CN101280678A - Oil well chemical gorge and disgorge yield increasing and inverse direction regulating block connection working process - Google Patents
Oil well chemical gorge and disgorge yield increasing and inverse direction regulating block connection working process Download PDFInfo
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- CN101280678A CN101280678A CNA2008100644817A CN200810064481A CN101280678A CN 101280678 A CN101280678 A CN 101280678A CN A2008100644817 A CNA2008100644817 A CN A2008100644817A CN 200810064481 A CN200810064481 A CN 200810064481A CN 101280678 A CN101280678 A CN 101280678A
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Abstract
The invention relates to a technique combining the chemical huff and puff stimulation and the reversed plugging control. The technique adopts slug-type injection mode, including active agent slug, water plugging profile modification agent slug an displacement fluid slug, and includes the following steps: (1) firstly, injecting the active agent into the oil production layer, (2) injecting the water plugging profile modification agent 0-20 hours later, (3) then using excessive displacement fluid to lift all chemical agents to a place which is more than 3m away from well bore, and then using water to displace the excessive displacement fluid to the stratum and finally closing the well for 1 to 2 days for condensation. The purpose of the technique is to combine the huff and puff of the active agent with high oil-washing efficiency and low interfacial tension and the reversed profile control and flooding of the oil well, thus not only increasing the conformance factor of the injection of the water but also improving the oil displacement efficiency and extending the life circle.
Description
Technical field:
The present invention relates to a kind of method that improves the oil well recovery ratio in the oil recovery field, oil field, especially a kind of oil well chemical is handled up and is increased production and the stifled combination operation process of reverse accent.
Background technology:
Hyposmosis, oil field, crack be poor, the stratum energy deficiency of reservoir properties not only, in the water flooding later stage, because reservoir heterogeneity is serious, when causing the oil reservoir height moisture, still has segment thickness not wash in the layer; The interior washing of layer is inhomogeneous, segmentation washing phenomenon generally occurs; Occur strong washing section in the layer, but general thickness is thinner; By bottom oil reservoir washing degree height, positive especially rule oil reservoir; So after the water drive, remaining oil is more.Facts have proved, be to improve high moisture heterogeneous body sandstone oil reservoir rate of oil production with profile control, water-plugging technique, improves development effectiveness, improves the effective way of recovery ratio.To how removing residual oil in the push layer in the high moisture heterogeneous body sandstone oil reservoir, Meehan etc. once proved: use the high permeability zone band is carried out selective shut-off and can increase oil production to the way of water guiding low-permeability layer.And traditional water injection well profile control and oilwell water shutoff can improve the sweep efficiency that injects water, but can not improve the displacement efficiency that injects water, see that from the aspect that improves recovery ratio its effect is not enough to some extent.
Summary of the invention:
Purpose employing displacement efficiency height of the present invention, the activating agent that interfacial tension is low are handled up and are combined with the reverse transfer drive of oil well, not only improve the sweep efficiency that injects water but also improve its oil displacement efficiency, prolong its production cycle.
Technical scheme of the present invention is: this process using slug formula injection mode is respectively activating agent slug, water plugging profile control agent slug, displacement fluid slug: 1. at first inject activating agent to the oil recovery stratum; 2. inject water plugging profile control agent after 0-24 hour; 3. used displacement fluid that whole chemical agent piston types are pushed up to beyond well 3m after, water will be crossed the displacement fluid replacement to the stratum then, and closing well 1-2 weather coagulates; Wherein activating agent is that concentration is the 0.2%HLS-08 aqueous solution, and profile control agent is by polyacrylamide and Cr
3+The aqueous solution of preparation, pH value is 6-8, the concentration of polyacrylamide is 2000mg/L, Cr
3+Concentration is 20mg/L, Molecular Weight for Polyacrylamide is 1500-1900 ten thousand, above-mentioned HLS-08 surfactant is that petrobenzene sodium sulfonate and fatty acid alkanol amides form in 1: 1 ratio is composite, crossing displacement fluid is that concentration is the polyacrylamide solution of 5000mg/L, and Molecular Weight for Polyacrylamide is 1500-1900 ten thousand.
The present invention has following beneficial effect: profile control (water blockoff) agent and oil displacement surfactant all can be used for improving recovery ratio, but they are based on different mechanism.The former only increases recovery ratio by improving swept volume, and the latter increases recovery ratio by improving displacement efficiency.The present invention combines the two, produce cooperative effect, that is: by the displacement efficiency height, the activating agent that interfacial tension is low combines with the reverse transfer drive of oil well (water blockoff) technology, the liquid stream changed course effect of profile control agent performance deep, make the activating agent and the follow-up water of follow-up injection can enter the not enough stratum of exploitation such as hyposmosis effectively, give full play to the effect that chemical oil displacement agent improves recovery ratio in the zone that these residual oils are concentrated, not only improve the sweep efficiency that injects water but also improve its oil displacement efficiency, make improve recovery ratio mechanism more comprehensively, the oil well productivity of comprehensively taping the latent power prolongs its production cycle.
