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Special features of fracture network in Iranian fractured reservoirs

机译：伊朗裂缝性储层裂缝网络的特征

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摘要

U raspucanim le?i?tima nafte zbog postojanja dva razli?ita tipa porozne sredine, nazvane blokovi matriksa i pukotine, postoji vi?e vrsti pona?anja le?i?ta. Zbog kompleksnosti strukture raspucanih le?i?ta, pridobivanje nafte je rezultat kombinacija nekoliko mehanizama proizvodnje kao ?to su gravitacijsko dreniranje i apsorpcija. Kapilarne i gravitacijske sile su dvije glavne sile koje kontroliraju ove mehanizme proizvodnje. Ovaj rad je usredoto?en na utjecaj kapilarnog tlaka pukotina koji je razli?it od nule, relativnu propusnost pora koje nisu pravocrtne, pojavu reinfiltracije, visinu bloka matriksa i pona?anje aktivnih mehanizama u raspucanim le?i?tima za vrijeme prirodnog iscrpljivanja le?i?ta i injektiranja nemje?ljivog plina. Terenske studije simulacije polja napravljene su kori?tenjem simulatora ECLIPSE s formulacijom obi?ne sirove nafte i opcijom dvostruke poroznosti. Rezultati simulatora, obzirom na relativnu propusnost pora koje nisu pravocrtne, pokazuju da utjecaj tog parametra na pona?anje le?i?ta ovisi ne samo o fizi?kim svojstvima pukotina ve? i o kapilarnom tlaku praga matriksa i visini bloka matriksa.rnRezultati simulacije pokazuju da je na pridobivanje nafte utjecao, u rasponu od 1% do 2%, razmatrani kapilarni tlak praga matriksa od 0,007 bara (0,1 psi) do 0,214 bara (3,1 psi). Isto tako na pridobivanje nafte utje?e, u rasponu od 1,5% do 0,5%, razmatrana visina bloka matriksa od 4,57 m (15 f5) do 18,29 m (60 ft). Na?i rezultati simulacije sugeriraju da je za raspucana le?i?ta s malom visinom bloka ili velikim kapilarnim tlakom praga matriksa, neophodno izna?i adekvatnu, od nule razli?itu, krivulju kapilarnog tlaka pukotina. Nakon toga smo prou?ili djelovanje relativne propusnosti zakrivljenih pora na pona?anje le?i?ta. Rezultati su istaknuli ovisnost utjecaja relativne propusnosti nelinearnih pukotina na visinu bloka matriksa. Rezultati simulacije dobiveni primjenom razli?itih visina bloka matriksa pokazuju pove?anje iscrpka u rasponu od 2,3% do 5,2%, primjenom injektiranja nemje?ljivog plina. Stoga su ovi rezultati pokazali da le?i?ta s najvi?im blokom matriksa mogu biti dobri kandidati za primjenu injektiranja nemje?ljivog plina.%Due to the presence of two different types of porous media, namely matrix blocks and fractures; there are varieties of reservoir performance behaviors in fractured oil reservoirs. Because of this complex structure of fractured reservoirs, oil recovery is the result of the combination of several production mechanisms such as gravity drainage and imbibition. Two main forces controlling these production mechanisms are capillary and gravity forces.rnThis work is focused on the influence of non-zero fracture capillary pressure, non-straight line fracture relative permeability, reinfiltration phenomenon and matrix block height on the performance of active