The way oil and gas development

 

(57) Abstract:

The invention relates to the field of development of oil fields. The purpose of the invention enhanced oil recovery and the pace of development of deposits, as well as reduced flow, and reduction of specific consumption of heat on oil production and the achievement of the desired temperature is injected into the gas cap water. For this purpose, the injection of the coolant into the reservoir combined with barrier flooding, and barrier flooding is carried out by pumping water with a temperature in excess of the initial sheet. The temperature of the hot water injected along the gas-oil contact is 60 To 300°C or maintained at the temperature to which warms up the roof of an oil rim for the whole period of development. The string of pipe making up the upper part of the heat-insulated pipes. Length metallizovannoj part of the column pipe is selected so that the temperature of the water supplied through the annular space in the field of gas-oil contacts, has reached a predetermined value. 3 C. p. F.-ly, 1 Il.

The invention relates to a method of oil and gas development.

There is a method of developing oil and gas deposits by implementing b is ω flooding conditions for simultaneous operation of an oil rim and gas cap. The disadvantage of this method is the low displacement efficiency of high-viscosity oil injected water. In the oil recovery is not significantly increased and remains very low.

There is a method of developing waterfowl deposits of high-viscosity oils by pumping fluid into the injection well. The injected coolant breaks in production wells in water-saturated part of the reservoir, through which heated oil-saturated part of the reservoir. By heating the oil reduces its viscosity, and oil recovery increases. The disadvantage of this method is the slow warming of the entire thickness of the oil rim, which makes the coverage of the reservoir displacing agent in thickness is low, and the specific flow extraction unit mass of oil high.

There is a method of developing oil and gas deposits, including the injection of inert gas in the gas-oil contact to prevent breakthrough in the gas cap of the coolant, which is pumped into the oil-saturated part of the reservoir. The disadvantage of this method is the slow heating oil rims and low efficiency of oil displacement in the region adjacent to the gas-oil contact.

aboutWith or supported is equal to the temperature to which warms the roof of an oil rim for the whole period of development.

The application listed the distinctive characteristics to achieve this goal in the literature is not detected, which suggests that the proposed solution meets the criteria of "novelty" and "significant differences".

The displacement efficiency of a viscous oil depends largely on temperature. Warming of the productive part of the reservoir to a temperature of 80-120aboutWith leads to a sharp decrease in the viscosity of the oil, which substantially increases the efficiency of its displacement. For heating the reservoir into the reservoir pumped fluid. If the Deposit is a fringe of oil with a gas cap and an active bottom water, the injected coolant enters mainly in water-saturated part of the reservoir, talanta. To prevent penetration of fluid into the gas cap and breakthroughs gas production wells, along with thermal impact of implementing barrier flooding by pumping cold water into the gas cap. However, when the thickness of the rim oil heating layer injected into the region of the oil-water contact coolant is extremely slow. As a result, the rate of extraction of oil remain very low, and the specific flow of the coolant increases. More effectively you can develop waterfowl reservoirs, pumping the coolant in the gas cap, and in the area of oil-water contact. In the latter case, heating of the oil rim is twice as fast, and the pace of development are almost two times higher.

The method is illustrated in the drawing.

The method is as follows. In injection well perforined production casing not only in the oil-saturated part of the reservoir, but a few meters above the gas-oil contact, and a few yards below the oil-water contact. The perforation interval in saturated and gas-saturated zones determine, based on the projected expenditure of the heat carrier in gatewat water, and in this case the hot water. To reduce heat loss in the trunk injection wells suitable hot agent to upload the string of pipe and the cold water in the annular space. The string of pipe, which pumped hot agent (hot water or steam), it is advisable to do a composite, when the upper part of the column is collected from teploizolirovannykh pipe, and the bottom of metallizovannyh pipes. When the contact of cold water with a heat-insulated pipe is heated and the temperature of agents can practically lining. If the heat from the injected steam into the reservoir last fully condensed and converted into hot water, installation of the packer downhole injection wells is not required. If, after heat exchange at the bottom of injection wells supplied water vapor, which require the installation of a packer separating gas and oil-saturated part of the reservoir, because the use of steam as a barrier impractical. For calculation of heat transfer between the cold water, moving along the circular space, and a hot agent acting in a string of pipe, using a special developed in the MING method.