Description of drawings:
Fig. 1 is that activating agent improves the recovery ratio empirical curve;
Fig. 2 is that activating agent improves the recovery ratio empirical curve behind the reverse profile control.
The specific embodiment:
The invention will be further described below in conjunction with embodiment:
This technology adopts slug formula injection mode according to reverse transfer drive chemical increasing production know-why, is respectively high-efficiency activated dose of slug, water plugging profile control agent slug, displacement fluid slug.1. annotate high-efficiency activated dose of slug to the ground floor height discharge capacity of recovering the oil, less permeable layer pressure raises in making, and the activator solution that enters high permeability zone still is in low pressure to diffusion inside.2. low pressure, low discharge capacity are injected efficient oilwell water shutoff profile control agent, and these chemical agents all preferentially enter the high permeability zone of low pressure, have realized that by injection technology the selectivity of chemical agent is injected.3. with the full-bodied displacement fluid of crossing whole chemical agent piston types are pushed up to beyond well 3m, make oil well that high as far as possible production fluid amount be arranged, water will be crossed the displacement fluid replacement to the stratum then, and closing well is waited and coagulated.4. after bringing in, the water that comes along high permeability zone is redirected to middle less permeable layer before the oilwell water shutoff profile control agent at a distance, carries high-efficiency activated dose that seals up for safekeeping before water plugging profile control agent, and the sweep efficiency and the displacement efficiency that inject water all are improved, can reach the increase oil yield, reduce the purpose of moisture content.
Used chemical agent prescription is as follows among the following embodiment: activating agent is that concentration is the 0.2%HLS-08 aqueous solution, and profile control agent is by polyacrylamide and Cr
3+The aqueous solution of preparation, pH value is 6-8, the concentration of polyacrylamide is 2000mg/L, Cr
3+Concentration is 20mg/L, Molecular Weight for Polyacrylamide is 1500-1900 side, above-mentioned HLS-08 surfactant is that petrobenzene sodium sulfonate and fatty acid alkanol amides form in 1: 1 ratio is composite, crossing displacement fluid is that concentration is the polyacrylamide solution of 5000mg/L, and Molecular Weight for Polyacrylamide is 1500-1900 ten thousand.
Water plugging profile control agent consumption and the total consumption of mistake displacement fluid are calculated as follows among the following embodiment:
In the formula, w one water plugging profile control agent consumption and the total consumption of mistake displacement fluid, m
3
The radius that r one handles, m;
H one high permeability zone thickness, m;
φ one formation porosity;
It is 0.75 that η involves on one plane coefficient value.
In formula, h, φ, three parameters of η are definite values for a bite well, have only treatment radius r size decision water plugging profile control agent consumption and cross the total consumption of displacement fluid.The usually oil well water plugging agent is that 15-20m (stifled as far as possible deeply) calculates with crossing the displacement fluid total amount by treatment radius, and wherein crossing the displacement fluid consumption is that 3m calculates according to treatment radius.
High-efficiency activated dose of consumption:
For further improving recovery ratio, make the surfactant injection rate should satisfy residual oil enrichment in the water plugging and profile controlling zone in, low permeability pay forms effective driving, surfactant system displacement radius is greater than the treatment radius that equals water plugging profile control agent, consider simultaneously and inject liquid in factors such as injection process fingering, absorption losses, the surfactant injection rate is designed to 1.5 times of water plugging profile control agent consumption.
The performance evaluation of embodiment 1, above-mentioned chemical agent:
One, water plugging profile control agent performance evaluation:
1.PH be worth influence to gel-forming property:
The aqueous solution that is made into water plugging profile control agent under the condition of 60 ℃ of temperature, is investigated the influence of pH value to the water plugging profile control agent gel-forming property.Table 1 data show, increase with pH value, and gelation time prolongs, and gel strength is constant substantially.
PH value is to the table 1 that influences of gel-forming property
| PH value | Gelation time (h) | Gel strength (MPa) |
| 6.0 | 1.9 | 4.2 |
| 6.5 | 3.7 | 4.2 |
| 7.0 | 6.5 | 4.0 |
| 7.5 | 9.8 | 4.0 |
| 8.0 | 12.4 | 3.9 |
2. temperature is to the influence of gel-forming property:
Raise with temperature, gelation time descends, but gel strength is all higher.In the time of temperature 50-90 ℃, concerning site operation, gelation time is more satisfactory.
