| Citation: | Xiucheng Tan, Hong Liu, Ling Li, Bing Luo, Xiaoguang Liu, Xiaohui Mou, Yong Nie, Wenyan Xi. Primary Intergranular Pores in Oolitic Shoal Reservoir of Lower Triassic Feixianguan Formation, Sichuan Basin, Southwest China: Fundamental for Reservoir Formation and Retention Diagenesis. Journal of Earth Science, 2011, 22(1): 101-114. doi: 10.1007/s12583-011-0160-2
|
Marine carbonates are key targets of petroleum exploration all over the world, where the reserve and reservoir production have reached around 50% and > 50% of the total, respectively (Ma, 2006). In China, the success of carbonate exploration shows promising prospects during recent years (especially in the Sichuan and Tarim basins; Li, 2007; Ma, 2006). However, in either China or other countries, carbonate exploration is difficult due to reservoir characterization (Hao et al., 2009; Liu et al., 2008; Luo et al., 2008; Tan et al, 2008; Wang G Z et al., 2008; Xu et al., 2008; Wang Y G et al., 2007; Heydari, 2000). This is because the carbonates are very sensitive to diagenesis, leading to the primary reservoir pores likely being altered during long geological evolution (Huang et al., 2009). As a consequence, the type and origin of the pores are hard to determine (Ma, 2006). Previous studies have suggested six main origins in general, including preservation of intergranular pores (Ehrenberg et al., 2007; Ehrenberg, 2004; Honda et al., 1989; Scholle and Halley, 1985; Moore and Druckman, 1981; Vinopal and Coogan, 1978), dolomitization (Moore, 2001; Sun, 1995), syngenetic dissolution (Luo et al., 2009; Dickson and Saller, 2006; Wang and Al-Aasm 2002; Saller et al., 1999), burial dissolution (Ma, 2007; Ma et al., 2007; Zeng et al., 2006), surface dissolution (Chen et al., 2007; Kang, 2005; Lu et al., 2003; Wang et al., 2002; Tinker et al., 1995; Honda et al., 1989; Kerans, 1988; Vinopal and Coogan, 1978) and structural fracturing (Ma, 2007; Ma et al., 2007; Zeng et al., 2006; Kang, 2005; Lu et al., 2003).
The oolitic shoal reservoir of the Lower Triassic Feixianguan Formation in the Sichuan basin (Southwest China) has a big success in hydrocarbon (especially gas) exploration recently (Li, 2007), as some giant, large and middle gas fields have been discovered (e.g., the Luojiazhai, Dukouhe, Tieshanpo, Puguang and Longgang fields; Hao et al., 2009; Ma et al., 2008; Zou et al., 2008; Li, 2007; Ma, 2006). Hence, the issue of reservoir origin receives large research attention during recent years for shaping future petroleum exploration strategies and thereby gaining bigger exploration successes (Luo et al., 2008; Yang et al., 2006). It is widely accepted that the reservoir is developed on the basis of the primary intergranular pores, and then subject to multiple geological processes (Yang et al., 2006), including dolomitization (Zheng et al., 2008; Huang et al., 2006), syngenetic dissolution (Luo et al., 2009), and burial dissolution (Ma, 2007; Ma et al., 2007; Wang Y G et al., 2007). In general, for the formation of high-quality reservoirs, burial dissolution and dolomitization are believed to be the main forces on the basis of primary pores (Ma, 2007; Zeng et al., 2006). However, the primary intergranular pores, though believed to be fundamental for the reservoir formation, have not been well investigated in comparison with burial dissolution and dolomitization. Thus, in order to more precisely characterize the reservoir origin, we lay a research emphasis on the intergranular pores in this article, and address the contribution of burial dissolution and dolomitization to the reservoir formation.
The Sichuan basin is located in Southwest China, with an area of approximately 18×104 km2 (Zhao et al., 2007; Tong, 1992) (Fig. 1a). In tectonics, it is a large cratonic basin, containing up to 6–12 km of Sinian to Quaternary sediments. The basement of the basin, usually termed as the Yangtze paraplatform, is a united craton, which was formed during the Jinning (850 Ma) and Chengjiang (700 Ma) orogenies and then crystallized and metamorphosed before the Late Sinian (Wei et al., 2004).
Figure 1b presents the simplified depositional evolution during the Early Triassic Feixianguan period. The southwestern basin is deposited under alluvial fan to fluvial facies, with terrigenous clastic supply from the far western Kang-Dian paleo-continent and Longmenshan Mountain chain island arc (Wei et al., 2004). To the northeast, the sedimentary setting transits to the mixed transitional deposition of carbonates and clastic rocks gradually. As to the carbonates, they occur mainly in the middle-east and north of the basin (Chen et al., 2007; Wei et al., 2004). Of the carbonates, the oolitic shoal rock is one important type, and is good gas reservoirs (Wang Y G et al., 2008, 2007; Ma et al., 2005; Wei et al., 2004). As shown in Fig. 1b, gas has been discovered in many oolitic shoal rock developing areas. Figure 1. (a) Location of the Sichuan basin in China; (b) simplified depositional evolution during the Early Triassic Feixianguan period, Sichuan basin. Outcrop section and wells studied in the article are shown.
