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Research article
Specific features of kinetics of thermal transformation of organic matter in Bazhenov and Domanik source rocks based on results of pyrolysis gas chromatography
Svetlana V. MozhegovaH, Roman S. Gerasimov, Irina L. Paizanskaya, Anna A. Alferova, Elizaveta M. Kravchenko
Scientific and Analytical Centre of Aprelevka Branch, All-Russian Research Geological Oil Institute, Aprelevka, Russia
How to cite this article: Mozhegova S.V., Gerasimov R.S., Paizanskaya I.L., Alferova A.A., Kravchenko E.M. Specific features of kinetics of thermal transformation of organic matter in Bazhenov and Domanik source rocks based on results of pyrolysis gas chromatography. Journal of Mining Institute. 2024. Vol. 269, p. 765-776.
Abstract. Pyrolysis of organic matter with subsequent analysis of hydrocarbon composition of the resulting products allows obtaining multicomponent distribution spectra of the generation potential by the activation energies of reactions of kerogen transformation into hydrocarbons. Configuration of the spectra depends on the structure of kerogen and is individual for each type of organic matter. Studies of kerogen kinetics showed that the distribution of activation energies is unique for each oil source rocks. The kinetic model of thermal decomposition of kerogen of the same type, for example, marine planktonic (type II), can differ significantly in different sedimentary basins due to the multivariate relationship of chemical bonds and their reaction energy threshold. The developed method for calculating multicom-ponent kinetic spectra (four-component models are used) based on results of pyrolysis gas chromatography allows obtaining one of the most important elements of modelling the history of oil and gas generation in geological basins. Kinetic parameters of organic matter of oil and gas source rocks influence the onset time of generation and directly reflect differences in the composition and structure of different types of kerogens. The results of determining the kinetic parameters of two high-carbon source rocks occurring across the territory of three oil and gas basins are shown. Generation and updating of the data of kinetic models of certain oil and gas source rocks will increase the reliability of forecasting oil and gas potential using the basin modelling method.
Keywords: pyrolytic gas chromatography; kinetics; hydrocarbon generation; kerogen; pyrolysis; activation energy; oil; gas Received: 25.04.2024 Accepted: 24.09.2024 Online: 12.11.2024 Published: 12.11.2024
Introduction. According to the sedimentary-migration theory [1-3], the origin of oil and gas is associated with organic matter (OM) of plants and living organisms buried together with mineral components in sedimentary basins. This theory is confirmed by results of modern fine chemical analyses that allow recording the presence of purely biogenic molecules in oils (biomarkers or che-mofossils). After sedimentation, diagenetic and early catagenetic transformation, OM is first decomposed by microorganisms to molecules of carbohydrates, proteins and lipids, then it is gradually transformed from a biopolymer into a geopolymer (kerogen) by polymerization and condensation [2, 4]. At this stage, the composition and oil and gas generation potential of kerogen form depending on composition of the source biomass and the conditions of OM burial in sediments. During further transformation at the stages of catagenesis, where the main factors influencing the transformation of OM are temperature and time, kerogen is subject to destruction with formation of hydrocarbons
Mathematical modelling of oil and gas formation processes is associated with development of pyrolytic studies of OM, which is currently the main tool for investigating the generation characteristics of source formations [6-8]. Quantitatively, the process of kerogen destruction with formation of
(HC) [1, 3, 5].
various hydrocarbon compounds is described by the kinetics of chemical reactions [9, 10]. To simplify the calculations, it is assumed that kerogen transformation is a series of reactions that occur simultaneously and have the same energy barrier [9, 11]. The energy barrier is the activation energy required to break the chemical bonds of a given set of reactions. The rate of the chemical reaction of OM cracking in laboratory conditions can be described by the first-order Arrhenius equation and extrapolated to geological time [5, 9, 12].
The spectra of OM transformation reactions obtained in the course of kinetic studies represent a set of activation energies and the proportion of total amount of generation products corresponding to each value. The kinetic spectra clearly illustrate the destruction features of kerogen of different genetic types to oil and gas components [5, 13].
Calculation and plotting of kinetic spectra are performed on the basis of studying samples of source rocks applying the method of pyrolysis gas chromatography (or Py-GC) [14-16] which allows dividing the pyrolysis products into groups of HC. Two- (oil and gas) and four-component (methane, gases C2-C5, liquid HC C6-C14 and heavy liquid and solid components C15+) kinetic schemes are most often applied in basin and petroleum generation modelling [17]. Frequently, due to the lack of data on kinetic constructions on samples of the source rocks of the investigated basin, while modelling, it is necessary to use kinetic spectra from other basins (from the geochemical library of the software package applied). Generation and updating of the database of our own kinetic models for oil and gas source rocks will improve the reliability of oil and gas presence forecast using the basin modelling method [13].
