“Exploring petroleum inside source kitchen”: Connotation and prospects of source rock oil and gas
Research Institute of Petroleum Exploration & Development, PetroChina, Beijing 100083, China
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Received: 2018-08-13 Online: 2019-02-15
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Based on the transitional background of the global energy structure, exploration and development of unconventional oil and gas, and investigation of key basins, the unconventional oil and gas resources are divided into three types: source rock oil and gas, tight oil and gas, and retention and accumulated oil and gas. Source rock oil and gas resources are the global strategic supplies of oil and gas, the key resource components in the second 150-year life cycle of the future petroleum industry, and the primary targets for “exploring petroleum inside source kitchen”. The geological connotation of source rock oil and gas was proposed, and the models of source rock oil and gas generation, expulsion and accumulation were built, and five source rock oil and gas generation sections were identified, which may determine the actual resource potential under available technical conditions. The formation mechanism of the “sweet sections” was investigated, that is, shale oil is mainly accumulated in the shale section that is close to the oil generation section and has higher porosity and permeability, while the “sweet sections” of coal-bed methane (CBM) and shale gas have self-contained source and reservoir and they are absorbed in coal seams or retained in the organic-rich black shale section, so evaluation and selection of good "sweet areas (sections)" is the key to “exploring petroleum inside source kitchen”. Source rock oil and gas resources have a great potential and will experience a substantial growth for over ten world-class large “coexistence basins” of conventional-unconventional oil and gas in the future following North America, and also will be the primary contributor to oil stable development and the growth point of natural gas production in China, with expected contribution of 15% and 30% to oil and gas, respectively, in 2030. Challenges in source rock oil and gas development should be paid more attention to, theoretical innovation is strongly recommended, and a development pilot zone can be established to strengthen technology and promote national support. The source rock oil and gas geology is the latest progress of the “source control theory” at the stage of unconventional oil and gas. It will provide a new theoretical basis for the new journey of the upstream business in the post-industry age.
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Cite this article
YANG Zhi, ZOU Caineng.
Introduction
Unconventional oil and gas will be the most important alterative resources in the middle and late 21st century, and source rock oil and gas, such as shale gas, shale oil and coalbed methane (CBM), are extremely important contributors[1]. General “exploring petroleum inside source kitchen” involves exploring tight oil and gas “near sources”, exploring shale oil and gas, and CMB “inside sources”, and developing shale oil, oil shale oil “in full sources”. This paper only covers two aspects: exploring petroleum “inside sources” and exploiting petroleum “in full sources”. To exploring oil and gas “inside sources” means to identify sweet areas and sections by entering the layer generating oil and gas. To develop oil and gas “in full sources” means to develop retention hydrocarbons and converted organic matter and try to utilize all potential oil and gas resources. The continuous and targeted research on the theoretical technology will have important theoretical and strategic significance at present and in the future. In the past 10 years, supported by the National 973 Program and the National Science and Technology Major Projects, based on the experimental bases such as the National Energy Tight Oil and Gas R&D Center, and taking the source rocks in major basins such as Ordos, Junggar, Songliao, Sichuan, and the Western Coast of the United States, experimental analysis, geological evaluation and industrial practice have been carried out on the forming and distribution and industrial evaluation of source rock oil and gas in a multi-disciplinary mode involving geology, geochemistry and geophysics; the geological connotation of source rock oil and gas has been analyzed; and the classification and comparison, the forming mechanism of “sweet sections”, the distribution law of “sweet areas” and the development prospects of source rock oil and gas resources have been investigated.
1. Background of “exploring petroleum inside source kitchen”
1.1. Development and transformation of energy structure
However, objectively, fossil energy will keep increasing as a main energy source in a long time. The successful development of unconventional oil and gas further strengthens the foundation of oil and gas resources, it is predicted that oil and gas will continue to play a major role in the future, and will play an irreplaceable role in a certain period of time. Natural gas will become the simple fossil energy with the highest percent after 2030, and it will serve as a reliable bridge for the transformation of fossil energy into renewable energy[1, 3].
For China, the continuous increase of oil and gas, decrease of coal, and development of new energy in a long period of time is the key to optimizing the energy structure. The rapid development of unconventional oil and gas will be an important guarantee for the long-term stable development of oil and gas, and the important weight of national basic energy security.
1.2. Exploration and development progress of unconventional oil and gas
Unconventional oil and gas refers to continuously distributed oil and gas resources that can be economically exploited by new technologies to improve reservoir permeability or fluid viscosity, rather than traditional techniques to obtain natural industrial production[4] (Fig. 1). The unconventional oil and gas revolution refers to subverting the traditional oil and gas production mode, breaking the conventional permeable reservoir and the classical oil and gas trap accumulation concept, discovering industrial-grade nano-scale pores from tight sandstone and shale, innovating the theory of large-scale continuous oil and gas accumulation and the factory technology for volume fracturing of horizontal wells, transforming the traditional trap “reservoir” exploration and development mode, breaking through the technical theory of vertical-well seepage development, and achieving a major energy revolution in the industrialized production area of traditional oil and gas. According to the characteristics of migration and accumulation, unconventional oil and gas can be divided into three types: source rock oil and gas, tight oil and gas, and retained and accumulated oil and gas. Source rock oil and gas are unconventional resources that are generated and preserved in the same formation. They include shale gas, shale oil, CBM and oil shale oil, this paper discusses the first three types mainly. Tight oil and gas are the resources that are generated in source rocks and then migrate and accumulate in the reservoir near the source rock. They mainly include tight oil and tight gas. Retained and accumulated oil and gas refer to the resources accumulating in reservoirs such as near-surface layers, seabed sediments, and tundra after transporting over a long distance and experiencing water washing, degradation and thickening, and crystallization at the stable temperature and pressure zone (Fig. 1, Table 1), primarily including hydrates, oil sands and heavy oil.
Fig. 1.
Fig. 1.
Classification and comparison of conventional and unconventional oil and gas (adapted from reference [4]).
Table 1 Comparison of geology and development characteristics of conventional with unconventional oil and gas.
Resource Type | Distribution | Relation of source rock and reservoir | Migration | Accumu- lation | Preservation | Fluid | Production process | Hydrocarbon composition | Recoverable resources/ (oil/t; gas/m3) | Examples | |||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Composition | Movable hydrocarbon | Target | Key technology | Initial production | Cumulative production | Global | China | ||||||||
Conventional | Oil | Favorable traps at structural highs | Separate | Secondary | High abundance; stratigraphic and lithologic reservoirs | Regional and immediate caprock | Liquid hydrocarbon | 40%-80% movable hydrocarbon | Oil with high abundance, good reservoir properties and high natural production | Vertical and horizontal wells, etc. | 90%- 100% movable oil | 90%- 100% movable oil | 4 878 ×108 | 200× 108 | Gawal Oilfield, Daqing Oilfield |
Gas | Favorable traps at structural highs | Separate | Secondary | High abundance; stratigraphic and lithologic reservoirs | Regional and immediate caprock | Gas hydrocarbon, generally CH4 | 90%- 100% free gas | Oil with high abundance, good reservoir properties and high natural production | Vertical and horizontal wells, etc. | 90%- 100% free gas | 90%- 100% free gas | 471 ×1012 | 20× 1012 | North-South Pars Gas Field, Kela 2 Gas Field | |
Retained | Heavy oil +asphalt | Near surface | Separate | Secondary | Favorable trap in the drainage area | Caprock and self- sealing | Heavy oil | Unmo- vable oil | Heavy oil with poor movability and no natural pro- duction | Steamflooding, gravity, steam stimulation, cooling production | Almost unmovable oil | Almost unmovable oil | 2 146 ×108 | 42× 108 | Heavy oil in Venezuela, asphalt sandstone in the Western Canada Basin |
Hydrate | Stable T and P zone | Separate | Secondary | Reservoir enrichment in coarse facies | T and P conditions | Domi- nant CH4 | Almost no free gas | Unconsolidated seabed pay zone, unstable and without natural production | Pressure drop, thermal production | Hardly free gas | Hardly free gas | 3 000 ×1012 | (50- 70)× 1012 | Hydrate in the northern part of the South China Sea | |
Tight | Oil | Basin center or slope | Direct contact or neighbor | Primary or short secondary migration | High abundance in the tectonic or fractured zone | Good top and bottom | Matured oil | 20%-50% movable hydro- carbon | Tight reservoirs | Energizing, fracturing in horizontal wells | 90%- 100% movable oil | 90%- 100% movable oil | (400- 600) ×108 | (20- 25)× 108 | Triassic in Ordos Basin, Cretaceous tight sandstone oil in Songliao Basin, |
Gas | Basin center or slope | Direct contact or neighbor | Primary or short secondary migration | High abundance in the tectonic or fractured zone | Good top and bottom | Different gas saturation, almost 60% below | 90%- 100% free gas | Tight reservoirs with low natural production | Fracturing in horizontal wells | 90%- 100% free gas | 90%- 100% free gas | 210× 1012 | (9- 13)× 1012 | Carboniferous-Permian in Ordos Basin, Triassic tight sandstone gas in Sichuan Basin | |
Source rock | Shale oil | Developed shale in deep sags or slopes | Same | No or short inside-source primary migration | Nano-pore and throat system, enrichment in the fracture development zone | Good top and bottom | Less mature oil and immature oil sand | 0%-30% movable hydrocarbon | Low or no production, low natural production | In-situ thermal transformation | 0%-100% movable oil | 0-5% movable oil | 15 000 ×108 | (200- 300)× 108 | Triassic shale oil in Ordos Basin |
