scholarly journals Source rock investigations and shallow core drilling in central and western North Greenland

1986 ◽  
Vol 130 ◽  
pp. 17-23
Author(s):  
F.G Christiansen ◽  
O Nykjær ◽  
H Nøhr-Hansen
Keyword(s):  
Source Rock ◽  
Field Work ◽  
Geological Mapping ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Fully Integrated ◽  
Rock Quality ◽  
Lithostratigraphic Units ◽  
Field Season ◽  
North Greenland

The aim of project 'Nordolie' (Christiansen & Rolle, 1985) is to study the distribution and maturity of potential hydrocarbon source rocks in central and western North Greenland. A first broad reconnaissance and examination of most lithostratigraphic units throughout the region in 1984, followed by organic geochemical and palynofacies analyses, showed that some intervals in the Cambrian shelf sequence and in the Cambrian to Silurian trough sequence are sufficiently rich in organic matter to be considered as potential source rocks (Christiansen et al., 1985). The Cambrian and Ordovician trough sequence is thermally postmature with respect to hydrocarbon generation in the whole area. Consequently the second and final field programme within the project (1985) concentrated on the Cambrian shelf sequence (especially the Henson Gletscher Formation in the Brønlund Fjord Group) and the Silurian slope to trough sequence (Lafayette Bugt Formation and Wulff Land Formation). The main purpose of the 1985 work was to make a detailed study of these units combining field work and shallow core dril!ing. The samples and cores provide the basis for later detailed maturity studies and a quantitative evaluation of source rock quality and volume. As in 1984, the 1985 field season was fully integrated with the geological mapping programme in the region (Henriksen, this report). The field work was carried out by a team of two geologists and a dril!ing team with three technicians (John Boserup, Anders Clausen, Jørgen Bojesen-Koefoed) and a dril! site geologist. The three geologists alternated often in order to obtain continuity in the programme and furthermore six of the total 14 camps were located at the dril! sites (fig. 1).

scholarly journals The Cambrian Henson Gletscher Formation: a mature to postmature hydrocarbon source rock sequence from North Greenland

1987 ◽  
Vol 133 ◽  
pp. 141-157
Author(s):  
F.G Christiansen ◽  
H Nøhr-Hansen ◽  
O Nykjær
Keyword(s):  
Source Rock ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Hydrocarbon Source Rock ◽  
Reservoir Rocks ◽  
Potential Source ◽  
Potential Reservoir ◽  
Field Season ◽  
North Greenland

During the 1985 field season the Cambrian Henson Gletscher Formation in central North Greenland was studied in detail with the aim of evaluating its potential as a hydrocarbon source rock. The formation contains organic rich shale and carbonate mudstone which are considered to be potential source rocks. These are sedimentologically coupled with a sequence of sandstones and coarse carbonates which might be potential reservoir rocks or migration conduits. Most of the rocks exposed on the surface are, however, thermally mature to postrnature with respect to hydrocarbon generation, leaving only few chances of finding trapped oil in the subsurface of the area studied in detail.

scholarly journals Eastern North Greenland 1994, the 1:500 000 mapping project

1995 ◽  
Vol 165 ◽  
pp. 53-58
Author(s):  
N Henriksen
Keyword(s):  
Field Work ◽  
Fully Integrated ◽  
General Overview ◽  
North East ◽  
Field Season ◽  
Geological Map ◽  
Field Campaigns ◽  
Council Of Ministers ◽  
North Greenland ◽  
Land Region

The second field season of the Geological Survey of Greenland's (GGU) mapping project in eastern North Greenland (1993–95) was carried out according to plan and with full accomplishment of all geoscientific goals. The programme aims at producing a general overview of the onshore geology of the Jokelbugten to Kronprins Christian Land region (78–81 °N) in eastern North Greenland (Fig. 1) to be compiled as sheet no. 9 in GGU's 1:500 000 geological map sheet series; this is the last remaining incomplete map sheet at this scale in North and North-East Greenland. The field work was initiated in 1993 with limited reconnaissance work (Henriksen, 1994a), and in 1994 the first of two more intensive field campaigns was carried out. In addition to establishing a general overview of the regional geology the work aims at obtaining an evaluation of the economic geological potential of the region, in respect of both minerals and hydrocarbons. Two glaciological programmes were fully integrated with the project: one was carried out by the Alfred Wegener Institute (AWi), Bremerhaven, Germany, while the other was partly based on a special grant from the Nordic Council of Ministers.