Temperature is to the table 2 that influences of gel-forming property
| Temperature (℃) | Gelation time (h) | Gel strength (MPa) |
| 40 | 72.0 | 4.3 |
| 50 | 15.0 | 4.3 |
| 60 | 6.5 | 4.3 |
| 70 | 6.2 | 4.2 |
| 80 | 6.0 | 4.2 |
| 90 | 5.1 | 4.0 |
| 100 | 3.2 | 4.0 |
3. the compatibility test on different permeabilities stratum:
Change rock core original permeability (K) when temperature is 60 ℃, carry out rock core flowing experiment, measure water plugging rate and breakthrough pressure.Under different permeability conditions, this water plugging profile control agent can be well crosslinked in rock core, and water plugging rate, water plugging rate retention rate, breakthrough pressure gradient are very high, and the water plugging rate of 7d is greater than 24h.Illustrate that this water plugging profile control agent is subjected to the influence of in-place permeability hardly, its water plugging effect increases in time and improves.
Different permeability rock cores are to water plugging and profile controlling Effect on Performance table 3
| Sequence number | K 1h(μm 2) | K 24h(μm 2) | K 7d (μm 2) | 24h water plugging rate (%) | 7d water plugging rate (%) | Water plugging rate retention rate (%) | Breakthrough pressure gradient (MPa.m -1) |
| 1 | 0.947 | 0.011 | 0.008 | 98.80 | 99.10 | 100.20 | 23.67 |
| 2 | 1.563 | 0.012 | 0.010 | 99.20 | 99.34 | 100.10 | 56.71 |
| 3 | 1.350 | 0.009 | 0.004 | 99.30 | 99.70 | 100.40 | 58.89 |
| 4 | 0.450 | 0.004 | 0.003 | 99.10 | 99.20 | 100.10 | 29.43 |
| 5 | 1.671 | 0.011 | 0.009 | 99.34 | 99.41 | 100.07 | 61.42 |
4. abrasion resistance:
In rock core flowing experiment, record breakthrough pressure after, water washes away respectively, investigates the abrasion resistance of this water plugging profile control agent.When this water plugging profile control agent becomes glue in rock core, and be injected into water breakthrough and in the process that continues to be washed away by water, increase with water injection rate, washing away pressure increases gradually.This is owing to increase with water injection rate, the colloid water-swellable in the rock core, and intensity is bigger, and therefore, this water plugging profile control agent has very strong anti-scouring capability, applicable to the profile control operation.
The evaluation experimental table 4 of abrasion resistance
| Sequence number | Water injection rate (PV) | Flow (ml/min) | Wash away pressure (MPa) | Breakthrough pressure gradient (MPa.m -1) |
| 1 | 2 | 4.5 | 18.72 | 62.39 |
| 2 | 10 | 4.5 | 18.90 | |
| 3 | 15 | 4.5 | 19.60 | |
| 4 | 20 | 4.5 | 20.38 | |
| 5 | 25 | 4.5 | 20.91 |
Two, activating agent oil displacement system performance evaluation:
1. oil water interfacial tension is measured:
Why efficient high-efficiency activated dose of HLS-08 is, determines it and can be reached even be lower than ultralow interfacial tension (promptly 10 by the interfacial tension between the crude oil of displacement
-3The mN/m order of magnitude).High-efficiency activated dose of HLS-08 is surfactant solution or surfactant system normally.Determine alkali-free HLS-08 surfactant system by screening study, dynamic interface tension force can reach 10 between mensuration 0.2%HLS-08 surfactant system and Daqing oil field dewatered oil
-3The mN/m order of magnitude.
2.HLS-08 activating agent displacement of reservoir oil efficiency test:
Displacement 0.3PV HLS-08 activating agent (concentration is 0.2%), the relative water drive of rock core ultimate recovery improves 7.0 percentage points.
HLS-08 activating agent displacement of reservoir oil step-down physical simulation experiment tables of data 5
Three, cross displacement fluid:
Cross displacement fluid and be meant the liquid that working solution can be replaced destination locations to the stratum.Used displacement fluid can reduce the pollution of blocking agent to oil reservoir.Cross the selection of displacement fluid and must satisfy two conditions: the one, displacement fluid viscosity must be higher than blocking agent viscosity, shift onto beyond well 3m with guaranteeing the blocking agent piston type; The 2nd, can be come out by the formation fluid displacement during oil well production. oil reservoir is not subjected to big influence to the permeability of formation fluid when guaranteeing oil well production.The viscosity of crossing displacement fluid should be higher than the oilwell water shutoff profile control agent viscosity of its front.