mechanisms in fractured reservoirs during natural depletion and immiscible gas injection project. The field simulation studies were performed using ECLIPSE commercial simulator with black oil formulation and dual porosity option. Simulator results considering non-zero fracture capillary pressure indicated that the influence of this parameter on reservoir performance depended not only on fracture physical properties, but also it depended on matrix threshold capillary pressure and matrix block height. Simulation results indicated that oil recovery was affected by the range from 1 % to 2% considering matrix threshold capillary pressure of 0.1 psi (0.007 bar) to 3.1 psi (0.214 bar). Also oil recovery was affected by the range from 1.5% to 0.5% considering matrix block heights of 15 ft (4.57 m) to 60 ft (18.29 m). Our simulation results suggest that for the fractured reservoirs with small block heights or with large matrix threshold capillary pressure, the appropriate non-zero fracture capillary pressure curve is necessary. Subsequently we have investigated the effect of non-straight line fracture relative permeability on reservoir performance. The results emphasized that the matrix block height depended on the influence of linear line fracture relative permeability. Simulation results acquired by applying different matrix block heights indicated the enhancement in oil recovery by immiscible gas injection in the range from 2.3% to 5.2% considering matrix block heights of 15 ft (4.57 m) to 60 ft (18.29 m). Hence, these results showed that the fractured reservoirs with the highest matrix block heights could be good candidates for implementing the immiscible gas injection operation.
机译：由于存在两种不同类型的多孔介质（称为基质块和裂缝），因此在裂缝型油藏中存在几种类型的油藏行为。由于裂缝性储层结构的复杂性，石油采收是多种生产机制（例如重力驱油和吸收）相结合的结果。毛细管力和重力是控制这些生产机制的两个主要力。本文关注的是非零毛细管裂缝毛细管压力的影响，非直线孔隙的相对渗透率，再渗透的发生，基质块的高度以及裂缝性油藏在自然枯竭过程中的活动机理。清洗和注入不混溶的气体。使用ECLIPSE仿真器对普通原油配方和双孔隙度选项进行了田间田间模拟研究。在给出非直线孔隙的相对渗透率的情况下，仿真器结果表明，该参数对储层行为的影响不仅取决于裂缝的物理性质，而且还取决于裂缝的物理性质。模拟结果表明，考虑到的基质阈值的毛细管阈值（从0.007 bar（0.1 psi）到0.214 bar）在1％至2％的范围内对油的提取产生了影响。小狗）。所考虑的基体块高4.57 m（15 f5）至18.29 m（60 ft）也影响了采油率（1.5％至0.5％）。我们的模拟结果表明，对于裂块高度低或基质阈值毛细管压力高的裂缝性储层，有必要找到适当的，非零的毛细管裂缝压力曲线。然后，我们研究了弯曲孔隙的相对渗透率对储层行为的影响。结果突出了非线性裂纹的相对渗透率对矩阵块高度的影响。通过应用不同高度的基质块获得的模拟结果显示，通过应用不混溶气体注入，采收率提高了2.3％至5.2％。因此，这些结果表明，具有最高基质区块的储层可能是不混溶气注入应用的良好候选者。％由于存在两种不同类型的多孔介质，即基质区块和裂缝；裂缝性油藏中有多种储层性能行为。由于裂缝性储层的这种复杂结构，石油采收是多种生产机制（例如重力排水和吸收）结合的结果。控制这些生产机制的两个主要力是毛细管力和重力。这项工作的重点是非零裂缝毛细管压力，非直线裂缝相对渗透率，再渗透现象和基质块高度对裂缝活动机理的影响。自然消耗和不混溶气注入工程期间的储层。现场模拟研究是使用带有黑油配方和双重孔隙度选项的ECLIPSE商业模拟器进行的。考虑非零裂缝毛细管压力的模拟结果表明，该参数对储层性能的影响不仅取决于裂缝的物理性质，而且还取决于基质阈值毛细管压力和基质块高度。模拟结果表明，考虑到基质阈值毛细管压力为0.1 psi（0.007 bar）至3.1 psi（0.214 bar），采油率受1％至2％范围的影响。考虑到15英尺（4.57 m）至60英尺（18.29 m）的基体块高，采油率也受1.5％至0.5％的范围影响。我们的模拟结果表明，对于块高较小或基质毛细极限阈值较大的裂缝性储层，适当的非零裂缝毛细管压力曲线是必要的。随后，我们研究了非直线裂缝相对渗透率对储层性能的影响。结果强调，基体块高取决于线性裂缝相对渗透率的影响。通过应用不同的基质块高度获得的模拟结果表明，考虑到15英尺（4.57 m）到60英尺（18.29 m）的基质块高度，通过不混溶气体注入提高的采油率在2.3％至5.2％的范围内。因此，这些结果表明，具有最高基质块高度的裂缝性储层可能是实施不混溶气体注入作业的良好候选者。

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