scholarly journals Wandel Sea Basin: basin analysis – a summary

1995 ◽  
Vol 165 ◽  
pp. 42-48
Author(s):  
E Håkansson ◽  
L Stemmerik
Keyword(s):  
Financial Support ◽  
Research Council ◽  
Science Research ◽  
Field Work ◽  
Geological Mapping ◽  
Basin Analysis ◽  
Geological Survey ◽  
Natural Science Research Council ◽  
Field Season ◽  
North Greenland

In 1991 a three year research project was initiated by the Geological Institute, University of Copenhagen with financial support from the Ministry of Energy, the Danish Natural Science Research Council and the Carlsberg Foundation. The 'Wandel Sea Basin: basin analysis' project was carried out in collaboration with the Geological Survey of Greenland and included field work in North Greenland; in eastern Peary Land in 1991 and Amdrup Land in 1993 (Fig. 1; Hakansson et al., 1994). The project is a continuation of earlier investigations in the Wandel Sea Basin carried out during geological mapping of North Greenland by the Geological Survey of Greenland in 1978–1980 and during later expeditions to the area (e.g. Hakansson, 1979; Hakansson et al., 1981, 1989, 1991, 1994). Hydrocarbon related studies of the Wandel Sea Basin were continued during the 1994 field season (Stemmerik et al., this report).

scholarly journals Preliminary analysis of the hydrocarbon source rock potential of central and western North Greenland

1985 ◽  
Vol 126 ◽  
pp. 117-128
Author(s):  
F.G Christiansen ◽  
H Nøhr-Hansen ◽  
F Rolle ◽  
P Wrang
Keyword(s):  
Source Rocks ◽  
Hydrocarbon Source Rock ◽  
North East ◽  
The North ◽  
South West ◽  
Oil Generation ◽  
Lithostratigraphic Units ◽  
Field Season ◽  
Rock Eval ◽  
North Greenland

During the 1984 field season potential hydrocarbon source rocks were studied in central and western North Greenland. Samples from most lithostratigraphic units were collected from Freuchen Land in the north-east to Washington Land in the south-west. Preliminary results from LECO, Rock-Eval and palynofacies analyses suggest that some intervals in the Cambrian shelf sequence and in the Ordovician and Silurian trough sequence have enough organic matter to qualify as source rocks. Most of the trough sequence is, however, thermally postrnature with respect to oil generation and only the Cambrian Brønlund Fjord Group is expected to have been the source of the oil accumulations in the subsurface.

Palaeo-oil field in a Silurian carbonate buildup, Wulff Land, North Greenland: project ‘Resources of the sedimentary basins of North and East Greenland’

1997 ◽  
pp. 24-28 ◽  
Author(s):  
Lars Stemmerik ◽  
Martin Sønderholm ◽  
Jørgen A. Bojesen-Koefoed
Keyword(s):  
Large Scale ◽  
Sedimentary Basins ◽  
Field Work ◽  
Oil Field ◽  
Source Rocks ◽  
Long Distance ◽  
East Greenland ◽  
Field Season ◽  
North Greenland ◽  
Carbonate Buildup

