A METHOD OF IMPROVING THE FLOW PROPERTIES OF A CRUDE OIL OR NATURAL GAS LIQUID

Abstract: A method to improve the flow properties of wax containing crude oils and natural gas liquids which contain a natural pour point depressant by adding a synthetic pour point depressant at a higher temperature than 20 DEG C below the inversion temperature of the crude oil or natural gas liquid.

Description: A method of improving the flow properties of a crude oil or natural gas liquid The present invention relates to a method of improving the flow properties of a wax containing crude oil or natural gas liquid containing a natural pour point depressant by adding a synthetic pour point depressant. Typically, crude oils and natural gas liquids contain several types of hydrocarbons, such as paraffins, naphte- nes and aromatics. However, the paraffins, which are nor- mally liquid or gaseous at reservoir conditions, have the disadvantage that at lower temperatures they tend to form a solid wax phase. In practice this gives rise to problems, such as formation of a gel with a significant gel strength, e.g. during shut down of wells, pipelines, processing plants etc. Likewise problems caused by wax deposition on cold surfaces, e.g. in pipelines and heat exchangers, can occur. Furthermore the formation of a solid wax phase can lead to an increased viscosity, which means that the crude oil or natural gas liquid may become significantly more difficult to handle. For the purpose of alleviating the above problems it has been known for long to add so-called "pour point depressants" in order to lower the pour point of the crude oil or natural gas liquid, which point according to ASTM D97 or ASTM D5853 is defined as the temperature at which a crude oil or natural gas liquid at given conditions starts to solidify. Such synthetic pour point depressants may comprise a wide range of polymers and copolymers (polyacetates, polyacrylates, polymethacrylates, poly- amides, etc. ) . The polymers may roughly be divided into nucleators and growth arrestors depending on their function in the crude oil or natural gas liquid. However, it is a common fea- ture thereof that they are incorporated in the solid wax phase and thereby change its structure and properties. To achieve improved efficiency, it is normal practice to add the former type of wax inhibitor at or close to the wax appearance temperature (WAT) of the crude oil or natural gas liquid, which is defined as the temperature at which the wax starts to precipitate. The latter type of wax inhibitor can be added at lower temperatures, although the efficiency hereof seems to increase if the polymer is in- corporated already in the solid wax phase first formed. In certain crude oils and natural gas liquids there are, however, also naturally occurring pour point depressants for instance in the form of asphaltenes, which are a group of heavy polar aromatic compounds having a molecu- lar weight in the range 700-1000 g/mole. These natural pour point depressants are present in the crude oil or natural gas liquid when it is produced from the reservoir, and are normally fully dispersed in the liquid phase at initial reservoir conditions. At lower tempera- tures they may, however, start to flocculate, which reduces their pour point depressing efficiency. This phenomenon gives rise to the concepts upper and lower pour points, as defined in the standard ASTM D97. Flocculation of the natural pour point depressants may also be induced by changed pressure or mixing with water or other oils/condensates. Just like synthetic pour point depressants they change the structure of the wax phase formed, although in many cases their mere presence does not completely suffice for solving the problems associated with wax precipitation. In practice during oil production, an amount of the abovementioned synthetic pour point depressants has therefore been added to crude oils and natural gas liquids at a temperature close to the WAT of the crude oil or natural gas liquid, assuming that thereby an additive effect of the natural and synthetic pour point depressants would be obtained. In certain cases this additive effect does not appear, as the naturally occurring pour point depressants seem to be capable of counteracting and even totally neutralizing the effect of the synthetic pour point depressants. Consequently, it is the object of the present invention to provide a method of reducing or eliminating the above problems and thereby ensure an effective improvement of the flow properties of crude oils and natural gas liquids . The method according to the invention is characterized in that the synthetic pour point depressant is added to the crude oil or natural gas liquid at a higher temperature than 20 °C below the inversion temperature of the crude oil or natural gas liquid. The inversion temperature of a crude oil or natural gas liquid is determined by the use of a modified ASTM D97 or modified ASTM D5853 standard method. These standards specify upper and lower pour points to be measured after