EP1046780A1 - Verfahren zur Stimulation der Gewinnung von Kohlenwasserstoffen durch Injezierung einer wässrigen und einer gasförmigen Phase, zumindest teilweise mischbar mit Wasser - Google Patents

Verfahren zur Stimulation der Gewinnung von Kohlenwasserstoffen durch Injezierung einer wässrigen und einer gasförmigen Phase, zumindest teilweise mischbar mit Wasser Download PDF

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Publication number
EP1046780A1
EP1046780A1 EP00400945A EP00400945A EP1046780A1 EP 1046780 A1 EP1046780 A1 EP 1046780A1 EP 00400945 A EP00400945 A EP 00400945A EP 00400945 A EP00400945 A EP 00400945A EP 1046780 A1 EP1046780 A1 EP 1046780A1
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Prior art keywords
gas
aqueous phase
fluid
injection
deposit
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EP00400945A
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English (en)
French (fr)
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EP1046780B1 (de
Inventor
Nicole Doerler
Gérard Renard
Alexandre Rojey
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IFP Energies Nouvelles IFPEN
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IFP Energies Nouvelles IFPEN
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/20—Displacing by water
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/164—Injecting CO2 or carbonated water

Definitions

  • the present invention relates to an enhanced recovery method of hydrocarbons by the combined injection of water and gas into a deposit.
  • the method according to the invention finds applications in particular for improve the movement of petroleum fluids to producing wells and this increases the recovery rate of recoverable fluids, oil and gas, initially in place in the rock mass.
  • Recovery is said to be primary when petroleum fluids are produced under the sole action of the energy present in situ. This energy can result from the expansion of pressurized fluids in the deposit: expansion of oil saturated or not in gas, expansion of a gas cap above the oil deposit, or an active body of water. During this phase, if the pressure in the deposit drops below the oil bubble point, the gas phase from the oil will help increase the recovery rate. Recovery by natural drainage rarely exceeds 20% of fluids initially in place for light oils and is often less than this value for heavy oil deposits.
  • Secondary recovery methods are used to avoid excessive pressure drop in the deposit.
  • the principle of these methods is to bring external energy to the deposit.
  • fluids are injected into the deposit by one or more injector wells in order to move the recoverable petroleum fluids (hereinafter designated by "oil") to production wells.
  • Oil is frequently used as displacement fluid.
  • its effectiveness is limited. Much oil remains in place because in particular its viscosity is greater than that of water.
  • the oil remains trapped in the pore narrowing of training due to the large difference in interfacial tension between it and water.
  • the rock mass is frequently heterogeneous. In this context, the injected water will take the paths of greatest permeability to reach the producing wells, leaving large masses of oil not swept away. These phenomena induce a significant loss of recovery.
  • Pressurized gas can also be injected into a deposit at for secondary recovery, the gas has the well-known property of displacing significant amounts of oil.
  • the gas being much less viscous than the oil and water in place, it will cross the rocky massif using only a few of the most permeable and will arrive quickly at producing wells without having the effect of expected displacement.
  • WAG Water Alternate Gas
  • water and gas are injected successively as long as the fluids tankers are produced under economic conditions.
  • the role of water plugs is to reduce gas mobility and increase the swept area.
  • Many improvements of this technique are proposed: the addition of water surfactants in order to decrease the water-oil interfacial tension, adding foaming agent in water: the foam formed in the presence of the gas will reduce significantly the mobility of the latter.
  • One such method is by example described in US Patent No. 3,893,511.
  • patent FR 2,735,524 of the applicant there is also known an improved method consisting in add an agent to at least one of the water plugs injected alternately reducing the interfacial tension between water and gas. Under the influence of this agent, alcohol for example, the oil cannot spread on the film of water covering the rocky massif. The oil remains in the form of droplets which brake the displacement of gas.
  • patent FR 2 764 632 of the applicant we know also a process comprising the alternating injection of gas caps and water plugs in which at least one of the water plugs is added with pressurized gas both soluble in water and oil. The stage of production involves the release of the pressure prevailing in the deposit, so as to generate gas bubbles which will expel the hydrocarbons from pores of the rock mass.
  • Tertiary recovery aims to improve this rate of recovery, when the residual oil saturation is reached.
  • We regroup under this name the injection into the miscible gas tank, of micro emulsion, or steam or in situ combustion.
  • the process of enhanced recovery of a petroleum fluid produced by a deposit according to the invention aims, by a combined injection of a phase water and gas from an external source or, to the extent of possible, at least in part from acid gases from effluents from deposit itself, to increase the rate of recovery of hydrocarbons.
