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WO2016000090A1 - 两级封窜抑制低渗透裂缝型油藏co2驱过程中发生窜逸的采油方法 - Google Patents

两级封窜抑制低渗透裂缝型油藏co2驱过程中发生窜逸的采油方法 Download PDF

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Publication number
WO2016000090A1
WO2016000090A1 PCT/CN2014/000865 CN2014000865W WO2016000090A1 WO 2016000090 A1 WO2016000090 A1 WO 2016000090A1 CN 2014000865 W CN2014000865 W CN 2014000865W WO 2016000090 A1 WO2016000090 A1 WO 2016000090A1
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Prior art keywords
permeability
low
sealing
flooding
oil
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Ceased
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PCT/CN2014/000865
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English (en)
French (fr)
Inventor
侯吉瑞
赵凤兰
刘中春
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China University of Petroleum Beijing
China University of Petroleum East China
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China University of Petroleum Beijing
China University of Petroleum East China
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Priority to US14/778,053 priority Critical patent/US20170107422A1/en
Publication of WO2016000090A1 publication Critical patent/WO2016000090A1/zh
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08F—MACROMOLECULAR COMPOUNDS OBTAINED BY REACTIONS ONLY INVOLVING CARBON-TO-CARBON UNSATURATED BONDS
    • C08F251/00—Macromolecular compounds obtained by polymerising monomers on to polysaccharides or derivatives thereof
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/138—Plastering the borehole wall; Injecting into the formation
    • 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 invention belongs to the technical field of oil and gas stimulation, and particularly relates to a method for suppressing CO 2 flooding in a low permeability fracture type reservoir to improve oil recovery by two-stage sealing.
  • low-permeability reservoirs Due to the limitations of economic policies and technological level, the low-permeability reservoirs that have been put into operation are only about 50%, and they are mainly mined by conventional water injection methods. Due to the special properties of poor permeability, low abundance, serious heterogeneity and complex pore structure, low-permeability reservoirs not only require high water quality, but also have complicated water treatment processes, and are easy to form. Out of the passive situation. At the same time, the water flooding efficiency is also very low, and the oil layer is not fully exploited. The development of low-permeability sandstone reservoirs is difficult, and it has become the focus of current domestic and foreign reservoir engineering experts.
  • Low-permeability oilfields especially high-pressure and low-permeability oilfields, have high pressure and natural energy at the initial stage of development. Generally, they are firstly exploited by elastic energy and dissolved gas to drive energy. After entering the low-yield period, they are transferred to water injection development.
  • problems such as excessive injection pressure, excessive water injection cost, severely reduced permeability in the near-well zone, and low productivity.
  • a large number of domestic and foreign research and practice have proved that due to the huge difference between the pore structure and seepage characteristics of low permeability reservoirs and medium and high permeability reservoirs, chemical flooding EOR technology has been applied and achieved good results in medium and high permeability reservoirs.
  • the gas injection development of low-permeability reservoirs has its unique advantages. It not only has no injection problems, but also has a mechanism of action that water flooding does not have. That is, under certain conditions, it can be mixed with the crude oil of the reservoir to eliminate the displacement agent and The influence of the interface between the displaced fluids greatly reduces the seepage resistance and can greatly improve the oil recovery. Even if the injected gas and the crude oil cannot reach the miscible phase under the reservoir conditions, the mass transfer between the two can improve the fluidity of the crude oil, so that the oil displacement effect is better than the water flooding under certain geological conditions. It has been confirmed by a large number of mine tests.
  • CO 2 flooding has obvious technical advantages compared with water flooding, which not only overcomes the problem of high water injection pressure in low permeability oilfields, but also can significantly change crude oil fluidity.
  • CO 2 flooding also has outstanding technical problems. For example, because the gas/oil fluidity ratio is much larger than the water/oil fluid ratio, the viscous fingering will be more serious; since the oil and gas density difference is greater than the oil-water density difference, it will be produced.
  • the two-stage sealing provided by the invention inhibits the low-permeability (permeability ⁇ 50 ⁇ 10 -3 ⁇ m 2 ) crack type reservoir CO 2 flooding, and comprises the following steps:
  • the crack may be an artificial crack or a natural crack between the injection well and any production well that can cause the injected water or the injected oil displacement CO 2 to escape;
  • the high-strength glue is formed by graft polymerization and cross-linking of the following raw materials: 1-5 parts of natural modified polymer materials, 1-5 parts of monomers, 0.01-0.3 parts of cross-linking agent, initiator 0.001-0.3 parts, stabilizer 0-0.5 parts, and the gelation process can be carried out normally under the acidic conditions formed by the prior injection of CO 2 (general CO 2 injection pressure difference 1-8 MPa).
  • the natural modified polymer material is selected from at least one of the following: carboxymethyl starch, carboxyethyl starch, hydroxyethyl starch, hydroxypropyl starch, ⁇ -starch, hydroxypropyl guar gum, carboxymethyl fiber And alkali cellulose;
  • the monomer is an allyl monomer selected from at least one of the following: acrylamide, methacrylamide, acrylonitrile, acrylic acid, methacrylic acid, sodium acrylate, sodium methacrylate And acrylate;
  • the crosslinking agent is selected from at least one of the following: bisacrylamide, N, N'-methylenebisacrylamide, and N-methylol acrylamide;
  • the initiator is selected from at least one of the following: potassium persulfate, ammonium persulfate, hydrogen peroxide and benzoyl peroxide;
  • the stabilizer is selected from at least one of the group consisting of sodium sulfite and sodium thiosulfate.
