficient of proportionality pushed (or established) produced water in the gas storage zone;

and mode of operation of the store with gas leakage ratio

(Ωo-qin)Ptp/Zt-ΩoPo/Zo=0tqtdt-Cy 0tPtpZtdt,(3)

where Cythe proportionality coefficient of the gas leak.

Then define the function (F) as the average of the deviations of(PtP)(Ptf)received at each i-th dimension for the operation of the store without gas leaks

F=1ni=1n|(PtiP-Ptif)|, (4)

where n is the number of measurements of reservoir pressure,

i - ordinal number of the measurement reservoir pressure;

and the function (Fyfor operation mode store with gas leaks

Fy=1ni=1n|(PtiP-Ptif)|,mtext> (5)

and the execution of inequality Fy<F conclude that the presence of gas leaks in the repository.

During the operation of UGS gas leak mostly fixed in the later stage of their development, that is, when the manifestation of the gas to the surface and pollution control horizons, which further complicates the search for the specific cause of the gas leak, and can cause serious complications during the operation of UGS.

For UGS change the volume of the gas in the reservoir in time is determined from the equation:

dVt/dt=qt, (6)

where Vtthe volume of gas in the reservoir at time t;

t - time;

qt- volume selection (or injection) of gas per unit of time t.

Turning to the integral form, we obtain:

0tdVt=0tqtdt (7)

Vt-Vo=0tqtdt, (8)

where Vothe volume of gas in the initial moment of time;

From the material balance equations (Zakirov S. N. "Design and development of gas fields". M.: Nedra, 1974, S. 28-35) it is known

Vt=ΩtPt/Zt, (9)

where Ωt- gas-saturated pore volume of the reservoir at time t;

Pt- formation gas pressure at time t;

Ztis the coefficient of sverkhlineinoi gas at time t.

Equation (9) for storage in the aquifer with the water regime of exploitation takes the form

(Ωo-qin)Ptp/Zt-ΩoPo/Zo=0tqtdt,the (10)

The coefficient of sverkhlineinoi (Z) depends on the gas composition, temperature, pressure, and is the reference index is (Trebinje F. A. "Natural gas production". M.: Nedra, 1976, S. 78-85). Z one can accurately be approximated by a polynomial of the form

Zt=aPt2-bPt+c, (11)

whereaa , b, c are the coefficients of the polynomial.

Thus, the mode of operation of UGS with water regime describe through the measured parameters selection (injection) gas and pressure in the gas and water-bearing formation zone the following system of equations

{(Ωo-qin)PtpZt-ΩoPoZo=0tqtdtZt=aPt2-bPt +cwhat is (12)Z0=aP02-bP0+cqin=with ain(Ptp-Pfin)

Tightness (the presence of a flow of gas), i.e., the mode of operation of the underground gas storage facilities gas leaks equation (6) takes the form

dVt/dt=qt-qty, (13)

whereqtythe flow rate of the flowing gas from storage per unit of time t.

The flow rate of gas leakage from underground storage facilities can be described by equation (Zakirov S. N. "Design and development of gas fields". M.: Nedra, 1974, S. 220-226)

Qy=Cy0tPtZtdt,mtext> (14)

where Cy- coefficient of a gas leak.

Then for the operation of UGS in water mode with gas leaks equation (14) takes the form

(Ωo-qin)Pt/Zt-ΩoPo/Zo=0tqtdt-Cy0tPtmrow> Ztdt(15)

To calculate the reservoir pressure(PtP)the UGS operation with the water regime can be described by the following system of equations:

- no gas leaks

{(Ωo-qin) PtpZt-ΩoPoZo=0tqtdtZt=aPt2-bPt+cthe (16)Z0=aP02-bP0+cqin=with ain(Ptp-Pfin)

- gas leaks

{(Ωo-qin)Ptp Zt-ΩoPoZo=0tqtdt-Cy0tPtpZtdtZt=aPt2-bPt+c (17)Z0=aP02-bP0+cqin=with ain(Ptp-Pfin)

To estimate the variance of the estimated reservoir pressure (PtP)from the actual(Ptf)use the function (F) characterizing the technological model of operation of UGS, obtained by solving equations (16) and (17), relative to the reservoir pressure(PtP)

F=1ni=1n|(PtiP-Ptif)|the (18)

The method is as follows.

