A Multi-Process Reservoir Modelling Workflow as the Key for Unlocking Reservoir Prediction in Carbonates. Application to a Sector Model from the Albion R&D Project

2021 ◽  
Author(s):  
Gérard Joseph Massonnat ◽  
Charles Danquigny ◽  
Emmanuelle Leonforte ◽  
Lucie Dal Soglio ◽  
Mickael Barbier ◽  
...  
Keyword(s):  
Lattice Gas ◽  
Carbonate Platform ◽  
Carbonate Sediments ◽  
Reservoir Properties ◽  
Reservoir Prediction ◽  
Depositional Facies ◽  
Sector Model ◽  
Geological Processes ◽  
Multi Stage ◽  
Well Data

Abstract In carbonate reservoirs, because of the diversity of geological processes involved in the reservoir construction, the extrapolation of properties directly from well data to reservoir model gridblocks may lead to poorly predictive reservoir properties and then production forecasts. This paper proposes a modelling workflow in which new tools from disruptive technologies are associated in order to produce reservoir models consistently with reservoir geological construction. The workflow combines the simulation of the depositional facies and their transformation after diagenesis overprint. Original depositional facies are carried out from SED-RES™, a stratigraphic forward modelling software that generates and transports carbonate sediments according to ecological conditions and wind-induced currents. Then GODIAG™, a lattice gas, reproduces the evolution of the properties of the sediment after it has been deposited. The diagenesis history can be multi-stage and can involve different kinds of physical and chemical reactions. This new workflow has been evaluated in the framework of the ALBION R&D Project dedicated to the study of the Barremian-Aptian rudist-rich carbonate platform from south France that is known as an analogue of the Kharaib and Shuaiba reservoirs (UAE). Thanks to its multi-scale and multi-site aspect, ALBION offers the opportunity to test new modelling tools. The efficiency of the new workflow has been successfully applied on a sector model from an ALBION site on which a rich geological and petrophysical dataset is available from outcrops and numerous wells,

Defining Heterogeneity and Compartmentalisation Predictions of Minor Reservoirs in Fluvial Environments: Geological and Dynamic Context

2021 ◽  
Author(s):  
Nur Azah Zulkifli ◽  
Lisa Claire Chisholm ◽  
Amy Mawarni M Yusoff ◽  
Nur Khairina Kosnon ◽  
Mohd Zubair Mohd Azkah ◽  
...  
Keyword(s):  
Seismic Analysis ◽  
Primary Objective ◽  
Lessons Learned ◽  
Reservoir Modeling ◽  
Well Performance ◽  
Reservoir Properties ◽  
Reservoir Prediction ◽  
Depositional Facies ◽  
Fundamental Study ◽  
Well Production

Abstract Reservoirs in MN Field comprise predominantly fluvial delta deposits. A number of reservoir modeling studies have been performed for major reservoirs, however, there are still challenges to be addressed. After 20 plus years of production, a project for minor reservoirs has been crafted based on the understanding and challenges of major reservoirs. The primary objective of this study was to improve the understanding of the uncertainties impacting the well performance and reservoir connectivity; and to find potential infill opportunities. A 2D conceptual modelling approach was used as a practical way to incorporate the static and dynamic data of logs, core, seismic and pressure data. Taking the lessons learned from the major reservoir performances, this study focused on the fluvial reservoir sedimentology to address and decrease the uncertainties through the different scales of heterogeneity. Consequently, depositional facies maps were developed with the integration of geophysical study and interpretation derived from seismic analysis. These integrated depositional facies maps were then further refined with the well production data and scenarios of multiple compartments from multiple iterations to fit into the conceptual models of this field. Refined paleo depositional maps for these minor reservoirs allowed for a better understanding on reservoir heterogeneities and further improved the geological understanding. This fundamental study can show us a more precise distribution and tendency of the sand and the scales of heterogeneity with different depositional facies. However, capturing and preserving the different levels of heterogeneities and compartmentalization is complex for some thin sand reservoirs which are below seismic resolution and have low correlation of reservoir properties-seismic response. Additionally, multiple compartments were inferred due to pressure difference and multiple contacts within a reservoir. This was further complicated by the uncertainty in log interpretation due to inadequacy of high confidence data (DST/fluid sampling), suppressed resistivity from shaly sands and below log resolution of thin beds. Despite of these issues and challenges, with integration of all the data available and rigorous team discussions; the minor reservoirs depo-facies, static and dynamic compartmentalization were finalized, leading to enhancement of reservoir prediction, communication and quality.