Based on hot (Gg) and cold (Gxwater. The degree of dryness of steam (hot fluid) is determined by the following dependencies:

X=Xo1-e+a5Z+a6Z2< / BR>
(1)

Cold water temperature:

=ts+ 1-e-(ts-x)e + Z

(2)

At full steam condensation in the tubing in hot water or in the case of injection of the surface temperature of hot water is determined as follows: t a12exp (a10z) + a11exp (a9z) + a8+ Gz, (3) and the temperature of the cold heat-carrier:

+xa10Z)+aexp(a9Z)+

(4)

where a1a a2a3< / BR>
a4=a2+a3; a5a6< / BR>
a7=a+a2+a3; a8=aa3o-a7G; a9= +

a10a11< / BR>
a12< / BR>
where x is the current degree of dryness of steam at depth z;

xaboutthe degree of dryness of steam at the wellhead

tsthe temperature of the steam or hot water at the mouth,aboutC;

xthe temperature of the cold water in the mouth,aboutC;

x' cold water temperature at the depth of a complete steam condensation,aboutC;

- current temperature of cold water at depth z,aboutC;

z depth considered secenege coolant for rocks W/(m2K);

TO2the coefficient of heat transfer from the cold fluid to the rocks, W/m2K);

r latent heat of vaporization, j/kgK;

WITHWGWITHpxthe specific heat of hot and cold fluid, respectively. J/kgK;

d1the internal diameter of the tubing. m;

d2the inner diameter of casing m;

the temperature of the surrounding rocks in this section of hole,aboutC;

aboutthe temperature of the undisturbed layer of rocks, aboutC.

The temperature is injected into the reservoir pair depends on the reservoir pressure. When a significant reservoir pressure steam temperature may be much larger than necessary for efficient oil displacement. If water vapor gets into the water-saturated zone of the collector, he quickly condenses, mixing with formation water, and then filtered in the form of hot water. In the gas cap of the high-temperature coolant is not needed, because to a certain extent the increase in oil recovery with significant temperature increase, and then gradually decreasing, it becomes inconspicuous. For such deposits reduce heat loss, it is advisable to limit the temperature of the water is impressive for the displacement of oil at different temperatures. Experience of application of thermal methods of oil deposits shows that the minimum temperature is injected into the gas cap water should be 60aboutFor deposits, lying at a small depth with low reservoir temperature and high viscosity oil. At a lower temperature water displacement of oil ineffective, and enhanced oil recovery is not enough. The maximum temperature of the injected water reaches 300aboutWith as at a lower temperature in fractured-porous collector efficiency of capillary impregnation may be low and does not provide a sufficient increase oil recovery. At higher temperature of the injected water increase oil production does not compensate for the costs of heating water to a higher temperature. If oil b has a small thickness, and the distance between the wells is high, then all oil-saturated part of the reservoir is heated to a considerable temperature. In this case, the cold water will reduce the temperature of the oil rim, contributing to the fall in oil recovery. When developing such fields temperature is injected into the gas cap water should be higher than the one to which warms the roof of an oil rim for the entire term solution is to replace the o)erf(l/2) temperature of the formation at a distance l from the sole of an oil rim in time after the start of discharge of the coolant;

taboutthe initial temperature of the reservoir;

and the coefficient of thermal diffusivity of the reservoir;

The method is as follows.

On the field, lying at a depth of 400 m, the oil rim with a thickness of 30 m is not underlain by water and covered with a gas cap. Oil viscosity 100 mPas very slowly displaced water and gas producing wells, resulting in maximum cut and maximum gas factors are achieved when the rate of only 20% With the aim of increasing the efficiency of oil displacement decided to pump fluid along the oil-water contact, and along the gas-oil contact. Laboratory experiments it was found that the effective displacement of the oil is achieved at a temperature of 60aboutC. Therefore, it was decided to further flooding to use water with a temperature of 60aboutC. to this end, in the well was lowered composite column, the upper part of which consists of heat-insulated pipes and the bottom of metallizovannyh pipes. The annular space isolated from the downhole injection squaretoe steam with a temperature of 250aboutWith the amount of 200 tons/day, and the annular space in the well served with a rate of 100 t/d cold water, which is heated before entering the area of the gas-oil contact to a temperature of 60aboutC. To achieve this temperature composite column shall consist of insulated pipes with a length of 70 m and metallizovannyh pipes with a length of 330 meters of the Injection fluid into the formation is carried out cyclically (six months injection and six months break). Due to the application of the method development time is one element of the system arrangement of wells is reduced by 1.5 times from 15 to 10 years, production increased by 15%