Matured oil | 20%-50% movable hydrocarbon | Low or no production, low natural production | Fracturing in horizontal wells | 90%- 100% movable oil | 90%- 100% movable oil | Bakken shale oil in Wyckenston Basin | |||||||||
Shale gas | Near basin subsidence-sedimenta- tion center | Same | No or short inside-source primary migration | Disperse distribution in shale, enrichment in fracture zones | Good top and bottom | Dry gas absorbed to kerogen, pores and free in fractures | 40%-70% free gas | Low production and recovery | Fracturing in horizontal wells | 80%- 100% free gas | 30%-60% free gas | 456× 1012 | (10- 25)× 1012 | Masalus shale gas in Appalachian Basin, Lower Paleozoic shale gas in Sichuan Basin | |
CBM | Basin or de- pression synclines | Same | No or short inside-source primary migration | Enrichment in fractures and joints | Good top and bottom | Absorbed and free gas | 5%-20% free gas | Low production, no natural production | Fracturing in horizontal wells | 5%-10% free gas | 0-5% free gas | 256× 1012 | 11× 1012 | Carboniferous-Permian CBM in Qinshui and Ordos Basins |
In the 21st century, represented by American shale oil and gas, Canadian oil sands and Venezuelan heavy oil, a series of breakthroughs have been made in exploration and development of unconventional oil and gas which have become an important part of global oil and gas production, and deeply reshaped the global energy chart and the geopolitical pattern[5,6,7]. Tight gas, CBM, heavy oil, asphalt sandstone, etc. are targets of exploration and development of unconventional oil and gas in the world, shale gas is a hot spot, and tight oil is a highlighted spot. With the rapid growth of unconventional oil and gas production worldwide, unconventional oil and gas are more and more prominent in the global energy supply and have become important components of oil and gas production. In 2017, global oil production was 43.9×108 tons, of which unconventional oil accounted for 14%; global natural gas production was 3.7×1012 m3, of which unconventional natural gas accounted for 25%[1, 3, 6]. In the past 10 years, the United States has made a “golden decade of revolutionary development” of shale gas and tight oil. Relying on three major experiences in the accumulation theory of continuous oil and gas, volume fracturing for horizontal wells and support of national policy, the United States has successively realized the revolution of shale gas and tight oil. In 2017, the US natural gas production was 7 345×108 m3, of which unconventional gas accounted for 85%, including shale gas of 4 746×108 m3, tight gas of 1 200×108 m3, and CBM of 302×108 m3. Thanks for the rapid development of unconventional gas, the natural gas production in the United States hit a record high, and made it almost sufficient by itself. In 2017, the US tight oil production was 2.36×108 tons, accounting for 37% of total oil production[1, 3, 6]. In general, the US unconventional oil and gas production has accounted for 70%, become the leading contributor to the production increase, and will continue promoting the implementation of the US strategy in “energy independence”.
In China, after more than 10 years, industrial development has been basically made to unconventional oil and gas. First, production of unconventional natural gas has been at industrial scale. By the end of 2016, the proven reserves of unconventional natural gas reached 4.7×1012 m3, accounting for 36%. In 2017, the production was 499×108 m3, accounting for 34%[1]. Tight gas covers a number of gas provinces at scales of trillion m3 and even 100 billion m3 represented by the Upper Paleozoic in the Ordos Basin and the Xujiahe Formation in the Sichuan Basin. The total national production in 2017 was 360×108 m3; the proven geological reserves of shale gas were up to 9 209×108 m3; and three marine shale gas fields at the scale of 100 billion m3 were built in Fuling, Changning and Weiyuan in the Sichuan Basin, which produced shale gas of 90×108 m3 in 2017. The development of CBM is effective, and two production bases were built in Qinshui and Ordos, with the production of 49×108 m3 in 2017[1]. Second, the development of unconventional tight oil has been initially industrialized. Tight oil has entered the reserve stage, and three billion-ton-scale tight oil fields have been built, including Xin'anbian in the Ordos Basin, Fuyu in the Songliao Basin, and Jimusal in the Junggar Basin. The production in 2017 was about 150×104 tons. In addition, significant progress has been made in the exploration of natural gas hydrates. In 2017, natural gas was produced from the Miocene and Pliocene formations, 203-277 m thick, below the seabed at 1 266 m deep in the Shenhu area of the Pearl River Mouth Basin. More than 23.5×104 m3 of natural gas was produced in 42 days[8]. The potential of shale oil resources is huge, and the “sweet areas (sections)” are almost clear. Pilot test feasibility demonstration on in-situ heating conversion, non-water fracturing and other scientific exploration are being carried out on the Chang 7 shale of the Triassic Yanchang Formation in the Ordos Basin. It is expected to take the lead in China to achieve the continental “shale oil revolution”[9,10]. By the end of 2017, the production of unconventional oil and gas reached 6 600× 104 tons of oil and gas equivalent, accounting for 20% of total oil and gas production, and achieved a “strategic breakthrough” in China. This provides basic conditions for revolutionary development.
1.3. The strategic position of “source rock oil and gas”
Unconventional source rock oil and gas resources such as shale gas, shale oil and CBM (referred to as “source rock oil and gas”) are strategic fields for global oil and gas supply. The global unconventional oil recoverable resources are 6 200×108 tons, which is equivalent to conventional oil, and of which source rock oil accounts for 50%. The global unconventional natural gas recoverable resources are 3 922×1012 m3, which is 8 times that of conventional natural gas, and much of which source rock natural gas accounts for 77% (excluding gas hydrate)[1,7,11-14]. In general, source rock oil and gas have huge resource scales, but the overall proven percent is extremely low. It is a pivotal component of the second 150-year life cycle of the petroleum industry and has an extremely important strategic position[4].
The mainland of China is located at the intersection of three major plates, the Pacific Ocean, the Siberia and the India. The formation and development of sedimentary basins are diverse. They have experienced two stages of the Paleozoic marine and Mesozoic and Cenozoic continental evolutions, and formed more than 10 sets of organic-rich shale and coal series. China’s source rock oil and gas has a good resource base. Compared with the source rock oil and gas in North American, the formation and distribution of China's source rock oil and gas are more complex, and more affected by tectonic activities; the reservoir is more heterogeneous in vertical and horizontal distribution; the relationship among oil, gas and water is relatively more variable; and the evaluation on sweet sections/ areas is more difficult. The shale gas discovered is dominated by highly-to-over mature marine facies; the CBM discovered is dominated by highly mature marine and transitional facies; the shale oil discovered is dominated by middle-to-low mature continental facies (Fig. 2). According to the geological conditions, it is important for large-scale development of source rock oil and gas by strengthening the research on the distribution law, evaluation and production technologies of source rock oil and gas in China.
Fig. 2.
Fig. 2.
Comparison of unconventional oil and gas geological conditions between China and North America.
The study on the geological theory and method of source rock oil and gas will be the focus of future petroleum geology. Compared with conventional resources, the source rock con-taining oil and gas is characterized by nano-pore and -throat systems, continuous hydrocarbon distribution, tight reservoirs, multi-phase coexistence, inside-source accumulation, and special reservoir-forming mechanisms (Fig. 1, Table 1). These break through many limitations in petroleum geology and bring major challenges to traditional petroleum geology. To deep the research on the geological theory of source rock oil and gas and to develop the theoretical system of reconstructed petroleum geology have become the frontier and are urgent requirements for the future oil and gas industry[4].
In the past 10 years, many significant achievements have been made to micro-characterization of nano-pore and -throat system, pore evolution and hydrocarbon occurrence in tight reservoirs, resource evaluation based on production performance, and evaluation on “sweet areas” based on the concept of continuous oil and gas accumulation[4, 14-31]. These promoted the development of source rock oil and gas. As a new discipline of petroleum geology, source rock oil and gas will face many theoretical and methodological challenges such as pore development mechanism, oil and gas migration and accumulation law, and sweet evaluation and prediction. How to effectively break through the bottlenecks in exploration and promote large-scale development is the important part of geological evaluation and prediction of source rock oil and gas.
2. Theoretical connotation of source rock oil and gas
2.1. Geological connotation
Source rock oil and gas refers to the resources generated in the source rock, and then retained or accumulated inside or near the source rock. As one of the important types of unconventional oil and gas resources, they are continuously distributed and can be produced industrially using new technologies to generate “man-made permeability” and construct “man- made reservoirs”. New technologies include horizontal-well volume fracturing, in-situ heating conversion/modification, and other industrial measures to improve permeability, reduce fluid viscosity, and increase formation energy. The geological connotation of source rock oil and gas refers to a geological discipline that studies the hydrocarbon generation model, forming mechanism, distribution law, development geology, engineering geology and development strategy of unconventional source rock oil and gas, covers shale gas, CBM, shale oil, etc., and include exploration geology and development geology. The exploration geology takes favorable resource zones with hydrocarbon occurrence as objectives to evaluate six types of properties like “lithology, hydrocarbon source, reservoir, hydrocarbon-bearing, compressibility and anisotropy” of the source rock, with the core to clarify the scope of continuous oil and gas accumulation and reserves scale. The development geology takes “sweet sections” and “sweet areas” as objectives to induce “man-made permeability” or “man-made energy field” and construct “man-made oil and gas reservoirs”, with the core to realize the large-scale and effective production of oil and gas resources.