During operation of UGS with water regime carry out cyclical impact is and the reservoir. In each cycle from production wells are injecting gas into the reservoir, followed by selection of gas. The gas injection is carried out before reaching the reservoir pressure in storage, not exceeding the maximum allowable design values. The gas sampling conducted before reaching the reservoir pressure is not below the minimum allowable design value. Cyclical effects on the producing formation is carried out for not less than 10 cycles. During each cycle time per day measure the current pressure in the gas and the aquifer storage zone, and the volume of injection (selection) gas. Then calculate the pressure in UGS(PtP)mode of operation of the store without gas leaks and mode of operation of the store with gas leaks by formulas (16) and (17). Then calculate the function (F) describing the mode of operation of UGS without gas leaks and gas leaks (Fythe formula (18). Perform a comparison of values (F) and (Fy). If Fy<F, conclude that the presence of gas leaks in underground gas storage, i.e. the tightness of the store.

The proposed method was investigated according to UGS. Obtained during the study measured values of reservoir pressure in the gas and water the area of the reservoir, volume injection (selection) gas, as well as calculated values of formation pressures given in the table.

The results of the comparison of measured and calculated parameters, the conclusion was made about the presence of gas leaks in the specified UGS (Fy=2,3, F=4,4), i.e., Fy<F).

Thus, the proposed method can improve the reliability and safety of operation of UGS, created in aquifers by simplifying control the tightness, as well as by improving the reliability of determination of the tightness.

Table
Measured parameters (actual data)Design parameters (water mode)Design parameters (water drive gas leaks)
No. for measureInjection / Sampling (is), million m3The pressure measured in the gas zone,(PtF), PAThe pressure measured in the aquifer zone,(PtFin) , PAPressure(PtP), PAPtP-PtF, PAPressure(PtP), PAPtP-PtF, PA
12345678
1-5,9621,647,021,6021,60
256,4640,547,0 38,02,5of 37.82,7
37553,147,055,2of-2.154,7-1,6
477,6161,147,065,4-4,364,8was 3.7
577,2367,947,170,3-2,469,6-1,7
644,2167,747,168,5-0,867,70
7-2,6563,8to 47.262,21,661,32,5
8-35,5454,447,354,5-0,153,41

Continuation of the table
12345678
9-79,5443,847,343,70,142,41,4
10-82,5432to 47.234,0-232,3-0,3
11-60,4423,747,127,6-3,925,4-1,7
12 -45the 17.347,023,1-5,820,5-3,2
13-6,4219,847,025,4-5,622,8-3
1439,1739,147,037,61,536,62,5
1585,0955,447,056,5-1,157,7-2,3
1677,9861,847,066,0-4,267,1-5,3
1780,5768,447,0 70,9a-2.571,4-3
1852,6569,447,170,0and-0.669,8-0,4
19-11,7961to 47.262,3-1,361,3-0,3
20-54,7151to 47.252,6-1,651,00
21-82,3941to 47.242,1-1,139,71,3
22-77,413047,133,3-3,330,1-0,1
-55,2419,447,127,7-8,323,7-4,3
24-29,7614,947,025,8-10,9of 21.2-6,3
25020,947,029,2-8,3to 25.3-4,4

Continuation of the table
12345678
2642,4943,746,940,7340,63,1
27/td> 81,9257,846,956,8160,4-2,6
2881,2664,547,066,1-1,669,1-4,6
2973,7669,747,069,8-0,171,5-1,8
3054,4269,947,169,50,470,0-0,1
317,2569,6to 47.264,45,263,85,8
32-78,350,3to 47.2 52,2-1,950,00,3
33-81,1340,5to 47.242,4-1,939,01,5
34-76,4130,847,134,2-3,429,61,2
35-54,45to 19.947,129,0-9,123,3-3,4
36-21,8415,947,028,4is 12.522,5-6,6
3717,0432,547,034,0of-1.530,32,2
3846,4248,747,044,0the 4.744,74
3953,5456,947,052,9456,10,8
4077,1664,947,062,12,866,0-1,1
4175,177047,067,22,870,1-0,1
4255,4770,747,168,02,769,41,3