On the field, lying at a depth of 1400 m, the collector of which is represented fractured-porous limestone, oil rim thickness of 45 m and is underlain by water and covered with a gas cap. Oil with a viscosity of 1 Pas virtually no stesnjaetsja gas and very badly displaced water at reservoir temperature, component 20aboutC. it Was found that the effective capillary impregnation takes place at a temperature of 180-200aboutC, therefore, it was decided to pump the gas cap water with a temperature of 320aboutAnd in the annular space injection wells serves 75 tonnes of cold water, which is, however, the pumping pipe shall consist of insulated pipes (upper 350 m) and metallizovannyh pipe (lower 1050 m). Due to the application of the method development time deposits declining by 1.8 times, and the specific heat consumption will be reduced by a factor of 1.2.

Field oil rim thickness of 10 m underlain by plantar water and covered with a gas cap. Oil with a viscosity of 300 mPas very badly displaced gas and water at the initial reservoir temperature (30aboutC). When a natural mode of production does not exceed 10% in order To increase oil recovery factor decided to pump in the reservoir water vapor having a temperature of 320aboutC. the Coolant injected into the region of the oil-water contact, will effectively warm the oil-saturated part of the reservoir. To create a barrier between the gas cap and oil rim in the area of gas-oil contacts pumped water. However, if injected at the barrier flooding water is cold, the oil rim will be cooled, and production to decline. Development time is one element of the system arrangement of wells up to 10 years. During discharge of the coolant roof rim oil is heated to a temperature of 130aboutC. So as to prevent cooling of the reservoir in the area of oil and gas should contact nanolane pumping pipes, the upper part of which consists of heat-insulated pipes and the bottom of metallizovannyh pipes. Length metallizovannoj part of the column at the rate of steam injection 200 tons/day, and cold water 100 t/d will be 400 m with a total length of the column 950 m due to the application of the method of oil recovery compared to the prototype will increase by 5%and development time will be reduced by 1.4 times.

1. The WAY OIL and gas DEVELOPMENT, including the injection of fluid through the string of pipe wells in the reservoir and agent, preventing outbursts of gas from the gas cap into the producing wells, characterized in that, to increase oil recovery and the pace of development of deposits, as agent, preventing the breakthrough of gas from the gas cap into the producing wells, use hot water with a temperature above the initial reservoir.

2. The method according to p. 1, characterized in that, to reduce specific consumption of coolant, the temperature of the hot water injected along the gas-oil contact is 60 300oC.

3. The method according to p. 1, characterized in that the temperature of the water injected along the gas-oil contact is maintained equal to the temperature to which the heated roof oil autolocked heat oil and achieve the desired temperature is injected into the gas cap water, the column of tubes through which flows the fluid in the reservoir, consists of heat-insulated pipes in the upper part and the lower part consists of metallizovannyh pipe, and the length of metallizovannyh pipes selected depending on conditions of temperature, injected in the annular space hot water.

 

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FIELD: oil and gas production.

SUBSTANCE: invention provides a method of developing oil pool allowing production of oil from water-rich oil reservoir under difficult geological-tectonic conditions in the last development stage. In the method, neutral salt of carbonic acid and acid solution are forced into formation through injecting well with water generated in gas-liquid fringe created in formation. After pumping of neutral salt of carbonic acid, acid solution is pumped by portions alternating with water pumping. Before pumping of acid solution portions beginning by at least second portion, selective insulation of high-permeable formation intervals is performed. Aforesaid neutral salt of carbonic acid utilized is sodium carbonate aqueous solution or aqueous suspension of calcium carbonate and aforesaid acid solution is aqueous hydrochloric acid solution. Selective insulation of high-permeable formation intervals involves use of freshly prepared controllable viscoelastic composition containing water-soluble acrylic polymer, cross-linking agent, thermal stabilizer, surfactant, and water. Summary concentration of acid solution is determined from concentration of neutral salt of carbonic acid on the base of stoichiometric proportions.