The organic matters of source rock oil and gas are generally classified into type I and type II1 sapropel-type lacustrine black shale, type II sapropel-type marine black shale and type III humus-type black coal series. According to the hydrocarbon generation characteristics, the source rock oil and gas can be divided into oil shale oil, shale oil with low-to-medium maturity, shale oil with medium-to-high maturity, favorable shale gas, and favorable coal-formed gas. They are produced in different windows. Based on hydrocarbon generation simulation experiments on lacustrine shale, marine shale, coal seam samples[10, 31-36], the generation, migration and accumulation models have been established (Fig. 3). The oil shale oil section is an unconverted organic-rich shale section, currently which is produced by artificial refinement from surface or near-surface layers. The shale oil section with low to medium maturity contains potential hydrocarbon from unconverted organic matter and hydrocarbon generated but not discharged. The favorable maturity window falls in the Ro of 0.5% to 0.9%, and the amount of liquid hydrocarbon retained in the window and that of unconverted organic matter are large. The shale oil with medium to high maturity contains mainly the hydrocarbon generated but not discharged. The favorable maturity window has the Ro of 0.9% to 1.3%, and the amount of liquid hydrocarbons retained in the window reaches the maximum. The favorable shale gas is mainly the gas generated but not discharged, the Ro greater than 1.3% means a favorable maturity window, and the amount of retained gaseous hydrocarbons in the window reaches the maximum. The favorable coal-formed gas is mainly adsorbed gas generated but not discharged, the Ro greater than 0.8% means a favorable maturity window, the amount of gaseous hydrocarbon adsorbed in the window gradually reaches the maximum, and the amount of coal-formed gas greatly increases.
Fig. 3.
Fig. 3.
Generation, discharge and accumulation models of source rock oil and gas.
The actual resource potential of source rock oil and gas depends on the amount of hydrocarbons that have been generated and retained in the source rock, and the amount of hydrocarbons that can be affected and produced by manual stimulation. The staged volumetric fracturing technology of horizontal wells has basically solved the large-scale development and utilization of shale oil with medium to high maturity, favorable shale gas and favorable coal-formed gas. For oil shale oil and shale oil with low to medium maturity, underground in-situ heating conversion technology may be effective in the future, but now is still under research[9].
The coupling mechanism of rock (organic matter)-fluid- pore/fracture system in shale is a new topic of petroleum geology theory. The mechanism of near-source secondary migration and accumulation of oil and gas in the tight reservoir near the source rock is basically clear, but the mechanism of primary migration and accumulation inside the source rock is still a major scientific problem that plagues petroleum geologists. The shale burial and thermal evolution process is a complex coupling process of the solid-fluid-pore/fracture ternary system in a temperature and pressure evolution environment[18,36]. It is often difficult to recover actual evolution of shale by conventional experimental methods and consideration of single factors[35], and accordingly it is difficult to grasp the critical time-depth node of pore and fracture changes and hydrocarbon occurrence. Therefore, systematic research on the three elements of solid, fluid and pores/fractures at different stages of maturity is an effective way to recover the history of hydrocarbon generation and discharge of shale oil and gas and the development mechanism of pores/fractures in shale.
2.2. Classification and comparison
Compared with domestic and international shale oil, shale gas and CBM, their common characteristics are the organic- rich source rocks widely distributed and thick, with high abundance and hydrocarbon potential, dominant nano-pores, strong adsorption to hydrocarbon, high fullness in the reservoir space, continuous distribution and large resources (Fig. 4, Tables 2-4).
Fig. 4.
Fig. 4.
Argon ion polishing-SEM photos of source rock oil and gas in major basins in China. (a) Weiyuan block of Sichuan Basin; Lower Silurian Longmaxi Formation; core; black shale; organic matter coexisting with quartz, calcite, dolomite and clay minerals; (b) Weiyuan block of Sichuan Basin; Lower Silurian Longmaxi Formation; core; black shale; organic matter coexisting with quartz, calcite, dolomite and clay minerals; (c) Weiyuan block of Sichuan Basin; Lower Silurian Longmaxi Formation; core; black shale; organic matter coexisting with quartz and clay minerals; (d) Weiyuan block of Sichuan Basin; Lower Silurian Longmaxi Formation; core; black shale; organic matter coexisting with quartz and clay minerals; (e) Well 147 in Ordos Basin; Upper Triassic Yanchang Formation; core; black shale; organic matter coexisting with quartz, feldspar, pyrite and clay minerals; (f) Well 147 in Ordos Basin; 7th member of the Upper Triassic Yanchang Formation; core; black Shale; organic matter coexisting with pyrite and clay minerals; (g) Well Jin 432 in Songliao Basin; Lower Cretaceous Qingshankou Formation; core; black shale; organic matter coexisting with quartz, feldspar, pyrite and clay minerals; (h) Well Ji 174 in Jimsar Sag, Junggar Basin; Middle Permian Lucaogou Formation; core; black shale; organic matter coexisting with quartz, dolomite and calcite minerals; (i) Coal mine in Qinshui Basin; Lower Permian Shanxi Formation; coal sample; black coal rock; organic matter coexisting with clay minerals such as illite and I/S mixed-layers; (j) Coal mine in Qinshui Basin; Lower Permian Shanxi Formation; coal sample; black coal rock; organic matter coexisting with clay minerals such as kaolinite; (k) Coal mine in Qinshui Basin; Upper Carboniferous Taiyuan Formation; coal sample; black coal rock; organic matter coexisting with calcite; (l) East margin coal mine of Ordos Basin; Lower Permian Shanxi Formation; coal sample; black coal rock; organic matter coexisting with clay minerals such as kaolinite.
Table 2 Comparison of primary parameters of shale oil in China and abroad.
Basin | Geology | Geochemistry | |||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
System | Structure | Sed. background | Formation | Depth/ m | Area/ km2 | Shale thickness/m | Lithology | TOC/ % | S1+S2/ (mg∙g-1) | Ro/ % | Organic matter | ||||||||||
Ordos | Triassic | Slope, sag | Shallow water, Lake basin | Yanchang | 1 500-3 000 | 30 000 | 30-70 | Mud shale | 5.0-16.0 | 6-97 | 0.6-1.1 | Ⅰ, Ⅱ1 | |||||||||
Songliao | Cretaceous | Slope, sag | Shallow water, Lake basin | Qingshankou | 1 000-2 700 | 20 000 | 40-150 | Mud shale | 2.0-3.0 | 5-26 | 0.5-1.2 | Ⅰ, Ⅱ1 | |||||||||
Bohai Bay | Paleogene | Slope, sag | Shallow water, Lake basin | Shahejie | 2 000-4 500 | 20 000 | 100-250 | Mud shale, marl | 3.0-10.0 | 4-20 | 0.5-1.3 | Ⅰ, Ⅱ1 | |||||||||
Junggar | Permian | Slope, sag | Shallow water, Lake basin | Lucaogou | 2 000-4 000 | 3 000 | 100-240 | Calcareous mudstone | 3.0-12.0 | 2-50 | 0.6-1.2 | Ⅱ | |||||||||
Williston | Upper Devonian - Lower Carboniferous | Depression | Continental, marine basin | Bakken | 2 600-3 200 | 50 000 | 5-49 | Shale | 3.0-25.0 | 10-65 | 0.6-0.9 | Ⅱ | |||||||||
Gulf Coast | Cretaceous | Slope | Deep water, shelf | Eagle Ford | 1 000-3 600 | 40 000 | 20-60 | Mud shale | 3.0-7.0 | 0.7-1.4 | Ⅱ | ||||||||||
Permian | Permian | Depression | Deep water, shelf | Wolfcamp, Spraberry | 2 200-3 800 | 520 000 | 20-150 | Shale | 2.2-7.2 | 0.7-1.7 | Ⅱ | ||||||||||
Basin | Reservoir | Fluid | Resource | Production | |||||||||||||||||
Pore | Porosity/ % | Permea- bility/ 10-3 μm2 | Brittle mineral/ % | Pressure coefficient | Oil visco- sity/ (mPa·s) | Oil density/ (g·cm-3) | GOR/ (m3·t-1) | Water saturation/% | Hydrocarbon generation/ 108 t | Geological resources/ 108 t | Initial production/ well/(t∙d-1) | Cumulative production/ well/104 t | |||||||||
Ordos | Nano-pores | 1-3 | < 0.10 | 30-50 | 0.7-0.9 | 5-20 | 0.80-0.85 | 20-100 | 0 | 1 300 | 300-350 | 1-25 | |||||||||
Songliao | Nano-pores | 2-6 | <0.02 | 40-60 | 1.0-1.2 | 20-200 | 0.82-0.85 | 50-100 | 0-15 | 1 160 | 250-300 | 1-8 | 0.5-1.0 | ||||||||
Bohai Bay | Nano-pores | 2-6 | <0.10 | 40-60 | 1.2-1.9 | 10-100 | 0.67-0.86 | 50-130 | 0 | 1 100 | 250-300 | 1-50 | 0.5-2.8 | ||||||||
Junggar | Nano-pores | 1-3 | <0.10 | 60-90 | 1.2-1.5 | 50-120 | 0.87-0.92 | 10-20 | 0 | 200 | 30-50 | 1-20 | |||||||||
Williston | Nano-pores | 4-14 | <1.00 | 50-70 | 1.2-1.5 | 0.81-0.83 | 50-150 | 450 | 570 | 210 | 1.0-5.0 | ||||||||||
Gulf Coast | Nano-pores | 5-10 | <1.00 | 60-90 | 1.3-1.8 | 0.82-0.87 | 200-500 | 5-15 | 400 | ≈ 500 | 200 | 1.0-5.0 | |||||||||
Permian | Nano-pores | 3-12 | <1.00 | 55-85 | 1.0-1.4 | 0.78-0.84 | 100-500 | 15-25 | 1000 | ≈ 1000 | 80 | 1.0-5.7 |
Table 3 Comparison of main parameters of shale gas in China and abroad.