It has been widely suggested that burial dissolution is critical to the Feixianguan reservoir formation, especially in the case of the Puguang gas field (e.g., Ma, 2007; Ma et al., 2007; Wang et al., 2007). However, in an overall view of the entire Sichuan basin, burial dissolution may not be the fundamental force of the reservoir formation; this can be constrained from four types of evidence as demonstrated below.
According to simulation experiments on the solution of carbonate rocks, among the solution solvent including organic acid, CO2 and H2S, H2S-seawater has a relatively strong solution ability, and the micrite and oolitic limestones are primarily favorable for the solution, followed by micrite dolostone, while oolitic dolostone is the most difficult to be dissolved (Zhang et al., 2008). Thus, if burial dissolution is the fundamental force for reservoir formation, the oolitic dolostone should have the least possibility to be the reservoir rock type. However, hydrocarbons are currently discovered mainly in the oolitic dolostone reservoirs (Li, 2007; Ma, 2007; Ma et al., 2007). Thus, burial dissolution may not be the fundamental factor controlling the reservoir development.
As to burial dissolution, the pathway for solution fluid to migrate is necessary, which generally includes reservoir space, fault, cleavage, fracture and unconformity (Mazzullo and Harris, 1992). If there is little primary pore space present, burial dissolution will take place mainly along fault and fracture systems, forming the vug-fracture type reservoir (Lønøy, 2006; Heydari, 2000). For example, in the Linfengchang structure of South Sichuan, wells Lin 12 and Tan 7 have few intergranular pores in the limestones of the first member of the Feixianguan Formation (termed as Fei-1) due to early cementation. Thus, there is little lateral pore-type pathway for the burial fluid to migrate. As a consequence, the dissolution proceeds mainly along fractures formed by later structural processes, leading to the vug-fracture type reservoir (Figs. 2a, 2b). Another case is the oolitic dolostone of well Du 3 in East Sichuan. The primary intergranular pores almost disappear due to early cementation prior to burial diagenesis. As a consequence, the dissolution only takes place along fractures and stylolites (Fig. 2c). Thus, under such conditions, for either limestone or dolostone reservoirs, the burial solution fluid cannot easily migrate laterally and thus cannot form a pore or pore-fracture type reservoir, which, however, is the main successful target in the present practical exploration of the Feixianguan Formation (Li, 2007; Ma et al., 2007). Hence, burial dissolution is not the fundamental force for high-quality reservoir development.
As shown in Fig. 2 and the above discussion, burial dissolution can obviously improve the reservoir quality. Nevertheless, the improvement is limited in general. For example, in the Fei-1 reservoir of Zhongliangshan Section, the reservoir space mainly includes two types, i.e., isolated and solution-enlarged intergranular pores (Fig. 3a). The isolated intergranular pores are in dominance, characterized by straight crystal face of shallow burial granular cement (Fig. 3a). This is a representative feature of pores with little influence of burial dissolution (Qiang, 1998). The bulk reservoir porosity improved by solution is less than 10%. This is also observed in the oolitic dolostone reservoir of East Sichuan (Fig. 3b).
Altered bitumen with asphalt mainly in component is commonly regarded as an indication of burial dissolution in the shoal reservoir of the Sichuan basin (Wang et al., 2007; Zhu et al., 2007). As shown in Fig. 3c, the crystal face of the dolomite is generally straight before hydrocarbon charge, suggesting a weak dissolution and reservoir porosity improvement. Later, the pores are dissolved along with hydrocarbon charge, evidenced by the presence of bitumen. However, the porosity improvement is limited, commonly less than 10% of the bulk porosity.
As discussed above, burial dissolution may improve the reservoir porosity to a certain degree. Nevertheless, this improvement will be nearly eliminated due to mass balance during the dissolution.
The dissolution of carbonate rocks, commonly by H2S and CO2, often occurs in the following ways (Qiang, 1998)
|
|
The reactions will proceed to the right direction when the fluid system receives excessive H2S or CO2. As a result, the carbonate rocks will be dissolved, and the solution products will migrate under motivation of multiple geological processes, including ion communication, subsurface thermal fluid convection, and fluid activity due to pressure. During these processes, the concentration of H2S and CO2 decreases, leading to the reaction proceeding to the left direction. Thus, the carbonate rocks that have been dissolved will re-crystallize. As a result, when some pores are enlarged due to dissolution, some other pores will be occluded due to fluid and matter migration. Hence, during this process, the bulk reservoir porosity can be changed, while it may not be really improved (Zhang et al., 2008). This is the so-called mass balance during burial dissolution.