Continuation of the table
12345678
4336,3870,5to 47.266,6a 3.966,83,7
44-70,8953,747,355,3-1,653,30,4
45-88,394347,345,0-241,21,8
46-80,832,6to 47.236,7-4,1of 31.41,2
47-60,47of 21.947,131,2/td> -9,324,5-2,6
48-28,51747,029,7is-12.722,5-5,5
4933,03a 38.547,036,71,832,95,6
5050,09a 50.547,0to 45.45,146,04,5
5166,4858,847,054,44,458,00,8
5287,6466,247,063,13,167,7of-1.5
5371,3670,947,166,9470,10,8
5446,6670,7to 47.266,9the 3.868,52,2
5525,926847,365,12,965,32,7
56-61,0156,147,456,2-0,154,21,9
57-77,0946,147,447,9-1,844,12
58-96,133447,3 38,8-4,833,01
59-67,6224,1to 47.233,2-9,125,8-1,7

Continuation of the table
12345678
60-4917,247,129,5-12,320,8-3,6
6154,5637,647,038,2and-0.633,7a 3.9
6157,3347,147,04,3 0,846,20,9
6337,7753,647,050,82,852,21,4
6493,8563,247,160,13,164,3-1,1
65seen at the level 78.7368,347,165,23,168,9and-0.6
6656,3569,3to 47.266,62,768,90,4
6713,6457,647,464,1-6,564,4-6,8
68-63,0955,347,656,0a-0.753,81,5
69-110,0442,247,645,5-3,340,61,6
70-108,0528,347,436,2vs.-7.9bn28,6-0,3
71-65,2919,7to 47.231,2-11,5of 21.9-2,2
72-34,781547,129,4-14,419,0-4
7329,3531,647,0 34,9-3,327,93,7
7494,75047,047,42,649,01
7535,9847,447,051,3-3,954,1-6,7
76100,365,347,060,94,466,7of-1.4

Continuation of the table
12345678
7772,5767,447,165,0 2,469,6-2,2
7852,7268,6to 47.266,22,468,9-0,3
7924,2867,447,464,72,765,51,9
80-65,0154,347,656,7-2,454,4-0,1
81-9444,247,647,8-3,642,81,4
82-98,84to 33.847,439,6-5,831,91,9
83-78,0322,7to 47.233,5-10,823,6-0,9
84-43,7714,747,130,9-16,219,4-4,7
8513,5225,247,034,3-9,125,10,1
8659,434247,042,5-0,540,02
8784,1955,847,052,13,756,3-0,5
8890,9963,647,0 60,23,466,8-3,2
8980,626847,165,12,970,7-2,7
9066,4369,5to 47.267,42,171,1-1,6
9121,7367,847,465,62,266,71,1
92-65,0957,347,657,7-0,455,41,9
93-86,344747,649,8-2,844,62,4

Continuation of the table1234567894-103,0232,147,541,5-9,433,3-1,295-79,7322,447,335,5-13,125,0-2,696-50,0215,547,132,4-16,920,0to-4.59710,2214.4V47,135,220, 8C24,9situated 10.5 FunctionF=4,4Fy=2,3

How to determine the tightness of underground gas storage facilities with a water mode of operation, characterized by cyclical impact on the formation, wherein each cycle includes a gas injection through wells into the reservoir until the value of the reservoir pressure not exceeding the maximum allowable design value, with subsequent selection of gas until the value of the reservoir pressure is not below the minimum allowable design value, and the stimulation is carried out, at least for 10 cycles, with each cycle periodically simultaneously measure the current pressure in the gas(Ptf)and aquifer(Ptfin)the storage zone, and the amount of selection (or injection) gas (qt), then taking into account the measured parameters determine the design pressure in underground gas storage(PtP) for the operation mode storage without leakage of gas from the relation
(Ωo-qin)Ptp/Zt-ΩoPo/Zo=0tqtdt,
where Ωo- gas-saturated pore volume UGS,
Pothe initial reservoir pressure,
PtP- estimated reservoir pressure at the time t,
Zo- the initial factor sverkhlineinoi gas,
Ztis the coefficient of sverkhlineinoi gas at time t,
qt- volume injection (or selection) of gas at time t;
qin- volume pushed (or established) produced water in the gas storage zone at time t, with
qin=Cin(PtP-Ptfin),
where Cin- coefficient proporzionalno and pushed (or established) produced water in the gas storage zone;
and mode of operation of the store with gas leaks from the relation
(Ωo-qin)Ptp/Zt-ΩoPo/Zo=0tqtdt-Cy0tPtpZtdt,
where Cythe proportionality coefficient of a gas leak,
then define the function (F) as the average of the deviations of(PtP)(Ptf)received at each i-th dimension for the operation of the store without gas leaks
F=1ni=1n| PtiP-Ptif)|,
where n is the number of measurements of reservoir pressure,
i - ordinal number of the measurement reservoir pressure;
and the function (Fyfor operation mode store with gas leaks
Fy=1ni=1n|(PtiP-Ptif)|,
and the execution of inequality Fy<F conclude that the presence of gas leaks in the store.