Gas field | Geology | Geochemistry | Fluid | ||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Structure | Sed. background | Formation | Depth/ m | Area/km2 | TOC>2%, shale thickness/m | TOC/ % | Ro/ % | Organic matter | Pressure coefficient | CH4/ % | Gas/ (m3·t-1) | ||||||||||||
Changing | Wide and gentle slope, syncline | Deep water, shelf | Upper Ordovician - Lower Silurian | 2 000- 3 000 | 2 050 | 33-46 | 0.3-7.9 | 2.4-2.8 | Type II | 1.4-2.0 | 96-99 | 1.9-7.8 | |||||||||||
Weiyuan | Wide and gentle slope, syncline | Deep water, shelf | Upper Ordovician - Lower Silurian | 1 600- 2 900 | 1415 | 20-60 | 0.3-8.2 | 1.8-2.3 | Type II | 1.4-2.0 | 96-99 | 2.8-3.9 | |||||||||||
Fuling | Box anticline, serious slippage pay zone | Deep water, shelf | Upper Ordovician - Lower Silurian | 2 000- 4 500 | 600 | 38-44 | 1.5-6.1 | 2.2-3.1 | Type II | 1.5-2.0 | 96-99 | 2.0-5.0 | |||||||||||
Yanchang shale | Wide and gentle slope | Shallow water, lake basin | Upper Triassic | 800- 1 600 | 2 367 | 21-66 | 2.0-10.0 | 0.8-1.2 | Type I, type II1 | 0.7-1.0 | 50-80 | 2.0-8.1 | |||||||||||
Marcellus | Foreland depression and slope, serious slippage pay zone | Deep water, shelf | Middle Devonian | 1 300- 2 600 | Southwest 7,000, Northeast 6,900 | 15-61 | 2.0-10.0 | 1.1-3.0 | Type II, less type Ⅲ | 1.0-1.3 | >95 | 1.7-2.8 | |||||||||||
Gas field | Reservoir | Resource | Production | ||||||||||||||||||||
Pore | Porosity/ % | Matrix porosity/ % | Fracture porosity/% | Permeability/10-3 μm2 | Brittle mineral/ % | Recoverable resource/ 108 m3 | Abundance/ (108 m3∙km-2) | Production/ho- rizontal well/ (104 m3·d-1) | Cumulative production/ 108 m3 | Yearly production/ 108 m3 | |||||||||||||
Changning | Matrix pores and less fractures | 3.4-8.4 | 3.4-8.2 | 0-1.16 | 0.000 22- 0.001 9 | 65-98 | 3 500 | 4.38 | 5.55-27.4 | 0.80-1.00 | 25 | ||||||||||||
Weiyuan | Matrix pores and less fractures | 2.5-9.7 | 3.4-7.9 | 0.000 11- 0.000 6 | 55-98 | 2 300 | 4.00 | 2.30-22.80 | 0.70-1.00 | ||||||||||||||
Fuling | Matrix pores and fractures | 4.6-7.8 | 3.7-5.2 | 0.50-3.30 | 0.05-0.30 | 55-75 | 2000 | 9.92 | 5.90-54.70 | 1.13-2.00 | 60 | ||||||||||||
Yanchang shale | Nano-pores | 0.5-4.0 | < 0.05 | 30-50 | 5 318 | 2.25 | 0.20-1.60 | ||||||||||||||||
Marcellus | Matrix pores and fractures | 6.0-10.0 | 5 | 3.50-4.50 | 0.13- 0.77 | 50-70 | 85 000 | 6.12 | 7.10-76.50 | Southwest 0.60-3.40, northeast 0.60-5.70 | 1 590 |
Table 4 Comparison of main parameters of CBM in China and abroad.
Basin | Geology | Geochemistry | ||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Basin type | Sed. background | Formation | Depth/ m | Area/ km2 | Net coal seams/m | Gas genesis | C1 isotope/ ‰ | Ro/ % | Coal rank | |||||||||
Qinshui | Cratonic | Transitional | Carboniferous-Permian | 300-2 000 | 5 000 | 4-17 | Thermal | -31.95 | 1.5-3.0 | Thin coal, lean coal, anthracite | ||||||||
Ordos | Cratonic | Transitional | Carboniferous-Permian | 600-2 000 | 10 000 | 5-18 | Thermal | -32.41 | 1.2-2.8 | Coking coal, lean coal | ||||||||
Fenhe | Foreland | Swamp | Paleogene | 60-760 | 3 300 | 24-45 | Biogenetic | -62.33 | 0.3-0.4 | Subbituminous coal | ||||||||
San Juan | Foreland | Transitional | Cretaceous | 150-1 200 | 1 900 | 9-21 | Thermal and less biogenetic | -41.12 | 0.3-1.3 | High and low volatile bituminous coal | ||||||||
Basin | Reservoir | Fluid | Resource | Production | ||||||||||||||
Pore | Permeability/ 10-3 μm2 | Pressure coefficient | CH4/% | Gas/ (m3·t-1) | Recoverable resources/ 108 m3 | Abundance/ (108 m3∙km-2) | Production/well/ (104 m3·d-1) | Yearly production/108 m3 | ||||||||||
Qinshui | Nano-pores | 0.01-5.75 | 0.7-0.9 | 98.87 | 4.0-32.0 | 6 064 | 1.2 | 0.2-0.3 | 30.9 | |||||||||
Ordos | Nano-pores | 0.02-16.17 | 0.8-1.0 | 90.80 | 4.0-20.0 | 11 481 | 1.1 | 0.2-0.7 | 10.4 | |||||||||
Fenhe | Nano-pores | 35.00-1 000.00 | 0.9-1.0 | 98.60 | 0.8-1.6 | 6 600 | 2.0 | 0.5-0.6 | 145.0 | |||||||||
San Joan | Nano-pores | 5.00-60.00 | 1.0-1.2 | 97.00 | 10.0-12.7 | 3 800 | 2.0 | 1.0-3.0 | 150.0 |
2.3. Formation mechanism of vertical “sweet sections”
The “sweet section” refers to the source rock section with relatively rich or potential oil and gas accumulation and that can provide high production after stimulation. The study on “sweet section” is one of core tasks to study the geology of source rock oil and gas. The formation of “sweet section” is the result of long-term coupling between the hydrocarbon generation inside the source rock and the reservoir space or medium after long geological evolution (Fig. 5). The formation of the “sweet section” of shale oil is a process that at the peak of oil production, and after the kerogen adsorption is saturated, oil/gas migrates from the oil generation section with rich organic matter and poor permeability to the shale section with poor organic matter and good permeability at a large scale. The “sweet section” generally has better oil/gas-bearing properties and is easier to fracture than the oil generation section. The formation of the “sweet segment” of CBM is a process in which the coal-formed gas is adsorbed, in place, on the surface of the coal seam and forms a gas-rich section with high gas abundance, high formation pressure, and good preservation conditions. The sweet section and the gas generation section are the same. The formation of shale gas “sweet section” is a process of natural gas self-generating and self-storing in the black organic shale. The “sweet section” generally has high TOC, abundant joints and pores, high content of free gas, overpressure developed natural fractures, and better top and bottom plates sealing conditions (Fig. 5). The “sweet section” is generally thin, for example the shale gas “sweet section” from the Ordovician Wufeng Formation to the Silurian Longmaxi Formation is a graptolite-rich shale section 20-40 m thick and formed within 6.85 Ma. The identification of “sweet sections” plays a crucial role in targeting the source rock oil and gas layer, the selection of geophysical methods, the evaluation of the resource scale in the “sweet area”, the horizontal section and the determination of stimulated intervals.
Fig. 5.
Fig. 5.
Forming mechanism of source rock oil “sweet sections”.