In the Sichuan basin, the Feixianguan reservoir is generally overpressured and faults do not cut up to the surface (Li, 2007; Ma et al., 2007). As a result, the environment where the burial dissolution takes place most likely belongs to a closed system, under which there may be a balance between dissolution and cementation. For example, in well Du 3 of the Huanglongchang structure in Northeast Sichuan, although some pores are dissolved, the solution products migrate and cement later, forming a cement zone (Fig. 4). Thus, in an overall sense, the burial dissolution may not really improve the reservoir quality due to the mass balance during the dissolution.
The Feixianguan dolomitization has been studied widely, whose origin may include seepage-reflux, mixed water and burial (e.g., Zhang and Hu, 2008; Zeng et al., 2007; Zhao et al., 2006; Su et al., 2004).
In deed, according to the occurrence of the dolomite, it can be implied that the dolomitization is related to evaporated seawater as the dolomites are present mainly in the platform margin areas enriched in gypsum rocks and residual gypsum nodules are observed in the oolitic dolomite reservoirs (Wang et al., 2007). In contrast, the middle and west parts of the basin have limited dolomitization. This may be related to the decrease of seawater salinity by supply of far western river fresh water. However, the reason for the limited dolomitization in the east of the basin is different, which has been ascribed to relatively weak effect of seawater evaporation and concentration (Wang et al., 2007; Zeng et al., 2007). In summary, the dolomitization is most likely of seepage-reflux origin.
During the dolomitization, one calcite molecule transits to one dolomite molecule, leading to a ca. 15% increase of pore space in theory (Qiang, 1998). However, according to the comprehensive macroand micro-observation of Wang et al. (2007) in the Sichuan basin, the dolomitization has little impact on the reservoir formation because the pore space volume does not change.
Based on the above discussion, it can be indicated that the burial dissolution and dolomitization may not be the fundamental reservoir origin. Thus, there must be a new mechanism. It is most likely the preservation of intergranular pores and the diagenesis is called the retention diagenesis. This can be indicated from five types of evidence below, with analogies to other typical cases reported previously (e.g., Moore and Druckman, 1981).
The physical property of the Feixianguan shoal reservoir is closely related to facies and rock types. For example, in East Sichuan, the rocks with high porosity are mainly oolitic dolostone and fine crystalline oolitic dolostone, while the other rocks have low porosities (Fig. 5). This suggests that the development of the reservoir space is related to the oolitic shoals. Furthermore, the reservoir porosity varies in different micro-facies. In the platform marginal shoal of the second member of the Feixianguan Formation (termed as Fei-2), or Puguang area, the reservoir development has a positive correlation with cumulative depth of the oolitic shoal (Fig. 6). The reservoir property of the shoal core microfacies is better than that of the shoal margin microfacies (Fig. 6), suggesting a typically facies-controlled feature (Moore and Druckman, 1981).
The development of the reservoir intergranular pores is related to the shoal-body thickness in different facies. For the oolitic shoal inside the platform, the thickness of 3 m may be a threshold standard. When the thickness in one shoal cycle is lower than 3 m, oolites are most likely pointto float-contacted, and thus most intergranular pores will disappear because of early cementation (Fig. 7a). In contrast, when the thickness is greater than 3 m, the intergranular pores occur widely in the oolitic dolostones and limestones. In the platform-margin area, the thickness of one shoal cycle is commonly greater than 3 m, hence both the individual and cumulative thickness of the oolitic shoal are big. As a result, the intergranular pores occur widely. Under such conditions, if the reservoir is hardly or slightly influenced by the burial dissolution, it will form a thick shoal reservoir consisting mainly of the primary intergranular pores (Figs. 7b, 7c). These features indicate that the reservoir is faciescontrolled.
In summary, due to the reservoir being faciescontrolled, the development of the primary pores in relatively high-energy facies is fundamental for the reservoir formation (cf. Moore and Druckman, 1981).
For the oolitic shoal reservoir, either inside or outside of the platform, the intergranular pores are developed when the thickness of the individual shoal body is greater than 3 m, and thereby form a reservoir composed mainly of the intergranular pores. In certain cases, later burial dissolution can improve reservoir physical property to certain degrees, and many intergranular pores will be enlarged and even change into different shapes. However, in places with weak influence of burial dissolution, there still exist large quantities of residual intergranular or solution-enlarged residual intergranular pores. For example, in the Fei-1 oolitic limestone of Zhongliangshan Section, the intergranular pores preserve and develop into an oolitic carbonate reservoir due to submarine and shallow burial cementation (Fig. 3a). Similar features were observed in the oolitic dolostone reservoir of well Du 3, where the residual intergranular and solutionenlarged residual intergranular pores are present (Fig. 3b).
Thus, if burial dissolution is the fundamental force for reservoir formation, the reservoir space should be dominated by non-selective solution pores and vugs (Yang et al., 2006). However, this has not been observed (Fig. 3), further supporting that burial dissolution may not be the fundamental factor for the high-quality reservoir development.
