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The Middle Cretaceous to Early Miocene Petroleum System in the Zagros Domain of Iran and Its Prospect Evaluation*
By
M.L. Bordenave1
Search and Discovery Article #10040 (2003)
*Adapted from “extended abstract” of presentation at AAPG Annual Meeting, March 10-12, 2002, Houston, Texas.
1Consultant, 24 Avenue President Kennedy, 75016 Paris, France
An impressive gathering of giant fields, located in the 50,000 sq km Dezful Embayment, produces from the Asmari Limestone of early Miocene and from the Cenomanian Sarvak Limestone, and contains some 400 billion barrels of oil-in-place, or 7% of the oil global reserves.
Two excellent source rocks are associated with these reservoirs, the Albian Kazhdumi Formation and the middle Eocene Pabdeh Formation. The Kazhdumi was deposited in a depression corresponding to the present Dezful Embayment, and probably extended northeastward, while the Pabdeh accumulated in a NNW-SSE trough, from Shiraz to Lurestan.
Modeling
showed
that Kazhdumi and Pabdeh reached the onset of oil expulsion 1 to10 Ma, after the
beginning of the Zagros folding. Therefore, migration took place almost
vertically and was facilitated by intense fracturing in high-relief anticlines.
The distribution of source rocks, thickness, characteristics, and maturity were
used to forecast if an undrilled structure is expected to be oil, gas, or
water-bearing and what would be the order of magnitude of the oil-in-place.
In the Dezful
Embayment, many low-relief Zagros anticlines, poorly defined by a poor-quality
early seismic, remain to be drilled, after seismic confirmation. However, their
fracturing, critical for limestone permeability, is expected to be less
developed. N-S oriented pre-Zagros salt-related elongated structures, also fed
by Kazhdumi or deeper sources, are prospective, especially for Zubair (Lower
Cretaceous) and Burgan (Middle Cretaceous) sandstones. In addition, large
anticlines remain to be drilled to the Middle Cretaceous Sarvak, north of the
mountain front.
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The Zagros Foothills, a system of large size whaleback asymmetric anticlines, formed as the result of a late Miocene to Pliocene orogeny, includes two uplifted areas, Lurestan to the north, where anticlines are deeply dissected, and Fars to the south. In between, a 50,000 sq km depressed area, known as the Dezful Embayment (Figure 1), corresponds to an impressive gathering of 45 oil fields, often associated with gas caps. Several of them are categorized as supergiants as they contain 10 to 50 billions barrels of oil-in-place; i.e., Agha Jari, Ahwaz, Bibi Hakimeh, Gachsaran, Mansuri, Marun, and Rag-e Safid. About 98% of the oil-in-place, namely 250 billions barrels of oil and more than 200 Tcf of associated gas are trapped in two reservoirs (Figure 2), the 300 to 500 m thick early Miocene high energy Asmari Limestone, which is extremely porous almost everywhere in the study area and well sealed by the efficient Gachsaran evaporites, and the Sarvak Limestone (Cenomanian and early Turonian), very thick, up to 1000 m, but porous only in some of the high-energy platform facies, capped by the thick Gurpi/Pabdeh marls. In most of the fields, which correspond to high-relief, asymmetric, often thrusted anticlines, the Asmari and Sarvak reservoirs are interconnected as the result of an intense fracturing of the Pabdeh-Gurpi marls in the crestal part of the anticlines.