  • the method includes continuous injection through an injection well a sweeping fluid consisting of an aqueous phase with gas added to it less partially miscible in water and in petroleum fluid, with a permanent control at the top of the injection well, of the flow rate report for this aqueous and gas phase forming the sweeping fluid so that, at the bottom of the injection well, the gas is there in a saturation or supersaturation state
  • the sweeping fluid can be formed either at the bottom of the well with separate routing of the constituents to the injection zone, i.e. at the top well
  • a means arranged in the injection well to create a pressure drop such as a valve or a pipe restriction and so increase the rate of dissolution of gas in water.
  • a pump is used multiphase rotodynamic type for example to compress the gas, pressurize the aqueous phase and form an intimate mixture between this phase water and gas under pressure before injecting it into the injection well.
  • the gas in the sweeping fluid contains at least one acid gas such as than carbon dioxide and / or hydrogen sulfide and optionally, in varying proportions, other gas: methane, nitrogen, etc.
  • acid gas such as than carbon dioxide and / or hydrogen sulfide
  • other gas methane, nitrogen, etc.
  • gases can be taken from the effluents from a deposit, operation carried out by a processing unit adapted to separate them from other gases otherwise recoverable or come from chemical units or units thermal burning lignite, coal, fuel oil, natural gas etc.
  • the aqueous phase used to form the sweeping fluid can be for example water from an underground deposit (a water table by example or brine produced during the exploitation of a deposit) or any other readily available water (seawater).
  • the aqueous phase is added a surfactant additive to promote the dispersion of the gas therein and / or one or several additives to increase the solubility of the gas in the scanning.
  • the sweeping fluid is injected, for example, into one or more wells, horizontal or of complex geometry located for example at the base of the deposit .and the fluid tanker is produced for example by one or more deviated wells or complex geometry that can be located on the roof of the deposit.
  • the process can be implemented from the start of the operation of the deposit.
  • the aqueous phase preferably injected at the periphery of the producing area, sweeps the porous medium containing the hydrocarbons to recover.
  • carbon dioxide much more soluble in oil than in injected water, passes fluid sweeping with petroleum fluid causing it to swell and reducing its viscosity.
  • the invention also relates to an assisted recovery system. of a petroleum fluid extracted from a deposit, by continuous injection into the deposit of a sweeping fluid consisting of an added aqueous phase gas at least partially miscible in the aqueous phase and in the fluid tanker, which includes a set for conditioning the sweeping fluid and a permanent control unit for the packaging unit adapted to control the ratio of the flow rates of this aqueous phase and of the gases forming the sweeping fluid reached the bottom of the well, so that the gas is in a state of saturation or supersaturation.
  • the system includes status sensors arranged in the injection area to measure parameters thermodynamic and connected to the control unit.
  • the recovery process which is the subject of the present invention includes four steps:
  • the carbon dioxide mixed with the aqueous phase reacts according to the balanced reaction: CO 2 + H 2 O ⁇ H 2 CO 3 giving carbonic acid.
  • the solubility of carbon dioxide in water depends on the salinity of the water, the temperature and the pressure.
  • the CO 2 dissolution rate increases with pressure and decreases with temperature.
  • the effect of pressure is preponderant.
  • the rate of dissolution of carbon dioxide at the bottom of an injection well is higher than the rate of dissolution on the surface, despite the increase in temperature due to the geothermal gradient.
  • H 2 S For example, under a pressure of 150 bars and for a temperature of 70 ° C, the solubility of H 2 S will be approximately 8.3% by weight (83 kg of H 2 S are dissolved in 1 m 3 d 'water). Acid gases from petroleum production mainly contain carbon dioxide, it is the solubility of this gas which will be limiting when the mixture is dissolved in an aqueous fluid.
  • the volumes of acid gases and water likely to be reinjected into the deposit may be available in a ratio much higher than the ratio of solubility of acid gas in water. This ratio may change during exploitation or according to production constraints.
  • the increase in pressure at the bottom of the injection well is partially compensated by a increase in temperature linked to the geothermal gradient. However, the effect pressure is generally higher, especially as the fluid injected does not reach flow conditions of thermal equilibrium.
  • the fluid scanning is produced by a PA packaging unit and its constituents, brought separately to the injection area at the bottom of the well.
  • the gas is compressed by a compressor 1 and injected by an injection tube 2 to the bottom of the IW injection well, while the water from a pump 3 is injected into the annular space 4 between the casing and the injection tube 1.