According to Moore and Druckman (1981), the shoal reservoir with the origin of the preservation of primary pores has an important feature, i.e., the grains are mainly pointto line-, and even to concave-convex contacted. This was observed in the Sichuan basin. As shown in Fig. 3, early compaction results in a framework-supported structure, and further results in an anti-compaction effect. This is indicative of syngenetic compaction prior to the grain solidification, and is hence favorable for the preservation of the intergranular pores. Zhongliangshan Section is a typical example. The early submarine fibrous cement is present in grain contact zones (Fig. 3a). The grains are pointto line-contacted due to the early compaction, while later shallow burial granular cement only partially fills the intergranular pores with little occurrence in the grain contact zones (Fig. 3a). These are all good for the preservation and development of the intergranular pores.
The presence of shallow burial and chemical precipitation in the intergranular pores is an important feature of the shoal reservoir consisting mainly of primary pores (Yang et al., 2006). This is typical in the Feixianguan oolitic shoal reservoir. For example, in Zhongliangshan Section, content of the submarine fibrous cement is 5%–10%. The formation hydrostatic pressure makes oolites grain-supported under the effect of fast overlying sedimentation. As a result, pore fluid is not active in communicating, further leading to the development of shallow burial cement only in walls of intergranular grains. The cements fill 15%– 30% of the residual pores, and isolate the pores. Consequently, the pore fluid stops communicating and residual intergranular pores are thus formed (Fig. 3a). In contrast, if thickness of the individual shoal body is thin (commonly < 3 m), the overlying sedimentation will be slow after the submarine cementation. Hence, the early compaction will not make oolites framework-supported. The pores are connected and the fluid is active in communicating, leading to the shallow burial cements almost fully filling the intergranular pores. This is evidenced by granular cements of shallow burial origin, which are commonly observed between grains (Fig. 7c). The feature is also observed in the oolitic dolostone, as the intergranular pores nearly disappear due to early cementation, while being preserved due to lack of early cementation (Figs. 3b, 3c).
The undissolved reservoir cement is the ultimate evidence that the reservoir is not of burial dissolution origin (Qiang, 1998). In the Sichuan basin, some intergranular pores are preserved with little dissolution. Under such conditions, the shallow burial granular calcite cement has good crystal shape and straight crystal face, and with few influencing records of the burial digenetic fluid (Figs. 3a, 3b). Moreover, even though some pores are influenced by burial dissolution, this process may have relatively small contribution to the reservoir space as discussed in above section (Fig. 3a).
From the above analyses, it can be indicated that the shoal reservoir of the Lower Triassic Feixianguan Formation in the Sichuan basin, especially for the reservoir in the platform margin, is developed on the basis of the intergranular pores, and burial dissolution and dolomitization have not significantly improved the reservoir quality as suggested by previous studies. The reservoir forming evolution and model is proposed below.
The depositional environment decides the development of the primary pore space (Wilson, 1975). In a low-energy environment, although lime-mud sediment commonly has high primary porosity, it will decrease largely and rapidly due to diagenesis. In contrast, in a high-energy environment, sediment has a low content of matrix, and thus also has high primary porosity. In such an environment, grainstones occur widely, and framework-supported texture is easy to be formed due to early compaction. As a consequence, some of the primary pores preserve during diagenesis. However, not all oolitic rocks can form a reservoir finally (Fig. 8). This is called the initial reservoir differentiation.
The environment favorable for reservoir formation is most likely related to the topographic highs above the wave base (Fig. 9) (Qiang, 1998). In such places, reef and bank bodies occur widely due to high-energy fluid activity. Otherwise, the depositional rate here is higher than in other places. Hence, the topographic high structure is inherited, leading to big individual and cumulative thickness of the shoal body, and a high primary porosity up to 40% (Qiang, 1998). Furthermore, different microfacies of the shoal vary in depositional rate, with the fastest in the shoal core and slowest in the shoal margin. Thus, the shoal core has a thicker shoal body than the shoal margin, and thereby has higher porosity (Fig. 9). This is also an initial reservoir differentiation.
After deposition, grainstones are present in a submarine diagenetic environment, under which the fibrous grain-coating cementation takes place commonly. This will make a 5%–10% decrease of the primary porosity in general. Variation of depositional rate of different shoal bodies results in different compaction effect, which further decides the development of shallow burial early cement (Qiang, 1998).
