Abstract: The invention is related to the development of gas condensate deposits and may be used to determine current condensate saturation in the near-wellbore zone in the formation. The method for the current condensate saturation determination in the near-wellbore zone requires the measurement of the formation rock parameters and formation fluid parameters before the start of gas-condensate production and creation of the numerical model of the neutron logging signal change during the production period for the measured formation rock parameters and formation fluid parameters and expected condensate saturation value. During the production period when the well productivity decreases, neutron logging is performed and then the measured signals are matched with the model calculations and based on the provision of the best match of the measured and simulated neutron logging signals condensate saturation is determined.

Abstract: The invention is related to the development of volatile oil deposits and may be used to determine current gas saturation in a near-wellbore zone in a volatile oil formation. The method for the current gas saturation determination in the near-wellbore zone requires the measurement of the formation rock parameters and formation fluid parameters before the gas accumulation start in the near-wellbore zone and creation of the numerical model of the neutron logging signal change during the production period for the measured formation and formation fluid parameters and expected gas saturation value. During the production period when the well productivity decreases, neutron logging is performed and then the measured signals are matched with the model calculations and based on the provision of the best match of the measured and simulated neutron logging signals gas saturation is determined.

Abstract: The invention is related to the development of volatile oil deposits and may be used to determine current gas saturation in a near-wellbore zone in a volatile oil formation. The method for the current gas saturation determination in the near-wellbore zone requires the measurement of the formation rock parameters and formation fluid parameters before the gas accumulation start in the near-wellbore zone and creation of the numerical model of the neutron logging signal change during the production period for the measured formation and formation fluid parameters and expected gas saturation value. During the production period when the well productivity decreases, neutron logging is performed and then the measured signals are matched with the model calculations and based on the provision of the best match of the measured and simulated neutron logging signals gas saturation is determined.

Abstract: The invention is related to the development of gas condensate deposits and may be used to determine current condensate saturation in the near-wellbore zone in the formation. The method for the current condensate saturation determination in the near-wellbore zone requires the measurement of the formation rock parameters and formation fluid parameters before the start of gas-condensate production and creation of the numerical model of the neutron logging signal change during the production period for the measured formation rock parameters and formation fluid parameters and expected condensate saturation value. During the production period when the well productivity decreases, neutron logging is performed and then the measured signals are matched with the model calculations and based on the provision of the best match of the measured and simulated neutron logging signals condensate saturation is determined.

Abstract: Method to determine the point of the gas leak from the buried pipeline located in the ditch under the soil, providing positioning at least one fiber-distributed temperature transmitter in the soil over the pipeline; the fiber-distributed temperature transmitter's readings allow to determine the leak point presence and location; the method is characterized by the fact that the fiber-distributed temperature transmitter is located above the pipeline surface; in the ground, between the pipeline and the transmitter or over the transmitter a shield is mounted which deflects the gas flow (in case of leakage) in the upper central part of the ditch adjacent to the transmitter and preventing the gas flow to the ditch peripheral areas located far away from the transmitter; the temperature is measured continuously and by the temperature drop the gas leak and its location is determined.