NOTE: This article was published in a former series of GEUS Bulletin. Please use the original series name when citing this article, for example: Stemmerik, L., Sønderholm, M., & Bojesen-Koefoed, J. A. (1997). Palaeo-oil field in a Silurian carbonate buildup, Wulff Land, North Greenland: project ‘Resources of the sedimentary basins of North and East Greenland’. Geology of Greenland Survey Bulletin, 176, 24-28. https://doi.org/10.34194/ggub.v176.5056 _______________ The multi-disciplinary research project ‘Resources of the sedimentary basins of North and East Greenland’ was initiated in 1995 with financial support from the Danish Research Councils (Stemmerik et al., 1996). During the 1996 field season, hydrocarbon-related studies within the project were focused on the sedimentary basins of East Greenland (Stemmerik et al., 1997), while field work in the Franklinian Basin of North Greenland from which the observations reported here derive, was limited to two weeks in early August. The project also includes research related to the ore geology of North Greenland, especially focused on the zinc-lead deposit at Citronen Fjord (Fig. 1). This aspect of the project is covered by Langdahl & Elberling (1997) and Kragh et al. (1997). The work on the Franklinian Basin succession was based at Apollo Sø in eastern Wulff Land (Fig. 1), with the main emphasis on sedimentological and sequence stratigraphic studies of carbonates of the Cambrian portion of the Ryder Gletscher Group and the Silurian Washington Land Group. These two carbonate-dominated shelf successions are equivalent in age to the main source rocks for liquid hydrocarbons in the basin, and have been suggested as potential reservoir units in the conceptual reservoir models proposed for the basin (Christiansen, 1989). Earlier investigations in the region have shown that small occurrences of bitumen are widespread in western North Greenland, although typically closely associated with nearby source rocks (Christiansen et al., 1989a). Notable exceptions are the asphalt seepages in southern Warming Land and southern Wulff Land (Fig. 1); in these cases, long distance migration of the order of 75–100 km is envisaged (Christiansen et al., 1989a). During the 1996 field season, a palaeo-oil field was identified in a carbonate buildup in eastern Wulff Land (Victoria Fjord buildup), thus demonstrating for the first time that Silurian buildups have formed large-scale reservoirs for generated hydrocarbons in the geological past.

scholarly journals Study on Geochemical Characteristics of tight sandstone gas accumulation in Linxing area

2020 ◽  
Vol 206 ◽  
pp. 01017
Author(s):  
Yangbing Li ◽  
Weiqiang Hu ◽  
Xin Chen ◽  
Litao Ma ◽  
Cheng Liu ◽  
...  
Keyword(s):  
Source Rock ◽  
Ordos Basin ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Light Hydrocarbons ◽  
Tight Sandstone ◽  
Source Type ◽  
Reservoir Type ◽  
Sandstone Reservoir ◽  
Main Component

Based on the comprehensive analysis of the characteristics of tight sandstone gas composition, carbon isotope, light hydrocarbons and source rocks in Linxing area of Ordos Basin, the reservoir-forming model of tight sandstone gas in this area is discussed. The study shows that methane is the main component of tight sandstone gas, with low contents of heavy hydrocarbons and non-hydrocarbons, mainly belonging to dry gas in the Upper Paleozoic in Linxing area. The values of δ13C1, δ13C2 and δ13C3 of natural gas are in the ranges of -45.6‰ ~ -32.9‰, -28.9‰ ~ -22.3‰ and -26.2‰~ -19.1‰, respectively. The carbon isotopic values of alkane gas show a general trend of positive carbon sequence. δ13C1 value is less than -30‰, with typical characteristics of organic genesis. There is a certain similarity in the composition characteristics of light hydrocarbons. The C7 series show the advantage of methylhexane, while the C5-7 series mainly shows the advantage of isoalkane. The tight sandstone gas in this area is mainly composed of mature coal-derived gas, containing a small amount of coal-derived gas and oil-type gas mixture. According to the mode of hydrocarbon generation, diffusion and migration of source rocks in Linxing area, the tight sandstone gas in the study area can be divided into three types of reservoir-forming assemblages: the upper reservoir type of the far-source type (upper Shihezi formation-shiqianfeng formation sandstone reservoir-forming away from source rocks), the upper reservoir type of the near-source type ( the Lower Shihezi formation sandstone reservoir-outside the source rock), and the self-storage type of the source type (Shanxi formation-Taiyuan formation source rock internal sand reservoir).

scholarly journals GEOCHEMICAL AND GEOSTATISTICAL ASSESSMENT OF CRETACEOUS COALS AND SHALES IN SOME NIGERAIN SEDIMENTARY BASINS FOR THEIR HYDROCARBON PRONESS AND MATURITY LEVELS

2020 ◽  
Vol 1 (2) ◽  
Keyword(s):  
Source Rock ◽  
Oil And Gas ◽  
Linear Regression Analysis ◽  
Sedimentary Basins ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Good Source ◽  
Type Iii ◽  
Limit Value ◽  
The Impact