 

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3 cl, 2 dwg

FIELD: transport.

SUBSTANCE: invention relates to application of drones and can be used for continuous control over conditions of oil- and gas-lines, storages, high-voltage lines and similar long structures. Proposed method comprises measurement of flight altitude H, horizontal distance to design distance to touch-down point D, deviation from vertical plane extending through runway axis ΔZ, definition of three velocity components and acceleration at touch-down point, generation of pilot path of lower flight H0(D,D0) and Z0(D,D0) from the point of landing start at the distance D0 reference tough-down point, definition of drone deviation from reference landing part Δh=H-H0(D,D0) and ΔZ=Z-Z0(D,D0), generation of control signals proceeding from measurement results and feeding them to drone control surfaces. Drone landing path cross-section is set as a circle located on the plane perpendicular to reference part and with centre at landing reference line. In case the drone flies out from reference cross-section a new landing part is generated.

EFFECT: higher reliability and safety.

3 cl, 2 dwg

FIELD: measurement equipment.

SUBSTANCE: air pressure is created inside a spacecraft body, and the conclusion is made on availability of local untightness using sensitive medium. The sensitive medium is represented by indicator discrete particles sent with a specified pitch along the surface of its body and changing their trajectories under action of the gas flow from the leak. Deviation in positions of impact sites of these particles is measured as they strike against a sensitive target-screen installed at the specified angle for their reflection into a trap. And sensitivity of measurements is controlled by variation of initial speeds of indicator discrete particles and distance between the source sending indicator discrete particles and the target screen.

EFFECT: simplified diagnostics of spacecraft body untightness, its higher accuracy and reduced time for searching for a leak point.

2 dwg

FIELD: test equipment.

SUBSTANCE: leakage is tested on a step-by-step basis on cylindrical parts and bottoms of a cryogenic tank, but first, the above said components are tested additionally for strength with cryogenic component; then, they are welded; after that, strength test of circumferential welds is performed at normal temperature of an empty cryogenic tank considering the action of total axial load from action of excess internal pressure and external housing tensile loads, and leakage test of circumferential welds is performed.

EFFECT: enlarging the possibility of tests and their simplification, reducing costs for tests of components.

3 dwg

FIELD: mining.

SUBSTANCE: in killed well temperature is measured, and the temperature change rate is measured in the depth intervals located within the productive formations, and in the depth intervals located in immediate proximity from productive formations. In the depth intervals located within the productive formations, the sections are separated, the temperature change rate in which is much higher than the temperature change rate in the depth intervals located in immediate proximity from productive formations. The numerical model of temperature change in a killed well is developed which takes into account the influence of formation fluid filtering at the temperature change rate in the killed well, the measurements results are compared with the results of numerical simulation and using the best agreement of measurement results and simulation results the filtration rate of formation fluids in the depth intervals located within the of productive formations are determined.

EFFECT: identification of depth intervals, where fluid flow occurs, and estimation of rate of their filtering in the location of observation well.

8 cl, 7 dwg

FIELD: measurement equipment.

SUBSTANCE: invention refers to devices for determination of fluid rate and flow direction. down-hole flowmeter sensor containing a housing, tachometric transducer installed in housing including transducer housing, impeller with shaft located in supports with a gap, mechano-electric transducer of impeller rotation installed in transducer housing and being its motionless element in transducer housing as well as being moving element on impeller shaft, protection unit including caps installed on supports one of which is transducer housing, and protective atmosphere source in the form of capsule, to which transducer housing cap is connected. As protective atmosphere, used is protective fluid not mixing with borehole fluid and having less density. Capsule is installed in sensor housing, at that volume of protective fluid in it is not less than volume of transducer housing cap. Capsule is designed as a syringe with spring loaded piston in its housing, which underpiston volume is connected to volume of transducer housing cap. Piston is designed with possibility of contact with its lock installed on curved plate outside capsule housing, designed with possibility of interaction with float moving in capsule housing.