scholarly journals Reservoir characterisation using process-response simulations: the Lower Cretaceous Rijn Field, West Netherlands Basin

2003 ◽  
Vol 82 (4) ◽  
pp. 313-324
Author(s):  
L.J.H. Alberts ◽  
C.R. Geel ◽  
J.J. Klasen
Keyword(s):  
Seismic Data ◽  
Lower Cretaceous ◽  
Small Scale ◽  
Depositional Model ◽  
Response Model ◽  
Reservoir Properties ◽  
Reservoir Heterogeneity ◽  
Geological Processes ◽  
Basin Scale ◽  
Well Data

AbstractPetroleum geologists always need to deal with large gaps in data resolution and coverage during reservoir characterisation. Seismic data show only large geological structures, whereas small-scale structures and reservoir properties can be observed only at well locations. In the area between wells, these properties are often estimated by means of geostatistics. Numerical simulation of sedimentary processes offers an alternative method to predict these properties and can improve the understanding of the controls on reservoir heterogeneity. Although this kind of modelling is widely used on basin scale in exploration geology, its application on field scale in production geology is virtually non-existent. We have assessed whether the recent developments in numerical modelling can also aid petroleum geologists in the interpretation of the reservoir geology.Seismic data, well data and a process-response model for coastal environments were used to characterise the Lower Cretaceous oil-bearing Rijn Field. Interpretation of seismic and well data led to a definition of the structural setting and the depositional model of the Rijn Member in the area. From the sedimentological interpretation the sea-level history could be estimated, which is the one of the most important input parameters for the process-response model.Application of the process-response simulator to the Rijn Field resulted in approval of the depositional model. The output was presented in a 2-dimensional north-south profile, which corresponds very well to the well logs along this section. The results demonstrate that numerical simulations of geological processes can be very useful as a tool to explore many likely geological scenarios. While it cannot be used to supply a unique solution in many cases, it forms a helpful guide during reservoir characterisation to find an optimal scenario of the controls on deposition of the Rijn Member, which contributes to the understanding of the inter-well reservoir heterogeneity.

Seismite in the Devonian Sultan Formation, Frenchman Mountain, Nevada: Evidence of far-field effect of the Alamo Event

2016 ◽  
Vol 53 (2) ◽  
pp. 93-114
Author(s):  
Jesús Pinto ◽  
John Warme
Keyword(s):  
Carbonate Platform ◽  
Far Field ◽  
Carbonate Sediments ◽  
Impact Event ◽  
Complex Matrix ◽  
Near Surface ◽  
Fault Block ◽  
Southern Nevada ◽  
Salt Pan ◽  
The Alamo

