储气调峰能力不足是当前我国天然气产运储销体系建设的短板之一.由于地下储气库建设存在选址难度大、建设周期长等特点,为满足更多区域调峰需求,单井气藏改建储气库作为一种新模式应运而生,成为地下储气库的重要补充.为了解决单井气藏改造成储气设施的经济性论证问题,结合单井改建储气库的技术经济特征,在评价末期回收垫底气,建立与之相适应的经济评价方法.研究结果表明:①以川西北地区WC1井为例论证了考虑垫底气回收经济评价方法的可行性,项目整体内部收益率为6.78％,高于6％的基准收益率,从财务评价角度证实方案经济可行;②对比了评价方法对方案效益的影响,不考虑垫底气回收情况下,方案整体内部收益率为6.17％,低于考虑垫底气回收时6.78％的收益率.最后,提出两点建议:①推广单井气藏改建储气库的建库新模式,尤其是在选址难度大,但是又有调峰需求的资源地,可充分利用区域内现有的产能和枯竭气藏资源,开展单井气藏改造储气库的探索;②推荐经济评价时考虑回收垫底气,以解决改造项目的经济性论证难题.

对于压力高于70 MPa的含H2S天然气,其分子之间间距缩小,极性H2S分子之间缔合作用增强,传统SRK、PR状态方程计算高压含硫天然气的压缩因子准确性有待进一步改进.基于压力3.72～97.58 MPa、H2S体积分数0％～70.03％的154组压缩因子修正CPA(Cubic-Plus-Association)状态方程中H2S与CH4、CO2分子间二元交互作用系数,综合评价SRK、PR、CPA状态方程对压缩因子的计算精度.结果表明,对于中低压含硫天然气(p<35 MPa),采用PR方程精度最高,平均相对偏差为1.12％;对于高压及超高压含硫天然气(p>35 MPa),CPA方程精度最高,平均相对偏差为-1.46％.进一步采用法国ST抗硫高压PVT仪测试了4种含硫天然气在70～131 MPa条件下的138组压缩因子实测值,验证了采用CPA状态方程对于高压含硫天然气压缩因子的计算精度.

The exorbitant salinity of formation water and the improper use of chemicals often have a severe effect on the operation of TEG dehydration unit .This paper mainly discussed the common problems and influencing factors of TEG dehydration unit ,deeply analyzed the reasons of the device operation ,put forward corresponding treatment and preventive measures ,which might provide refer‐ence for the steady operation of TEG dehydration equipment .

In order to effectively classify the flow units of the tight sandstone reservoirs with strong heterogeneity and the carbonate reservoirs,according to the information of flow units in gas reservoir and the principle of the same or similar geochemical characteristics of flows in one identical flow unit,the T3x2 gas reservoir in Qiongxi area was divided into four flow units using the factor analysis,clustering analysis and cross plot method.The four flow units include the north fault horst flow unit,the south fault high-flow unit,west wing nasale flow unit and No.12 well flow unit in Qiongxi area.The demarcation results fit the production performance of this area.The method can also be used to detect and evaluate the change of flow units,which can offer the reference to gas field development program.The real application proved that the geochemical characteristics of flows are useful to demarcate gas flow units in gas field.

Calcites in the form of cement are quite common in the second member of the Upper Triassic Xujiahe formation of Qiongxi area,Sichuan basin,and their content,distribution and degree of dissolution directly influence the performance of the reservoirs. Core test data,thin section data and log data are used to analyze the features and genesis of the calcite-cement intercalations in the second member of the Xujiahe formation in the study area. The calcite-cement intercalations are characterized by low Gama value,low interval transit time and bayonet-like high resistivity on borehole logs. They mainly occur near argillaceous beds and act as barriers in local areas. Analysis of the measured carbon and oxygen isotope of calcite cements shows that the organic acid generated during hydrocarbon expelling of argillaceous rocks or coal measures is the main source of acidulous water.

This paper investigates water producing characteristics in Xu'er gas reservoir of Pingluoba gas field,discriminates the stages and ways of water producing,defines water sources of gas wells including interstitial water,edge water,interbedded water and so on,and analyzes gas well production characteristics when water is produced from different sources.This research provides in-depth understanding of the reasons of water invasion in gas reservoirs and is of practical significance to future production and development.

Penglaizhen Fm gas pool in Baimamiao area is by now the largest shallow gas accumulation in respect of gas reserves in southwest of Sichuan basin and is characterized by tight reservoir, complex pore structure, strong heterogeneity, low single well deliverability and steep decline of single well production. Study of reservoir characteristics, the main control factors of gas well production performance and well stimulation should be strengthened, so as to efficiently develop the gas pool. Both study and practice show that gas well deliverability increases and its decline rate lowers along with the increasing reservoir capacity (Hφ). All the nine gas producers with high to medium production capacities, including Baiqian 26 and 38 wells, are positioned on the main channel sandbody and the success ratio of production tests is 100%. Their average gas production is 4.3 times that of gas wells located in other facies belts. In view of the reservoir characteristics of low porosity and low permeability and strong water sensitivity, under-balanced and gas drilling technologies are used to shorten the drilling time, lessen formation damage and liberate pay zones. Study of rational production proration is strengthened to prolong the production plateau. Full-reservoir sand fracturing, with a success ratio of 71.43%, was performed in 42 wells/times, resulting in an incremental AOF of 855,300 m3/d. Highly-deviated wells and horizontal wells are drilled in a common well site to fully expose and liberate the gas reservoir and to lower well site investment. There is a 18-fold increase in the AOF compared with the vertical wells in the same well site and the production performances are remarkably improved after they are brought on line.

Penglaizhen Gas Pool of BaiMamiao Gasfield,which belongs to tight sandstone gas reservoir, was put into production in May, 1997. The initial productivity of gas wells in this gas field were low. In fact, there shouldn' t have had commercial gas out from most of them without any stimulation measurement. So far,29 wells in this gas field have been fractured, 20 of which have been improved. According to the fracturing operation plots, well test interpretation results and gas production data, we analyzed in detail the key factors that influenced the outcome of fracturing. It has important practical significance to guide the reservoir fracturing in the near future.