SOURCE ROCK DISTRIBUTION AND CHARACTERISTICS Excellent type IIs source rocks were deposited in intracratonic depressions when anoxic conditions prevailed as the result of water stratification during the Middle Jurassic(Sargelu Formation), Valanginian (base of the Garau Formation), Albian (Kazhdumi Formation), and middle/late Eocene (Pabdeh Formation). In the northern part of the Gulf, organic-rich layers were also deposited in the Ahmadi Member (early Cenomanian) of the Sarvak Formation (Figure 2). In addition, marginal source rocks were deposited during the Barremian (Gadvan Formation) and the Late Cretaceous (Gurpi Formation), but their contribution to the charge of the Iranian fields is negligible (Bordenave and Huc, 1995). In spite of their excellent characteristics (initial TOC values in the 5-15% range, high Hydrogen Index (HI) varying from 500 to 700 g HC/kg C, and thickness from 100 to 300 m), the contribution of each source rock to the charge of the Zagros oil fields was extremely variable. This contribution, based on source rock maturity and association of mature source rocks with reservoirs and traps, was verified by oil-to-source rock and oil-to-oil correlations using stable isotopes (d13C and d34S) and biomarkers (Bordenave and Burwood, 1990). Two source rocks, Sargelu and Garau, are not associated with reservoirs, being limited above and below by basinal facies, either massive evaporates or thick marls and tight argillaceous limestone. Their contribution to the oil accumulated in the Dezful Embayment is limited to 1 or 2%. Only the two source rocks, which play an important role in the charge of the Dezful Embayment oil reserves, the Kazhdumi and the Pabdeh, are considered in this paper.
At the end of Aptian, a major regression, which caused the shallow-water Aptian carbonates to become emergent, was followed by a low-amplitude transgression marked by a sudden influx of clastics. Most of Saudi Arabia, Kuwait, and Iraq, west of the Euphrates River, were covered by alluvial plain facies, while deltaic sediments rapidly prograded in the Safaniya-Burgan area. The more distal part of the basin was the locus for the deposition of the Kazhdumi Formation, dated as Albian. A depression was limited to the SE by the Fars Platform, where the deposition of shallow-water thin oxic marls was interrupted by temporary emergences. To the north, it was limited by the E-W Bala Rud carbonate shoal, which separated the Kazhdumi Depression centered on the present day Dezful Embayment from the Lurestan Depression. To the east, the depression was bordered by a sill, on which anoxic and oxic facies fluctuated according to sea level changes (Figure 3); however, little information is available on a possible eastern extension. Up to 300 m of dark grey marls and subordinate argillaceous limestone, containing a pelagic fauna of Globigerina, Globotruncan, and radiolaria, were deposited in strictly euxinic conditions. The organic matter is of algal origin. Kazhdumi TOC values vary from 1 to 11%, with average values in the 5% range in the center of the depression. The potential S2 may reach 50 to 60 g HC/kg rock and HI reaches values as high as 500 to700 g HC/kg C. The source Potential Index (SPI) may be in excess of 25 tonnes/m2, classifying the Kazhdumi as one of the richest source rocks. The Kazhdumi organic matter contains up to 5 to 7% per weight of sulfur; this fact explains the high sulfur content of the oil generated. During the Albian, the Arabian Platform was close to the Equator, according to plate tectonic reconstruction, and under a humid climate as shown by the large amount of fresh water which flowed into the Dezful Depression through a system of rivers (Bordenave and Burwood, 1995). This fluvial water, outwash from the Arabo-Nubian land mass, was nutrient-rich (nitrates and phosphates). Ideal conditions were realized for a high plankton productivity in the shallow low-density oxygenated fresh water. Density stratification and the fall of organic matter in the oxygen-deprived zone are a classical mechanism for anoxic conditions. Sulfate-reducing bacteria were extremely active, as demonstrated by the sulfur incorporated in the Kazhdumi organic matter. As a consequence of the aggradation of the former Radiolarite Trough to the Arabian Platform, during the Campanian, direct access of the Arabian Platform to the South Tethys ceased, and a thick sequence of flysch, containing radiolarite debris for the large part, accumulated in front of the newly emergent area, which was actively eroded. A well individualized NW-SE-trending depression, parallel to the Zagros Suture, extended from Fars to Lurestan, during the Paleocene-Eocene and even Oligocene in Lurestan (Figure 4). It was bordered to the SW by platform carbonates covering most of the Arabo-Persian Gulf. To the SE, the depression was limited by the Fars Platform, where the shallow-water dolomitic limestone of the Jahrum Formation surrounded a subsident sebkha (Sachun Formation). A monotonous and thick (200 to 1000 m) sequence of grey marls, containing a rich planktonic fauna of Globorotalia and Globigerina, was deposited. Euxinic conditions prevailed in the central part of the depression during middle/late Eocene and even early Oligocene in Lurestan. 150 to 200 m of organic-rich marls contain up to 11.5% organic carbon, the average TOC values varying from 3% in Fars to 7.5% in Lurestan (Figure 4). The organic matter is mostly algal (Tasmanacea), with HI up to 500/650 g HC/kg C; however, terrestrial influences are visible in the vicinity of the NE shoreline.