We interpret a discrete, anomalous ~10-m-thick interval of the shallow-marine Middle to Late Devonian Valentine Member of the Sultan Formation at Frenchman Mountain, southern Nevada, to be a seismite, and that it was generated by the Alamo Impact Event. A suite of deformation structures characterize this unique interval of peritidal carbonate facies at the top of the Valentine Member; no other similar intervals have been discovered in the carbonate beds on Frenchman Mountain or in equivalent Devonian beds exposed in ranges of southern Nevada. The disrupted band extends for 5 km along the Mountain, and onto the adjoining Sunrise Mountain fault block for an additional 4+km. The interval displays a range of brittle, ductile and fluidized structures, and is divided into four informal bed-parallel units based on discrete deformation style and internal features that carry laterally across the study area. Their development is interpreted as the result of intrastratal compressional and contractional forces imposed upon the unconsolidated to fully cemented near-surface carbonate sediments at the top of the Valentine Member. The result is an assemblage of fractured, faulted, and brecciated beds, some of which were dilated, fluidized and injected to form new and complex matrix bands between beds. We interpret that the interval is an unusually thick and well displayed seismite. Because the Sultan Formation correlates northward to the Frasnian (lower Upper Devonian) carbonate rocks of the Guilmette Formation, and the Guilmette contains much thicker and more proximal exposures of the Alamo Impact Breccia, including seismites, we interpret the Frenchman Mountain seismite to be a far-field product of the Alamo Impact Event. Accompanying ground motion and deformation of the inner reaches of the Devonian carbonate platform may have resulted in a fall of relative sea level and abrupt shift to a salt-pan paleoenvironment exhibited by the post-event basal beds of the directly overlying Crystal Pass Member.

Deep fluids and their role in hydrocarbon migration and oil deposit formation exemplified by supercritical СO2

2021 ◽  
pp. 1-11
Author(s):  
Sara LIFSHITS
Keyword(s):  
Supercritical Fluid ◽  
Oil And Gas ◽  
Gas Permeability ◽  
Sedimentary Rocks ◽  
Source Rocks ◽  
Reservoir Properties ◽  
Hydrocarbon Migration ◽  
Geological Processes ◽  
Before And After ◽  
Oil Source

ABSTRACT Hydrocarbon migration mechanism into a reservoir is one of the most controversial in oil and gas geology. The research aimed to study the effect of supercritical carbon dioxide (СО2) on the permeability of sedimentary rocks (carbonates, argillite, oil shale), which was assessed by the yield of chloroform extracts and gas permeability (carbonate, argillite) before and after the treatment of rocks with supercritical СО2. An increase in the permeability of dense potentially oil-source rocks has been noted, which is explained by the dissolution of carbonates to bicarbonates due to the high chemical activity of supercritical СО2 and water dissolved in it. Similarly, in geological processes, the introduction of deep supercritical fluid into sedimentary rocks can increase the permeability and, possibly, the porosity of rocks, which will facilitate the primary migration of hydrocarbons and improve the reservoir properties of the rocks. The considered mechanism of hydrocarbon migration in the flow of deep supercritical fluid makes it possible to revise the time and duration of the formation of gas–oil deposits decreasingly, as well as to explain features in the formation of various sources of hydrocarbons and observed inflow of oil into operating and exhausted wells.

scholarly journals The Arab Formation in central Abu Dhabi: 3-D reservoir architecture and static and dynamic modeling

GeoArabia ◽  
2003 ◽  
Vol 8 (1) ◽  
pp. 47-86 ◽  
Author(s):  
Jürgen Grötsch ◽  
Omar Suwaina ◽  
Ghiath Ajlani ◽  
Ahmed Taher ◽  
Reyad El-Khassawneh ◽  
...  
Keyword(s):  
Dynamic Modeling ◽  
Fourth Order ◽  
High Energy ◽  
Development Planning ◽  
Abu Dhabi ◽  
Small Scale ◽  
Reservoir Properties ◽  
Depositional Facies ◽  
Well Completion ◽  
Fifth Order