  • the high-strength glue is preferably formed by graft polymerization and cross-linking of the following raw materials: ⁇ -starch 4 parts, acrylamide 4 parts, N,N'-methylenebisacrylamide 0.1 parts, potassium persulfate 0.1 Parts, 0.2 parts of sodium sulfite.
  • the method for the first stage sealing comprises the following steps: mixing the raw material for preparing the high-strength glue with water (such as oil field injection water or mine clear water) to prepare a solution having a mass concentration of 2%-10%, and The solution is injected into the crack at a pressure less than the fracture of the formation and coagulated.
  • water such as oil field injection water or mine clear water
  • the solution is injected into the crack at a pressure less than the fracture of the formation and coagulated.
  • the injection amount of the gelation solution is close to the pore volume of the crack, and the pore volume of the crack is calculated according to geological knowledge and dynamic data of on-site injection.
  • the time of the coagulation is 24h-120h.
  • the fatty amine has a boiling point close to the reservoir temperature.
  • the fatty amine is selected from at least one of the following: methylamine and its derivatives, ethylamine and its derivatives, propylamine and its derivatives, butylamine and its derivatives, and ethylenediamine and its derivatives; preferably B. Diamine.
  • step 2) a fatty amine is injected into a relatively high-permeability layer in the matrix in which CO 2 liberation has occurred, and a carbamate is formed by reacting with CO 2 residing in the ruthenium channel to generate a blocking effect; After the plug is isolated, the fatty amine is injected, and liquid nitrogen is injected for subsequent isolation of the slug (to avoid plugging at the wellhead), and then no coagulation is required, and CO 2 is directly injected to continue the displacement.
  • the amount of fatty amine injected is generally 1/5-1/3 of the pore volume of the CO 2 escape channel (ie, the channel in the matrix relative to the high-permeability layer where CO 2 is released) (based on geological understanding and on-site injection dynamic data) Calculation).
  • the injection of CO 2 will also produce different degrees of relaxation in multiple directions, and the secondary sealing method can be applied in multiple rounds (The highest permeable zone in each round of construction is blocked one by one until the final level of production reaches the required level.
  • the secondary seal specifically includes the following steps: after injecting liquid nitrogen as the isolation slug, the pressure is not higher than 20% of the CO 2 injection pressure (under which conditions the fatty amine can only enter the CO 2 escape channel) The fatty amine is injected into the permeation layer having the highest permeability of the substrate in which the escape has occurred, and after the liquid nitrogen is injected for subsequent isolation of the slug, the coke is not required to be continuously injected, and the CO 2 is continuously injected for displacement.
  • the liquid nitrogen may be injected in an amount of 1-2 tons.
  • the method of using the two-stage sealing technology to perform low permeability fracture type reservoir mining is also within the scope of protection of the present invention.
  • the method for mining the low permeability fracture type reservoir comprises the following steps:
  • the first-stage sealing is performed (the raw material solution capable of forming high-strength glue is injected) Crack and wait for condensation), then inject CO 2 flooding;
  • step C1 may be repeated until the total degree of recovery reaches the desired level.
  • the required characteristics and reservoir development, and some low permeability in the first CO 2 flooding water flooding, in this case the fracture formation filled with CO 2 and CO 2 in the blow-Yi occurrence of cracks in this case, the same may be carried out
  • the first-stage sealing is to inject a high-strength raw material solution into the crack and wait for sufficient time (the CO 2 acidic environment does not affect the gelation effect), and then inject the CO 2 flood; and then continue to step C.
  • the specific method includes the following steps:
  • the first-stage sealing is performed (the high-strength glue is formed soon).
  • the raw material solution is injected into the crack and coagulated, and then injected into the CO 2 flooding;
  • the first time in the secondary sealing is performed. Operation, that is, after injecting liquid nitrogen (injectable amount of 1 ton) as an isolation slug, inject a design amount of fatty amine sealant (generally 5 tons - 15 tons), and then inject 1 ton of liquid nitrogen for subsequent isolation Plug, no waiting for condensation, continue to inject CO 2 displacement;
  • step C2 may be repeated until the total production level reaches the desired level.
  • the invention is directed to different escape conditions in the process of injecting CO 2 into a low permeability crack type reservoir, and adopts a two-stage sealing method to first block the slip in the crack and then block the relatively high permeability layer in the low permeability matrix. Yi Yi has improved oil recovery.
  • Figure 1 shows a radial flow low permeability crack physical model.
  • Figure 2 is a flow chart of the entire flooding simulation experiment.
  • Fig. 3 is a summary of the effect of sealing construction at each stage of the first embodiment.
  • Fig. 4 is a summary of the effect of sealing construction at each stage of the second embodiment.
  • Fig. 5 is a summary of the effect of sealing construction at each stage of the third embodiment.
  • Figure 1 shows a radial flow low permeability crack physical model.