In the Feixianguan reservoir, a large quantity of the oolitic limestones has little primary intergranular pores due to the submarine cementation, while some grainstones are developed with the residual intergranular pores. This differentiation is caused by different early compaction and shallow burial cementation in shoal bodies. For the oolitic shoal with individual body less than 3 m, a weak compaction leads to the development of big pores and throats, which are favorable for the diagenetic fluid to migrate. As a result, the cementation is easy and the intergranular pores disappear. In contrast, as to the oolitic shoal with the individual body greater than 3 m, diagenetic feature varies in different microfacies. In the shoal margin and top of the shoal core, the diagenetic feature is similar to that of the shoal with the individual body less than 3 m, due to thin thickness of the shoal body and interbed with fine-grained carbonate rocks. In the bottom of the shoal core, grains are mainly lineto concave-convex contacted due to the early compaction. Hence, the pores and throats are slim, and still can receive compaction fluid when contacted with fine-grained sediments. Consequently, only a few primary intergranular pores can preserve. In the main body of the shoal core, the early compaction results in the development of slim pores and throats. Thus, diagenetic fluid cannot easily activate and the cementation most likely ceases, combined with the sequences having less chance to contact with finegrained sediments than the bottom of the shoal core (Tan et al., 2007). Otherwise, the fluid supersaturated to carbonate rocks decreases in cementing ability along the migration from the shoal margin to core area. As a result, the diagenetic lenses are formed in the shoal margin area. These all lead to a small number of cements occurring in the intergranular pores, and the cements are characterized by granular shape of shallow burial origin.
After the diagenetic stage discussed above, the reservoir is generally differentiated, with the reservoir space dominated by isolated residual intergranular pores. The best porosity commonly occurs in the middle of the shoal core, reaching between 5% and 15%.
As discussed above, the shoal reservoir is lenticular distributed after the shallow burial, with different shoal parts varying in cements and pore spaces. The oolitic rocks with little development of the primary pore space will be dissolved and fractured only in a fault-related conduit, forming the pore-vugfracture type reservoir (Fig. 2a). In contrast, for the oolitic shoal with developed primary pore space, the pores will be dissolved primarily by the first stage petroleum fluid of acidic origin. Then, the second stage H2S-bearing fluid charges the reservoir and further alters the pores. In the parts with severe solution, the primary pores will even be fully changed in shape, and seem to be pure solution pores and vugs. This may be the reason why the reservoir is ascribed to dissolution origin by many current studies. In this stage, the porosity improvement can exceed up to 10% (Fig. 8b). However, this improvement is generally eliminated by mass balance as discussed in above section (Fig. 4). Because of this effect, the net porosity improvement is often lower than 3%. Therefore, burial dissolution has little big contribution to the reservoir porosity improvement as suggested by many previous works. The solution alters and adjusts the primary reservoir pore space, whereas it cannot change reservoir distribution in essence. Thus, it is not the fundamental reservoir origin.
When the reservoir receives the last stage gaseous hydrocarbons, there is little activating fluid (Hao et al., 2009). Thus, fluid migration and mass exchange almost cease, and the reservoir diagenetic alteration is weak, leading to reservoir formation finally.
(1) For the Lower Triassic Feixianguan Formation oolitic shoal reservoir in the Sichuan basin, the burial dissolution and dolomitization are widely believed to have an important impact on reservoir formation. In this study, mainly based on four types of evidence including type of reservoir rock and space, contribution of the dissolution to reservoir quality, and mass balance during dissolution, the dissolution is suggested not to be the fundamental factor controlling reservoir development. It alters and adjusts the reservoir, but does not change reservoir distribution and not really improve the reservoir quality in general. With respect to the dolomitization, it is most likely of seepage-reflux origin and does not change the pore volume.
(2) Five basic reservoir features indicate that the primary intergranular pores are fundamental for reservoir formation and the diagenesis is called retention diagenesis. They include the following: the reservoir is facies-controlled, reservoir space consists mainly of residual intergranular or solution-enlarged residual intergranular pores, grains are contacted mainly in lineto concave-convex styles, only submarine cement is present in grain contact zone, and some cements are not dissolved.
(3) The reservoir formation is complex and includes multiple stages. Depositional environment is the basis of reservoir initial formation, while early compaction and shallow burial cementation is the key to reservoir formation. Then, multi-stage burial dissolution alters and adjusts the reservoir. As the last stage gaseous hydrocarbons have little diagenetic effect, the reservoir is formed finally.
(4) During the long reservoir diagenesis, the primary intergranular pores will likely experience multistage structural fracturing and burial dissolution to certain degrees. Thus, the reservoir geological and geochemical features have a complex and superimposed origin. In many cases, the geological and especially geochemical features reflecting burial dissolution and/or dolomitization are so remarkable that they even cover up the features of the other geological processes. This may be why many researchers believe that the reservoir origin is of burial dissolution and/or dolomitization. In this study, through a relatively comprehensive discussion, a possible new fundamental mechanism for reservoir formation is suggested. However, in the Sichuan basin, there must be a heterogeneous effect. For example, especially in the northeast (e.g., the famous Puguang gas field) and south Sichuan basin, burial and syngenetic dissolution are of significance to reservoir formation, respectively. Thus, in order to provide precise data for shaping petroleum exploration strategies, the impact of different geological processes on reservoir evolution and formation should be investigated more comprehensively and deeply in the future.