ABSTRACT A 3-D geological model of the Kimmeridgian-Tithonian Manifa, Hith, Arab, and Upper Diyab formations in the area of the onshore Central Abu Dhabi Ridge was based on a newly established sequence stratigraphic, sedimentologic, and diagenetic model. It was part of an inter-disciplinary study of the large sour-gas reserves in Abu Dhabi that are mainly hosted by the Arab Formation. The model was used for dynamic evaluations and recommendations for further appraisal and development planning in the studied field. Fourth-order aggradational and progradational cycles are composed of small-scale fifth-order shallowing-upward cycles, mostly capped by anhydrite within the Arab-ABC. The study area is characterized by a shoreline progradation of the Arab Formation toward the east-northeast marked by high-energy oolitic/bioclastic grainstones of the Upper Arab-D and the Asab Oolite. The Arab-ABC, Hith, and Manifa pinch out toward the northeast. The strongly bioturbated Lower Arab-D is an intrashelf basinal carbonate ramp deposit, largely time-equivalent to the Arab-ABC. The deposition of the Manifa Formation over the Arab Formation was a major back-stepping event of the shallow-water platform before the onset of renewed progradation in the Early Cretaceous. Well productivity in the Arab-ABC is controlled mainly by thin, permeable dolomitic streaks in the fifth-order cycles at the base of the fourth-order cycles. This has major implications for reservoir management, well completion and stimulation, and development planning. Good reservoir properties have been preserved in the early diagenetic dolomitic streaks. In contrast, the reservoir properties of the Upper Arab-D oolitic/bioclastic grainstones deteriorate with depth due to burial diagenesis. A rock-type scheme was established because complex diagenetic overprinting prevented the depositional facies from being directly related to petrophysical properties. Special core analysis and the attribution of saturation functions to static and dynamic models were made on a cell-by-cell basis using the scheme and honoring the 3-D depositional facies and property model. The results demonstrated the importance of integrating sedimentological analysis and diagenesis with rock typing and static and dynamic modeling so as to enhance the predictive capabilities of subsurface models.

Geological model and optimal well placement substantiation at the western part Tyumen suite layers of Khanty-Mansiysk Autonomous Okrug — Ugra

2021 ◽  
pp. 8-24
Author(s):  
S. R. Bembel ◽  
R. V. Avershin ◽  
R. M. Bembel ◽  
V. I. Kislukhin
Keyword(s):  
Seismic Survey ◽  
Geological Model ◽  
Reservoir Properties ◽  
Well Placement ◽  
Oil Reserves ◽  
Multi Stage ◽  
Reservoir Conditions ◽  
Hydrodynamic Calculations ◽  
Field Information ◽  
Clay Barriers

The middle Jurassic Tyumen sediments have been involved in the development of oil facilities in the territory of the Khanty-Mansiysk Autonomous Okrug — Ugra for the last decade. The Jk2-5 formation is represented by complex interlayering of poorly permeable sandy-aleurite lenses and clay barriers with low reservoir properties. Recoverable oil reserves of the Jk2-5 formation on the Krasnoleninsky arch amounts to several hundred million tons. According to the collector permeability, the reserves of the object are classified as hard-to-recover. There are no effective technologies to involve such reserves in the development now. Standard methods of drilling and operation of inclined wells doesn't allow achieving acceptable oil production rates under these reservoir conditions. Based on the analysis of seismic survey data, correlation of well sections, field information, a geological model of a productive reservoir on the Krasnoleninsky arch was created. The multi-step hydrodynamic calculations made it possible to clarify the parameters of the profile of horizontal wells, the number and configuration of operations for multi-stage hydraulic fracturing. Based on the results of the research, recommendations were developed to well placement, drilling and well operation for specific field areas in order to increase the oil resource development efficiency.