To conduct kinetic studies, it is necessary to be follow by a number of conditions for sampling: the sample should characterize the average OM content for the oil source rocks and their generation potential; the degree of OM maturity should correspond to the beginning of the "oil window" (Tmax of pyrolysis 420-435 °C, Ro - 0.5-0.7 %), i.e. before the start of generation of the main volumes of HC [6, 18].
The results of kinetic studies of two source rocks highly enriched in marine planktonic OM -Domanik deposits - are presented using core samples from wells of the Volga-Ural and Timan-Pechora oil and gas basins and the Bazhenov formation of the West Siberian oil and gas basin as examples.
Methods. The essence of the pyrolytic chromatography method is heating a weighed quantity of rock in a pyrolytic cell followed by chromatographic separation of kerogen cracking products on a capillary column and registration of the investigated components using a flame ionization detector (FID). A set of devices was applied in the study - a Frontier Lab EGA/PY-3030D pyrolytic cell, an Agilent 7890A gas chromatograph, and a unit for trapping pyrolysis products with liquid nitrogen. One of the main elements of this process flow chart is the PY-3030D pyrolytic cell. This is a multifunctional tool that allows studying samples in both single-stage and multi-stage pyrolysis modes.
For complete separation of gases and their separation from liquid pyrolysis products, a cryogenic trap is installed in the thermostat of the gas chromatograph, into which the initial section of the capillary column is placed. The process of cryogenic focusing of pyrolysis products is fully automated and controlled by the software for operating the pyrolytic cell. Pyrolysis products entering the capillary column are concentrated in its initial section. For separation of light hydrocarbons C1-C5, a system of cryotrapping of pyrolysis products with liquid nitrogen in the initial section of the column is applied. This allows achieving complete separation of C1-C5 from each other due to the start of the column temperature program from deep-freeze area. A non-polar PONA 50M x 0.2 mm x 0.5 p,m column was used in the analysis. The pyrolysis oven temperature was 300-650 °C (with a 25 °C interval); heating time at each stage was 5 min; time of capturing the pyrolysis products with liquid nitrogen 5 min; stable temperature of coolant (liquid nitrogen) -180 °C.
At the same time, rock samples were investigated on a Rock-Eval analyser using the Optkin method to determine the Arrhenius frequency factor characteristic of reactions of a specific kerogen. The investigation of one sample includes a set of six analyses using the Bulk Rock method with different heating rates at the pyrolysis stage - 1; 5; 10; 15; 20; 25 °C/min. Processing of the obtained pyrolysis curves, calculation of kinetic characteristics and plotting of single-component histograms of activation energy distribution are performed using Optkin software.
When solving the Arrhenius equation for each heating stage programmed during the pyro-GC study, a set of activation energies is obtained that describes the reactions of thermal destruction of kerogen in the studied rock samples. The quantities of generated gaseous and liquid HC obtained by stages are normalized to the total yield of generation products during pyrolysis of a specific sample (hydrogen index HI), thus obtaining the ratio of HC-components released during pyrolysis.
All samples were pre-extracted with chloroform until the solvent in the Soxhlet apparatus tube completely ceased to glow in UV light. The chromatogram obtained at heating to 300 °C was not taken into account in the calculations for avoiding the inclusion of sorbed free HC contained in rock.
Discussion of results. A comparative study of oil and gas formation processes in source formations of different ages containing similar types of OM is of scientific interest from the viewpoint of identifying the genetic features and quantitative characteristics of HC generation and migration, which allow to perform a reasonable forecast of oil and gas presence and an estimation of the potential oil and gas resources in prospective areas. The results of geochemical studies of OM in Domanik-type deposits are considered, which include the Domanik (Semilukskii) horizon and the Bazhenov formation in respect of enrichment (over 0.5 % [19]) and the marine type of OM.
Domanik deposits in the Volga-Ural and Timan-Pechora oil and gas basins occur as a broad band along the eastern margin of the East European Platform. Within the Volga-Ural Basin, siliceous-carbonate deposits highly enriched in marine OM occur on slopes of the South and North Tatarskii, Bashkirskii, Zhigulevskii-Pugachevskii, Permskii and Orenburgskii paleodomes and within paleo-troughs of the Kamskaya-Kinelskaya system [20-22]. In the Volga-Ural Basin, the Domanik-type deposits are most widespread in the Middle Frasnian Domanik and Upper Frasnian Rechitskii horizons (Devonian). In the Voronezhskii, Evlanovskii and Livenskii horizons of the Upper Frasnian, the occurrence area of Domanik-type deposits narrows. They occur within the axial parts of the Kamskaya-Kinelskaya system of paleotroughs and outer slopes of paleodomes. In the Famennian (Upper Devonian) and Tournaisian (Lower Carboniferous) high-carbon carbonate-siliceous rocks occur only as thin interbeds among the predominantly carbonate sections and are concentrated in axial parts of depressions of the Kamskaya-Kinelskaya system [23].