2.4. Laternal distribution of “sweet areas”
The source rock “sweet area” refers to the relatively high- yield and enrichment area distributed in the favorable source rock, and that can be industrially improved by artificial stimulation. The “sweet area” of source rock oil and gas is generally distributed continuously in the stable structures in basin centers and slopes. The “sweet area” of shale gas is generally located in the organic-rich shale area in a semi-deep, deep, isolated and anoxic environment. For example, three “sweet areas”—Jiaoshiba, Changning-Zhaotong, and Weiyuan—have been identified in the Wufeng Formation-Longmaxi Formation in the middle and upper Yangtze Region in South China. The “sweet area” of CBM is generally located in the syncline of the coal-bearing basin at medium to high ranks, such as the San Juan Basin in the United States and the Qinshui Basin in China. The “sweet area” of shale oil is generally located in the semi-deep, deep, organic-rich shelf shale area, and semi-deep, deep, lacustrine, organic-rich shale area. In China, the shale oil is mainly rich in organic matter with low to medium maturity, at lake basin centers. The selection of “sweet area” is a core part of geological evaluation and development plan of source rock oil and gas.
In addition, it should be noted that source rock “sweet areas (sections)” have rich connotations, mainly including three aspects. “Geological sweet areas (sections)” focus on comprehensive evaluation involving the characteristics of oil and gas occurrence, the distribution of organic-rich source rocks, the distribution of top and bottom plates, natural fractures and formation energy. “Engineering sweet areas (sections)” focus on comprehensive evaluation involving the lateral continuity of target intervals, formation fractureability, and geostress anisotropy. “Economic sweet areas (sections)” pay attention to comprehensive evaluation involving the buried depth of target intervals, the scale of recoverable oil and gas resources, surface conditions and infrastructure. “Geological sweet areas (sections)” refer to the target zones (sections) where unconventional source rock oil and gas are relatively rich and high in production in the developed source rock, which can be explored and developed first under the current economic and technical conditions. Using available horizontal well volume fracturing, platform “factory” operation and other technologies, the “higher resource abundance zones (sections)” of shale gas, CBM and shale oil with medium to high maturity are generally deemed favorable zones (sections) which are thick, stable and distributed continuously, with relatively high porosity and permeability, good preservation conditions and tectonic background. These are geological properties for evaluating “sweet areas (sections)”. Under potential technical conditions, using underground in-situ heating conversion, the "sweet areas (sections)" of oil shale oil and shale oil with medium to low maturity are organic-rich shale sections which have large thickness, high organic matter abundance, stable and continuous distribution, shallow burial, and top and bottom plates with good sealing abilities. “Engineering sweet areas (sections)” mean “man-made permeability zones (sections)”, generally favorable zones (sections) with developed fractures, high content of brittle minerals and small horizontal stress difference. These are "engineering properties for evaluating “sweet areas” (sections).
The “sweet sections” of source rock oil and gas include “geological, engineering and economic sweet areas (sections)”. And only these three “sweet areas (sections)” match well and superimpose with each other, the resources can be developed effectively. “Geological sweet areas (sections)” focus on the quality of source rock (for volume fracturing on shale oil and gas, the Ro should be 0.9% to 3.5%, the TOC should be greater than 2%; for in-situ heating conversion on shale oil, the Ro should be 0.5% to 0.9%, the TOC should be greater than 6%), reservoir capacity (the porosity of shale oil and gas should be greater than 3%), seepage capacity (formation pressure, permeability, natural fractures, oil and gas quality, etc.), resource abundance (the oil/gas saturation should be greater than 50%; the resource abundance should be greater than 2 × 105 t∙km-2), resource scale (the resources should be greater than 1 × 108 tons, and two years of cumulative production per well should be greater than 2.0 × 104 tons of oil/gas equivalent). “Engineering sweet areas (sections) focus on rock brittleness (the brittle minerals in shale should be greater than 40%), anisotropy (the horizontal stress difference should be less than 10 MPa), burial depth (less than 3500 m), surface conditions (infrastructure, hydroelectric power supply, transportation). “Economic sweet areas (sections)” focus on changes in oil prices, market mechanisms (engineering services companies, pipeline companies, sales companies, etc.), management methods (seamless chains of development, operation, transportation, sales, etc.), policies (finance and fund for R&D of new technology), environmental protection (Environmental Protection Act, green operation).
In short, source rock oil and gas have two basic characteristics: extensive and continuous distribution, and low resource abundance; no natural industrial production, but production to be obtained by artificial stimulation. Therefore, “to find oil/gas inside the source rock” means to find “higher resource abundance zones (sections)” and those easy to induce “man-made permeability”. Based on favorable resources areas, and available and potential economic and technical conditions, evaluation and selection of “sweet areas (sections)” is the core task of “ to find oil/gas inside the source rock”, and should be carried out throughout the whole process of exploration and development.
3. Development prospects and challenges of “source rock oil and gas”
3.1. Resource basis
Source rock oil and gas resources are quite abundant. Source rock oil accounts for 25% of the total recoverable oil resources all over the world, including 2 080×108 tons for shale oil and 1 051×108 tons for oil shale oil. Source rock natural gas is 1.5 times the total conventional natural gas recoverable resources, including shale gas of 456 × 1012 m3, and CBM 256 × 1012 m3[7, 11-14]. The formation and development of sedimentary basins in China have undergone two evolutionary stages—the Paleozoic marine facies and the Mesozoic and Cenozoic continental facies, and the geological conditions for the formation of source rocks are better (Fig. 6). China's oil shale oil recoverable resources are 131.80×108 tons, shale gas recoverable resources are 12.85×1012 m3, and CBM recoverable resources are 12.51×1012 m3. It is predicted that underground in-situ heating conversion may bring recoverable resources of (700-900)×108 tons and natural gas of about (60-65)×1012 m3 from the organic-rich shale with medium to low maturity[10], and recoverable resources more than 200 × 108 tons from the shale oil with medium to high maturity by volume fracturing in horizontal wells.
Fig. 6.
Fig. 6.
Distribution of favorable “source rock oil and gas” resources on land in China.
3.2. Disciplinary significance
After the discovery of Daqing Oilfield in 1959, according to the practical experience from the Songliao Basin, Chinese petroleum ancestors summarized the theory that oil and gas migrated in a short distance, and the oil source area controlled the distribution of oil and gas fields, referred to as the “source control theory”, and proposed the exploration idea of “selecting favorable belts in defined sags”[37]. In the past 60 years, adhering to the “source control theory”, oil and gas exploration in China has always followed the principle of looking for favorable conventional oil and gas fields in the hydrocarbon supply range based on major hydrocarbon generation sags, and many oil and gas fields have been discovered in eastern Mesozoic and Cenozoic continental and marine fault basins, western Mesozoic cratonic and foreland basins, and even foreign oil and gas basins[38,39].
The geology of source rock oil and gas is a new development of the “source control theory” in the unconventional oil and gas stage. It is an important part of the unconventional oil and gas geology, and an emerging discipline that is booming and needs to be continuously summarized and improved. Following the principle of “exploring petroleum inside source kitchen”, the development of source rock oil and gas in North American is getting better and better. The development of source rock oil and gas in China and other several countries is just beginning, but that in many regions all over the world is still slow. The changing geological conditions and harsh technical requirements determine the theoretical and technological progress and overall development of source rock oil and gas in the world is a long-term process. Large conventional-unconventional oil and gas “coexisting basin” is the major area for developing source rock oil and gas, which has rich resource, high exploration degree, deep geology understanding and geophysics exploration data, etc. As scientists working on the development of oil and gas, and focusing on the actual geological conditions in China, it is our task to keep thinking and summarizing the geology theory of source rock oil and gas in China with long-term persistence and continuous innovation and develop foreign source rock oil and gas. The geology of source rock oil and gas will provide a new theoretical basis for following and promoting the new journey in the upstream field of the post-industry era.
3.3. Development challenges and prospects
Source rock oil and gas still faces challenges in geological recognition and innovation, effective evaluation on sweet areas/sections, drilling and production technologies, cost reduction and profit increase. Geological research includes characterization of source rock oil and gas occurrence, recovery of fluid migration and accumulation process, and revealing oil and gas distribution law. Evaluation on sweet areas/sections includes the description of the nano-pores and fractures system, the establishment of a reservoir evaluation system, and the search for enrichment sweet areas/sections. Drilling and production technologies include the development of rotary-steering drilling technology, and breaking the bottlenecks in core technologies. Economic evaluation involves cost reduction and profit increase, large-scale production, and strategic resource replacement plan. Development technologies for inducing “man-made fractures” or building “man- made energy field” and constructing “man-made oil and gas reservoirs” are important for the large-scale and economic development of source rock oil and gas (Fig. 7).
Fig. 7.
Fig. 7.
Primary technologies for source rock oil and gas development.
Source rock oil and gas development in China faces many problems. For the development of shale gas, problems lie in complex surface conditions, deep burial, poor water source conditions, imperfect pipeline network and facilities, difficult engineering technology below 3 500 m, high thermal evolution of Cambrian shale, no breakthrough in normal shale gas, and no breakthrough in transitional shale gas. Problems in the development of CBM include complex gas and water distri- bution, unclear enrichment law, unavailable technology below 800 m, and difficult reservoir stimulation. Problems in the development of shale oil include strong heterogeneity of mud shale, high content of clay mineral, low maturity of organic matter, poor fluidity of crude oil, and unsuitable application of horizontal well fracturing technology.