EFFECT: obtaining down-hole flowmeter sensor reliably operating in contaminated borehole fluids at various unrestricted depth of its downwelling in borehole and its hydrodynamic investigations.

3 cl, 4 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: proposed process comprises series of thermometer measurements at quasistationary injection in tubing in interval from its funnel upward to 30-40 m. these measurements are used to define casing pipe tightness above tubing funnel.

EFFECT: accelerated determination.

2 dwg

FIELD: oil and gas industry.

SUBSTANCE: group of inventions is related to oil and gas producing industry and may be used for current accounting of flow rate measurement of gas-condensate and oil well in real time mode. The unit for flow rate measurement of oil wells comprises a hydrocyclone separator with condensate collector. Liquid pipeline connected to a condensate collector and gas pipeline connected to a hydrocyclone separator. A liquid flow meter installed at the liquid pipeline, a gas meter installed in the gas pipeline. The unit is equipped with at least one sampler in the gas pipeline and additional separation unit capable to determine condensate content in gas. Gas-liquid mixture is supplied continuously to the hydrocyclone separator with the condensate collector; the mixture is separated continuously into liquid and gas in the hydrocyclone separator. Gas and liquid are supplied to the gas and liquid pipeline with gas and flow meters, gas and liquid flow rates are defined by the flow meters, at that gas sample is taken from the gas pipeline by the sampler. Condensate in the gas sample is analysed by additional separating installation and the product flow rates are determined considering condensate content in gas against the data of additional separation unit.

EFFECT: ensuring on-line and accurate measurement of quantity of separated liquid, associated gas and gas condensate and potential determination of their composition.

25 cl, 1 dwg, 3 tbl

FIELD: oil and gas industry.

SUBSTANCE: invention is related to oil industry and may be used for calibration of multiphase meters in operating conditions of oil wells. The method includes division of the well product into gas and liquid components. Measurement of the liquid component rate is made by in-series reference Coriolis acceleration flow meter and the calibrated multiphase meter. Measurement of the gas component rate is made by a gas flow meter. For each of the set values for oil well rate pressure drop ΔPi is measured at the calibrated multiphase flow meter at different values of the volume flow Qri of gas component and/or mass flow rate Qmi. The obtained values of the oil well product rate - Qri and Qmi and respective pressure drop values ΔPi are recorded to memory of the controller of the calibrated multiphase flow meter. In process of operation the calibration flow rate factors for the well are specified. When the difference between the compared preset values exceeds the absolute measurement error by the multiphase flow meter then Qmi and Qri values are accepted as the reference values.

EFFECT: improving determination accuracy for factors of the calibrated multiphase flow meter and ensuring on-line control and correcting of its readings in operating conditions of oil wells.

1 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: invention relates to well with horizontal borehole. Well comprises flow string with sealed horizontal borehole seam interval isolator and perforations between said isolators. Flow string is provided with bushes with ID smaller than that of flow string and smooth rustproof inner surface. Flow string houses perforated stem with hollow unions lowered on tubing that can be displaced in lengthwise direction. Unions can tightly interact with the bush inner surface. Said bushes can be equally spaced apart.

EFFECT: higher reliability, simplified design.

2 cl, 2 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: evaluation of fluid inflow fraction from every productive zone of multi-zone productive well comprises determination of pressure at wellhead. Integrated indicator curve (IPR1) is obtained to describe the relationship between pressure and fluid yield from first productive zone and integrated indicator curve (IPR2) is obtained to describe the relationship between pressure and fluid yield from second productive zone. Value for integrated indicator curve at the point of mixing (IPRm) is obtained with the help of IPR1 and IPR2. Initial fluid inflow fraction from first productive zone at mixing points and initial fluid inflow fraction from second productive zone are defined. First total curve of outflow (TPR1) is obtained describing the relationship between fluid pressure and yield, fluid flowing from mixing point to wellhead. First portion of fluid inflow from first productive zone (Q11) and first portion of fluid inflow from second productive zone (Q21) are defined at mixing point with the help of IPRm and TPR1. Machine-readable carrier accessible for processor comprise program including instructions for above listed jobs.

EFFECT: more efficient evaluation of the portion of influx from productive seam.