Stratigraphic range of Domanik deposits in the Timan-Pechora oil and gas province coincides with the range of the Volga-Ural Basin. Domanik horizon of the Middle Frasnian is the most OM-enriched part of the Domanik deposits, which also has the greatest areal distribution. The upper boundary of occurrence of Domanik-type rocks gradually changes eastwards - from the Domanik horizon of the Middle Frasnian in Southern Timan to the Tournaisian (Lower Carboniferous) in depressions of the Pre-Ural Trough [24-26].
The Domanik sequence under consideration demonstrates a highly diverse lithological composition of rocks. It comprises limestones, often siliceous, siliceous marls, siliceous mudstones, silicites, and oil shales. The deposits contain a large amount of free silica and have a low clay content [27].
Domanik deposits are considered to be the classic oil source rocks with a high content of marine OM accumulated under conditions of a long-term uncompensated subsidence of large sea basins. The thickness of Domanik-type deposits is small - from a few tens to 100 m. Concentrations of organic carbon (TOC) averaged through the thickness of the Domanik-Famennian complex vary from 0.8 % in zones of paleodomes, where Domanik-type rocks make up only the Domanik and Rechitskii
horizons, to 5-6 % in zones of paleotroughs, where the occurrence range of OM-enriched rocks covers the Middle-Upper Frasnian and the Famennian deposits.
According to the material-petrographic composition [28] the source material of OM in the Do-manik deposits, along with planktonic algae, was Zooplankton (tentaculites). Zooplankton enriches the OM with humoid components at the expense of transformation products of shell chitin. The specific composition of the source material of OM in the Domanik sequence distinguishes it from other oil source deposits and reduces its initial hydrocarbon generation potential.
In the Volga-Ural Basin, samples of the Semilukskii (Domanik) and Rechitskii horizons were taken from Kutushskaya 264 well on the western slope of the South Tatar Arch. In the Timan-Pechora Region, samples of the Domanik horizon were taken from the shallow Komi 1 well in Southern Timan.
Table 1 shows the results of analysing rock samples by the Rock-Eval method before and after extraction reflecting the content and some data on the composition of OM in rocks of the Domanik and Rechitskii horizons. The selected samples represent three different lithotypes of the studied deposits: oil shales with the highest OM content, siliceous limestones, and silicites [21].
Table 1
Results of investigating samples by Rock-Eval method
Well Formation Sampling depth, m Bit, % Stage of investigation S1, mg HC/g of rock S2, mg HC/g of rock T °c 1 max, C TOC, % H, mg HC/g of TOC PI
Kutushskaya 264 (siliceous limestone) D3f3 rc 1,958.25 0.42 Before extraction After extraction 0.94 0.20 20.51 19.54 420 420 3.78 3.67 543 532 0.04
Kutushskaya 264 (oil shale) D3f3 rc 1,959.05 2.37 Before extraction After extraction 11.24 2.99 209.92 210.05 406 409 35.02 34.87 599 602 0.05
Kutushskaya 264 (silicite) D3f2 sm 1,972.00 0.23 Before extraction After extraction 0.85 0.66 15.86 15.93 419 421 2.93 3.02 541 527 0.05
Komi 1 (siliceous limestone) Dfidm 74.05 0.24 Before extraction After extraction 0.47 0.12 8.93 8.84 415 415 1.67 1.62 536 546 0.05
Komi 1 (oil shale) D3f2dm 112.85 5.45 Before extraction After extraction 24.15 4.60 260.65 208.51 415 413 42.09 35.57 619 586 0.08
Komi 1 (silicite) D3fidm 113.47 3.29 Before extraction After extraction 6.72 0.29 40.81 21.63 415 416 6.52 4.11 626 526 0.14
Verkhnetyumskaya 34 (siliceous clay rock from the upper part of formation) J3-Kièg 2,550.58 1.88 Before extraction After extraction 7.22 0.41 102.25 88.96 425 426 16.29 14.56 628 611 0.07
Verkhnetyumskaya 34 (siliceous clay rock from the lower part of formation) J3-Kièg 2,591.90 0.66 Before extraction After extraction 4.58 0.44 91.79 68.86 426 424 14.52 13.73 632 502 0.05
Notes. Bit - content of chloroform bitumen in rock. Rock-Eval parameters: Si - content of thermodesorbed free HC; S2 - content of HC released during pyrolysis of kerogen and resine-asphaltene fraction; Tmax - temperature at maximum of S2 peak; TOC - total content of organic carbon; HI - hydrogen index of kerogen, HI = S2^ IOO/TOC; PI - productivity index, PI = Si/(Si + S2).