reheating the sample to 48 °C and 105 °C, respectively. By reheating the crude oil or natural gas liquid to a given temperature and subsequently determining the pour point of this sample and repeating this measurement at different reheating temperatures and subsequently depicting these pour points as a function of the reheating temperature, the reheating temperature at which the pour point has been reduced to its minimum value can be deter- mined. This point is defined as the inversion temperature, and is the temperature at which the natural pour point depressants are fully active. The result will typically be within the interval 80-110 °C. The inversion temperature definition is, however, not applicable to hydrocarbon samples, where the upper and lower pour points are identical. This phenomena is believed to be due to the lack of natural pour point de- pressants mainly found among the asphaltene fraction of the fluid. When using the method according to the invention it has turned out that in situations m which addition of synthetic pour point depressants has otherwise been without result, a positive effect can be obtained. This is presumably due to the pour point depressant being added to the crude oil or natural gas liquid at a time when the natural pour point depressants are fully or at least partly dispersed. In this way it is avoided that the flocculated natural pour point depressants, which apparently form a separate, polar liquid phase, are capable of absorbing the synthetic pour point depressants by virtue of their content of polar groups. Due to a more efficient pour point depression, it is pos- sible to obtain a suitable pour point even by addition of small amounts of synthetic pour point depressants. Alternatively, a lower pour point can be obtained by using the usual amount of synthetic pour point depressant. Preferably the synthetic pour point depressant should be added at a higher temperature than e.g. 10 °C below the inversion temperature, more preferably at or above the inversion temperature. If the synthetic pour point depressant is added at a temperature 20 °C below the inversion temperature of the crude oil or natural gas liquid, the natural pour point depressants are thus not fully dispersed, whic means that the efficiency obtained is not optimal. In practice, the best effect is obtained by injecting the synthetic pour point depressant into the well bore at a depth, where the crude oil or natural gas liquid has a temperature at or higher than the inversion temperature. An appropriate depth for adding the synthetic pour point depressant, may be determined as the depth at which the formation temperature corresponds to the inversion temperature of the crude oil or natural gas liquid produced. Since the temperature at this point automatically will increase once the production starts, adding the depressant at this depth ensures that the temperature of the crude oil or natural gas liquid will always exceed the inversion temperature when mixed with the synthetic pour point depressant. The required dosage of synthetic pour point depressant depends on factors such as the type of crude oil, amount of wax formed in the crude oil at different temperatures, ambient conditions etc. The optimum dose rate is normally estimated by means of laboratory measurements of pour point, viscosity, gel strength and wax deposition tendency. The two latter measurements are often carried out on laboratory coils. In practice the synthetic pour point depressant is added in an amount of 5-2000 ppm, preferably 20-500 ppm and most preferably 20-100 ppm. A preferred synthetic pour point depressant useful in the method according to the invention comprises a chemical compound having the general formula I: -CH 2 -CH-(CH 2 -CH 2 ) n - C = 0 O R m where m = 20-300, preferably m = 25-100 and most preferably m = 50-80, n = 5-50, preferably n = 5-25 and most preferably n = 8-15 and R symbolises a hydrocarbon, preferably an aliphatic hydrocarbon and most preferably an aliphatic hydrocarbon consisting of 2-20 carbon atoms. However, also other compounds may be used, such as poly- acetates, polyacrylates, polymet acrylates, polyamides etc. The invention is described in more detail in the follow- ing examples. Example 1 It is the purpose of this experiment to demonstrate a correlation between the temperature of the oil sample at which the synthetic pour point depressant is being added and the efficiency of the synthetic pour point depressant added. In this experiment an oil sample no. 1 having the following characteristics is used: Wax appearance temperature (°C) 50 Upper pour point (°C) 33 Lower pour point (°C) 24-27 Wax content (weight % at -30 °C) 22 Asphaltene content (weight %) 0.2 Density (g/cm 3 ) 0.868 Kinematic viscosity at 80 °C (cSt) 3.50 Kinematic viscosity at 75 °C (cSt) 3.91 Kinematic viscosity at 70 °C (cSt) 4 -34 Kinematic viscosity at 65 °C (cSt) 4 -81 Kinematic viscosity at 60 °C (cSt) 5 -36 Kinematic viscosity at 55 °C (cSt) 6.03 Kinematic viscosity at 50 °C (cSt) 6-85 Kinematic