Recommendations on the development of source rock oil and gas in China: (1) Continue innovative research on the geology theory of source rock oil and gas. At present, the formation mechanism and distribution law of shale oil are still in the exploratory stage. The “sweet areas” and “sweet sections” with continuously distributed oil and gas still need to be verified repeatedly. The innovative research on the geological theory is still the means to guide the future development of source rock oil and gas. (2) Establish three types of development test areas. A technological breakthrough test area will study key development technologies such as for shale oil in the 7th member of the Triassic Yanchang Formation in the Ordos Basin. An enhanced oil recovery test area will make breakthrough in key production technologies such as for CBM. A cost reduction and profit increase test area will implement integrated low-cost and large-scale development of shallow shale gas in southern Sichuan Basin. (3) Invest on bottleneck technology. Efforts will be made to strengthen the technical research on three types of bottlenecks that restrict the development of source rock oil and gas. Core technologies will be strengthened, including precise underground drilling, fine seismic modeling, geo-steering vertical and fast drilling, rotatory-steering drilling in horizontal wells. Deep shale oil and gas reservoirs will be stimulated, especially “well factory” fracturing in the shale interval 3 500-4 500 m deep. Pilot tests on in-situ heating conversion and non-water fracturing stimulation will be carried out to develop shale oil, and “shale oil revolution” will be realized in continental shale in China. (4) Promote national policy support for source rock oil and gas. The sustainable development of unconventional source rock oil and gas in the United States depends on the long-term stable national policy support, which is worth learning.
Source rock oil and gas resources have a great potential and have broad development prospects. Just as the conventional-unconventional “coexistent basins” in North America such as Appalachian, Permian, Gulf Coast, Williston where rapid development of the source rock oil and gas is going on, in the large conventional-unconventional “coexistent basins” in another more than 10 mature exploration areas, such as Central Arabia, West Siberian and Zagros in Middle East, Central Asia-Russia, Africa, South America and Australia, the source rock oil and gas will see a “golden period” of development in the future. In China, source rock oil will be the main contributor to the stable development of oil in the future; source rock gas will be the growth point of natural gas production; and it is estimated that the production of source rock oil and source rock gas will account for 15% and 30% respectively in 2030, “coexistent basins” like Ordos Basin and Sichuan Basin will make great contribution. It should be further increase the development of source rock oil and gas, promote and accelerate China's source rock oil and gas revolution, and lead source rock oil and gas to become important weights in the energy transformation stage and ensure China's basic energy security.
4. Conclusions
Source rock oil and gas are continuous resources that are generated in source rocks, and then retained or accumulated inside or near the source rocks, and can be produced by new technology. The primary task of “exploring petroleum inside source kitchen” means to find “sweat areas (sections)”, and developing retained hydrocarbon and transformed organic matter. The geology of source rock oil and gas is a new development of the “source control theory” in the unconventional oil and gas stage, and is an important part of the geology of unconventional oil and gas.
As a strategic field of global oil and gas supply, source rock oil and gas has seen four advances. (1) The geology connotation of source rock oil and gas was proposed as a geological discipline for studying the hydrocarbon generation model, formation mechanism, distribution law, production mechanism and development strategy of source rock oil and gas; the models of hydrocarbon generation, drainage and retention were established for source rock oil and gas; it was pointed out that five source rock oil and gas generation sections determined the actual resource potentials under available technical conditions. (2) The formation mechanism of source rock “sweet sections” was analyzed; it’s proposed that “sweet areas” should be considered in terms of geological, engineering and economic aspects; and the evaluation and selection of “sweet areas (sections)” is the core part of the principle of “exploring oil and gas inside source rocks”. (3) Conventional and unconventional oil and gas “coexistent basins” all over the world are major fields for the development of source rock oil and gas, and have broad development prospects. It is expected that China’s source rock oil and gas production will account for 15% and 30% respectively in 2030. (4) To promote the development of source rock oil and gas, recommendations were proposed, involving theoretical innovation, technical research, development pilot areas, and policy support.
At present, the development of source rock oil and gas also faces a series of basic theoretical and technical problems such as individual types of source rock oil and gas. At the same time, solar energy, energy storage, hydrogen energy and other new energy development, geopolitical economy, etc. have profoundly affected the fossil energy development process and production. In the future, the production of source rock oil and gas will change with the reform of fossil and non-fossil energy. This is an irreversible development trend of energy revolution.
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The discovery of the giant Anyue gas field in Sichuan Basin gives petroleum explorers confidence to find oil and gas in Proterozoic to Cambrian. Based on the reconstruction of tectonic setting and the analysis of major geological events in Mesoproterozoic-Neoproterozoic, the petroleum geological conditions of Proterozoic to Cambrian is discussed in this paper from three aspects, i.e. source rocks, reservoir conditions, and the type and efficiency of play. It is found that lower organisms boomed in the interglacial epoch from Mesoproterozoic-Neoproterozoic to Eopaleozoic when the organic matters concentrated and high quality source rocks formed. Sinian-Cambrian microbial rock and grain-stone banks overlapped with multiple-period constructive digenesis may form large-scale reservoir rocks. However, because of the anoxic event and weak weathering effect in Eopaleozoic-Mesoproterozoic, the reservoirs are generally poor in quality, and only the reservoirs that suffered weathering and leaching may have the opportunity to form dissolution-reconstructed reservoirs. There are large rifts formed during Mesoproterozoic-Neoproterozoic in Huabei Craton, Yangtze Craton, and Tarim Craton in China, and definitely source rocks in the rifts, while whether there are favorite source-reservoir plays depends on circumstance. The existence of Sinian-Cambrian effective play has been proved in Upper Yangtze area. The effectiveness of source-reservoir plays in Huabei area depends on two factors:(1) the effectiveness of secondary play formed by Proterozoic source rock and Paleozoic, Mesozoic, Cenozoic reservoir rocks;(2) the matching between reservoirs formed by reconstruction from MesoproterozoicNeoproterozoic to Eopaleozoic and the inner hydrocarbon kitchens with late hydrocarbon generation. As for Tarim Basin, the time of Proterozoic and the original basin should be analyzed before the evaluation of the effective play. To sum up, Proterozoic to Cambrian in the three craton basins in China is a potential exploration formation, which deserves further investigation and research.
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Connotation and strategic role of in-situ conversion processing of shale oil underground in the onshore China
,In-situ conversion processing (ICP) of shale oil underground at the depth ranging from 300 m to 3 000 m is a physical and chemical process caused by using horizontal drilling and electric heating technology, which converts heavy oil, bitumen and various organic matter into light oil and gas in a large scale, which can be called"underground refinery". ICP has several advantages as in CO2capture, recoverable resource potential and the quality of hydrocarbon output. Based on the geothermal evolution mechanism of organic materials established by Tissot et al., this study reveals that in the nonmarine organic-rich shale sequence, the amount of liquid hydrocarbon maintaining in the shale is as high as 25%in the liquid hydrocarbon window stage (R o less than 1.0%), and the unconverted organic materials (low mature-immature organic materials) in the shale interval can reach 40%to 100%. The conditions of organic-rich shale suitable for underground in-situ conversion of shale oil should be satisfied in the following aspects, TOC higher than 6%, R o ranging between 0.5%and 1%, concentrated thickness of organic-rich shale greater than 15 meters, burial depth less than 3 000 m, covering area bigger than 50 km2, good sealing condition in both up-and down-contacting sequences and water content smaller than 5%, etc. The shale oil resource in China onshore region is huge. It is estimated with this paper that the technical recoverable resource reaches 70-90 billion tons of oil and 60-65 trillion cubic meters of gas. The ICP of shale oil underground is believed to be a fairway to find big oil in the source kitchen in the near future. And it is also believed to be a milestone to keep China long-term stability of oil and gas sufficient supply by putting ICP of shale oil underground into real practice in the future.
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Tight gas reservoirs refer to the tight sandstone fields or traps accumulating natural gas of commercial values.According to reservoir characteristics,reserves,and structural height,they can be divided into two types,continuous-type and trap-type: the former are located at the lower part of the structure and have indistinct trap boundaries,inconsistent gas-water boundaries and reversal of gas and water,and their reservoirs are the same as or near the source;the latter are located at the higher part of the structure,with gas above water in traps,low reserves,and relatively high production.Tight gas in China is all coal-derived,dominantly alkane gases(C1 4),in which the amount of methane is greatest and the alkane gases have positive carbon isotopic series.The content of non-hydrocarbon gases(mainly CO2and N2) is low.At the end of 2010,the reserves and annual production of tight gas in China accounted for 39.2% and 24.6% of the total natural gas,respectively,and the proportions are expected to increase.Compared to the shale gas and coalbed gas,tight gas should be considered in priority in the exploration and exploitation of unconventional gas in China.