  • the physical model size is ⁇ 400mm ⁇ 60mm, which is made by drilling, cutting and grinding the natural outcrop. According to the five-point well pattern, a four-row well group is designed.
  • the permeability between the injection wells and the four production wells is also inconsistent, which is a more realistic simulation of the site.
  • the crack was filled with a small amount of quartz sand having a particle diameter of about 0.3 mm as a crack proppant, and the crack permeability was measured to be 12762.3 mD.
  • Figure 2 shows the entire oil flooding simulation experiment process, which consists of four parts:
  • Liquid supply system model body, metering system, constant temperature system.
  • liquid supply system is a high pressure pump and an associated intermediate container for simulating constant velocity injection
  • the metering system is divided into two parts: one is the pressure transmission system, including the pressure sensor and the processing module; the other is the flow metering system (including the high-pressure CO 2 gas flow meter), which accurately measures the injected and produced liquid and gas.
  • the temperature in the incubator was set according to the formation temperature, and the experiment was carried out under simulated formation temperature conditions.
  • the control back pressure is 7.0 MPa
  • the injection pressure is 8.0 MPa
  • the model ring pressure is 12 MPa.
  • the first-stage sealing is carried out, that is, the crack is blocked by the strong rubber of the modified natural polymer material, and the composition of the strong rubber system is 4 parts of ⁇ -starch and acrylamide 4 0.1 parts of N,N'-methylenebisacrylamide, 0.1 parts of potassium persulfate and 0.2 parts of sodium sulfite.
  • oily water is used to prepare a solution with a concentration of 8%, which will be less than the pressure at which the formation is broken. 18ml of the solution before the glue is injected into the crack, and after 48h of coagulation, the injection of CO 2 is started for displacement, that is, the first CO 2 flooding is performed;
  • the stage # 1 by communication with the well, the well fractures direction # 3 is sealed glue, and to give priority to the injection direction of walk relatively high permeability CO.'S 2, so that only well # 2, # 4 gas injection wells the produced oil ( See the list of primary gas drives in Table 2, and first the CO 2 escape phenomenon occurs in the # # well.
  • the second operation in the secondary sealing is started, that is, after injecting 4 ml of N 2 as the isolation slug, the design quantity B is injected.
  • the diamine (18 ml) was then refilled with 4 ml of N 2 for subsequent isolation of the slug to block the escape from the center injection well to the 3 # well.
  • the third CO 2 flooding is started again;
  • the relatively high permeability layer in the matrix of the 3 # well direction has been injected with ethylenediamine to form a salt with CO 2 and then sealed.
  • the 3 # well has no liquid output, and the 1 # well and 2 # wells have a large amount of oil.
  • there is also a small amount of oil produced in the 4 # well see the list of three gas drives in Table 2), and it is found that the CO 2 escape phenomenon occurs again in the direction of the # # well.
  • Table 2 shows the oil recovery of the model of Example 1 at various stages.
  • Figure 3 is a summary of the effect of sealing construction at each stage of Example 1.
  • the two sets of examples are further compared and verified.
  • the experimental scheme is the same, different models are selected, the permeability is changed, and the repeatability of the two-stage sealing effect is verified and examined.
  • the operation procedures of the respective stages and the sequence of the transfer operations are also identical (Example 2 and Example 3).
  • the two-stage sealing is also carried out, and after the crack is sealed, the CO 2 flooding is performed, and after a gas generation occurs in a well, the circulation of the relatively high-permeability layer in the matrix is started to be closed, and the results are shown in Table 4 and Figure 4.
  • Figure 4 is a summary of the effect of sealing construction at each stage of Example 2.
  • Fig. 5 is a summary of the effect of sealing construction at each stage of the third embodiment.
  • the two-stage sealing technology can effectively control the escape in the CO 2 flooding process in low-permeability fractured reservoirs and expand the volume.
  • the secondary sealing will be constructed several times, and in theory all the remaining oil can be produced. In practical applications, it is necessary to control the secondary sealing construction round according to technical and economic constraints to obtain the best economic benefits.
  • the invention is directed to different escape conditions in the process of injecting CO 2 into a low permeability crack type reservoir, and adopts a two-stage sealing method to first block the slip in the crack and then block the relatively high permeability layer in the low permeability matrix. Yi Yi effectively controls the enthalpy in the CO 2 flooding process in low-permeability fractured reservoirs, expands the sweep volume, and improves oil recovery.