viscosity at 45 °C (cSt) 9 -31 Kinematic viscosity at 40 °C (cSt) 14.73 The wax appearance temperature of the oil sample was determined from the viscosity measurements. Measurement of the pour point of oil sample no. 1 was then conducted on two uninhibited subsamples nos. 1A and IB by heating the oil samples to various temperatures succeeded by cooling in order to determine the pour point of the oil samples. From the results of the measurements, in Figure 1, showing the pour point as a function of the reheating temperature, it is seen that the inversion temperature of the oil sample may vary from 90 to 100 °C . Then the same oil sample no. 1 was again heated to different temperatures, followed by addition of 250 ppm of the chemical additive A, and the effect hereof was exam- ined by measuring the pour point of the oil sample, by letting it cool down in accordance with standard procedure ASTM D97. The result hereof is also seen from Figure 1 (250 ppm of chem. A) . It appears clearly that the pour point of the oil sample no. 1 with addition of additive A follows the trend of the two uninhibited subsamples up until approx . 80 °C, above which point the additive becomes active with a resulting strong decrease in the pour point of the oil sample. This is consistent with the theory proposed, as the 100 °C corresponds to the inversion temperature of the oil sample no. IB, which means that the natural pour point depressants here are fully dispersed. Thus Figure 1 shows that for this very waxy crude oil sample a pour point improvement of the magnitude of 18-21 °C can be observed with chemical dosage of only 250 ppm. Example 2 It is the purpose of this example to demonstrate that in accordance with the proposed theory, it is only in case of crude oil or natural gas liquid samples containing natural pour point depressants that the favourable effect of an increased chemical injection temperature is achieved. In this experiment an oil sample no. 2 having the following characteristics is used: Wax appearance temperature (°C) 40 Upper pour point (°C) 12 Lower pour point (°C) 1 Wax content (weight % at -30 °C) 10 - 4 Asphaltene content (weight %) <0.05 * Density (g/cm 3 ) 0.799 Kinematic viscosity at 70 °C (cSt) 1.224 Kinematic viscosity at 60 °C (cSt) 1.394 Kinematic viscosity at 50 °C (cSt) 1.596 Kinematic viscosity at 40 °C (cSt) 1.866 Kinematic viscosity at 30 °C (cSt) 2.733 Kinematic viscosity at 20 °C (cSt) 5.4 * detection limit The wax appearance temperature of the oil sample no. 2 was determined from the viscosity measurements. Measurements of the pour point of the uninhibited oil sample no. 2 as a function of the heating temperature were conducted, as stated above, and the results appear from Figure 2. It should be noted that upper and lower pour point are identical, which is strongly indicative of the absence of natural pour point depressants. Hereafter the pour point was determined again following addition of 50 ppm of chemical additive A in order to test the effect of the addition temperature according to the above example. As is seen from Figure 2 (50 ppm of chem. A) , the temperature has no influence on the efficiency of the additive, which according to the proposed theory is consistent with the missing content of natural pour point depressants.

Claims: C l a i m s : 1. A method of improving the flow properties of a wax containing crude oil or natural gas liquid containing a natural pour point depressant by adding a synthetic pour point depressant, c h a r a c t e r i z e d in that the synthetic pour point depressant is added to the crude oil or natural gas liquid at a higher temperature than 20 °C below the inversion temperature of the crude oil or natural gas liquid. 2. A method according to claim 1, c h a r a c t e r i z e d in that the synthetic pour point depressant is added to the crude oil or natural gas liquid at a higher temperature than 10 °C below the inversion temperature, preferably at a temperature at or above the inversion temperature. 3. A method according to claim 1 or 2, c h a r a c t e r i z e d in that the chemical additive comprises a substance having the formula I : -CH 2 -CH-(CH 2 -CH 2 ) n - O O R m where m = 20-300, preferably m = 25-100 and most preferably m = 50-80, n = 5-50, preferably n = 5-25 and most preferably n = 8-15 and R symbolizes a hydrocarbon, preferably an aliphatic hydrocarbon and most preferably an aliphatic hydrocarbon consisting of 2-20 carbon atoms. 4. A method according to any of the above claims, c h a r a c t e r i z e d in that the synthetic pour point depressant is added in an amount of 5-2000 ppm, preferably 20-500 ppm and most preferably 20-100 ppm. 5. A method according to any of the above claims, c h ar a c t e r i z e d in that the synthetic pour point de- pressant is injected into the well bore.

Inventors: HANSEN JENS H, HANSEN, JENS, H.
Applicants: HANSEN JENS H, MAERSK OLIE & GAS A S, HANSEN, JENS, H., MAERSK OLIE & GAS A/S
Application year: 1998
Main classification: C10G29
IPC codes: C09K8, C10G29, C10L1, E21B37, E21B43