The Rock–Eval pyrolysis and LECO analysis for 9 shale and 12 coal samples, as well as, geostatistical analysis have been used to investigate source rock characteristics, correlation between the assessed parameters (QI, BI, S1, S2, S3, HI, S1 + S2, OI, PI, TOC) and the impact of changes in the Tmax on the assessed parameters in the Cretaceous Sokoto, Anambra Basins and Middle Benue Trough of northwestern, southeastern and northcentral Nigeria respectively. The geochemical results point that about 97% of the samples have TOC values greater than the minimum limit value (0.5 wt %) required to induce hydrocarbon generation from source rocks. Meanwhile, the Dukamaje and Taloka shales and Lafia/Obi coal are found to be fair to good source rock for oil generation with slightly higher thermal maturation. The source rocks are generally immature through sub-mature to marginal mature with respect to the oil and gas window, while the potential source rocks from the Anambra Basin are generally sub-mature grading to mature within the oil window. The analyzed data were approached statistically to find some relations such as factors, and clusters concerning the examination of the source rocks. These factors were categorized into type of organic matter and organic richness, thermal maturity and hydrocarbon potency. In addendum, cluster analysis separated the source rocks in the study area into two groups. The source rocks characterized by HI >240 (mg/g), TOC from 58.89 to 66.43 wt %, S1 from 2.01 to 2.54 (mg/g) and S2 from 148.94 to 162.52 (mg/g) indicating good to excellent source rocks with kerogen of type II and type III and are capable of generating oil and gas. Followed by the Source rocks characterized by HI <240 (mg/g), TOC from 0.94 to 36.12 wt%, S1 from 0.14 to 0.72 (mg/g) and S2 from 0.14 to 20.38 (mg/g) indicating poor to good source rocks with kerogen of type III and are capable of generating gas. Howeverr, Pearson’s correlation coefficient and linear regression analysis shows a significant positive correlation between TOC and S1, S2 and HI and no correlation between TOC and Tmax, highly negative correlation between TOC and OI and no correlation between Tmax and HI. Keywords- Cretaceous, Geochemical, Statistical, Cluster; Factor analyses.

Liquid hydrocarbon characterization of the lacustrine Yanchang Formation, Ordos Basin, China: Organic-matter source variation and thermal maturity

2017 ◽  
Vol 5 (2) ◽  
pp. SF225-SF242 ◽  
Author(s):  
Xun Sun ◽  
Quansheng Liang ◽  
Chengfu Jiang ◽  
Daniel Enriquez ◽  
Tongwei Zhang ◽  
...  
Keyword(s):  
Organic Matter ◽  
Source Rock ◽  
Ordos Basin ◽  
Depositional Environments ◽  
Source Rocks ◽  
Type I ◽  
Hydrocarbon Generation ◽  
Type Ii ◽  
Thermal Maturity ◽  
Yanchang Formation

Source-rock samples from the Upper Triassic Yanchang Formation in the Ordos Basin of China were geochemically characterized to determine variations in depositional environments, organic-matter (OM) source, and thermal maturity. Total organic carbon (TOC) content varies from 4 wt% to 10 wt% in the Chang 7, Chang 8, and Chang 9 members — the three OM-rich shale intervals. The Chang 7 has the highest TOC and hydrogen index values, and it is considered the best source rock in the formation. Geochemical evidence indicates that the main sources of OM in the Yanchang Formation are freshwater lacustrine phytoplanktons, aquatic macrophytes, aquatic organisms, and land plants deposited under a weakly reducing to suboxic depositional environment. The elevated [Formula: see text] sterane concentration and depleted [Formula: see text] values of OM in the middle of the Chang 7 may indicate the presence of freshwater cyanobacteria blooms that corresponds to a period of maximum lake expansion. The OM deposited in deeper parts of the lake is dominated by oil-prone type I or type II kerogen or a mixture of both. The OM deposited in shallower settings is characterized by increased terrestrial input with a mixture of types II and III kerogen. These source rocks are in the oil window, with maturity increasing with burial depth. The measured solid-bitumen reflectance and calculated vitrinite reflectance from the temperature at maximum release of hydrocarbons occurs during Rock-Eval pyrolysis ([Formula: see text]) and the methylphenanthrene index (MPI-1) chemical maturity parameters range from 0.8 to [Formula: see text]. Because the thermal labilities of OM are associated with the kerogen type, the required thermal stress for oil generation from types I and II mixed kerogen has a higher and narrower range of temperature for hydrocarbon generation than that of OM dominated by type II kerogen or types II and III mixed kerogen deposited in the prodelta and delta front.