In accordance with regional Mesozoic stratigraphic charts of Western Siberia, high-carbon deposits of the Bazhenov horizon occur in central regions (Bazhenov formation and Nizhne-tutleimskaya Subformation) and are surrounded by its less OM-enriched stratigraphic equivalents [29]. According to the OM distribution schemes in the Bazhenov formation and its facies equivalent, the Nizhnetutleimskaya Subformation, TOC content over most of the occurrence area of high-carbon deposits exceeds 5-7 % [30, 31]. At the same time, the most OM-enriched interbeds with TOC content over 10-15 % are mainly confined to the upper part of the formation the thickness of which is 30-50 % of total thickness. The lower part of the Bazhenov formation is less enriched in OM than the upper one.
Taking into account the heterogeneous structure of the Bazhenov formation, samples for kinetic investigations were taken from the two most OM-enriched lithological units from the protocatagene-sis zone (Verkhnetyumskaya 34 well) (Table 1).
A comparative analysis of Rock-Eval results for a large collection of rock samples showed that the initial characteristics of the Domanik OM differ from OM of the Bazhenov formation. The predominant component of OM in the Bazhenov formation is phytoplankton (peridinium algae, diatoms, coccolithophores, etc.) [32] with a higher proportion of lipids. Before the start of intense HC generation processes, the hydrogen index HI of kerogen in the Bazhenov formation is 700 mg HC/g TOC, and the share of pyrolyzable carbon PC participating in the formation of HC accounts for 60 % of TOC. The remaining share of TOC is non-pyrolyzable RC, i.e. inert carbon. OM of Domanik is characterized by a lower initial HI - 600 mg HC/g TOC and, accordingly, a lower proportion of PC - ~55 % (Fig.1).
Zooplanktonogenic OM in Domanik deposits is characterized by increased initial bituminosity, which is one of the causes of early migration of HC and manifestation of the main phase of oil and gas formation at lower temperatures compared to the Bazhenov formation.
The rate of OM conversion into HC for the Domanik sequence is lower compared to the Bazhenov deposits. For example, by the maturity level of MK3-MK4 (Tmax > 455 °C), the residual generation potential (HI) of Domanik OM is 170 mg HC/g TOC, whereas for OM of the Bazhenov formation it does not exceed 100 mg HC/g TOC, i.e. it is virtually exhausted. According to T.K.Ba-zhenova, the generation process of liquid HC in Domanik source rocks with algozoogenic OM extends over a larger cata-genetic range compared to the algogenic biocenotic type of OM [33]. This is due to a significant proportion of resinous-asphaltene materials in the products generated by algozoogenic OM which, when subjected to secondary cracking, can be destroyed with release of light liquid HC till the end of apoca-tagenesis.
HI, mg HC/g TOC 0 200 400 600 800
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Fig. 1. Rock-Eval parameters and their relations with growth of OM catagenesis (rmax) in Domanik-type deposits
1 - deposits of Domanik (Semilukskii) and Rechitskii horizons; 2 - deposits of Bazhenov and Nizhnetutleimskaya formations PC - pyrolyzable organic carbon in rock, %; RC - non-pyrolyzable organic carbon in rock, %. Values of parameters and ratios are taken as the mean ones for the well section
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Modelling of kinetic spectra for samples from Domanik deposits showed a similar character of the dynamics of HC generation (Fig.2). An extensive distribution of activation energies Ea in the range of 43-69 kcal/mol, typical of marine planktonic OM, was obtained. More than 80 % of the volume of generated HC are distributed within a narrow range of activation energy - only 4-6 kcal/mol. A pronounced maximum of HC generation is recorded within 52-56 kcal/mol.
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Fig.2. Four-component kinetic distribution spectra of generation potential of kerogen depending on activation energy
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At the same time, significant differences in the intensity of HC generation in samples of different lithotypes were recorded. Highly OM-enriched oil shale is characterized by a more symmetrical distribution relative to the maximum - 20-25 % of HC products are generated before the maximum and 30-40 % after the maximum (Table 2). In other samples (more carbonate varieties and silicites), only 11-15 % of total mass of HC pyrolysis products is generated before the maximum and 37-40 % after the maximum.