  • the mixing between the two phases is carried out under the seal 5 at right of the injection area.
  • the injection pressures of compressor 1 and the pump 3 are determined by a control device 6.
  • the injection of gas requiring a high pressure at the wellhead we prefer to mix the surface before to inject it.
  • This simultaneous injection increases the weight of the liquid column in the injection well, and significantly reduce the pressure gas required.
  • the mixture produced in wellhead is strongly supersaturated with acid gases and particularly homogeneous, the gas being dispersed in the liquid phase.
  • a compression device can be used for this purpose (Fig. 2) and conventional pumping known to specialists, for injecting the scanning under saturation or supersaturation at the bottom of the well.
  • the acid gases are compressed in a compressor 1 in stages successive and cooled between two compression sections.
  • the water is pressurized by a pump 3 at a pressure equal to that applied by the compressor 1.
  • the gas and the liquid are then introduced into a mixer static or dynamic 7 having sufficient efficiency to allow the total dispersion of the gas in the liquid. Downstream of the mixer 7, the mixture can be compressed by an additional pump 8 to allow either dissolution of an additional quantity of gas, i.e. the injection of the scanning in the IW well.
  • Acid gases, heated during the compression can for example be cooled, by means of heat exchangers heat (not shown) before their introduction into the mixer 7 so to favor their dissolution.
  • a multiphase pump of the rotodynamic type can advantageously replace a conventional reinjection chain and fill the three functions: compress the gas, pressurize the liquid phase and mix intimately the two phases.
  • a rotodynamic multiphase pump suitable for this type of application is described in patents FR 2,665,224 (US 5,375,976) of the applicant or FR 2,771,024 of the applicant. By its design, this type of pump can inject a mixture into a well diphasic composed of saturated carbonated water and an excess of carbon gas without cavitation problem.
  • a pressure drop additional in the injection line in the form of a shut-off valve lamination or restriction of the injection pipe.
  • a lining is also placed in the well IW injection to improve the mixture of constituents while inducing an additional pressure drop, preferably in one and the other case of the state sensors (not shown) lowered to the bottom of well, in the injection area, to measure different parameters thermodynamics: pressures, temperatures etc., and linked to the control 6.
  • a transmission system adapted to transmit surface signals from permanent sensors permanently installed in wells to monitor a deposit, and in particular state sensors allowing know for example the temperatures and pressures prevailing at the bottom of the well, is described in particular in US patent 5,363,094 of the applicant.
  • the device control 6 adjusts the flow rates and their ratio in this case according to the conditions prevailing in situ.
  • the system is adapted to form a saturated or supersaturated mixture at least in part through controlled recombination of effluents pumped out of the deposit by one or several production wells from the PW deposit.
  • effluents include generally a liquid phase consisting of water and oil, and a phase carbonated.
  • the effluents therefore pass through a water-oil-gas separator S1.
  • the gas phase possibly supplemented by external contributions, crosses a separator S2 intended to separate the recoverable gases moreover for other applications, acid gases that we want to recycle.
  • Water from separator S1 is then recombined with the acid gases recovered in a controlled mixing device M, so as to form the saturated mixture or supersaturated under the conditions prevailing at the bottom of the well.
  • the pressure required to inject the fluid into the porous mass is less than the CO 2 liquefaction pressure, a liquid phase and a gaseous phase will be present in the injection well.
  • the user must ensure that the dispersion of the gas is maximum and that the gas plugs circulating in the injection well are entrained by the liquid column at the bottom of the well, in other words that the liquid speed is greater than the ascent rate of the gas plugs in order to avoid segregation in the injection well.
  • the pressure required to inject the fluid into the porous mass is greater than the liquefaction pressure of CO 2 .
  • the liquefied gas will be intimately mixed with the water and an emulsion formed of fine droplets of liquefied gas in the water will then be injected.
  • a small proportion of surfactant is added to the aqueous phase, promoting the dispersion of the gas bubbles.
  • additives promoting its dissolution such as monoethanol amine, diethanol amine, ammonia, sodium carbonate, potassium carbonate, sodium or potassium hydroxide, potassium phosphates, diamino-isopropanol, methyl diethanol amine, tri-ethanol amine and other weak bases.
  • concentration of these additives in water can vary from 10 to 30% by weight.
  • the injection wells can be vertical or horizontal wells.
  • the aqueous phase can be injected at the base of the tank to be drained by means of one or more horizontal wells and the liquid hydrocarbon phase can be drawn off from the roof of the tank by means of one or more horizontal wells.