Reservoir Quality Versus Completion Intensity: An Application of Supervised Fuzzy Clustering on Western Canadian Well Data

2021 ◽  
Author(s):  
Tamer Moussa ◽  
Hassan Dehghanpour ◽  
Melanie Popp
Keyword(s):  
Fuzzy Clustering ◽  
Oil And Gas ◽  
Approximate Reasoning ◽  
Design Parameters ◽  
Water Volume ◽  
Reservoir Quality ◽  
Reservoir Properties ◽  
High Quality ◽  
Tight Reservoirs ◽  
Well Data

ABSTRACT The industry is facing significant challenges due to the recent downturn in oil prices, particularly for the development of tight reservoirs. It is more critical than ever to 1) identify the sweet spots with less uncertainty and 2) optimize the completion-design parameters. The overall objective of this study is to quantify and compare the effects of reservoir quality and completion intensity on well productivity. We developed a supervised fuzzy clustering (SFC) algorithm to rank reservoir quality and completion intensity, and analyze their relative impacts on wells' productivity. We collected reservoir properties and completion-design parameters of 1,784 horizontal oil and gas wells completed in the Western Canadian Sedimentary Basin. Then, we used SFC to classify 1) reservoir quality represented by porosity, hydrocarbon saturation, net pay thickness and initial reservoir pressure; and 2) completion-design intensity represented by proppant concentration, number of stages and injected water volume per stage. Finally, we investigated the relative impacts of reservoir quality and completion intensity on wells' productivity in terms of first year cumulative barrel of oil equivalent (BOE). The results show that in low-quality reservoirs, wells' productivity follows reservoir quality. However, in high-quality reservoirs, the role of completion-design becomes significant, and the productivity can be deterred by inefficient completion design. The results suggest that in low-quality reservoirs, the productivity can be enhanced with less intense completion design, while in high-quality reservoirs, a more intense completion significantly enhances the productivity. Keywords Reservoir quality; completion intensity; supervised fuzzy clustering, approximate reasoning,tight reservoirs development

Rock Magnetic and Magnetostratigraphic Study of Chicxulub Crater Impact Breccias and Post-Impact Carbonates in the Yaxcopoil-1 and Santa Elena Boreholes

2020 ◽  
Author(s):  
Jaime Urrutia-Fucugauchi ◽  
Ligia Perez-Cruz ◽  
Elia Escobar-Sanchez ◽  
Miriam Velasco-Villarreal ◽  
Edgar Garcia-Garnica
Keyword(s):  
Oxygen Isotope ◽  
Carbonate Platform ◽  
Magnetic Hysteresis ◽  
Magnetization Vector ◽  
Carbonate Sediments ◽  
Carbon And Oxygen Isotope ◽  
Post Impact ◽  
Chicxulub Crater ◽  
The Impact ◽  
Santa Elena

<p>Chicxulub crater was formed ~66 Ma ago by an asteroid impact at the Cretaceous/Paleogene (K/Pg) boundary on the Yucatan carbonate platform in the southern Gulf of Mexico. The crater is the youngest and best preserved of the three large impact basins, with a ~200 km diameter and multi-ring and peak ring morphology. The crater, covered by post-impact carbonate sediments with thickness up to ~1.1 km, has been investigated by geophysical studies and drilling programs. Initial drilling in Yucatan was carried out by the Pemex oil company, followed by the National University UNAM Chicxulub program, the ICDP Yaxcopoil-1 project and the IODP-ICDP Expedition 364 marine drilling. Here, results of combined paleomagnetic, rock magnetic, petrographic and geochemical studies are used to characterize the sequence and constrain the unit’s emplacement and crater formation. We analyze core samples of suevitic breccias and Paleogene carbonates from the Yaxcopoil-1 and Santa Elena boreholes drilled in the southern sector, inside and to the south of the crater rim marked by the ring of cenotes.  Magnetic hysteresis, low-field susceptibility and coercitivity analyses indicate that main carriers are titanomagnetites and magnetite. Mineralogical and magnetic properties indicate effects of hydrothermal alteration, associated with the high temperature system generated by the impact. Higher coercitivity minerals are also observed in some samples. In the carbonate sections, hydrothermal effects as marked by the geochemical logs decrease upwards from the breccia-carbonate contact. Alternating field and thermal demagnetization is used to investigate the magnetization vector composition and isolate the characteristic remanent components. Magnetic polarities defined from the inclination data show a sequence of reverse to normal, which correlate to polarity chrons 29r to 26r, with impact occurring within 29r chron.  The correlations of the magnetostratigraphy and stable isotopes indicate a hiatus at the basal Paleocene section. In Santa Elena cores, d<sup>13</sup>C values range from 1.2 to 3.5%<sub>0 </sub>and d<sup>18</sup>O values range from -1.4 to -4.8%<sub>0, </sub>with variation trends correlating with the marine carbon and oxygen isotope records for the late Maastrichtian and early Paleocene. The positive carbon isotopes indicate high productivity after the K/Pg extinction event, while the oxygen isotope values are more negative reflecting regional and local effects. Silica contents decrease from high in the suevites to low values in carbonates showing higher variability and then increased contents at the Paleocene-Eocene Thermal Maximum (PETM). The geochemical trends correlate in other elements including iron, titanium, potassium and aluminum that record impact-induced hydrothermal effects and possibly changing depositional conditions. Ca shows an opposite trend, with lower values in the upper suevitic breccias, higher values in the Paleocene carbonates and lower values in the PETM.</p>