Table 2
Results of calculating of four-component kinetic spectra of organic matter transformation reactions
Pyrolysis Activation energy, Transformation ratio Proportion in total volume of generated products, % HC content, rel. %
temperature, °C kcal/mol TR, % CH4 C2-C5 C6-C14 C15+
Kutushskaya 264 well, siliceous limestone, 1,958.25 m, D3f3rc A 58.71E+12 s 1
325 44 1.0 0.55 0.12 0.41 0.77 0.74
350 46 2.3 0.75 0.23 0.65 1.02 0.85
375 48 5.3 1.69 0.53 1.35 2.33 2.03
400 50 13.6 4.98 1.61 3.76 6.82 6.53
425 52 29.3 10.51 3.47 8.60 14.68 11.56
450 54 53.5 20.15 7.90 18.60 24.59 26.22
475 56 75.8 24.60 11.60 26.29 26.77 31.32
500 57 90.0 19.93 16.52 24.52 18.78 18.06
525 59 94.6 7.37 16.25 10.06 3.22 2.35
550 61 96.7 3.70 13.59 3.49 0.66 0.28
575 63 98.1 2.30 10.75 1.15 0.16 0.04
600 65 99.0 1.62 8.08 0.51 0.11 0.00
625 67 99.6 1.06 5.46 0.27 0.05 0.00
650 69 100.0 0.80 3.89 0.33 0.05 0.01
Proportion in total HC yield 17.67 28.81 39.30 14.22
Kutushskaya 264 well, oil shale, 1,959.05 m, D3f3rc A 22.02E+12 s-1
325 43 2.5 1.26 0.25 1.37 1,61 1,31
350 45 7.7 2.74 0.67 2.63 3.72 2.58
375 47 19.3 6.71 1.73 5.58 9.00 8.67
400 49 37.9 12.67 3.41 10.69 16.80 16.47
425 51 61.3 20.89 6.63 19.83 26.11 26.30
450 52 79.2 21.25 9.24 24.28 23.37 25.10
475 54 89.1 14.78 11.41 20.36 13.37 12.21
500 56 93.0 6.62 14.10 6.73 4.00 4.40
525 58 95.7 4.78 14.21 5.25 1.25 2.10
550 60 97.4 3.23 13.08 2.10 0.47 0.69
575 61 98.5 2.13 10.19 0.71 0.16 0.13
600 63 99.3 1.49 7.63 0.27 0.06 0.03
625 65 99.7 0.92 4.76 0.13 0.04 0.01
650 67 100.0 0.52 2.69 0.08 0.02 0.00
Proportion in total HC yield 18.14 27.20 43.48 11.19
Kutushskaya 264 well, silicite, 1,972.00 m, D3f2.ro A 16.06E+12 s-1
325 43 2.1 1.19 0.11 0.68 1.78 2.50
350 45 4.5 1.34 0.29 1.06 1.88 2.21
375 47 9.0 2.62 0.70 2.44 3.54 3.61
400 48 22.9 8.91 2.40 7.47 12.84 11.97
425 50 45.7 17.56 5.39 16.75 23.13 23.83
450 52 70.9 25.57 9.60 26.44 31.09 34.30
475 54 85.5 19.17 12.87 24.46 19.08 17.25
500 55 91.5 9.25 15.15 13.34 4.70 2.63
525 57 94.8 5.36 15.57 4.75 1.27 1.50
550 59 96.8 3.37 12.97 1.58 0.42 0.08
575 61 98.2 2.41 10.55 0.52 0.08 0.04
600 63 99.1 1.72 7.64 0.27 0.08 0.03
625 64 99.7 0.98 4.34 0.14 0.06 0.04
650 66 100.0 0.56 2.43 0.11 0.05 0.02
Proportion in total HC yield 21.04 30.19 36.27 12.50
Table 2 continued
Pyrolysis temperature, °C Activation energy, kcal/mol Transformation ratio TR, % Proportion in total volume of generated products, % HC content, rel. %
CH4 C2-C5 C6-C14 Cl5+
Komi 1 well, siliceous limestone, 74.05 m, Dfidm A 74,14E+12 s 1
325 45 2.5 1.37 0.33 0.83 1.29 4.34
350 47 6.1 2.10 0.65 1.36 2.27 5.36
375 48 13.9 4.74 1.48 3.19 6.01 9.16
400 50 27.6 9.20 3.40 7.26 12.22 12.89
425 52 49.6 17.84 6.46 15.34 23.01 24.17
450 54 71.0 22.28 10.03 23.07 26.21 25.79
475 56 86.2 19.96 13.86 25.54 20.54 13.52
500 58 93.3 10.98 16.76 15.26 7.17 4.15
525 60 96.1 4.64 14.91 5.14 0.87 0.36
550 62 97.6 2.61 11.36 1.68 0.13 0.02
575 63 98.6 1.80 8.64 0.63 0.13 0.08
600 65 99.3 1.21 6.05 0.30 0.07 0.06
625 67 99.7 0.78 3.82 0.22 0.05 0.06
650 69 100.0 0.48 2.25 0.19 0.03 0.06
Proportion in total HC yield 17.98 30.65 38.42 12.95
Komi 1 well, oil shale, 112.85 m, D3f2dm A 22.02E+12 s-1
325 43 2.7 1.32 0.29 0.81 1.72 2.58
350 45 7.8 2.63 0.71 1.64 3.44 4.86
375 47 19.0 6.24 1.73 3.85 8.11 11.69
400 48 37.9 12.63 3.51 8.80 16.19 22.23
425 50 60.9 20.12 6.41 17.85 24.89 28.10
450 52 78.4 20.83 9.50 24.03 24.55 15.39
475 54 88.9 15.67 11.70 21.99 15.04 8.88
500 56 93.6 8.21 14.03 12.76 4.34 3.79