ACKNOWLEDGMENTS: We thank PetroChina Youth Innovation Foundation (No. 06E1018), and Key Subject Construction Project of Sichuan Province (No. SZD 0414) for financial support. Two anonymous reviewers and editors are thanked for constructive reviews.| Chen, J. S., Li, Z., Wang, Z. Y., et al., 2007. Paleokarstification and Reservoir Distribution of Ordovician Carbonates in Tarim Basin. Acta Sedimentologica Sinica, 25(6): 858–868 (in Chinese with English Abstract) |
| Dickson, J. A. D., Saller, A. H., 2006. Carbon Isotope Excursions and Crinoid Dissolution at Exposure Surfaces in Carbonates, West Texas, U.S.A. . Journal of Sedimentary Research, 76(3–4): 404–410 |
| Ehrenberg, S. N., 2004. Factors Controlling Porosity in Upper Carboniferous-Lower Permian Carbonate Strata of the Barents Sea. AAPG Bulletin, 88(12): 1653–1676 doi: 10.1306/07190403124 |
| Ehrenberg, S. N., Nadeau, P. H., Aqrawi, A. A. M., 2007. A Comparison of Khuff and Arab Reservoir Potential throughout the Middle East. AAPG Bulletin, 91(3): 275–286 doi: 10.1306/09140606054 |
| Hao, F., Guo, T. L., Du, C. G., et al., 2009. Accumulation Mechanisms and Evolution History of the Giant Puguang Gas Field, Sichuan Basin, China. Acta Geologica Sinica, 83(1): 136–145 doi: 10.1111/j.1755-6724.2009.00016.x |
| Heydari, E., 2000. Porosity Loss, Fluid Flow, and Mass Transfer in Limestone Reservoirs: Application to the Upper Jurassic Smackover Formation, Mississippi. AAPG Bulletin, 84(1): 100–118 |
| Honda, N., Odata, Y., Abouelenein, M. K. M., et al., 1989. Petrology and Diagenetic Effects of Carbonate Rocks: Jurassic Arab C Oil Reservoir in EI Bunduq Field, Offshore Abu Dhabi and Qatar. Middle East Oil Show, 787–796 |
| Huang, S. J., Qing, H. R., Pei, C. R., et al., 2006. Strontium Concentration, Isotope Composition and Dolomitization Fluids in the Feixianguan Formation of Triassic, Eastern Sichuan of China. Acta Petrologica Sinica, 22(8): 2123–2132 (in Chinese with English Abstract) |
| Huang, S. J., Zhang, X. H., Liu, L. H., et al., 2009. Progress of Research on Carbonate Diagenesis. Earth Science Frontiers, 16(5): 219–231 (in Chinese with English Abstract) |
| Kang, Y. Z., 2005. Palaeokarst of Cambro-Ordovician and Oil-Gas Distribution in Tarim Basin. Xinjiang Petroleum Geology, 26(5): 472–480 (in Chinese with English Abstract) |
| Kerans, C., 1988. Karst-Controlled Reservoir Heteorgeneity in Ellenburger Group Carbonates of West Texas. AAPG Bulletin, 72: 1160–1183 |
| Li, L. G., 2007. Standing on the Jumping-Off Point, Looking forward to a New Success: Written by the Time 10 Million Tons-Level Sichuan Oil and Gas Field was Built up. Natural Gas Industry, 27(1): 1–4 (in Chinese with English Abstract) |
| Liu, S. G., Wang, H., Sun, W., et al., 2008. Energy Field Adjustment and Hydrocarbon Phase Evolution in Sinian-Lower Paleozoic, Sichuan Basin. Journal of China University of Geosciences, 19(6): 700–706 |
| Lønøy, A., 2006. Making Sense of Carbonate Pore Systems. AAPG Bulletin, 90: 1381–1405 doi: 10.1306/03130605104 |
| Lu, X. B., Gao, B. Y., Chen, S. M., 2003. Study on Characteristics of Paleokarst Reservoir in Lower Ordovician Carbonate of Tahe Oil Field. Journal of Mineralogy and Petrology, 23(1): 87–92 (in Chinese with English Abstract) |
| Luo, B., Tan, X. C., Liu, H., et al., 2009. Genetic Mechanism Analysis on Oolitic Reservoir of Lower Triassic Feixianguan Formation in the Shunan Area, Sichuan Basin. Acta Sedimentologica Sinica, 27(3): 404–409 (in Chinese with English Abstract) |
| Luo, P., Zhang, J., Liu, W., et al., 2008. Characteristics of Marine Carbonate Hydrocarbon Reservoirs in China. Earth Science Frontiers, 15(1): 36–50 (in Chinese with English Abstract) |
| Ma, Y. S., 2006. Case of Discovery and Exploration of Marine Fields in Chinac (Part 6): Puguang Gas Field, Sichuan Basin. Marine Origin Petroleum Geology, 11(2): 35–40 (in Chinese with English Abstract) |