  • the injection and production wells will be vertical, and the sweeping of the hydrocarbons in place will be parallel to the limits of the tank.
  • Wells of more complex geometry can be used without departing from the scope of the present invention.
  • the recovery principle according to the invention makes it possible to provide the deposit additional energy.
  • the benefits of simultaneous injection water and acid gases are plentiful.
  • Carbonated water solubilizes the soluble carbonates present in the rock, calcite and dolomite, by forming soluble bicarbonates according to the reactions: Ca CO 3 + H 2 CO 3 ⁇ Ca (HCO 3 ) 2 Mg CO 3 + H 2 CO 3 ⁇ Mg (HCO 3 ) 2
  • This partial dissolution of carbonates causes an increase the permeability of the porous medium, whether it is sandstone, in which the dissolution will attack the cements and calcium deposits frequently present around the quartz grains, or a limestone formation in which the porous connection will be improved.
  • the gain in permeability resulting from the dissolution of carbonates may be notable, as is well known to specialists.
  • Carbonated water is also known to prevent swelling of clays frequently present in petroleum reservoirs. This effect is particularly sensitive for clays whose basic ion is sodium.
  • the dissolution of calcium also has an influence on the stabilization of clays at sodium ions by replacing sodium with calcium which gives more stable clays resistant to flow without disintegrating and clogging the porous medium.
  • the viscosity of water increases when the CO 2 dissolves in it.
  • the volume of this carbonated water increases from 2 to 7% depending on the concentration of dissolved gas and its density decreases slightly.
  • the overall effect of decreasing the density contrast between water and oil reduces the risk of segregation by gravity.
  • the water / oil mobility ratio is improved by the decrease in the oil / water viscosity ratio.
  • Carbon dioxide is much less soluble in water than in deposit oils. This solubility is a function of the pressure, the oil temperature and characteristics. Under certain conditions, the carbon dioxide may be partially or completely miscible with hydrocarbons. When injected into the deposit as water carbonate, carbon dioxide will preferentially pass from water to oil.
  • the dissolution of carbon dioxide in the oil also causes a decrease in its viscosity. This decrease will be greater when the amount of CO 2 increases.
  • An oil having initially a high viscosity will be more sensitive to the phenomenon. For example, an oil with a density of 12.2 API (0.99 g / cm 3 ) and having a viscosity of 900 mPa.s at ambient pressure and a temperature of 65 ° C will see its viscosity decrease to 40 mPa.s under pressure of 150 bars of CO 2 . Under identical conditions, the viscosity of an oil with a density of 20 API (0.93 g / cm 3 ) will drop from 6 to 0.5 mPa.s.
  • the swelling of the oil like the drop in its viscosity, promotes increased recovery of hydrocarbons initially in place in the deposit. They also speed up the recovery process hydrocarbons.
  • the carbonated water is at least saturated with CO 2 when it is injected into the tank.
  • the pressure of the injected fluid will drop due to the pressure losses linked to the flow.
  • gas will be released.
  • the nucleation of carbon dioxide bubbles will preferably occur in contact with the rock and specifically in areas with a high concentration of rock / liquid interfaces. These zones correspond to massifs of low permeability; the enlargement and migration of the gas bubbles will expel the oil which is trapped in the small diameter pores of the rock. This phenomenon significantly increases the rate of hydrocarbons mobilized during production.
  • the recovery process as described above finds a advantageous application when bringing into production a deposit a double porosity system such as cracked deposits.
  • a simple representation of these deposits is a set of rock blocks from decimetric or metric sizes with pores of small diameters and saturated in oil, linked together by a network of cracks providing a passage to the flow of fluids of a few tens of micrometers on average.
  • the water When these tanks are injected with water as part improved recovery of petroleum effluents, the water will preferably invade the cracks. The water will then tend to soak blocks of low permeability by driving out the oil trapped in the pores towards the network of cracks. If the tank is wettable with water, imbibition will will do under the effect of capillary forces and gravity. If the tank is wettable with oil, only gravity will favor the phenomenon of imbibition.
  • the exploitation of the deposit can include injection and depletion.
  • injection period production will be stopped or decreased while the injection of carbonated water will be maintained, in order to make build up the pressure in the tank above the water bubble pressure and thereby increase the concentration of available carbon dioxide.
  • This injection period will be followed by a production and partial depletion of the deposit.
  • the hydrocarbons produced have increasing concentrations of acid gases. As we saw above, these gases are advantageously separated from the gas that can be reused elsewhere and reinjected into the deposit. If the gas processing and refining units are close to producing wells, gas and oil will be separated by successive detents in separator tanks S1, S2 (Fig. 3) located near the production area.