525 57 96.0 4.51 14.18 5.20 1.04 1.71
550 59 97.6 3.05 13.00 1.98 0.41 0.60
575 61 98.7 2.06 10.29 0.69 0.15 0.11
600 63 99.3 1.36 7.24 0.22 0.07 0.02
625 65 99.8 0.87 4.71 0.10 0.03 0.01
650 66 100.0 0.50 2.71 0.06 0.02 0.00
Proportion in total HC yield 17.49 26.57 45.55 10.39
Komi 1 well, silicite, 113.47 m, D3f2dm A 16,24E+12 s-1
325 43 1.6 0.79 0.27 0.51 1.10 0.72
350 45 4.3 1.33 0.67 0.90 1.75 1.34
375 47 9.6 2.72 1.61 1.97 3.00 4.01
400 48 21.7 6.85 4.23 5.30 7.73 8.89
425 50 46.8 17.92 10.27 13.61 20.61 23.05
450 52 72.8 26.50 16.85 23.92 28.37 32.09
475 54 91.0 26.71 22.09 29.20 26.85 24.52
500 55 98.2 13.50 22.73 19.97 10.08 5.33
525 57 99.2 2.05 8.26 3.62 0.37 0.03
550 59 99.4 0.45 3.03 0.45 0.04 0.01
575 61 99.6 0.32 2.56 0.20 0.03 0.01
600 63 99.7 0.34 2.82 0.13 0.05 0.00
625 64 99.9 0.28 2.46 0.11 0.01 0.00
650 66 100.0 0.25 2.15 0.12 0.02 0.00
Proportion in total HC yield 9.86 29.26 45.61 15.27
Verkhnetyumskaya 34 well, siliceous clay rock of the upper part of formation, 2,550.58 m, J3-Ki6g A 9.59E+12 s -1
325 42 0,81 0.40 0.40 0.25 0.41 0.78
350 44 2.50 0.84 0.73 0.49 0.95 1.46
375 46 7.00 2.33 1.94 1.37 2.84 3.26
400 48 19.92 7.33 5.11 4.53 9.18 10.06
425 49 44.96 17.75 11.87 12.27 22.36 21.00
450 51 72.96 28.37 10.68 29.11 32.15 33.58
475 53 88.84 22.62 12.80 27.72 22.61 21.70
500 55 94.93 10.56 13.70 15.98 7.30 5.47
525 56 97.42 4.67 14.50 5.90 1.49 1.87
550 58 98.46 2.04 9.31 1.66 0.38 0.54
End of Table 2
Pyrolysis temperature, °C Activation energy, kcal/mol Transformation ratio TR, % Proportion in total volume of generated products, % HC content, rel. %
CH4 C2-C5 C6-C14 C15+
575 60 99.01 1.08 6.31 0.40 0.13 0.08
600 62 99.43 0.85 5.41 0.15 0.07 0.03
625 64 99.77 0.68 4.30 0.10 0.07 0.12
650 65 100.00 0.47 2.95 0.06 0.05 0.05
Proportion in total HC yield 14.18 29.45 45.38 11.00
Verkhnetyumskaya 34 well, siliceous clay rock of the lower part of formation, 2,591.90 m, J3-K1&g A 1.69E+14 s -1
325 46 1.0 0.51 0.16 0.37 0.63 0.57
350 48 2.9 1.00 0.42 0.83 1.20 1.06
375 50 8.5 3.00 1.31 2.39 3.65 3.06
400 51 23.8 9.15 4.02 7.58 11.22 8.68
425 53 56.0 25.49 9.53 20.74 28.06 34.63
450 55 80.2 28.06 14.48 27.46 30.29 30.48
475 57 93.2 20.11 16.81 24.34 19.50 17.24
500 59 97.2 7.32 16.28 11.90 4.37 3.49
525 61 98.6 2.54 12.24 3.25 0.83 0.72
550 63 99.1 0.96 7.53 0.67 0.12 0.04
575 65 99.4 0.68 6,13. 0.23 0.05 0.02
600 67 99.7 0.54 5.07 0.12 0.03 0.01
625 69 99.9 0.39 3.71 0.06 0.03 0.00
650 71 100.0 0.25 2.33 0.06 0.03 0.01
Proportion in total HC yield 9.65 25.94 47.40 17.01
The increased volume of HC for the generation of which low reaction energy is required is as-
sociated with high initial bituminosity of Domanik deposits. Carbonate-siliceous rocks of Domanik deposits have a high sorption capacity due to both a relatively high silica content [34], and a significant concentration of OM - to 30-35 % TOC. Despite a long-term extraction with chloroform, parau-tochthonous bitumen partially remained in rocks. According to Rock-Eval results, the content of free HC (Si) in these samples after extraction was determined at the level of 2-3 mg HC/g of rock, which is about 25 % of Si value before extraction. Although the Si peak is not taken into account in the calculations of kinetic models, pyrolysis decomposition of resinous-asphaltene components could make a small contribution to the S2 peak exactly in the region of low temperatures. It is very difficult to quantitatively assess such a contribution to the volume of generated products.
