In recent years, horizontal well fracturing water injection huff and puff technology has become the main development technology of tight oil.In the initial stage of water injection huff and puff, higher production was achieved,however,with the increase of huff and puff times,the production decreased rapidly and the oil⁃water replacement efficiency was low.Based on the compact oil data of Jimusaer Oilfield in Xinjiang,through laboratory core water injection huff and puff experiment and single well water injection huff and puff numerical simulation research,the effects of injection volume,time of water injection huff and puff,injection speed, huff and puff times,soaking time and production speed on water injection huff and puff recovery are analyzed.The single well geological model is established,and the influencing factors of water injection huff and puff are fitted by multi⁃nonlinear function.The empirical formulas of five parameters and three parameters of water injection huff and puff are deduced for the first time. The prediction error is within 8%, which provides important reference for the development of water injection huff and puff in the study area and similar tight reservoirs.

The permeability and absorption experiments of low permeability sandstone core under the actual formation temperature and pressure were carried out,which were used to analyze the waterflooding huff⁃puff 's oil recovery law of imbibition and compared with imbibition experiments of normal temperature⁃pressure.The experiments show that the imbibition efficiency of normal temperature⁃pressure is 18%~24%,with an average of 21%.The permeability rate of core in the first six hours is the fastest,which is 0.8~1.7 %/h.The imbibition efficiency of actual reservior's temperature and pressure conditions is 24%~31%,with an average of 27%;Imbibition rate is the fastest in the first round,which is 2.6~3.6 %/h.Compared with imbibition of normal temperature⁃pressure,the imbibition of actual reservior 's temperature and pressure conditions can promote the imbibition efficiency by 5% to 7%,and the imbibition rate is also significantly higher than the imbibition of normal temperature⁃pressure.The analysis believes that imbibition of actual reservior 's temperature and pressure conditions can increase the imbibition's power and reduce the imbibition's resistance,which is more conducive to oil⁃water displacement.Furthermore,the theoretical calculation model of the imbibition depth is established, and the cores' imbibition depth is about 0.25~0.63 cm.It is considered that the depth of the early rapid imbibition stage is in the centimeter range,and the imbibition depth increases with the imbibition efficiency.According to the comprehensive research,increasing the reservior's pressure and large⁃area fracturing can effectively improve the imbibition efficiency.

The enhanced oil recovery technology of ASG (alkali, surfactant and nitrogen) composite foam and water alternating injection was studied in high temperature and high salinity low permeability reservoir. The ASG foam and water alternating injection experiments were carried out through indoor flooding experiments, and compared with water flooding nitrogen flooding and surfactant flooding. The results show that the enhanced oil recovery of the method adopted by this study is 16.61%, 10.26% and 9.21%, respectively, compared with water flooding, nitrogen flooding and surfactant flooding technology. Experimental study on injection parameters optimization of ASG foam and water alternating injection is carried out, and the parameters such as slug size, injection rate and gas fluid ratio of ASG composite foam are optimized by bench scale displacement test. The results show that under the condition of the same foam injection volume (1.2 times the pore volume), the effect of foam slug injection with 0.4 times pore volume is best. The foam injection rate has an optimum value of 1.5 mL/min. When the injection rate is too low, less foam is produced, gasliquid separation is easy to occur, and the blocking effect is poor. When the injection rate is too high, the size of the bubble is different, and it is easy to cause the bubble to merge, causing the bubble to burst, and at the same time, it is easy to cause the shear defoaming of the foam. When the gas fluid ratio is 3∶1, 2∶1 and 1.5∶1, respectively, the recovery rate is 2.04% higher than that of the single gas fluid ratio.