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  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
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  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
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  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
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EP00400945A 1999-04-23 2000-04-06 Verfahren zur Stimulation der Gewinnung von Kohlenwasserstoffen durch Injezierung einer wässrigen und einer gasförmigen Phase, zumindest teilweise mischbar mit Wasser Expired - Lifetime EP1046780B1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
FR9905584A FR2792678B1 (fr) 1999-04-23 1999-04-23 Procede de recuperation assistee d'hydrocarbures par injection combinee d'une phase aqueuse et de gaz au moins partiellement miscible a l'eau
FR9905584 1999-04-23

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EP1046780A1 true EP1046780A1 (de) 2000-10-25
EP1046780B1 EP1046780B1 (de) 2006-02-08

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US (1) US6325147B1 (de)
EP (1) EP1046780B1 (de)
CA (1) CA2305946A1 (de)
DK (1) DK1046780T3 (de)
FR (1) FR2792678B1 (de)
NO (1) NO20002029L (de)

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FR2792678B1 (fr) 2001-06-15
CA2305946A1 (fr) 2000-10-23
FR2792678A1 (fr) 2000-10-27
NO20002029D0 (no) 2000-04-18
EP1046780B1 (de) 2006-02-08
NO20002029L (no) 2000-10-24
US6325147B1 (en) 2001-12-04

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