EFFECT: increased efficiency of maintaining formation pressure and thereby oil recovery of formation due to leveled displacement front and reduced probability of the rupture of formation rock backbone, and simplified control of phase state of gas-liquid fringe by changing pressure of pumped acid solution portions.

8 cl

FIELD: oil and gas production.

SUBSTANCE: invention aims at increasing productivity of oil- and gas-producing and injecting wells exposing high-temperature low-permeable oil reservoirs. In the treatment method according to invention including forcing enzyme substrate and separate enzyme into formation and creating conditions to enzymatically convert substrate into acid, geologic and productive characteristics for each interval of bottom zone are determined in order to pick out low-permeable intervals of oil reservoir for treatment, whereupon properties of enzyme substrate and separate enzyme as well as conditions for their pumping are chosen. Substrate utilized in the method is head fraction of methyl- and/or ethyl-, and/or butyl acetate production, to which aliphatic alcohols are added, and enzyme is an acid solution. Substrate is pumped simultaneously and/or before, and/or after pumping of enzyme, after which well is closed for some time and then opened and placed under predetermined operational conditions.

EFFECT: enhanced efficiency of acid treatment due to increased phase permeability for oil and deepness of active acid-treated zone of low-permeable oil reservoirs.

25 cl, 1 tbl, 3 ex

FIELD: oil and gas production.

SUBSTANCE: invention is intended for use during development of oil pools at different waterflooding phase for intensifying functioning of producing wells and increasing current oil recovery of formation. Composition contains, wt %: liquid hydrocarbon 10.0-20.0, oil-soluble surfactant 0.3-5.0, water-soluble or water-oil-soluble surfactant 0.1-1.0, superfine hydrophobic material 0.1-2.0, and water (the rest). Composition may further contain 0.3-5.0% calcium chloride. Oil recovery is increased owing to hydrophobization of formation structure, reduction of surface tension in water/rock/oil phase boundary, increase in detergent power of polluted surface, increase in composition viscosity, and increase of relative permeability of the formation for hydrocarbon phase as compared with water phase.

EFFECT: increased oil recovery.

2 cl, 2 tbl, 2 ex

FIELD: oil and gas production.

SUBSTANCE: composition contains 0.05-2.5% of hydrophobic power, 0.05-10% of ethylene/vinyl acetate copolymer, and organic solvent. Composition intensifies oil production owing to increased effective radius of formation bottom area treatment, prevention of moistening inversion effect upon fall of hydrophobic agent concentration, and, consequently, decreased volume of simultaneously produced water.

EFFECT: increased oil production, prolonged overhaul period, improved environmental safety, and lowered production expenses.

2 tbl, 3 ex

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes drilling product and force wells, forcing gas and water through force wells into separate zones of productive bed and extraction of hydrocarbons from product wells, forming separate gas, water and hydrocarbon saturated areas with major contents of respectively gas, collected therein for later use, water and hydrocarbons, periodical pumping of collected gas from formed gas saturated zones to water saturated zones, periodical pumping of water to gas saturated zones is performed. It is possible to pump collected gas to water saturated zones in form of gas-water mixture. It is possible to pump in passing gas of current deposit. It is possible to pump hydrocarbon or non-hydrocarbon gas from other sources. It is possible to pump water with admixture of specifically selected chemical reagents or compositions thereof. When gas content in water saturated zones reaches from 0.1 to 28% from water content in water saturated zones it is reasonable to generate resilient waves with frequency within range from 0.0001 to 45 KHz and amplitude within range from 0.02 to 2.8 MPa. It is reasonable to pump gas and water to separate areas of productive bed with concurrent generation of resilient waves in there with frequency within range from 0.0001 to 45 KHz and amplitude within limits from 0.02 to 2.8 MPa.