| Ma, Y. S., 2007. Generation Mechanism of Puguang Gas Field in Sichuan Basin. Acta Petrolei Sinica, 28(2): 9–14 (in Chinese with English Abstract) |
| Ma, Y. S., Fu, Q., Guo, T. L., et al., 2005. Pool Forming Pattern and Process of the Upper Permian-Lower Triassic, the Puguang Gas Field, Northeast Sichuan Basin, China. Petroleum Geology & Experiment, 27(5): 455–461 (in Chinese with English Abstract) |
| Ma, Y. S., Guo, X. S., Guo, T. L., et al., 2007. The Puguang Gas Field: New Giant Discovery in the Mature Sichuan Basin, Southwest China. AAPG Bulletin, 91: 627–643 doi: 10.1306/11030606062 |
| Ma, Y. S., Mou, C. L., Tan, Q. Y., et al., 2008. Permian/Triassic Boundary and Its Correlation in the Daxian-Xuanhan Area, Northeastern Sichuan Province, China. Acta Geologica Sinica, 82(1): 56–62 |
| Mazzullo, S. J., Harris, P. M., 1992. Mesogenetic Dissolution: Its Role in Porosity Development in Carbonate Reservoirs. AAPG Bulletin, 76: 607–620 |
| Moore, C. H., 2001. Carbonate Reservoirs: Porosity Evolution and Diagenesis in a Sequence Stratigraphic Framework. Developments in Sedimentology. Elsevier, Amsterdam. 460 |
| Moore, C. H., Druckman, Y., 1981. Burial Diagenesis and Porosity Evolution, Upper Jurassic Smackover, Arkansas and Louisiana. AAPG Bulletin, 65: 597–628 |
| Qiang, Z. T., 1998. Carbonate Rock Reservoir Geology. Petroleum University Press, Beijing. 243–245 (in Chinese) |
| Saller, A. H., Dickson, J. A. D., Matsuda, F., 1999. Evolution and Distribution of Porosity Associated with Subaerial Exposure in Upper Paleozoic Platform Limestones. AAPG Bulletin, 83(11): 1835–1854 |
| Scholle, P. A., Halley, R. B., 1985. Burial Diagenesis: Out of Sight, out of Mind!SEPM, 36: 309–334 |
| Su, L. P., Luo, P., Hu, S. R., et al., 2004. Diagenesis of Oolitic Bank of the Feixianguan Formation of Lower Triassic in Luojiazhai Gas Field, Northeastern Sichuan Province. Journal of Palaeogeography, 6(2): 182–190 (in Chinese with English Abstract) |
| Sun, S. Q., 1995. Dolomite Reservoirs: Porosity Evolution and Reservoir Characteristics. AAPG Bulletin, 79(2): 186–204 |
| Tan, X. C., Li, L., Cao, J., et al., 2007. Mechanism and Models for the Lower Tertiary Detrital Reservoir Evolution, Eastern Kuqa Depression of the Tarim Basin. Earth Science—Journal of China University of Geosciences, 32: 99–104 (in Chinese with English Abstract) |
| Tan, X. C., Zou, J., Li, L., et al., 2008. Research on Sedimentary Microfacies of the Epicontinental Sea Platform of Jia 2 Member in Moxi Gas Field. Acta Petrolei Sinica, 29(2): 219–225 (in Chinese with English Abstract) |
| Tinker, S. W., Ehrets, J. R., Brondos, M. D., 1995. Mutiple Karst Events Related to Stratigraphic Cyclity, San Andres Formation, Yates Field, West Taxas. In: Budd, D. A., Saller, A. H., Harris, P. M., eds., Unconformities and Porosity in Carbonate Strata. AAPG Bulletin, 63: 77–102 |
| Tong, C. G., 1992. Structral Evolution and Hydrocarbon Accumulation in Sichuan Basin. Geological Publishing House, Beijing. 19–37 (in Chinese) |
| Vinopal, R. J., Coogan, A. H., 1978. Effect of Particle Shape on the Packing of Carbonate Sands and Gravels. Journal of Sedimentary Research, 48(1): 7–24 |
| Wang, B. Q., Al-Aasm, I. S., 2002. Karst-Controlled Diagenesis and Reservoir Development: Example from the Ordovician Main-Reservoir Carbonate Rocks on the Eastern Margin of the Ordos Basin, China. AAPG Bulletin, 86: 1639–1658 |
| Wang, G. Z., Liu, S. G., Su, W. C., et al., 2008. Water Soluble Gas in Deep Carbonate Reservoir, Sichuan Basin, Southwest China. Journal of China University of Geosciences, 19(6): 636–644 |
| Wang, Y. G., Hong, H. T., Xia, M. L., et al., 2008. Exploration of Reef-Bank Gas Reservoirs Surrounding Permian and Triassic Troughs in Sichuan Basin. Natural Gas Industry, 28(1): 22–27 (in Chinese with English Abstract) |
| Wang, Y. G., Wen, Y. C., Hong, H. T., et al., 2007. Diagenesis of Triassic Feixianguan Formation in Sichuan Basin, Southwest China. Acta Sedimentologica Sinica, 25(6): 831–839 (in Chinese with English Abstract) |