The Main Fields area corresponds almost exactly to the depression where the Kazhdumi source rocks were deposited. Moreover, oil-to-oil and oil-to-source rocks correlations, based upon carbon and sulfur isotopes and biomarkers composition, have shown that most of the oil accumulated in the main fields in the Asmari/Sarvak reservoirs originated from the Kazhdumi, while only the oil of the NE Dezful fields (Lab-e Safid, Par-e Siah, Lali, Qaleh Nar, and Karun) comes from the Pabdeh (Bordenave and Burwood, 1990, 1995). Except perhaps in the Pazanan field, no interference was observed between the Asmari/Sarvak reservoirs and source rocks deeper than the Kazhdumi. This was explained by the high pore pressures developed in mature Kazdumi source rocks, which formed a barrier for the oil and gas from deeper origin. Only limited amounts of Kazhdumi oil have reached the tight generally basinal Khami Formation. Therefore, the Middle Cretaceous to early Miocene Petroleum System, limited on its lowermost part by the base Kazhdumi and on its uppermost part by the Gachsaran evaporites, includes two source rocks, Kazhdumi and Gurpi, and two main reservoirs, the Sarvak and the Asmari. The IFP Genex software was used to model the thermal evolution of the Kazhdumi and the Pabdeh source rocks and to determine the onset of the oil expulsion. Kinetic parameters were measured on source-rock samples by using the IFP Optkin program of pyrolysis. Because of the stability of the platform and its almost constant subsidence through time, the application of a constant heatflow was considered as reasonable. A value of 36mW/m2 was chosen as it gives a best fit between the observed and the calculated values of the thermal indicators, such as the vitrinite reflectance, the Rock-Eval Tmax, and the Hydrogen Index. The onset of oil expulsion was assumed to happen for a 30% oil saturation of the source rock pore space. It means that the onset of oil expulsion was reached earlier for rich source rocks.
If Karanj and Paris are excepted, the onset of oil expulsion from the Kazhdumi was reached when its base was buried to 3900 to 5000m, depending on locality, between 8 and 1Ma, in synclines as well as on anticlines. In Karanj and Paris, oil began to be expelled 16Ma. For the Pabdeh, the oil expulsion has not commenced yet on the Mansuri trend, even in the synclines. Elsewhere, it was not reached on the top of the Main Field anticlines, even at Karanj and Paris, but it was reached in the deeper part of some synclines, from present to 4.5 Ma. On the NE edge of the platform, Burdigalian sediments (16 and 20 Ma) were deposited before the Zagros folding (Ricou, 1974). In the Dezful Embayment, the main phase of Zagros folding apparently began after the deposition of the Mishan Formation (middle Miocene), and was witnessed by the deposition of the Agha Jari molasse, some 10Ma. Except for the Karanj and Paris fields, the oil expulsion, either on the anticlinal tops or in the deeper parts of the synclines, commenced later than 8Ma; i.e., after the beginning of the Zagros folding. It is likely that the fracturing of the Sarvak to Asmari interval in the anticlinal part of the high-relief structures facilitated the oil expulsion and its upward migration to the first caprock encountered, the Gachsaran Formation. The source rocks are expected to have been more easily drained in the anticlinal than in the synclinal part, which were in strong compression. As the oil expulsion from the source rocks happened when the Zagros folds were already individualized, oil migrated almost vertically to the reservoirs of the neighboring anticline. A concept of "Area of Drainage" could be applied for each anticline, and a tentative estimate of the oil trapped could be made, assuming a sufficient knowledge of the Kazhdumi and Pabdeh source rock characteristics (TOC,HI, TR, thickness) and of their geometry. The