scholarly journals Calpionellid biostratigraphy and microfacies analysis of a Tithonian–Berriasian carbonate succession in the Western Srednogorie (Bulgaria)

2017 ◽  
Vol 46 (1) ◽  
pp. 65-92
Author(s):  
Silviya Petrova ◽  
Polina Andreeva ◽  
Lubomir Metodiev ◽  
Daniela Reháková ◽  
Jozef Michalík ◽  
...  
Keyword(s):  
Carbonate Platform ◽  
Carbonate Sediments ◽  
Marine Environments ◽  
Microfacies Analysis ◽  
Diagnostic Features ◽  
Depositional Settings ◽  
Lithostratigraphic Units

In the eastern part of the Western Srednogorie Unit, around Dragovishtitsa Village, a specific succession of the Gintsi and Glozhene–Slivnitsa formations has provided micropalaeontological evidence for late Tithonian (Chitinoidella, Praetintinnopsella and the base of Crassicollaria zones) and mid-Berriasian (the Elliptica Subzone of the Calpionella Zone) age on the basis of 45 chitinoidellid and calpionellid species. A significant stratigraphic hiatus is documented within the Glozhene–Slivnitsa Formation, since a part of the Crassicollaria Zone, as well as the Alpina+Remaniella subzones of the Calpionella Zone, is absent from the Dragovishtitsa 1 section. The conformably overlying Salash Formation is of mid-Berriasian age (Elliptica Subzone) and is locally characterized by the presence of calcareous sandstones (Dragovishtitsa 2 section). The Salash–Cherni Osam Formation, as well as the clayey limestone unit covering the Slivnitsa Formation, is also of mid-Berriasian age (Elliptica Subzone). The Slivnitsa and Glozhene–Slivnitsa formations, which underlie the Salash–Cherni Osam Formation in the Dragovishtitsa East section, correspond to the Crassicollaria Zone and the Alpina Subzone, respectively. Reworking of calpionellids from the Crassicollaria Zone is documented in the Alpina and Elliptica subzones in all three studied sections. Eight microfacies types are distinguished, which suggests that the carbonate sediments were deposited in a carbonate platform rather than in a pelagic basin environment, althought the upper part of the studied sections reveals an upward-deepening trend. The Slivnitsa Formation is covered by highly diachronous sediments from more distal settings: from mid-Berriasian around Dragovishtitsa Village to the Berriasian/Valanginian transition at the Tri Ushi section to late Valanginian in the Dragoman and Kalotina sections. This fact, together with the significant stratigraphic hiatus within the Glozhene–Slivnitsa Formation, is interpreted here as tectonically controlled. The presence of transitional depositional settings from carbonate platform to deeper-marine environments caused deposition of specific lithostratigraphic units not always corresponding to the diagnostic features of the Glozhene, Salash and Cherni Osam formations.

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