The greatest differences are recorded between shales and carbonate rocks. In highly OM-enriched shales, an abrupt jump in generation is recorded at pyrolysis temperature of 400 °C, which corresponds to the activation energy of 49-50 kcal/mol. Before this jump, C6+ HC prevail among the generation products; after the jump, HC of C2-C5, C6-C14 and C15+ groups are generated in approximately equal volumes. Starting from the temperature of 500 °C (Ea = 56-58 kcal/mol), the extent of generation decreases, and, at the same time, the proportion of methane increases significantly reaching 90-95% in the composition of the generated products at temperatures above 550 °C.
In limestones and silicites, an increase in the volume of generated HC is recorded up to a higher temperature of 425-475 °C (Ea = 50-54 kcal/mol) compared to shales; a decrease in generation begins from 525 °C (Ea = 59 kcal/mol). The patterns of change in the ratios of different HC groups in the generation products remain the same as those observed in shales: C6+ HC predominate up to the generation maximum, after which methane generation increases. Thus, at the same temperature, the difference between the volumes of generated HC in rocks of the above lithotypes reaches 20-30 %. This is especially noticeable during generation of groups of gaseous HC of C2-C5 and liquid C6-C14, and C15+ HC. The generation of large volumes of methane begins at higher temperatures compared to liquid HC, and by this stage the differences in the intensity of its formation between lithotypes become less noticeable. All other things being equal, the extent of HC generation in different rock lithotypes can differ 3-5-fold. In the presence of interbeds of different lithological composition in the source
rock formation, which is especially characteristic of Domanik deposits, it is necessary to calculate weighted average kinetic models depending on the ratios of different lithotypes in the composition of formation.
In all the investigated samples of Domanik deposits, the proportion of liquid C6+ HC in total volume of generated products is 50-55 %, and the share of gaseous C1-C5 HC is 45-50 %.
Thermal transformation of kerogen of the Bazhenov formation is also divided into several stages for each of which certain patterns are recorded.
The first stage is characterized by a significant prevalence of liquid HC (C6-C14 and C15+) in the composition of generation products. Thus, in all analysed samples of the Bazhenov formation, the prevalence of liquid HC (60-70 %) is recorded to the temperature of 475 °C. Ea value corresponding to this temperature is somewhat higher compared to the Domanik samples - 53-55 kcal/mol (Fig.2).
At the second stage (500-550 °C, Ea = 53-58 kcal/mol), a gradual decrease in the proportion of liquid HC and an increase of gaseous HC in the composition of kerogen pyrolysis products is recorded. At the same time, a significant decrease in the content of relatively heavy hydrocarbon components (C15+) is noted in the composition of liquid HC, and a gradual increase in the proportion of methane in the composition of gases.
The third stage of OM transformation in the Bazhenov formation is distinguished by a significant increase in the proportion of methane (over 80 %) in the composition of the generation products, which is recorded at heating above 575 °C, which corresponds to Ea = 60-65 kcal/mol. At this stage, there is an almost complete cessation of the generation of liquid HC, especially heavy C15+, which indicates the manifestation of processes characteristic of the main gas formation zone.
Based on results of thermal transformation of kerogen from different oil and gas source rocks obtained in laboratory experiments, modelling of HC generation was performed, which takes into account both the heterogeneous chemical structure (OM type) and the change in geological conditions (geothermal gradient and subsidence rate). For a correct comparison, the calculation of kinetic models was carried out for the same averaged geological conditions of deposit subsidence: subsidence rate of 50 m/Ma with a constant geothermal gradient of 25 °C/km.