The transformation effect of source rock-derived acidic fluid on carbonate reservoir from simulation experiments

2020 ◽  
Author(s):  
Qian Ding ◽  
Zhiliang He ◽  
Dongya Zhu
Keyword(s):  
Physical Properties ◽  
Source Rock ◽  
Carbonate Reservoir ◽  
Carbonate Reservoirs ◽  
Source Rocks ◽  
Petroleum Exploration ◽  
Hydrocarbon Generation ◽  
High Quality ◽  
Simulation Experiments ◽  
Deep Layers

&lt;p&gt;Deep and ultra-deep carbonate reservoir is an important area of petroleum exploration. However, the prerequisite for predicting high quality deep ultra-deep carbonate reservoirs lays on the mechanism of carbonate dissolution/precipitation. It is optimal to perform hydrocarbon generation-dissolution simulation experiments to clarify if burial dissolution could improve the physical properties of carbonate reservoirs, while quantitatively and qualitatively describe the co-evolution process of source rock and carbonate reservoirs in deep layers. In this study, a series of experiments were conducted with the limestone from the Ordovician Yingshan Formation in the Tarim Basin, and the low maturity source rock from Yunnan Luquan, with a self-designed hydrocarbon generation-dissolution simulation equipment. The controlling factors accounted for the alteration of carbonate reservoirs and dissolution modification process by hydrocarbon cracking fluid under deep burial environments were investigated by petrographic and geochemical analytical methods. In the meantime, the transformation mechanism of surrounding rocks in carbonate reservoirs during hydrocarbon generation process of source rock was explored. The results showed that: in the burial stage, organic acid, CO&lt;sub&gt;2&lt;/sub&gt; and other acidic fluids associated with thermal evolution of deep source rocks could dissolve carbonate reservoirs, expand pore space, and improve porosity. Dissolution would decrease with the increasing burial depth. Whether the fluid could improve reservoir physical properties largely depends on calcium carbonate saturation, fluid velocity, water/rock ratio, original pore structure etc. This study could further contribute to the prediction of high-quality carbonate reservoirs in deep and ultra-deep layers.&lt;/p&gt;

scholarly journals 3D-Basin Modelling of the Lishui Sag: Research of Hydrocarbon Potential, Petroleum Generation and Migration

Energies ◽  
2019 ◽  
Vol 12 (4) ◽  
pp. 650 ◽  
Author(s):  
Jinliang Zhang ◽  
Jiaqi Guo ◽  
Jinshui Liu ◽  
Wenlong Shen ◽  
Na Li ◽  
...  
Keyword(s):  
Source Rock ◽  
Thermal Evolution ◽  
Vitrinite Reflectance ◽  
Three Dimensional ◽  
Source Rocks ◽  
Rock Properties ◽  
Hydrocarbon Generation ◽  
Hydrocarbon Accumulation ◽  
Southeastern Part ◽  
Petroleum Generation

The Lishui Sag is located in the southeastern part of the Taibei Depression, in the East China Sea basin, where the sag is the major hydrocarbon accumulation zone. A three dimensional modelling approach was used to estimate the mass of petroleum generation and accumulated during the evolution of the basin. Calibration of the model, based on measured maturity (vitrinite reflectance) and borehole temperatures, took into consideration two main periods of erosion events: a late Cretaceous to early Paleocene event, and an Oligocene erosion event. The maturation histories of the main source rock formations were reconstructed and show that the peak maturities have been reached in the west central part of the basin. Our study included source rock analysis, measurement of fluid inclusion homogenization temperatures, and basin history modelling to define the source rock properties, the thermal evolution and hydrocarbon generation history, and possible hydrocarbon accumulation processes in the Lishui Sag. The study found that the main hydrocarbon source for the Lishui Sag are argillaceous source rocks in the Yueguifeng Formation. The hydrocarbon generation period lasted from 58 Ma to 32 Ma. The first period of hydrocarbon accumulation lasted from 51.8 Ma to 32 Ma, and the second period lasted from 23 Ma to the present. The accumulation zones mainly located in the structural high and lithologic-fault screened reservoir filling with the hydrocarbon migrated from the deep sag in the south west direction.

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