1. fill out sand tube rock core parameter in parallel:
Table 6
2. experimental program:
(1) surfactant improves the recovery ratio experimental program: concentration is 0.2% HLS-08 aqueous solution 0.5PV, and the HLS-08 surfactant is that petrobenzene sodium sulfonate and fatty acid alkanol amides form in 1: 1 ratio is composite.
(2) activating agent is made the technology experiment scheme with reverse profile control (water blockoff) connection: profile control agent 0.4PV+HLS-08 surfactant 0.5PV, profile control agent is polyacrylamide and Cr
3+The aqueous solution, the concentration of polyacrylamide are 2000mg/L, Cr
3+Concentration is 20mg/L.
3. experimental procedure:
(1) surfactant improves the recovery ratio experiment
1. fill out sand tube back-up sand: the quartz sand that mixes is inserted in the pipe compacting;
2. flow process is prepared: laboratory apparatus is connected by flow chart;
3. saturation water: under the constant flow rate, inject the simulated formation salt solution of artificial preparation in fill out sand tube, to constant pressure, record flow and pressure calculate the permeability of salt solution in fill out sand tube;
4. saturated oils: in fill out sand tube, annotate simulated oil under the flow velocity,, calculate and inject the poor of oil mass and output oil mass, be the fill out sand tube oil content to output oil fully;
5. water drive oil: under the constant flow rate, in fill out sand tube, inject simulated formation salt solution, survey pressure and oil production and aquifer yield at set intervals, set up remaining oil saturation or residual oil saturation according to the experiment needs;
6. inject surfactant slug: under the constant flow rate, in fill out sand tube, inject the surfactant for preparing;
7. follow-up water drive.
Heterogeneous reservoir injects activating agent, improves recovery ratio effect and not obvious (see figure 1).Mainly be because because formation heterogeneity is more outstanding, activating agent mainly passes through high permeability zone, the amount that enters less permeable layer is fewer, and residual oil mainly is present among the less permeable layer, activating agent and stratum react and stratum absorption causes loss in addition, so improve the recovery ratio DeGrain.
(2) activating agent is made the technology core experiment with reverse profile control (water blockoff) connection:
1. fill out sand tube back-up sand: the quartz sand that mixes is inserted in the pipe compacting;
2. flow process is prepared: laboratory apparatus is connected by flow chart;
3. saturation water: under the constant flow rate, inject the simulated formation salt solution of artificial preparation in fill out sand tube, to constant pressure, record flow and pressure calculate the permeability of salt solution in fill out sand tube;
4. saturated oils: in fill out sand tube, annotate simulated oil under the flow velocity,, calculate and inject the poor of oil mass and output oil mass, be the fill out sand tube oil content to output oil fully;
5. water drive oil: under the constant flow rate, in fill out sand tube, inject simulated formation salt solution, survey pressure and oil production and aquifer yield at set intervals, set up remaining oil saturation or residual oil saturation according to the experiment needs;
7. inject the gel slug; Under the constant flow rate, in fill out sand tube, inject the gel rubber system for preparing, wait and coagulated 48 hours;
8. inject surfactant slug: under the constant flow rate, in fill out sand tube, inject the surfactant for preparing;
9. follow-up water drive.
Adopt activating agent to combine with reverse profile control (water blockoff), it is effective to improve recovery ratio.
Fig. 2 injects activating agent behind the reverse profile control and improves the recovery ratio curve for adopting, comparison diagram 1 as can be seen: inject the activating agent slug after adopting reverse profile control, raising recovery ratio effect is better than independent injection activating agent.
Oil reservoir itself exists the non-homogeneity of both macro and micro, and microheterogeneity is mainly reflected in duct size in the rock pore structure, the difference of distribution of pores and pore surface character.Therefore in the water drive process, inject water and always be tending towards the less duct of intake resistance, and residual oil is always stayed in the fine pore or the oil droplet mode remains in macroporous central authorities.According to channel fluidised form theory, when oil phase lose continuity just become residual oil can not be by extraction.After microcosmic displacement test result confirms that the profile control sealing agent injects porous media, can change the flow direction of follow-up injection water, force injection water to enter and be not injected into the micro-pore that ripples reach as yet, thereby improve the microcosmic sweep efficiency.Inject chemical oil displacement agent and oppositely inject dual mode raising recovery ratio effect behind the profile control by comparative study, the effect of injecting chemical agent behind the reverse as can be known profile control obviously is better than injecting separately chemical agent, reason is: the liquid stream changed course effect of profile control agent performance deep, make the activating agent and the follow-up water of follow-up injection can enter the not enough stratum of exploitation such as hyposmosis effectively, give full play to the effect that chemical oil displacement agent improves recovery ratio in the zone that these residual oils are concentrated.