OM of the Domanik deposits begins to generate HC at lower temperatures compared with OM of the Bazhenov formation (Table 2). Early generation of HC by the Domanik deposits was noted by many scientists [28, 35]. According to the results obtained, the generation of HC by the beginning of the main phase of oil formation (vitrinite reflectivity Ro = 0.5 %) in Domanik reaches 15-20 % of the initial generation potential, and in the Bazhenov formation it is less than 5% (Fig.3). A probable cause of early generation of HC in Domanik is an increased bituminosity of the source OM [28]. The specificity of thermal transformation of Domanik OM, along with a more intense geothermal regime
in the past characteristic of Paleozoic basins contributes to a decrease in the manifestation depth of oil and gas formation phases. The Timan-Pechora and Volga-Ural basins are characterized by reduced depth zonation of OM catagenesis [24].
Quantitative assessment of realization of oil and gas source potential of the Domanik and Bazhenov formations showed that the differences in the ratio of different groups of HC (CH4, C2-C5, C6-C14 and C15+) in total generation are insignificant (Fig.4). The predominance of "light" oil (HC C6-C14) in the generation products is characteristic of all the studied oil source rocks. OM of the Domanik formation
100 80 60 40 20
°50 100 150 200 250 300
T, °c
047 0.68 0 83 1.04 1.45 2.35_
0.20 0.55 0.76 0.93 1.18 1.87
Vitrinite reflectivity Ro, %
Fig.3. Comparison of results of kinetic modelling of HC generation by different source formations.
Modelling of HC generation is performed for averaged values of subsidence rate 50 m/Ma, geothermal gradient 5 °C/km
is distinguished by a slightly higher proportion of methane in the composition of the generated HC. This is due to a significant contribution of the transformation products of chitinous parts of zooplankton, which belong to humoid components and enrich OM with cyclic structures [28], which distinguishes it from OM of the Mesozoic formation.
The kinetic studies of two highly OM-enriched oil source rocks in sedimentary basins in the Russian Federation (Bazhenov formation and Domanik deposits) demonstrated specific features of catagenetic transformation of OM in each of them. Multicomponent kinetic models of HC generation calculated for oil source rocks increase the reliability of basin modelling results.
Conclusion. One of the main target of modelling oil and gas generation and accumulation systems of sedimentary basins consists in identification of oil source deposits and their generation characteristics, which, along with OM-enrichment of rocks, comprise the kinetics of its thermal transformation. Therefore, generation and updating of libraries (databank) of kinetic spectra of oil and gas source rocks in sedimentary basins with new multicomponent models is a relevant challenge. The article presents the results of determining the kinetic parameters of source formations of three main oil-and-gas bearing basins in the Russian Federation.
Comparative analysis of the results of kinetic studies of high-carbon source deposits of the Do-manik and Bazhenov horizons containing similar types of OM showed significant differences in the time-temperature dynamics of HC generation. OM of the Domanik deposits begins to generate HC at lower temperatures compared to OM of the Bazhenov formation. Generation products of both source rocks are dominated by "light" oil (C6-C14 HC - 40-45 %). OM of the Domanik formation is noted for a slightly higher proportion of methane in the composition of the generated HC.
The use of experimentally obtained kinetic spectra enables geologists to make more reliable forecasts of the generation time and relative quantities of oil and gas in computer modelling of HC formation process in the history of geological evolution of the basin.
50 40
0
If 30
1 "B 20
? o. o ^
10
0
o K
CH4 C2C5 C6-C14 C15+
D3f'2.3dm JiKiig
Fig. 4. Ratio of different HC groups in total volume of generation products in oil-gas source rocks of different age
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Authors: Svetlana V. Mozhegova, Senior Researcher, [email protected], https://orcid.org/0009-0003-2235-2752 (Scientific and Analytical Centre of Aprelevka Branch, All-Russian Research Geological Oil Institute, Aprelevka, Russia), Roman S. Gerasimov, Researcher, https://orcid.org/0009-0008-5887-978X (Scientific and Analytical Centre of Aprelevka Branch, All-Russian Research Geological Oil Institute, Aprelevka, Russia), Irina L. Paizanskaya, Candidate of Chemical Sciences, Head of Laboratory, https://or-cid.org/0009-0005-1393-3795 (Scientific and Analytical Centre of Aprelevka Branch, All-Russian Research Geological Oil Institute, Aprelevka, Russia), Anna A. Alferova, Engineer of the 1st Category, https://orcid.org/0009-0003-9873-794X (Scientific and Analytical Centre of Aprelevka Branch, All-Russian Research Geological Oil Institute, Aprelevka, Russia), Elizaveta M. Kravchenko, Engineer of the 1st Category, https://orcid.org/0009-0007-2714-6607 (Scientific and Analytical Centre of Aprelevka Branch, All-Russian Research Geological Oil Institute, Aprelevka, Russia).
The authors declare no conflict of interests.
