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首页> 外文期刊>The APPEA Journal >RETROGRADE CONDENSATION OR WATER IMBIBITION ? A CASE STUDY OF GAS WELL PRODUCTIVITY DECLINE BEFORE AND AFTER HYDRAULIC FRACTURING
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RETROGRADE CONDENSATION OR WATER IMBIBITION ? A CASE STUDY OF GAS WELL PRODUCTIVITY DECLINE BEFORE AND AFTER HYDRAULIC FRACTURING

机译：凝结水凝结还是凝结？水力压裂前后天然气井产能下降的案例研究

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Studies have been carried out to diagnose the cause of productivity decline for the Kaimiro-1 well in the Kaimiro gas field, Taranaki Basin, New Zealand. The gas flow rate for Kaimiro-1, declined from 5 MMSCFD (0.14 Mm~3 per day) in 1983 to about 0.6 MMSCFD (0.017 Mm~3 per day) in 1993, immediately prior to hydraulic fracturing. While hydraulic fracturing initially increased production rates, long term post-fracture results have been disappointing. The volumetric gas-in-place for the field was estimated to be at least 100 BCF (2.83 Gm~3), whereas the total cumulative gas recovery to date is 5.1 BCF (0.14 Gm~3). During the production period prior to hydraulic fracturing, reservoir pressure declined from an initial 6,109 psi to 5,625 psi (42.1 MPa to 38.8 MPa). The well has produced water at low rates over its entire production history. Analysis of pressure build-up data showed a continued decline trend in effective reservoir permeability with time. Thus, it appears that the productivity decline is due to a decrease in effective permeability to gas and not to natural depletion. However, the exact origin of this decrease in effective permeability has been the subject of much controversy. Two competing theories regarding the decrease in permeability have been proposed: retrograde condensation and water imbibition. Based on black oil and compositional simulation studies of pre- and post-fracture production, together with hindsight analysis of hydraulic fracturing, it is concluded that retrograde condensation is more likely to be the primary cause of productivity decline.
机译：已经进行了研究以诊断新西兰塔拉纳基盆地Kaimiro气田的Kaimiro-1井生产率下降的原因。 Kaimiro-1的气体流速从1983年的5 MMSCFD（每天0.14 Mm〜3）下降到1993年的大约0.6 MMSCFD（每天0.017 Mm〜3），紧接在水力压裂之前。虽然水力压裂最初会提高生产率，但长期的压裂后结果却令人失望。据估计，该油田的现场天然气总体积至少为100 BCF（2.83 Gm〜3），而迄今为止的总累积天然气采收量为5.1 BCF（0.14 Gm〜3）。在水力压裂之前的生产期间，储层压力从最初的6,109 psi下降至5,625 psi（42.1 MPa至38.8 MPa）。该油井在其整个生产历史中均以低速生产水。对压力累积数据的分析表明，有效储层渗透率随时间持续下降。因此，似乎生产率的下降是由于对气体的有效渗透率降低而不是由于自然损耗。但是，有效渗透率下降的确切原因一直是很多争议的主题。已经提出了两种有关渗透率降低的相互竞争的理论：逆向凝结和吸水。基于黑油和压裂前后生产的成分模拟研究，以及水力压裂的事后分析，得出的结论是，逆凝结更有可能是生产力下降的主要原因。

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