Geologic aspects: platform 69-94 well location is in eternally happy oil field platform 105 cooperative region.This district's Putaohua reservoir belongs to hypotonic, crack oil reservoir.Its effecive porosity 13.4-21.8%, average 18.9%, air permeability 1.91-54.5 * 10-3 μ m
2, average 22.3 * 10-3 μ m
2Belong to low, ultra-low permeability reservoir by domestic reservoir criteria for classification; Get analysis of core well and observation for one group according to 4 Kou Jing Portugals in the block, grow relatively in this block crack, and the crack mainly contains two types: a kind of is the interlayer seam relevant with sedimentary characteristic, and another kind is to grow vertical build joint in the arenaceous rock.Hypotonic, crack oil reservoir permeability is low, fluid properties is poor, serious heterogeneity, part reservoir fracture development, the quickening of successively decreasing of well water height, oil well output has had a strong impact on the oil field development effect.
The exploitation present situation: it is 6.1m that platform 69-94 well is penetrated out sandstone thickness, and effective thickness is 4.0m, and the I of this well Portugal 4, the I of Portugal 5 intervals are grown better relatively, and effective pay thickiness is 1.3m, 1.8m, is main force's oil-producing formation; Be communicated with water injection well 1 mouthful of raised platform around a well 68-93 well is arranged.This well in February, 2003 goes into operation, and day at initial stage produce oil 9t amounts to 16 months at no Water-cut Period to 2004 year May, and (in May, 2007) this well day produce oil 0.6t at present is moisture 81.3%, totally produce oil 0.4435 * 10
4T.
(1) oil well basic data
Platform 69-94 well basic data. table 7
(2) be communicated with the water injection well data
Platform 69-94 well is communicated with water injection well and injects status list table 8
Platform 69-94 well oppositely transfers (water blockoff) to drive each slug scale 9
Inject discharge capacity:
When 1. annotating the activating agent slug, discharge capacity is ascending, and keeps maximum pump discharge to inject, and observes injection pressure and changes;
2. the water plugging profile control agent slug adopts low pressure, low discharge capacity to inject;
3. the displacement fluid slug injects discharge capacity, to guarantee that not breaking through the water plugging profile control agent slug is principle.
Injection pressure: injection pressure is controlled at below the oil reservoir fracture pressure, between the 11.48MPa-14MPa.
Seen tangible oil increasing precipitation effect after the measure, average cumulative increases oily 432.7t, has moisturely on average descended 10 percentage points, sees the following form 8.
Handle up yield-increasing technology and oppositely transfer (water blockoff) to drive combination operation process mining site effect table table 10 of oil well chemical
Field test shows: this technology is obtaining better effects aspect the volume increase of hyposmosis oil well, the steady oil control water.The present invention organically combines by the two technology of yield-increasing technology and the reverse transfer drive of oil well (water blockoff) that hyposmosis, crack oilfield chemistry are handled up, and can further improve hyposmosis, crack oil recovery.
Claims (1)
1, a kind of oil well chemical is handled up and is increased production and the stifled combination operation process of reverse accent, and it is characterized in that: this process using slug formula injection mode is respectively activating agent slug, water plugging profile control agent slug, displacement fluid slug: 1. at first inject activating agent to the oil recovery stratum; 2. inject water plugging profile control agent after 0-24 hour; 3. used displacement fluid that whole chemical agent piston types are pushed up to beyond well 3m after, water will be crossed the displacement fluid replacement to the stratum then, and closing well 1-2 weather coagulates; Wherein activating agent is that concentration is the 0.2%HLS-08 aqueous solution, and profile control agent is by polyacrylamide and Cr
3+The aqueous solution of preparation, pH value is 6-8, the concentration of polyacrylamide is 2000mg/L, Cr
3+Concentration is 20mg/L, Molecular Weight for Polyacrylamide is 1500-1900 ten thousand, above-mentioned HLS-08 surfactant is that petrobenzene sodium sulfonate and fatty acid alkanol amides form in 1: 1 ratio is composite, crossing displacement fluid is that concentration is the polyacrylamide solution of 5000mg/L, and Molecular Weight for Polyacrylamide is 1500-1900 ten thousand.
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