By using the self-developed twin-tube and multi-tube models of sand pack,four groups of twin-tube steam flooding experiments with the flow-line length ratio of 1.00,1.10,1.25and 1.41 respectively and one group of four-tube steam flooding experiments were conducted through changing the length of sand-packed tube, by which the steam sweep efficiency,recovery factor and the mutual influences among different flow lines were explored.Based on the experi- mental data,a new model to calculate the recov- ery factor and flow-line length ratio was estab-lished,and the ultimate recovery factor was pre-dicted for the entire area of a heavy oil reservoir by this model.In the twin-tube experiments,the bigger the ratio between the two tubes,the more the difference between their recovery,and the longer the flow line,the greater the impact on the recovery;In the multi-tube experiments,the more the flow line,the greater the impact on each other and the lower the recovery.This mathemat- ic model presented in this paper can be used to es- timate the ultimate recovery factor for the entire area of any reservoir,and the results will be quite accurate and reliable.

在三塘湖油田牛圈湖区决N2吞吐的试验中,为研究注采参数对产量、采收率的影响,对各个参数进行优化配比,选取正交表L25(56),采用正交试验并进行方差分析,考察周期注入量、井底流压、注入压力、注气速度、采液速度和焖井时间6个因素对吞吐效果的影响.结果表明,井底流压的极差值最大,影响最大,其余依次是注气压力、周期注气量、注入速度、采液速度、焖井时间.

Some high pour point oil reservoirs have high wax content,wax precipitation point and set point.Wax deposition may damage reservoir porosity and permeability,and normal temperature water injection may change the seepage law.2D water flooding physical simulation experiment is conducted to study the effect of different water temperatures and vertical well patterns on temperature field distribution,and the distribution of oil saturation in different well patterns is analyzed through numerical simulation.The research shows that water injection temperature has big influence on temperature field.It is suggested that the temperature of injected water shall be higher than the wax precipitation point for high pour point oil reservoirs developed by waterflooding,and five-spot pattern is preferable.

For Gas reservoirs in the sand,proppant has a vital role of mining,and proppant permeability is an important performance.Quartz sand and resin coated sand have different permeability,which should be tested loy laboratory methods.When we use gas measurement,gas flow rate is changed,so analysis of different flow rates and at different times on the permeability is got.As Liquid is measureed,under pressure the volatile liquid axial velocity is changed,and axial stability of the liquid under pressure affects the flow rate,the axial pressure,flow rate and data of different time are analyzed in terms of permeability.And the study has some significance for the deeper understanding of the dynamic development of oil and gas reservoirs and its recovery.

Aming at the development status of one high pour-point oil reservoir having high wax content,high wax precipitation point and freezing point,temperature sensitive of oil property,and the changes of seepage law as well as the large damages caused by the injection of room temperature water,etc.,the influence of water injection having different injection temperature,injection rate and well spacing on the temperature field distribution was studied by using the reservoir numerical simulation model to determine the reasonable water injection parameters.The results showed that the optimum water injection temperature is 66 ℃,injection rate is 600m3 /d,and the optimum well pattern is five-spot well network.

In the production of low-permeability sandstone reservoir,as effective stress rises gradually,the stress sensitivity will be appear,which causes permeability to decline.In considering in-situ stress of reservoir,cores,taken from Tarim Oilfield,were studied.The results showed that the stress sensitivity of the block was very strong,and its variation is consistent with exponential relationship.In the same block,permeability restoration of the cores with higher permeability was lower when the confined pressure changed.In addition,the experiments of the four cores from four different blocks,which were saturated with water,showed that after saturation,the permeability of the cores declined rapidly and that of the ones with higher permeability declined obviously.

In order to better find out the development characteristics of heavy oil reservoir,aiming at the geologic features and the fluid property characteristics of reservoir,the oil-water relative permeability curve of heavy oil reservoir is determined by the use of waterflooding nonsteady state method through laboratory experiment.JBN empirical formula is adopted in the process of data processing,using the logarithm for fitting and regression calculation to gain oil-water relative permeability curves,which obtains the experimental result.The study result shows that the two-phase fluid flow area is larger,residual oil saturation is relatively high,water permeability is relatively low and the isotope point saturation is larger than 50%.The oil-water relative permeability curve can be used to judge the reservoir wettability.The heavy oil reservoir is a weak water-wet reservoir.During the waterflooding,the water breakthrough time is early and the pressure difference of water breakthrough is 0.72,with less recovery ratio than 30% in water breakthrough.Ultimate recovery ratio is low.The study can provide a theoretical basis for EOR decision-making.Meanwhile,the reservoir wettability can be judged through the analysis of relative permeability curve.