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Characterization of micro-nano pore networks in shale oil reservoirs of Paleogene Shahejie Formation in Dongying Sag of Bohai Bay Basin, East China
,DOI:10.1016/S1876-3804(17)30083-6 URL
For typical blocky,laminated and bedded mudrock samples from the Paleogene Shahejie Formation in the Dongying Sag of Bohai Bay Basin,this work systematically focuses on their structure characterization of multiple micro-nano pore networks.A use of mercury injection capillary pressure (MICP) documented the presence of multiple μm-nm pore networks,and obtained their respective porosity,permeability and tortuosity.Different sample sizes (500-841 μm GRI fractions,1 cm-sized cubes,and 2.54 cm in diameter and 2-3 cm in height core plugs) and approaches (low-pressure N_2 gas physisorption,GRI matrix permeability,MICP,heliumpy cnometry,and pulse decay permeameter) were used to measure pore size distribution,porosity and permeability.The average porosity and matrix permeability determined from MICP are (6.31±1.64)% and (27.4±31.1)×10~(-9) μm~2,the pore throat diameter of pores is mainly around 5 nm,and the median pore throat diameter based on 50% of final cumulative volume is (8.20±3.01) nm in shale.The pore-throat ratios decrease with a decrease of pore size diameter.Moreover,the permeability of shale samples with lamination is nearly 20 times larger than matrix permeability.The geometrical tortuosity of the nano-scale 2.8-10.0 nm pore networks is 8.44 in these shales,which indicates a poor connectivity of matrix pore network and low flow capability.Overall,the variable and limited pore connectivity of shale samples will affect hydrocarbon preservation and recovery.
Mississippian Barnett Shale: Lithofacies and depositional setting of a deep-water shale-gas succession in the Fort Worth Basin, Texas
,DOI:10.1306/11020606059 URL [Cited within: 1]
Pore-throat sizes in sandstones, tight sandstones and shales
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Geochemical evidence for oil and gas expulsion in Triassic lacustrine organic-rich mudstone, Ordos Basin, China
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Controlling factors on the enrichment and high productivity of shale gas in the Wufeng-Longmaxi Formations, southeastern Sichuan Basin
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Classification and evaluation criteria of shale oil and gas resources: Discussion and application
,DOI:10.1016/s1876-3804(12)60042-1 URL
Research on the evaluation criteria of shale oil and gas is conducted to accurately assess the resource potential of shale oil and gas. Statistic analysis of the geochemical index of hydrocarbon source rocks in five areas such as Songliao, Hailaer, Jiyang, based on the characteristic of triple-division between the oil content and TOC of source rock, suggests that shale oil and gas can be categorized into three levels of resource enrichment: scattered (ineffective) resources, low efficient resources and enriched resources. The mature stage, at which organic matter generates oil and gas in large amounts, corresponds to the shale oil and gas enrichment window. Furthermore, recoverable index is defined and its computation formula is proposed to provide a quantitative index for recoverability evaluation, considering the brittle mineral content, thickness and depth of shale, etc. In practice, TOC variable values in well profile obtained by TOC-logging correspondence can be used to draw TOC isopach maps and calculate the amount of resources at different levels. Then combined with the evaluation criteria, TOC and Ro isopach maps are superimposed to identify the favorable shale oil and gasareas.
Characteristics of Meso- Cenozoic thermal regimes in typical estern and western sedimentary basins of China
,DOI:10.13745/j.esf.2015.01.013 URL
The thermal regime and thermal history of sedimentary basins play an important role in basin dynamics and hydrocarbon accumulation.The sedimentary basins in the western and eastern China underwent different tectonic background and dynamic mechanism,which resulted in the differentials of their thermal regimes.In this paper,the Meso-Cenozoic thermal regimes of the Bohai Bay Basin in the eastern China and Tarim Basin in the western China were studied based on the thermal history,"thermal"lithosphere and lithospheric thermal structure,and the results show that the thermal regimes in these two basins underwent different evolution since the Mesozoic.The heat flow of the Bohai Bay Basin underwent two peak evolution phases occurred in the Early Cretaceous to the early Late Cretaceous(K1-K12)and the Eocene-Oligocene(E2-E3)respectively,while the heat flow in the Tarim Basin gradually decreased from the Mesozoic to the Cenozoic.Two rapidly thinning processes of the"thermal"lithosphere in the Bohai Bay Basin occurred in the Late Early Cretaceous and the Paleocene,and its minimum thickness was only 43-55 km in the Paleocene.However,the thickness of the"thermal"lithosphere in the Tarim Basin increased slowly in the Mesozoic and then rapidly since the Paleocene.The ratio of crust to mantle heat flow revealed that the lithospheric thermal structure of the Bohai Bay Basin was divided into two phases:"cold mantle and hot crust"type during the Triassic-Jurassic but"hot mantle and cold crust"type since the Cretaceous,while that of the Tarim Basin always stayed in the"hot mantle and cold crust"phase and then transferred to"cold mantle and hot crust"phase since the end of the Neocene.The differences of the lithoshperic thermal structures and thermal conditions between these two basins were closely related to the thermal-rheological structure and deformation of the lithosphere.The research on the thermal history and lithospheric thermal structure of the sedimentary basins could effectively reveal the thermal regime in the deep of the sedimentary basins and provide scientific reference for studying the basin dynamic mechanism during the Meso-Cenozoic.
Oil retention and porosity evolution in organic-rich shales
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The Barnett Shale: Compositional fractionation associated with intraformational petroleum migration, retention, and expulsion
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Exploration potential of shale gas resources in China
,Shale gas is a kind of unconventional natural gas which mainly exists as adsorbed and free gas in shales.Shale gas or gas shale is extensively variable on the genetic mechanism,existing phase,accumulation mechanism,distribution variation,and relationship with other kinds of gas reservoirs.Since the boundary conditions for shale gas accumulation can be broadened moderately and the variation can be very extensive,every geological element for gas accumulation in shales is of obvious complementarity with each other.Based on geology analysis,logging data and seismic study,shale gas accumulations can be rapidly recognized.It demonstrates that there exist favorable geological conditions for regional distribution of shale gas in China,of which the primarily assessed resources of shale gas is about 15-30 tcm.The most profitable regions are South and Northwest China,including the Ordos basin and vicinage basins.Among the regions,the resource of shale gas in Paleozoic is the largest,while the second is in Mesozoic.
Nano-hydrocarbon and the accumulation in coexisting source and reservoir
,DOI:10.1016/S1876-3804(12)60011-1 URL
By comparison of the types, geological characteristics and exploration technologies of conventional and unconventional hydrocarbon, this paper proposes the concept of “nano-hydrocarbon” and regard nano-hydrocarbon as the development direction of oil and gas industry in the future. Nano-hydrocarbon refers to the research and production, by nano-technology, of oil and gas accumulated in the reservoir system of nano-sized pore-throats. It is mainly distributed in source rocks and the neighbouring tight reservoirs and includes shale oil, shale gas, coal-bed methane, tight sandstone oil and gas, tight limestone oil and so on, with nano-sized diameter of pore-throats in reservoirs. Oil, gas and water in nano-sized pore-throats exhibit poor percolation and phase separation, and are mainly driven by ultra-pressure, thus existing pervasively and continuously in the coexisting tight source and reservoir rocks. China's petroliferous basins develop multiple series such as coexisting tight source and reservoir, carbonate fractures and cavities, volcanic fractures and cavities, and metamorphic rock fractures. Among the series, the first type is located in the center or on the slopes of the basins, where nano-hydrocarbons are accumulated extensively within or near sources and are dominant potential sources. With accumulations within coexisting source and reservoir in the Ordos Basin and Sichuan Basin as examples, the method of “two lines and one area” to prospect continuous-type hydrocarbon accumulation is proposed, i.e. the top and bottom boundaries of a set of coexisting source and reservoir and the boundaries of hydrocarbon accumulation as lines, and “sweet spot” distributing core area as the main exploration target.
Formation mechanism, geological characteristics and development strategy of nonmarine shale oil in China
,DOI:10.1016/S1876-3804(13)60002-6 URL
As an important type of “conventional–unconventional orderly accumulation”, shale oil is mature oil stored in organic-rich shales with nano-scale pores. This paper analyzes and summarizes elementary petroleum geological issues concerning continental shale oil in China, including sedimentary environment, reservoir space, geochemical features and accumulation mechanism. Mainly deposited in semi-deep to deep lake environment, shale rich in organic matter usually coexists with other lithologies in laminated texture, and micron to nano-scale pores and microfractures serve as primary reservoir space. Favorable shale mainly has type I and IIA kerogens with a Ro of 0.7%–2.0%, TOC more than 2.0%, and effective thickness of over 10 m. The evolution of shale pores and retained accumulation pattern of shale oil are figured out. Reservoir space, brittleness, viscosity, pressure, retained quantity are key parameters in the “core” area evaluation of shale oil. Continuously accumulated in the center of lake basins, continental shale oil resources in China are about 30×108–60×108 t by preliminary prediction. Volume fracturing in horizontal wells, reformation of natural fractures, and man-made reservoir by injecting coarse grains are some of the key technologies for shale oil production. A three step development road for shale oil is put forward, speeding up study on “shale oil prospective area”, stepping up selection of “core areas”, and expanding “test areas”. By learning from marine shale breakthroughs in North America, continental shale oil industrialization is likely to kick off in China.