20 cl, 5 dwg

FIELD: oil and gas industry.

SUBSTANCE: method lies in continuous measurement of total consumption parameters of the well pad: mass flow rate Ml, volumetric gas discharge Qg, volumetric water cut Wl and coefficient Kg/v=0,01ΔQgΔWl, where Qg and ΔWl are differences of the previous and current average numerical values of total consumption of the well pad respectively for free volumetric gas discharge Q¯g and volumetric water cut W¯l. When the value of Kg/v is outside the preset points of ±ΔKg/v, parameters Mli, volumetric gas discharge Qgi and water cut Wli are calculated for each well respectively. The value of Kg/vi=Qgi100Wli coefficient is calculated. Values of Kg/vi coefficients are compared for each well with the current value of Kg/v. The well with variable value of volumetric water cut Wli is identified against minimum difference attribute between the value of Kg/vi of one of wells in the well pad and the value of Kg/v coefficient.

EFFECT: probable identification of the well with variable volumetric water cut of the well pad directly in measurement process of the oil well flow rate.

2 cl, 1 dwg

FIELD: physics; geophysics.

SUBSTANCE: invention relates to oil and gas well survey and specifically to determining the movement profile of fluids into a well from producing layers of multilayer reservoirs. When using the method, there is no need for thermal equilibrium time between well cleanout and perforation, and there is no need to measure the rate of change of temperature in the well before perforation thereof. The technical result is achieved by cooling the bottom-hole area before well perforation; performing well perforation and measuring flow temperature in the well over each perforation area; determining the flow rate of each producing layer, taking into account the thickness of the perforation area and using temperature measurement results obtained in the interval between the end of the initial extraction stage, characterised by the strong effect of the volume of the well and rapid change of flow temperature n the well, and the time, at the beginning of which the cooling effect of the bottom-hole area of the well on the temperature measurement becomes negligible.

EFFECT: high accuracy and reliability of determining the flow profile in a multi-pay well at the initial extraction stage, immediately after well perforation.

8 cl, 10 dwg

FIELD: oil and gas industry.

SUBSTANCE: the method is realized in two stages. At the first stage to the lower horizontal producer a flow string is run in to the beginning of a slotted filter. A heat insulated filter is set in the upper horizontal injector above the slotted filter. In the upper horizontal injector temperature tests are made in the interval from the well head up to the packer. Steam is injected to the lower horizontal producer and temperature tests are made simultaneously in the upper horizontal injector. Upon completion of steam injection to the lower well the final temperature test is made in the upper well. At the second stage fresh water is injected to the upper horizontal injector and a heat insulated flow string is run in with a thermal packer and shank. The packer is set before the slotted filter and control temperature test is made in tubular annulus in the interval from the well head up to the packer. Steam is injected to the upper horizontal injector though the heat insulated flow string, through the packer and shank to the beginning of the slotted filter. At that, periodically, upon commencement of injection, temperature tests are made in tubular annulus in the interval from the well head up to the packer. Upon completion of steam injection the final temperature test is performed in the upper horizontal injector. When required, tests in the lower producer and operational procedures for the wells are interchanged.

EFFECT: improving authenticity of the obtained results during identification of intervals with cross flows behind the casing for wells operated in deposits of viscous and superviscous oil.

FIELD: oil and gas industry.

SUBSTANCE: method includes alternating gas injection and extraction to/from the well and during their alternation one part of the reservoir bed is isolated while the other is penetrated. According to the invention at the well construction stage the production string with a cement-inflatable packer is run in to the well and cemented; at that the packer divides the borehole annulus in the reservoir bed area into two conditional parts. The production string is perforated in both parts above and below the cement-inflatable packer. Thereafter a tubing string with a tubing-casing packer equipped with a circulation valve is run in so that when the tubing string is set to the production string the above circulation valve is placed below the cement-inflatable packer and above the tubing-casing packer between the perforated sections of the production string. Then the space between the production and tubing strings are filled with immiscible portions of the packer fluid. During further operation of the well injection of gas to the reservoir bed is made through the tubing string and lower perforation interval with temporary isolation of the upper perforation interval by one of the packer fluid portions while gas extraction is made through the upper perforation interval and tubular annulus with temporary isolation of the lower perforation interval by the other portion of the packer fluid.

EFFECT: increased efficiency of the method.

2 dwg

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