geometry of the areas of drainage was deduced from early The initial oil-in-place (IOIP) of each fields was compared to the oil expelled from the source rocks, according to the model. As a large proportion of the fields are full to the spill point, the anticlines were grouped into trends, to take care of secondary migration. To summarize, the IOIP of the groups of fields of the Dezful Embayment corresponds to only between 12 and 21% of the oil calculated to have been expelled from the source rocks in their areas of drainage. The main contributor, the Kazhdumi Formation, would have generated some 95% of the oil generated in Zagros Foothills. As oil migrated vertically from the Kazhdumi and the Pabdeh source rocks to the Sarvak and the Asmari reservoirs of the Zagros structures, the distribution and the maturity of these two source rocks provides a good definition of the potentially prospective areas, at least for the Middle Cretaceous to early Miocene Petroleum System. In Lurestan, the Kazhdumi is not a source rock anymore and the Pabdeh is not mature, moreover, the Asmari reservoir is breached, and the Sarvak has almost everywhere a tight basinal facies. In Fars, the Kazhdumi is generally oxic, and the Pabdeh is immature. In the Shiraz area, however, the origin of the Sarvestan oil and of several noticeable seepages is not completely understood, but it might come from an eastern development of the Kazhdumi source rocks. A few large anticlines are prospective for the Sarvak, and perhaps for the Upper Khami, in the Shiraz area. Some large anticlines in Khuzestan, east and northeast of the Mountain front, are also prospective. In the
Dezful Embayment, all the large high-relief anticlines were drilled to
the Sarvak and deeper. A few anticlines of smaller size remain to be
drilled to the Sarvak. Several low-relief prospects, evidenced by the
early In
addition, in the south of the Dezful Embayment, in areas not influenced
by the Zagros folding, salt-related, large, N-S-elongated,very
low-relief structures, formed sometimes as early as the beginning of the
Jurassic, are prospective for the Sarvak and the Asmari Limestone/Ahwaz
sands and for the Burgan and the Zubair sands. Again a good quality
Bordenave, M.L., and Burwood, R., 1990, Source rock distribution and maturation in the belt, provenance of the Asmari and Sarvak reservoirs oil accumulations. Org. Geochem., v. 16, p. 369-387. Bordenave, M.L., and Burwood, R., 1995, The Albian Kazhdumi Formation of the Dezful Embayment, Iran: one of the most efficient petroleum generating systems, in Petroleum source rocks series: case book in Earth Sciences, Katz, B.J., ed.: Springer Verlag, Heidelberg, p. 183-207. Bordenave, M.L., and Huc, 1995, The Cretaceous source rocks in the Zagros Foothills of Iran: an example of a large size intracratonic basin. Rev. Inst. Fr. Petr., p. 727-753. James, G.A., and Wynd, J.G., 1965, Stratigraphic nomenclature of Iranian Oil Consortium Agreement Area, AAPG Bulletin, v. 49, p. 2182-2245. Ricou, 1974, L'étude géologique de la région de Neyriz (Zagros iranien) et l'évolution des Zagrides, Thesis, Université Paris-Sud, Orsay. 321p. |
Figure 1.
Location map of the Middle East, showing Zagros domain in Iran.
Figure 2.
Schematic stratigraphic chart of SW Iran, along with Iraq and Saudi
Arabia, with identification of source rocks, reservoirs, and seals in SW
Iran (after Bordenave, 2002).
Figure 3.
Isopach map of the Kazhdumi bituminous facies (>1% TOC) (after Bordenave
and Huc, 1995).
Figure 4.
Isopach map of organic-rich (>1% TOC) layers of the Pabdeh Formation.