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Abstract

一种两级封窜抑制低渗透裂缝型油藏CO2驱窜逸以提高石油采收率的方法，该两级封窜包括：注入天然改性高分子材料为主剂的强胶体系，并经过候凝形成高强胶封堵裂缝；以脂肪胺为封窜剂对低渗基质中的相对高渗透层导致的低粘度CO2的窜逸进行封堵。该两级封窜技术可以有效控制低渗透裂缝型油藏中CO2驱过程中的窜逸，扩大波及体积，从而提高石油采收率。

Description

两级封窜抑制低渗透裂缝型油藏CO2驱过程中发生窜逸的采油方法 技术领域
本发明属于油气增产技术领域，尤其涉及两级封窜抑制低渗透裂缝型油藏CO2驱窜逸以提高石油采收率的方法。
背景技术
随着现代工业的高速发展，对石油和天然气的需求量日益增加，而大部分老油田已进入中、高含水阶段，稳产和挖潜的难度越来越大。为了保持原油稳产，低渗透油田的开发受到了人们极大的关注，且已成为现在和将来的重要开发目标。因此，迫切需要探索科学开发低渗透油田的有效手段。目前，我国已探明的低渗透油藏有近百个，其石油储量占全国探明总储量的13％，预计将会增加到40％左右。我国石油工业中已探明未动用石油地质储量中，大部分为低渗透油田储量。低渗透油田是一个相对的概念，世界各国的划分标准和界限因不同国家、不同时期的资源状况和技术经济条件不同而各异。通常将其分为三种类型：I类储层渗透率50-10×10- 3μm2，II类储层渗透率10-1×10-3μm2，III类储层渗透率1-0.1×10-3μm2。“十五”期间，低渗透油气藏勘探储量所占比例逐年上升，近年来甚至年发现储量的80％为低渗透油藏。很显然，有效开发利用这部分资源是油田持续发展的重要方向。由于经济政策和工艺技术水平的限制，目前已投入开采的低渗透油藏仅为50％左右，且主要采用常规注水方法进行开采。由于低渗透油藏具有油层物性差、储量丰度低、非均质严重、孔隙结构复杂等特殊性质，不仅对注入水水质要求高，水处理工艺复杂，而且容易形成“注不进，采不出”的被动局面。同时，水驱效率也很低，油层得不到充分的开采。低渗透砂岩储层开发难度大，以成为目前国内外油藏工程专家们关注的焦点。
低渗透油田尤其是高压低渗透油田开发初期压力高、天然能量充足，一般先利用弹性能量和溶解气驱能量开采，在进入低产期后再转入注水开发。但是，在低渗透油田注水开发过程中存在着注入压力过高、注水成本过大、近井地带渗透率降低严重、产能低下等问题。国内、外大量研究和 实践证明，由于低渗透油藏的孔隙结构及渗流特性与中、高渗透油藏的巨大差异，在中、高渗透油藏中已经应用并取得良好效果的化学驱EOR技术，因注入问题、吸附问题等，则不能应用于低渗透油田。结合环境保护及节能减排的大趋势，从目前的技术发展形势看，具有应用前景的低渗油田提高采收率技术只有CO2驱。但是，由于低渗透油藏非均质性严重，或者存在天然和人工裂缝，注入水难以波及基质中剩余油，注气又因渗流阻力过低而发生明显窜逸现象，因此，单纯注水或注气开发的效果并不理想，这也是全世界CO2驱油都要面临的一个共性的技术难题。
注气开发低渗透油藏有其独特的优越性，不仅不存在注入问题，而且具有水驱所不具备的作用机理，即在一定的条件下可以与油藏原油达到混相，消除驱替剂与被驱替液之间相界面的影响，大大降低渗流阻力，可大幅度提高原油采收率。即使在油藏条件下注入气体与原油不能达到混相，两者之间存在的传质作用，也可改善原油的流动性，使其驱油效果在一定的地质条件下优于水驱，这已被大量的矿场试验所证实，如美国小布法洛盆地油田在水气交替注入后，产油量比水驱提高了45％；美国JAY油田预计水气交替注入后采收率可增加8％；我国大庆油田北二东试验区也开展了水气交替注入试验，三年半的试验表明，生产井含水不仅未升，而且略有不降，产量始终高于试验前的水平；阿尔及利亚在哈西梅萨乌德油田将产出的伴生气高压回注，形成了混相驱，到1982年共注气6.6×1010m3，利用高压气驱已采出原油1.22×108t，占油田累计采油量的28％。许多室内及矿场的研究工作已经证明，CO2驱与水驱相比，具有明显的技术优势，不仅克服了低渗透油田注水压力高的难题，而且还可以显著改变原油流动性。但是，CO2驱也存在比较突出的技术问题，例如，由于气/油流度比远大于水/油流度比，粘性指进将更为严重；由于油气密度差大于油水密度差，将产生不同程度的重力超覆；对于非均质性油藏，特别是存在裂缝或大孔道时，可产生更严重的气窜。因此，若要取得良好的CO2驱油效果，必须控制CO2的窜逸，扩大波及体积，使CO2最大限度地接触剩余油。很多进行CO2驱的油藏，都属于低渗透条件，正常注水存在困难，但是，注入CO2也存在明显的窜逸。此外，由于低渗透油藏往往还存在一定密度的裂缝，对注气扩大波及体积造成很大损失。显然，在这种条件下，由于低渗透基质中注水困 难，常规的以高粘凝胶类为主的调堵技术难以应用；而裂缝的封堵，需要凝胶不仅自身强度高，还要具有很强的与基质胶结的能力，同时还要耐CO2。在现有的文献报道中，并未检索到能够直接用于注水困难的低渗透油藏控制气体窜逸的技术资料，这也是该项研究工作所面临的主要技术困难。另外，作为耐CO2的裂缝强堵剂也需要开发新的技术。
发明公开
本发明的目的是提供一种两级封窜抑制低渗透裂缝型油藏CO2驱窜逸以提高石油采收率的方法。
本发明所提供的两级封窜抑制低渗透(渗透率≤50×10-3μm2)裂缝型油藏CO2驱窜逸的方法，包括下述步骤：
1)一级封窜：以高强胶封堵裂缝实现一级封窜；
所述裂缝可以为注入井与任意采油井之间能够导致注入水或注入的驱油CO2发生窜逸的人工裂缝或天然裂缝；
由于上述裂缝属于强窜通道，故需要高强胶封堵；
所述高强胶是由下述质量份的原料经接枝聚合、交联形成的：天然改性高分子材料1-5份，单体1-5份，交联剂0.01-0.3份，引发剂0.001-0.3份，稳定剂0-0.5份，且成胶过程可以在因先期注入CO2所形成的酸性条件下(一般CO2注采压差1-8MPa)正常进行。
所述天然改性高分子材料选自下述至少一种：羧甲基淀粉、羧乙基淀粉、羟乙基淀粉、羟丙基淀粉、α-淀粉、羟丙基瓜胶、羧甲基纤维素和碱纤维素；
所述单体为烯丙基单体，所述烯丙基单体选自下述至少一种：丙烯酰胺、甲基丙烯酰胺、丙烯腈、丙烯酸、甲基丙烯酸、丙烯酸钠、甲基丙烯酸钠和丙烯酸酯；
所述交联剂选自下述至少一种：双丙烯酰胺、N,N'-亚甲基双丙烯酰胺和N-羟甲基丙烯酰胺；
所述引发剂选自下述至少一种：过硫酸钾、过硫酸铵、过氧化氢和过氧化苯甲酰；
所述稳定剂选自下述至少一种：亚硫酸钠和硫代硫酸钠。
所述高强胶优选由下述质量份的原料经接枝聚合、交联形成：α-淀粉4份、丙烯酰胺4份、N,N’-亚甲基双丙烯酰胺0.1份、过硫酸钾0.1份、亚硫酸钠0.2份。
所述一级封窜的方法具体包括下述步骤：将制备所述高强胶的原料与水(如油田注入水或矿场清水)混合后配制成质量浓度为2％-10％的溶液，并在小于地层破裂的压力下将所述溶液注入裂缝中并候凝。封堵裂缝时，成胶溶液的注入量接近裂缝的孔隙体积，所述裂缝的孔隙体积根据地质认识及现场注采动态数据计算得到。
所述候凝的时间为24h-120h。
2)二级封窜：以脂肪胺对低渗基质中的相对高渗透层带导致的低粘度CO2的窜逸进行封堵；
所述脂肪胺的沸点与油藏温度接近。
所述脂肪胺选自下述至少一种：甲胺及其衍生物、乙胺及其衍生物、丙胺及其衍生物、丁胺及其衍生物和乙二胺及其衍生物；优选为乙二胺。
步骤2)中，将脂肪胺注入基质中已发生CO2窜逸的相对高渗透层中，通过与窜逸通道中驻留的CO2反应生成氨基甲酸盐而产生封堵作用；注入液氮作为隔离段塞后，注入脂肪胺，再注入液氮作后续隔离段塞(避免在井口产生封堵)，而后不需要候凝，直接注入CO2继续驱替。
脂肪胺的注入量一般为CO2窜逸通道(即基质中相对高渗透层中发生CO2窜逸的通道)孔隙体积的1/5-1/3(需根据地质认识及现场注采动态数据计算)。
如果低渗透基质中存在多个方向多个不同渗透率的高渗透层，注入CO2也会在多个方向上产生不同程度的窜逸，所述二级封窜方法可进行多轮次施工(逐次对每轮施工中最高渗透层带进行封堵)，直至最终的采出程度达到要求为止。
所述二级封窜具体包括下述步骤：注入液氮作为隔离段塞后，在不高出CO2注入压力20％的压力下(该条件下可保证脂肪胺只进入CO2窜逸通道)，将所述脂肪胺注入已发生窜逸的基质渗透率相对最高的渗透层中，再注入液氮作后续隔离段塞后，无需候凝，继续注入CO2进行驱替。
所述液氮的注入量可为1-2吨。
采用所述两级封窜技术进行低渗透裂缝型油藏开采的方法也属于本发明的保护范围。
所述低渗透裂缝型油藏开采的方法包括下述步骤：
A1.对低渗透裂缝型油藏进行水驱开采；
B1.当水驱发生明显的裂缝窜逸特征后(即采出液中含水超过98％，且含水指数特征曲线为凹型)，进行所述一级封窜(即将可形成高强胶的原料溶液注入裂缝并候凝)，再注入CO2驱替；
C1.当发现低渗基质中的相对高渗透层发生CO2窜逸后(即发现有油井基本不出油且连续大量产出CO2后)，进行所述二级封窜中的第一次作业，即在注入液氮(注入量可为1吨)作为隔离段塞后，注入设计量的脂肪胺封窜剂(一般为5吨-15吨)，再注入1吨液氮作后续隔离段塞，无需候凝，继续注入CO2驱替；
D1.当再次发现低渗基质中的相对高渗透层导致CO2窜逸后，可重复步骤C1，直至总的采出程度达到要求。
根据油藏特点及开发的需要，有些低渗透油田在水驱后要先进行CO2驱，此时地层的裂缝中充满CO2并发生CO2沿裂缝的窜逸，此时，同样可进行所述一级封窜，即将可形成高强胶的原料溶液注入裂缝并候凝足够时间(CO2酸性环境不影响成胶效果)，再注入CO2驱替；而后继续步骤C。
具体方法包括下述步骤：
A2.对低渗透裂缝型油藏先进行水驱开采；而后进行CO2驱开采；
B2.当CO2驱发生明显的裂缝窜逸特征后(即沿裂缝方向井中有CO2大量产出而裂缝两侧的井中无产出)，进行所述一级封窜(即将可形成高强胶的原料溶液注入裂缝并候凝)，再注入CO2驱替；
C2.当发现低渗基质中的相对高渗透层导致CO2窜逸后(即发现有油井基本不出油且连续大量产出CO2后)，进行所述二级封窜中的第一次作业，即在注入液氮(注入量可为1吨)作为隔离段塞后，注入设计量的脂肪胺封窜剂(一般在5吨-15吨)，再注入1吨液氮作后续隔离段塞，无需候凝，继续注入CO2驱替；
D2.当再次发现低渗基质中的相对高渗透层导致CO2窜逸后，可重复步骤C2，直至总的采出程度达到要求。
本发明针对低渗透裂缝型油藏注CO2过程中不同的窜逸情况，采用两级封窜的方式，先封堵裂缝中的窜逸，再封堵低渗基质中相对高渗透层中的窜逸，提高了石油采收率。
附图说明
图1为径向流低渗透裂缝型物理模型。
图2为整个驱油模拟实验流程图。
图3为实施例1各阶段封窜施工效果汇总。
图4为实施例2各阶段封窜施工效果汇总。
图5为实施例3各阶段封窜施工效果汇总。
实施发明的最佳方式
下述实施例中的实验方法，如无特别说明，均为常规方法
下述实施例中所使用的实验方法如无特殊说明，均为常规方法；下述实施例中所用的试剂、材料等，如无特殊说明，均可从商业途径得到。
下述实施例以径向流低渗透物理模型为基础，考虑裂缝以及基质中存在的部分相对高渗透层。图1为径向流低渗透裂缝型物理模型。
实施例1
实验条件
物理模型尺寸为φ400mm×60mm，是将天然露头经过钻取、切割、打磨制成，按照五点法井网，设计一注四采井组。
由于天然露头致密程度不一致，导致注入井到四个采出井间的渗透率也不一致，这恰好可以更真实地模拟现场情况。
物理模型1的物性及四个方向的渗透率见表1。
表1实施例1模型在各采出井方向渗透率测量结果
Figure PCTCN2014000865-appb-000001
Figure PCTCN2014000865-appb-000002
另外，为了模拟现场裂缝，在1#与3#井之间，人工压裂造缝。裂缝中填充有少量粒径约为0.3mm的石英砂作为裂缝支撑剂，测定裂缝渗透率12762.3mD。
实验流程及设备
图2为整个驱油模拟实验流程，由四部分组成：
供液系统，模型本体，计量系统、恒温系统。
其中，供液系统为高压泵以及相关的中间容器，用于模拟恒速注入；
计量系统分为两个部分：一是压力传送系统，包括压力传感器和处理模块；二是流量计量系统(包括高压CO2气体流量计)，精确计量注入与产出的液体、气体。按照地层温度设定恒温箱内温度，实验在模拟地层温度条件下进行。控制回压7.0MPa，注入压力为8.0MPa；模型环压12MPa。
实验方案与结果分析
(1)模型饱和油后，在1#井与3#井间人工造缝，之后按照矿场程序先进行水驱；
这个阶段在1#井、3#井、4#井中都有油产出，而2#井方向渗透率低，且无裂缝导引，没有油产出(见表2中水驱列)。
(2)在水驱发生明显的窜逸后，进行一级封窜，即用改性天然高分子材料的强胶封堵裂缝，该强胶体系的构成为α-淀粉4份、丙烯酰胺4份、N,N’-亚甲基双丙烯酰胺0.1份、过硫酸钾0.1份、亚硫酸钠0.2份，使用时用油田注入水配制成质量浓度为8％的溶液，在小于地层破裂的压力下将成胶前的溶液18ml注入裂缝，候凝48h后，开始注入CO2进行驱替，即进行第一次CO2驱；
这个阶段因连通1#井、3#井方向的裂缝被胶封死，并且注入CO2要优先走相对高渗透率的方向，因此，只有2#井、4#井有气驱油产出(见表2中一次气驱之列)，并且首先在4#井发生CO2窜逸现象。
(3)在发现4#井不出油且连续产出CO2后，开始二级封窜中的第一次作业，即先注入4ml的N2作为隔离段塞后，再注入设计量的乙二胺 (20ml)，接着再注入4ml的N2作后续隔离段塞，以封堵中心注入井至4#井间的窜逸。在第一次封窜作业后，再开始第二次CO2驱替；
这个阶段因4#井方向基质中的相对高渗透层已经被注入的乙二胺在与CO2反应成盐后封死，4#井无液体产出，1#井、2#井、3#井都有油产出(见表2中二次气驱之列)，并且发现在连续注入CO2后，在3#井又发生了CO2窜逸现象。
(4)在发现3#井不出油且连续产出CO2后，开始二级封窜中的第二次作业，即先注入4ml的N2作为隔离段塞后，再注入设计量的乙二胺(18ml)，然后再注入4ml的N2作后续隔离段塞，以封堵中心注入井至3#井间的窜逸。在第二次封窜作业后，再开始第三次CO2驱替；
这个阶段因3#井方向基质中的相对高渗透层已经被注入的乙二胺与CO2反应成盐后封死，3#井无液体产出，1#井、2#井有大量油产出，同时，4#井也有少量油产出(见表2中三次气驱之列)，并且发现在2#井方向再次发生CO2窜逸现象。
(5)在发现2#井不出油且连续产出CO2后，开始二级封窜中的第三次作业，即先注入4ml的N2作为隔离段塞后，再注入设计量的乙二胺(18ml)，然后再注入4ml的N2作后续隔离段塞，以封堵中心注入井至2#井间的窜逸。在第三次封窜作业后，再开始第四次CO2驱替；
这个阶段因2#井方向基质中的相对高渗透层已经被注入的乙二胺与CO2反应成盐后封死，2#井无液体产出，1#井有较多油产出，同时，3#井也有少量油产出(见表2中四次气驱之列)，并且发现4#井方向已经无油产出。至1#井、3#井全无油产出时停止注入。
表2给出了实施例1模型在各阶段封窜采油情况。
表2实施例1模型在各阶段封窜采油情况表
Figure PCTCN2014000865-appb-000003
Figure PCTCN2014000865-appb-000004
图3为实施例1各阶段封窜施工效果汇总
由图3可知：经过两级封窜，特别是二级封窜中三次施工封窜基质中的窜逸，使采出程度从注水阶段的14.4％提高到80.1％，增加65.7个百分点，两级封窜效果显著。
当然，实际矿场应用中还要考虑经济效益的因素，如本实验中，各阶段施工效果见图3。在二级封窜中，经过一级封窜裂缝及二级封窜的第一次注胺施工，可以将总采出程度提高到56.4％，这已经接近常规油田化学驱的效果，若经济允许，再增加一次注胺施工，总采出程度可以达到72.6％，此时已经远远超过常规油田化学驱的效果，可以不用考虑再进行第三次注胺施工了。
为了验证两级封窜方法的可靠性，继续进行两组实施例加以比较、验证。用相同的实验流程及设备，实验方案相同，选择不同的模型，渗透率有所改变，验证、考察两级封窜效果的重复性。为便于对比效果，各阶段的操作过程以及转注操作顺序也完全相同(实施例2和实施例3)。
实施例2
物理模型2的物性及四个方向的渗透率见表3。
表3实施例2模型在各采出井方向渗透率测量结果
Figure PCTCN2014000865-appb-000005
同样，在1#与3#井之间，人工压裂造缝。裂缝中填充有少量粒径约为0.3mm的石英砂作为裂缝支撑剂，测定裂缝渗透率11876.5mD。
同样进行两级封窜，在裂缝封窜后，进行CO2驱，至一个井发生气窜后再开始循环封堵基质中相对高渗层的窜逸，结果见表4和图4。
表4实施例2模型在各阶段封窜采油情况表
Figure PCTCN2014000865-appb-000006
图4为实施例2各阶段封窜施工效果汇总
由图4可知：同样经过两级封窜，使采出程度从注水阶段的13.6％提高到76.2％，增加62.6个百分点。相比实施例1，尽管物理模型的渗透率大幅度降低，但是，两级封窜效果仍然很显著。在经过二级封窜的两次注气施工后，采出程度已经达到67.4％，该效果也超过了常规油田的化学驱效果。
实施例3
物理模型3的物性及四个方向的渗透率见表5。
表5实施例3模型在各采出井方向渗透率测量结果
Figure PCTCN2014000865-appb-000007
Figure PCTCN2014000865-appb-000008
为进一步考察两级封窜控制平面非均质性的能力，人工造缝从中心井至1#井和2#井，构成一个“V”型缝，裂缝中同样填充少量粒径约为0.3mm的石英砂作为裂缝支撑剂，测定裂缝渗透率12676.8mD。
然后开始相同的操作程序，模型在水驱后进行气驱，经过两级封窜，考察窜逸控制效果。实验结果见表6和图5。
表6实施例3模型在各阶段封窜采油情况表
Figure PCTCN2014000865-appb-000009
图5为实施例3各阶段封窜施工效果汇总。
由图5可知：尽管两条裂缝构成“V”型，仍然获得了良好的调整平面非均质性的封窜效果，经过两级封窜，使采出程度从注水阶段的11.2％提高到73.0％，增加61.8个百分点。由于中心井至3#、4#井方向面积大，在3#方向发生两次窜逸，而1#、2#井方向在注胶封堵裂缝后进行CO2驱阶段没再发生窜逸，模型的内部孔隙构成比较均匀。在经过一级封窜和二级封窜的两次施工后，采出程度已经达到67.0％，可以说，不用进行第四次气驱，该效果同样也超过了常规油田的化学驱效果。
两级封窜技术可以有效控制低渗透裂缝型油藏中CO2驱过程中的窜 逸，扩大波及体积。在一级封窜封堵裂缝后，若不计经济因素，二级封窜多次循环施工，理论上可以采出全部剩余油。实际应用中，需要根据技术经济限制，控制二次封窜施工轮次，以获得最佳经济效益。
工业应用
本发明针对低渗透裂缝型油藏注CO2过程中不同的窜逸情况，采用两级封窜的方式，先封堵裂缝中的窜逸，再封堵低渗基质中相对高渗透层中的窜逸，有效控制低渗透裂缝型油藏中CO2驱过程中的窜逸，扩大波及体积，提高了石油采收率。

Claims (10)

  1. 一种两级封窜抑制低渗透裂缝型油藏CO2驱窜逸的方法，包括下述步骤：
    1)一级封窜：以高强胶封堵裂缝实现一级封窜；所述高强胶是由下述质量份的原料经接枝聚合、交联形成的：天然改性高分子材料1-5份，单体1-5份，交联剂0.01-0.3份，引发剂0.001-0.3份和稳定剂0-0.5份；
    2)二级封窜：以脂肪胺对所述低渗透裂缝型油藏基质中的相对高渗透层导致的CO2的窜逸进行封堵。
  2. 根据权利要求1所述的方法，其特征在于：步骤1)中，所述天然改性高分子材料选自下述至少一种：羧甲基淀粉、羧乙基淀粉、羟乙基淀粉、羟丙基淀粉、α-淀粉、羟丙基瓜胶、羧甲基纤维素和碱纤维素；
    所述单体为烯丙基单体，所述烯丙基单体选自下述至少一种：丙烯酰胺、甲基丙烯酰胺、丙烯腈、丙烯酸、甲基丙烯酸、丙烯酸钠、甲基丙烯酸钠和丙烯酸酯；
    所述交联剂选自下述至少一种：双丙烯酰胺、N,N'-亚甲基双丙烯酰胺和N-羟甲基丙烯酰胺；
    所述引发剂选自下述至少一种：过硫酸钾、过硫酸铵、过氧化氢和过氧化苯甲酰；
    所述稳定剂选自下述至少一种：亚硫酸钠和硫代硫酸钠。
  3. 根据权利要求1或2所述的方法，其特征在于：所述一级封窜的方法具体包括下述步骤：将制备所述高强胶的原料与水混合后配制成质量浓度为2％-10％的溶液，并在小于地层破裂的压力下将所述溶液注入地层中并候凝；
    所述候凝的时间为24h-120h。
  4. 根据权利要求1-3中任一项所述的方法，其特征在于：所述脂肪胺选自下述至少一种：甲胺及其衍生物、乙胺及其衍生物、丙胺及其衍生物、丁胺及其衍生物和乙二胺及其衍生物；优选为乙二胺。
  5. 根据权利要求1-4中任一项所述的方法，其特征在于：所述二级封窜具体包括下述步骤：注入液氮作为隔离段塞后，在不高出CO2注入压 力20％的压力下，将所述脂肪胺注入已发生窜逸的基质渗透率相对最高的渗透层中，再注入液氮作后续隔离段塞后，无需候凝，继续注入CO2进行驱替。
  6. 根据权利要求5所述的方法，其特征在于：所述脂肪胺的注入量为窜逸通道孔隙体积的1/5-1/3；所述液氮的注入量为1-2吨。
  7. 采用权利要求1-6中任一项所述的方法对低渗透裂缝型油藏进行开采的方法，包括下述步骤：
    A1.对所述低渗透裂缝型油藏进行水驱开采；
    B1.当水驱发生明显的裂缝窜逸特征后，进行权利要求1-6中任一项所述方法中所述的一级封窜，再注入CO2驱替；所述明显的裂缝窜逸特征为采出液中含水超过98％，且含水指数特征曲线为凹型；
    C1.当发现所述低渗透裂缝型油藏基质中的相对高渗透层发生CO2窜逸后，进行权利要求1-6中任一项所述方法中所述二级封窜，继续注入CO2驱替。
  8. 根据权利要求7所述的方法，其特征在于：所述方法还包括：在所述步骤C1后，当再次发现所述低渗透裂缝型油藏基质中的相对高渗透层发生CO2窜逸后，重复步骤C1，直至总的采收率达到要求。
  9. 采用权利要求1-6中任一项所述的方法，对低渗透裂缝型油藏进行开采的方法，包括下述步骤：
    A2.对低渗透裂缝型油藏先进行水驱开采；而后进行CO2驱开采；
    B2.当CO2驱发生明显的裂缝窜逸特征后，进行权利要求1-6中任一项所述方法中所述的一级封窜，再注入CO2驱替；所述明显的裂缝窜逸特征为发现有油井基本不出油且连续大量产出CO2；
    C2.当发现所述低渗透裂缝型油藏基质中的相对高渗透层发生CO2窜逸后，进行权利要求1-6中任一项所述方法中所述二级封窜，继续注入CO2驱替。
  10. 根据权利要求9所述的方法，其特征在于：所述方法还包括：在所述步骤C2后，当再次发现所述低渗透裂缝型油藏基质中的相对高渗透层发生CO2窜逸后，重复步骤C2，直至总的采收率达到要求。
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