Formation condition and “sweet spot” evaluation of tight oil and shale oil
,Liquid hydrocarbons in shale strata include two kinds of resources, i.e. tight oil and shale oil. Based on the exploration and research progress of liquid hydrocarbons in shale at home and abroad, their formation condition, accumulation mechanism, classification, and differences between lacustrine and marine shale systems are examined, and "sweet spots" are evaluated further. Analysis on the geological characteristics of the liquid hydrocarbons in the shale strata in North America and China shows the liquid hydrocarbons have two basic features: large-scale continuous distribution and no stable industrial production. The massive accumulation of the liquid hydrocarbons needs four fundamental formation conditions: stable tectonic background, widespread high quality source rocks, large-scale tight reservoirs with massive reservoir space, and co-existence of source and reservoir. The study reveals the formation mechanisms of the liquid hydrocarbons: source-reservoir coupling and porosity decrease during the diagenetic tightness; and identifies 24 kinds in 6 categories of the liquid hydrocarbons. It is concluded that the geological conditions of the lacustrine shales in China are characterized by lower thermal gradient and stronger heterogeneity than those of North America, so large scale "sweet spots" have to be picked out to push up industrial production steadily. "Sweet spots" evaluation should consider the three aspects of geology, engineering and economics comprehensively, and the maturity of source rocks is first and foremost factor controlling the "sweet spot" distribution. In China, prospective shale areas should meet the following conditions: the Ro between 0.8% and 1.3%, TOC higher than 2%, laminated shales or tight porous reservoirs, higher porosity(more than 8% for tight oil, and more than 3% for shale oil), higher content of brittle minerals(more than 70% for tight oil, and more than 40% for shale oil), oil saturation of 50%-90%, lower crude oil viscosity or higher formation pressure, and rich natural fractures. Liquid hydrocarbons in shale strata are huge in resource scale, so deepening the geological understanding on the formation and distribution of liquid hydrocarbons in marine and lacustrine shales constantly is of great significance for exploration and development of this important field.
Modeling of the whole hydrocarbon-generating process of sapropelic source rock
,Based on experimental data from hydrocarbon generation with a semi-open system, hydrocarbon generation kinetics modeling in gold tube of closed system, high temperature pyrolysis chromatography mass spectrometry experiment with open system and geological data, the characteristics of whole hydrocarbon-generating process, hydrocarbon expulsion efficiency and retained hydrocarbon quantity, origins of natural gas generated in high-over mature stage and cracking temperature of methane homologs were investigated in this study. The sapropelic source rock has a hydrocarbon expulsion efficiency of 30%6160% and 60%6180% in the major oil generation window (with R o of 0.8%611.3%) and high maturity stage (with R o of 1.3%612.0%) respectively; and the contribution ratio of kerogen degradation gas to oil cracking gas in total generated gas in high maturity stage is about 1:4. The degradation gas of kerogen accounts for 20%, the retained liquid hydrocarbon cracking gas accounts for 13.5%, and the amount of out-reservoir oil cracking gas (including aggregation type and dispersed oil cracking gas) accounts for 66.5%. The lower limit of gas cracking is determined preliminarily. Based on the new understandings, a model of the whole hydrocarbon-generating process of source rock is built.
Study on the models of hydrocarbon generation and expulsion from various source rocks in coal-bearing environments
,Using new technologies such as the thermo-pressure simulation experiment and hydrocarbon geochemistry, the hydrocarbon generation and expulsion models for various source rocks in coal-bearing environments were studied in detail on the bases of the systematic analysis and summarization of a number of geochemical and geological data. There are dramatic differences in hydrocarbon generation potential among dark mudstone, carbargillite and coal in coal-bearing environments. The coal and carbargillite formed in shore swamp are better than the mudstone, but the mudstone formed in relative deep to shallow lacustrine (sea) is better than the coal. Nine hydrocarbon generation and expulsion models for four organic matter types and two main rocks in coal-bearing environments were established, and the models were tested byreal geological profiles. The ability of hydrocarbon expulsion for mudstone with type Ⅲ1-Ⅱ1 organic matter is in an advantageous position comparing with coal and carbargillite in coal-bearing environments.
Effective oil expulsion threshold of argillaceous source rocks and geological significance of shale oil
,DOI:10.3969/j.issn.1673-5005.2018.01.004 URL
A method of determining the effective hydrocarbon expulsion threshold was carried out by a series of simulation experiments on immature-low mature source rocks of different types and organic carbon content,and the geological significance to shale oil exploration were discussed.The results show that the minimum oil production is 5-8 mg/g(oil/rock) when the effective oil expulsion occurrs.Effective hydrocarbon expulsion threshold is controlled by the match of type,abundance and evolution of organic matter.Source rocks with original organic matter content less than 1.5% of type I,2.0% of type 1,2.5% of type 2,respectively,can not reach the effective oil expulsion threshold in the whole oil generation stage.The remaining oil in the source rock strata would be as a favorable target for shale oil exploration.The poor exploitation prospect is due to the low degree of evolution and low quality,so the in-situ heating conversion mining technology could be a good way to develop this part of shale oil resources.The exploration and development of shale oil should focus on source rock strata where effective oil expulsion has occurred and evolution degree(Ro) is between 1.0%-1.3%.In these locations,there are more light oil and natural gas in detained hydrocarbon,and the high gas oil ratio and good fluidity imply optimistic mining prospect.
Pore and pore network evolution of Upper Cretaceous Boquillas (Eagle Ford- equivalent) mudstones: Results from gold tube pyrolysis experiments
,DOI:10.1306/04151615092 URL [Cited within: 1]
Organic matter-hosted pore system, Marcellus formation (Devonian), Pennsylvania
,DOI:10.1306/07231212048 URL [Cited within: 2]
Source bed controls hydrocarbon habitat in continental basins, east China
,DOI:10.7623/syxb198202002 URL [Cited within: 1]
Oil basins in East China are depressions grown up on the basement of different ages, characterized by three principle features: (1) blockfaulting structures, (2)continental deposit, (3)isolation of sedimentary depressions. As early as 1961, while conducting prospecting in the Songliao Basin, we summed up that oil and gas migration is of short distance, generally less than 50 KM, oil and gas generation region mainly controls the distribution of oil and gas pool, and this rule has been time and again verified and developed. Later exploration in Huabei, Nanyang, Jianghan, Liaoho, Subei and other depressions, supported our idea that major oil and gas fields are mostly distributed in areas favourble for oil generation.
Research on the appliance extent of “source control theory” by semi-quantitative statistics characteristics of oil and gas migration distance
,In order to clear the appliance extent of “Source Control Theory”, 200 basins, sags and the oil-gas migration distance of oil-forming system are researched and the semi-quantitative statistics analysis of oil-gas migration distance is conducted. It is discovered that most of areas are of the characteristics of “short distance migration” and only 10%—20% migration distance of them are more than 70 km. The kernel content of “Source Control Theory” is that oil-gas migration distance is short. So, it is considered that “Source Control Theory” is of wide appliance extent: ① the theory can be applied to greater part of China, which is proved by the exploration practices of Songliao Basin, east China, west China and offshore areas; ② it is proved by data that the theory is of wide applicability in most areas abroad.
Significant progress of continental petroleum geology theory in basins of Central and Western China
,DOI:10.1016/S1876-3804(18)30001-6 URL [Cited within: 1]
The discovery of the giant Anyue gas field in Sichuan Basin gives petroleum explorers confidence to find oil and gas in Proterozoic to Cambrian. Based on the reconstruction of tectonic setting and the analysis of major geological events in Mesoproterozoic-Neoproterozoic, the petroleum geological conditions of Proterozoic to Cambrian is discussed in this paper from three aspects, i.e. source rocks, reservoir conditions, and the type and efficiency of play. It is found that lower organisms boomed in the interglacial epoch from Mesoproterozoic-Neoproterozoic to Eopaleozoic when the organic matters concentrated and high quality source rocks formed. Sinian-Cambrian microbial rock and grain-stone banks overlapped with multiple-period constructive digenesis may form large-scale reservoir rocks. However, because of the anoxic event and weak weathering effect in Eopaleozoic-Mesoproterozoic, the reservoirs are generally poor in quality, and only the reservoirs that suffered weathering and leaching may have the opportunity to form dissolution-reconstructed reservoirs. There are large rifts formed during Mesoproterozoic-Neoproterozoic in Huabei Craton, Yangtze Craton, and Tarim Craton in China, and definitely source rocks in the rifts, while whether there are favorite source-reservoir plays depends on circumstance. The existence of Sinian-Cambrian effective play has been proved in Upper Yangtze area. The effectiveness of source-reservoir plays in Huabei area depends on two factors:(1) the effectiveness of secondary play formed by Proterozoic source rock and Paleozoic, Mesozoic, Cenozoic reservoir rocks;(2) the matching between reservoirs formed by reconstruction from MesoproterozoicNeoproterozoic to Eopaleozoic and the inner hydrocarbon kitchens with late hydrocarbon generation. As for Tarim Basin, the time of Proterozoic and the original basin should be analyzed before the evaluation of the effective play. To sum up, Proterozoic to Cambrian in the three craton basins in China is a potential exploration formation, which deserves further investigation and research.
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