EFFECT: higher efficiency.

7 cl, 5 dwg

FIELD: oil extractive industry.

SUBSTANCE: method includes pumping of Sulfacella water dispersion into bed through force well and extraction of oil through extracting well, said dispersion additionally containing non-ionogenic surfactant AF9-12 with following ratio of components, in percents of mass: Sulfacella 0.5-1, AF9-12 0.01-0.1, water- the rest, while, before pumping of said dispersion mineralized water is pumped with total mineralization until 290 g/l in amount of 10% from volume of said dispersion, when pumping said dispersion prepared in fresh water, drain water is previously pumped, and when pumping said dispersion made from drain or bed water, bed water is previously pumped. For preparation of said dispersion fresh, drain or bed water is used with mineralization till 290 g/l.

EFFECT: higher efficiency.

2 cl, 2 tbl

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes examination of operation well for gas-condensation and periodical cleaning of face-adjacent well area from precipitating hydrocarbon condensate by pumping hydrocarbon condensate solvent into bed, exposure of well for period of condensate dissolution and following removal of received solution from face-adjacent area during well launch, as solvent binary mixture is used with unlimited mutual solubility of components, while at least one of them has unlimited mutual solubility with hydrocarbon condensate, and relation of binary mixture components is determined from previously built phase diagram of three-component system, formed during dissolution of hydrocarbon condensate. As binary mixture with unlimited mutual solubility of components a mixture of acetone and methanol is used, or chloroform and methanol, or chloroform and aniline, or chloroform and acetone.

EFFECT: higher productiveness.

2 cl, 3 ex, 6 tbl, 2 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes placing water solution of carnallite ore, either modified, concentrated, or mixtures thereof, said solution is used at maximal for well temperature conditions concentration and is pumped in amount, necessary and enough for forming a hydraulic column in well shaft above ceiling of productive bed and along remaining shaft height well is filled with water up to mouth. Carnallite ore used has composition, in percents of mass: potassium chloride 20.5-21.5; sodium chloride 19.5-22.5; magnesium chloride 24.0-27.0; crystallization water 29.5-30.5. Modified ore has composition, in percents of mass: potassium chloride 23.0-29.5; magnesium chloride 31.8-46.0; crystallization water - the rest. Said water solution is prepared by dissolving ore in fresh technical water, drained from oil preparation plants, or in bed water. In case of dissolving in bed water, the latter is pumped from well at temperature 60-90°C. During perforation of well, value of technological liquid hydraulic column above productive bed ceiling is taken equal to (1.03-1.07)-(1.05-1.1)Pb, where Pb - productive bed pressure. Water solution of carnallite ore is used at density 1.23-1.37 t/m3. During use of said solution as working body of force wells it is used at density 1.05-1.20 t/m3, and solution also contains swelling inhibitor for argillaceous component of oil and gas bearing bed, like oxyethylenedendiphosphone acid, in amount 0.05-0.15% of used dissolved ore mass.

EFFECT: higher efficiency.

1 cl, 4 ex

FIELD: oil industry.

SUBSTANCE: method includes treatment of face area of oil bed by hydrophobic agent in organic solvent and pressing oil from collector with following delivery of oil from face area of product well for treatment of oil terrigenic bed, in form of hydrophobic agent solution of ethylene copolymer with vinylacetate in ethylbenzol or fraction thereof is used in relation 1:1 - 10, treatment of face area is performed with following ratio of components, in percents of mass: ethylene copolymer with vinylacetate 0.05-2.0, ethylbenzol or fraction 0.05-20.0, organic solvent - the rest.

EFFECT: higher efficiency.

2 tbl, 2 ex

FIELD: mining industry and alternative fuels.

SUBSTANCE: coal is affected by methanogenic consortium of microorganisms with culture medium utilizing continuous pumping of culture medium through wells and tank wherein methanogenic consortium of microorganisms with culture medium is placed. Tank is installed on the surface above wells and pumping of culture medium from the bottom of tank through methanogenic consortium of microorganisms. Process produces biogas and coal-water fuel.

EFFECT: increased yield of biogas to continuously effecting culturing of microorganisms.

1 dwg, 2 tbl

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