| Wang, Z. Y., Li, Y. P., Chen, J. S., et al., 2002. Characters of Atmospheric Diagenetic Lens along Middle-Late Ordovician Carbonate Shelf Margin in Central Tarim Area. Scientia Geologica Sinica, 37(S1): 152–160 (in Chinese with English Abstract) |
| Wei, G. Q., Chen, G. S., Yang, W., et al., 2004. Sedimentary System of Platformal Trough of Feixianguan Formation of Lower Triassic in Northern Sichuan Basin and Its Evolution. Acta Sedimentologica Sinica, 22(2): 254–260 (in Chinese with English Abstract) |
| Wilson, J. L., 1975. Carbonate Facies in Geologic History. Springer-Verlag, New York. 471 |
| Xu, G. S., Mao, M., Yuan, H. F., et al., 2008. Hydrocarbon Accumulation Mechanism of Sinian Reservoir in Anpingdian-Gaoshiti Structure, Middle Sichuan Basin. Journal of China University of Geosciences, 19(6): 685–699 |
| Yang, X. P., Zhao, W. Z., Cao, H., et al., 2006. Formation and Distribution of Triassic Feixianguan Oolitic Bank Favorable Reservoir in the NE Sichuan Basin. Petroleum Exploration and Development, 33(1): 17–21 (in Chinese with English Abstract) |
| Zeng, W., Huang, X. P., Yang, Y., et al., 2006. Burial Dissolution of Feixianguan Formation Reservoirs in Northeast Sichuan Basin. Natural Gas Industry, 26(11): 4–6 (in Chinese with English Abstract) |
| Zeng, W., Huang, X. P., Yang, Y., et al., 2007. The Origin and Distribution of Dolostone in Feixianguan Formation in Lower Triassic Series, Northeast Sichuan. Journal of Southwest Petroleum University, 29(1): 19–22 (in Chinese with English Abstract) |
| Zhang, B. Q., Hu, M. Y., 2008. Diagenesis and Porosity Evolution Characteristics of Lower Triassic Feixianguan Formation in the Eastern Sichuan and Western Hubei. Journal of Oil and Gas Technology, 30(6): 9–14 (in Chinese with English Abstract) |
| Zhang, J. Y., Liu, W. H., Fan, M., et al., 2008. Whether TSR Products can Meliorate Reservoir Property of Carbonate Rock or not: An Evidence from Experimental Geology. Marine Origin Petroleum Geology, 13(2): 57–61 (in Chinese with English Abstract) |
| Zhao, W. Z., Wang, Z. C., Wang, Y. G., 2006. Formation Mechanism of Highly Effective Gas Pools in the Feixianguan Formation in the NE Sichuan Basin. Geological Review, 52(5): 708–717 (in Chinese with English Abstract) |
| Zhao, Z. J., Fan, G. Z., Wu, X. Y., et al., 2007. Reservoir Types, Exploration Domains and Exploration Strategy of Marine Carbonates in China. Marine Origin Petroleum Geology, 12(1): 1–11 (in Chinese with English Abstract) |
| Zheng, R. C., Gen, W., Zheng, C., et al., 2008. Genesis of Dolostone Reservoir of Feixianguan Formation in Lower Triassic of Northeast Sichuan Basin. Acta Petrolei Sinica, 29(6): 815–821 (in Chinese with English Abstract) |
| Zhu, G. Y., Zhang, S. C., Liang, Y. B., et al., 2007. Formation Mechanism and Controlling Factors of Natural Gas Reservoirs of the Jialingjiang Formation in the East Sichuan Basin. Acta Geologica Sinica, 81(5): 805–816 doi: 10.1111/j.1755-6724.2007.tb01004.x |
| Zou, H. Y., Hao, F., Zhu, Y. M., et al., 2008. Source Rocks for the Giant Puguang Gas Field, Sichuan Basin: Implication for Petroleum Exploration in Marine Sequences in South China. Acta Geologica Sinica, 82(3): 477–486 |
Figures(9)
Copyright © 2013-2020 Journal of Earth Science 鄂ICP备15021562号-2
Tel: +86-27-67885075 Fax: +86-27-67885075 E-mail: xbb@cug.edu.cn
Address: Editorial Office of Journal, China University of Geosciences, Yujiashan, Wuhan, Hubei 430074, P. R. China
Supported by:
Beijing Renhe Information Technology Co. Ltd
E-mail:
info@rhhz.net
Xiucheng Tan, Hong Liu, Ling Li, Bing Luo, Xiaoguang Liu, Xiaohui Mou, Yong Nie, Wenyan Xi. Primary Intergranular Pores in Oolitic Shoal Reservoir of Lower Triassic Feixianguan Formation, Sichuan Basin, Southwest China: Fundamental for Reservoir Formation and Retention Diagenesis. Journal of Earth Science, 2011, 22(1): 101-114. doi: 10.1007/s12583-011-0160-2
DownLoad:
DownLoad:
