• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    A permeability-reducing, high molecular weight, water-soluble, synthetic, organic polymer accumulated at or near a wellbore used in an oil recovery process is degraded to a lower molecular weight by contacting the polymer with an aqueous inorganic peroxide solution to restore permeability.
    公开号:SU1519531A3
    申请号:SU853973323
    申请日:1985-11-11
    公开日:1989-10-30
    发明作者:Данн Сиданск Роберт
    申请人:Маратон Ойл Компани (Фирма)；
    IPC主号:
    专利说明:

    The invention relates to oil production and can be used to restore the reduced permeability of a well or near a well in a formation.
    The aim of the invention is to increase the efficiency of the process.
    To increase the flow rate or amount of oil extracted from a well, usually a number of high molecular weight water-soluble polymers are pumped into the underground oil-bearing formations. The polymer is introduced into a chemical stream or water stream as a substance imparting to hocTb to improve the efficiency of the horizontal and vertical flow coverage. The polymer can also be pumped into the polymer plug as a mobility buffer in series with the chemical plug to maintain the rheological stability of the chemical plug as it passes through the formation.
    Squam inks, which are subjected to polymer swelling for these purposes, often over time show an excessive decrease in polymer injection capacity, which leads to a longer injection time and
    ate
    about U1
    : Le
     cm
    reduction in oil production. This is caused by the accumulation of a high molecular weight polymer residue in or near the well. The accumulated polymer causes a decrease in permeability in the area of the mouth of the injection well or in the rock and crystal fractures near the mouth of the well. Similarly to injection wells, a decrease in permeability can occur in production wells or close to their mouth, where the injected polymer forms with the oil.
    The permeability restoration method in or near the well is used after a significant decrease in the permeability is detected in or near the wellbore caused by the accumulation of high molecular weight polymer. The accumulation of polymer is an undesirable, but sometimes unavoidable result of the injection of a high molecular weight, water soluble, synthetic organic polymer into the subterranean formation through the well to increase oil production from the formation. The accumulation of a discrete amount of high molecular weight polymer molecules can significantly clog small pores in the formation and significantly reduce formation permeability. The method is based on the decomposition of high molecular weight, water soluble, synthetic organic polymer by injecting a single plug and an aqueous inorganic peroxide, such as hydrogen peroxide, into treatment area. Hydrogen peroxide is an oxidizing agent. Hydrogen peroxide is pumped in at a concentration of 10-60 g / l.
    Hydrogen peroxide does not adversely affect the process (environment). It is usually compatible with metals used in injection equipment and casing pipes. Hydrogen peroxide decomposes into water and oxygen. Hydrogen peroxide decomposes almost no danger for the environment.
    The drawing shows a graph that compares the particle size distribution of partially hydrolyzed polyacrylamide before and after treatment with hydrogen peroxide, as determined by high-performance liquid chromatography.
    Q 5
    o 5 ",.,
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    The method is mainly used to treat wells that are supplied with polymer to increase oil levels and that are characterized by reduced injectivity caused by the formation and accumulation of stationary high-molecular-weight polymers on the well wall or in a fracture structure that communicates with the well. This method can also be applied to high-performance production wells or other subterranean regions that have lower permeability due to polymer accumulation. By permeability is meant either the permeability of the subterranean formation, or the well productivity of a well.
    The process begins by injecting an aqueous solution containing inorganic peroxide into the well. Hydrogen peroxide is an inorganic peroxide in solution at a concentration of from 500 ppm to 30 wt.%, Preferably 1-5 wt.%. Fresh water is an aqueous solvent, in some cases, formation water can be used, the pH of the hydrogen peroxide solution in fresh water is the inverse function of its concentration. The normal pH of a solution of hydrogen peroxide in fresh water is acid, i.e. below 7. Within the possible range of the concentration of hydrogen peroxide in fresh water, the pH value ranges from 7 to 500 ppm to a hydrogen peroxide concentration of 30%. A solution of hydrogen peroxide in a slightly alkaline reservoir water can have a pH value greater than 7. Typically, a solution of hydrogen peroxide can be pumped into the wellhead without adjusting the pH of the solution, departing from its normal value.
    The amount of hydrogen peroxide solution injected into the wellhead depends on the size of the zone to be treated. Usually, for treating the entire polymer occupying the treatment zone, a sufficient amount of solution is injected, which depends on the wellhead volume, pore volume (porosity) and oil saturation of the surrounding rock, the volume of the fracture start up ITOT, the amount of polymer introduced and special chemical characteristics of the polymer, and the environment surrounding the wellhead.
    Immediately after injection of the peroxide solution into the wellhead neo (1, the well should be blocked, allowing the solution to be absorbed to maximize the amount of polymer that came into contact and decomposed under the influence of the peroxide solution. Impregnation time can be from several minutes to 48 hours or Moreover, the decomposition of the polymer begins immediately after contact with the peroxide.
    To increase the rate of decomposition of the polymer, additives can be added to the peroxide solution, for example, hydroxide ions and metal cations such as copper, iron, lead and chromium. The positive effect of hydroxide ions and metal cations together with peroxide on the destruction of the polymer should be evaluated with the negative effect of hydroxide ions and metal cations on the peroxide. These ions accelerate the rate of decomposition of hydrogen peroxide into water and oxygen, which reduces the amount of peroxide that can act on the polymer. This exchange limits the usefulness of these supplements,
    Polymers that can be degraded using this method include high molecular weight, water soluble organic polymers having a carbon-carbon skeleton. Peroxide treatment is most effective against polyacrylamide and partially hydrolyzed polyacrylamide, with a molecular weight ranging from one to 20 ppm, while O-VL amide groups are subjected to hydrolysis.
    Peroxide acts on carbon-carbon bonds along the polymer frame (polymer bond), leading to a break in the frame. The rupture of the framework significantly reduces the molecular weight of the polymer, converting it into smaller units without significant changes in the chemical composition and characteristics of the functional groups of the polymer. Although the decomposed polymer is essentially the same material as the high molecular weight polymer originally introduced, due to its lower molecular weight, the destroyed polymer is too small from a physical point of view to accumulate and form a stable polymer.
    0
    gel at the wellhead or clog pores in the reservoir. Thus, the low molecular weight polymer has a small effect on reducing permeability.
    After treatment of the injection well, which may include more than one sequential injection of the treatment fluids, it is preferable to pump treatment fluids from the well, including broken polymer, peroxide decomposition products (water and oxygen) and any
    The remaining peroxide and motility gel before the well is put into operation again. The fluids formed during processing can be forced out of the wellhead area into the reservoir
    Q and divert from the production well to fluid communications associated with the injection well. In cases where it is necessary to re-inject the injection well directly after treatment, to prevent diffusion of the peroxide and the sequentially injected polymer between the treatment fluids and the sequentially introduced polymers, a water layer is preferably injected to increase oil production. Immediately after the end of the treatment and restoration of the injection pattern into the well, it is possible to restore the injection of fluids to increase oil production through the treated injection well,
    Example 1. Samples of aqueous partially hydrolyzed polyacrylamide (CPPA) were placed in a series of cans. In a jar with samples added either brine or solvents in fresh water. PPP in each bank was the same and had an average molecular weight of about |, 5 million and about 30% of hydrolyzed amide groups. To each of the polymer samples, with the exception of three samples (tsT 1, 3, and 6), which left, as a control, added aqueous hydrogen peroxide
    (d) The dissolved contents of the jars were stirred overnight at room temperature. After 17, viscosity, sieving factor and filter factor were measured and listed in Table. 1. In the column called PPP, the initial is given by weight percent concentration of CPPA in the initial sample placed in the jar, in which
    0
    five
    five
    In this case, called PPP, the final is the weight percent concentration of PPG1L after diluting the sample with hydrogen peroxide solution. In samples to which hydrogen peroxide was not added, the values in the PPP columns of the initial and PPP of the end are the same. The column under the name gives the weight percentage in the sample immediately after the addition,. The filtration factor is the time required for filtering 50 cm of the polymer solution divided by the time required for filtering 50 cm of brine. Both volumes (liquids) were filtered under pressure through a Millipore 0.22 micron cellulose cellulose filter with a diameter of 7 mm at a pressure drop of 138 kPa.
    The orbs M i and 2 were examined before filtration using dimensionless high-performance liquid chromatography. The results of liquid chromatography are shown in FIG. Sample No. 1 has two peaks; the high molecular weight PPP, extracted first, was followed by the low molecular weight material in the sample. The hydrogen peroxide sample N 2 has only one peak, corresponding to the low molecular weight material. The dissolved solids in sample k were examined after filtration with infrared radiation (IR). Solid particles exhibit those IR properties as CPPA.
    Example 1 indicates the ability to convert all high molecular weight CPPA to low molecular weight CPPA, which is confirmed by the results of high performance liquid chromatography and infrared radiation. IR analysis tends to confirm that the mechanism of polymer breakdown is the division (rupture) of the framework, which practically does not change the functional groups of the polymer. I
    PRI mme R 2. Countercurrent gel
    was obtained from a petroleum well, working with injection of CPG. The gel contained CPPA, similarly to example 1, at a concentration of 6500 ppm. In addition, the gel contained about 150 ppm of elemental iron and certain amounts of sand and other substances. A solution was added to the 1 ° 2 sample gel, while it was not added to sample No. 1. Two samples re
    five
    0
    five
    0
    five
    0
    five
    0
    five
    stirred for one night at room temperature. Viscosity, scattering factor and filtration factor were determined and tabulated. 2. The filtration factor was determined in the same way as in Example 1, except that 0.6 micron PVC filters were used.
    PRI me R 3. Solid pieces, containing 1: 50% by weight 4 of cross-linked polyacrylamide, were immersed in various samples of aqueous solutions. These amounts were such that the concentration of polyacrylamide in the sample when dissolved in solution could be 10 wt.%. Samples of the solution containing various amounts were maintained at atmospheric pressure and at room temperature until almost all of the solid polyacrylamide was dissolved. Samples W 1G3 mixed well. NV and 5 samples were not mixed at all. The filtration factor was determined by analogy with Example 1. The fT 1-3 samples were filtered through a 0.22 micron Millipore mixed cellulose and nitrocellulose filter, while samples 4 and 5 were filtered through a Polyvie flillipore 0.6 micron filter.
    The results are shown in Table. 3
    The concentration is the initial (initial) concentration. It is reduced due to contact time.
    In sample K 1, the concentration was restored to 3 in 22 hours. In sample f, the solid was broken into 20 small pieces, while in sample f 5 the solid was a single piece. In samples 1-5, all solid was dissolved before the specified contact time (up to 22 hours in sample 1),
     Example. In Japan, PPP injection wells of the type described in Example 2 were tested for reduced injection. Injection is expressed in liters per day with a discharge pressure of 6900 kPa. 9500 l of 5% aqueous treatment solution were injected into each well,. After pumping treatment fluids and holdings, the treatment fluids were pumped out. The wells were then returned to water injection.
    The results of infection are given in table. .
    Injection capacity of treatment: well 1,600 m, well 2,400 m.
    The wells are stabilized after about 5 Leah. The injection water in both wells at this moment is approximately twice the injection rate before treatment. The first 9,500 liters of fluid pumped out immediately after treatment were light, did not contain a gel, and contained only small amounts of oil. Subsequent liquids, pumped out after the first 9,500 liters, contained a small amount of gel. The appearance of small amounts of gel in an evacuated (circulating) liquid indicates that only PPP gels that were in direct contact with the processing liquid were destroyed.
    PRI me R 5. Aqueous samples containing 1.95 weight. PPP from example 1 was treated with various solutions of hydrogen peroxide or oxygen-containing gases. Gases were bubbled through the CPPA test solution. The weight ratio between PPP solution and hydrogen peroxide solution was 1: 1. In experiments with gases, distilled water was added to the PPP solution in a weight ratio of 1: 1. PPP was treated with a treating chemical at room temperature for 20 hours and then examined for viscosity, scattering factor and filtration factor by a method similar to Example 1. 0.6 micron Polyvic Millipore filters were used to determine the filtration factor b9 kPa.
    The results are shown in Table. five.
    From tab. 5 it follows that hydrogen peroxide is effective in breaking PPP, while oxygen-containing gases are ineffective in breaking PPP.
    EXAMPLE 6 A burned cork from Vegea sandstone, 7.6 cm long and 2.5 cm in diameter, with a permeability of 100 ml, was successively flooded with the fluids given in Table. 6. The fluid flow was supplied at a pressure of 2800 kPa. Tight plugs (plugs) are installed before the first
    531 O
    and second parts along the length of the plug to determine the corresponding reduction in permeability in these areas. The results are summarized in table. 6. All fluid concentrations are given in weight percent. PPP is given from example 1. The fluid volume is a pore volume filled with a water fluid in each sequence. The reduction in permeability is expressed as the ratio k of the coch, /
    / macha ribH.
    The flooding of PPP in sequence 2 led to an excessive decrease in permeability due to the accumulation of residual PPP in the core plug. In fact, all permeability was restored to the first half of the cork due to the hydrogen peroxide treatment in the sequence, while 803 were restored to the second half of the cork; permeability.
    25 Example7. Three small flasks were filled with pieces of metal tubes with an outer diameter of 0.6 cm. The remaining volume of the flask was filled with Clorox reagent, commercial
    30 Designation Firuma Clorox Co. ,
    5, with a weight solution of sodium hypochlorite, the pH of which was adjusted to 9. Experiments were carried out at room temperature.
    The non-metallic tubes in the first sample were carbon steel. After a few minutes, large amounts of a brownish-colored voluminous precipitate formed and continued to develop over two hours. The monel metal tubes in the second sample gave the same results, except that the sediment was black and somewhat smaller in volume. Modsnell is a trademark of an alloy containing approximately 67% nickel, 2S% copper, 1-2% manganese, and 1.9-2.5 ee. gland. Stainless steel tubes for 1st 316 steel were in
    r / j third sample. Even after several days, a slight reaction was observed.
    Sodium hypochlorite easily acts and corrodes carbon steel and monel-metal, which are commonly used in oil fields, to form metal oxidation products. These sediments can quickly plug a subterranean formation.
    35
    five
    Similar laboratory experiments with volorol peroxide and the above metals indicate that hydrogen peroxide is not at all corrosive compared to sodium hypochlorite.
    权利要求:
    Claims (1)
    [1]
    1. A method of restoring the permeability of a well or near it in fluid communications of a subterranean formation by introducing an oxidant in a range with a lower permeability, formed due to accumulated on the surface of the well or a subterranean formation of high molecular weight polyacrylamide or partially hydrolyzed polyacrylamide, and h a
    So that, in order to increase the efficiency of the process, the oxidizing agent is introduced into the well and kept in contact with high molecular weight polyacrylamide or partially hydrolyzed polyacrylamide to partially decompose them to lower molecular weight, and an aqueous solution is injected as an oxidizing agent. containing hydrogen peroxide in a concentration of 10-60 g / l.
    2, Method pop. 1, which differs from the fact that an aqueous solution containing hydrogen peroxide is used, and additionally, as an additive, transition metal cations selected from the group consisting of lead, chromium, iron, copper or mixes.
    Table 1
    SIV Synthetic and injection water of an oil field (reservoir water), containing 2.6 wt. dissolved solids and having 1.3 weight. rigidity.
    Table 2
    43 2.5 3.3 1.6 2.3 2.6
    Table3
    13
    1519531
    Table l)
    14
    TableB
    Sample 1 / ifeo6pQffomaHHMf I Sample 2 / Processed /
    3
    : s
    "
    About Time eluirokay / min
    Highly resilient migpea / t
    Editor A.Lezhnina
    Compiled by I. Lopakova
    Tehred P.Hodami h Corrector T.Kolb
    Order 6616/59
    Circulation 51
    VNIIPI State Committee for Inventions and Discoveries at the State Committee on Science and Technology of the USSR 113035, Moscow, “-35, Raushsk nab., 5/5
    t
    HuiKOfiO / ieKy ftpHbiijt Mi1leria / 1
    Subscription
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    同族专利:
    公开号 | 公开日
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    FR2560927A1|1985-09-13|
    GB2165567A|1986-04-16|
    WO1985004213A1|1985-09-26|
    CA1229479A|1987-11-24|
    JPS61501329A|1986-07-03|
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    引用文献:
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    US3818991A|1971-05-20|1974-06-25|Dow Chemical Co|Method of treating subterranean formation with a composition of improved viscosity control|
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    法律状态:
    优先权:
    申请号 | 申请日 | 专利标题
    US58826984A| true| 1984-03-12|1984-03-12|
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