scholarly journals Joint analysis of seismic and well log data applied for prediction of oil presence in Maykop deposits in Naftalan area

2021 ◽  
Vol 7 (3) ◽  
pp. 331-337
Author(s):  
Maleyka Agha Ali Aghayeva ◽  
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Well Logging ◽  
Oil Field ◽  
Seismic Survey ◽  
Joint Analysis ◽  
3D Seismic ◽  
Oil Saturation ◽  
North East ◽  
Joint Application

<abstract> <p>The paper is devoted to joint application of 3D seismic survey and well logging techniques to study oil and gas presence in Maykop deposits in Naftalan oil field. The field is located in Naftalan-Northern Naftalan area of Ganja oil and gas province, Azerbaijan. The paper brings data about Naftalan field, the ancient brachianticline type of field in Azerbaijan. The paper also considers the history of study of the field by use of geological and geophysical techniques. Despite the studies cover the area since 1873, the oil and gas presence in Maykop has not been studied sufficiently due to sparse network of wells and insufficient amount of core samples. To avoid this gap the results of previous studies have been revised. Joint interpretation of well logging data acquired from 22 wells and data of 3D seismic survey covering the area has been done. On the basis of oil-saturation cube, we have designed the map (the area between the top and the foot of I horizon of Maykop) and 3D model of target interval. It has been defined that uneven distribution of oil saturation and poor oil recovery depends also on sedimentation environment, characterized by rapid subsidence of the basin and increasing amount of clay in the process of sedimentation. Our studies revealed that the average value of oil saturation varies as 0.5–0.6 and increases towards the North-East of the study area. In the final stage of the study we have presented the oil saturation cube and the map drawn on the basis of this cube.</p> </abstract>

From Biomedical to Oil Industry: Promising Mesoporous Materials for Oil Field Applications

2021 ◽  
Author(s):  
Ahmed Wasel Alsmaeil ◽  
Mohamed Amen Hammami ◽  
Amr Ismail Abdel-Fattah ◽  
Mazin Yousef Kanj ◽  
Emmanuel P Giannelis
Keyword(s):  
Mesoporous Silica ◽  
Interfacial Tension ◽  
Mesoporous Materials ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Mesoporous Silica Nanoparticles ◽  
Exchange Process ◽  
Oil Field ◽  
Stimuli Responsive ◽  
High Salinity Water

Abstract Developing nanocarriers deliver molecules to targeted locations has received widespread attention in different fields ranging from biomedical to oil and gas industries. Mesoporous Silica Nanoparticles (MSNs), where the pore size diameter ranges from 2-50 nm, have become attractive in many fields including biomedicine. One advantage is the ability to control the size, morphology of the particles, and the internal and external surfaces properties which enable encapsulating molecules of different size and charges. Moreover, it is possible to functionalize the pores and the surface of the MSNs, which make them suitable to host different molecules and release them in situ in a controlled manner. Despite the numerous studies of MSNs, little has been devoted to subsurface applications. This review will highlight some of the interesting characteristics of MSNs that make them promising carriers of molecules for slow and/or stimuli-responsive delivery for oil field applications. For example, they could be utilized for the controlled release of surfactants for enhanced oil recovery applications to minimize surfactant losses near the well-bore area. The mesoporous materials can be designed to harvest the ions normally present in oil field water, and the high temperatures encountered when travelling deep in the reservoir to release the surfactant. The ion exchange process makes it possible to engineer the MSNs to release their cargo for efficient and stimuli responsive delivery applications. The ion-responsive release was analyzed by the interfacial tension behavior between crude oil and high salinity water (HSW). It is concluded that the interfacial tension could be reduced up to 0.0045 mN/m when the mesoporous silica particles are suspended in HSW in comparison to 0.9 mN/m when suspended in DI water.

CarbonNet progress towards a declaration of identified storage formation at the Pelican site with a new high-resolution 3D seismic dataset

2020 ◽  
Vol 60 (2) ◽  
pp. 718
Author(s):  
Nick Hoffman
Keyword(s):  
High Resolution ◽  
Greenhouse Gas ◽  
Oil And Gas ◽  
Co2 Storage ◽  
Gas Storage ◽  
Frequency Resolution ◽  
Seismic Survey ◽  
3D Seismic ◽  
Long Term Storage ◽  
Gippsland Basin

The CarbonNet project is making the first ever application for a ‘declaration of an identified greenhouse gas storage formation’ (similar to a petroleum location) under the Offshore Petroleum and Greenhouse Gas Storage Act. Unlike a petroleum location, however, there is no ‘discovery’ involved in the application. Instead, a detailed technical assessment is required of the geological suitability for successful long-term storage of CO2. The key challenges to achieving a successful application relate to addressing ‘fundamental suitability determinants’ under the act and regulations. At Pelican (Gippsland Basin), a new high-resolution 3D seismic survey and over 10 nearby petroleum wells (and over 1500 basinal wells) supplement a crestal well drilled in 1967 that proved the seal and reservoir stratigraphy. The GCN18A 3D marine seismic survey has the highest spatial and frequency resolution to date in the Gippsland Basin. The survey was acquired in water depths from 15 to 35 m with a conventional eight-streamer seismic vessel, aided by LiDAR bathymetry. The 12.5 m bin size and pre-stack depth migration with multiple tomographic velocity iterations have produced an unprecedented high-quality image of the Latrobe Group reservoirs and sealing units. The 3D seismic data provides excellent structural definition of the Pelican Anticline, and the overlying Golden Beach-1A gas pool is excellent. Depositional detail of reservoir-seal pairs within the Latrobe Group has been resolved, allowing a confident assessment of petroleum gas in place and CO2 storage opportunities. The CarbonNet project is progressing with a low-risk storage concept at intra-formational level, as proven by trapped pools at nearby oil and gas fields. Laterally extensive intra-formational shales provide seals across the entire structure, providing pressure and fluid separation between the overlying shallow hydrocarbon gas pool and the deeper CO2 storage opportunity. CarbonNet is assessing this storage opportunity and progressing towards a ‘declaration of an identified greenhouse gas storage formation’.

THE YELLOWTAIL OIL DISCOVERY

1983 ◽  
Vol 23 (1) ◽  
pp. 170
Author(s):  
A. R. Limbert ◽  
P. N. Glenton ◽  
J. Volaric
Keyword(s):  
Oil Recovery ◽  
Seismic Data ◽  
Joint Venture ◽  
Seismic Survey ◽  
3D Seismic ◽  
Well Control ◽  
Reservoir Volume ◽  
3D Data ◽  
Small Feature ◽  
Gippsland Basin

The Esso/Hematite Yellowtall oil discovery is located about 80 km offshore in the Gippsland Basin. It is a small accumulation situated between the Mackerel and Kingfish oilfields. The oil is contained in Paleocene Latrobe Group sandstones, and sealed by the calcareous shales and siltstones of the Oligocene to Miocene Lakes Entrance Formation. Structural movement and erosion have combined to produce a low relief closure on the unconformity surface at the top of the Latrobe Group.The discovery well, Yellowtail-1, was the culmination of an exploration programme initiated during the early 1970's. The early work involved the recording and interpretation of conventional seismic data and resulted in the drilling of Opah- 1 in 1977. Opah-1 failed to intersect reservoir- quality sediments within the interpreted limits of closure although oil indications were encountered in a non-net interval immediately below the top of the Latrobe Group. In 1980 the South Mackerel 3D seismic survey was recorded. The interpretation of these 3D data in conjunction with the existing well control resulted in the drilling of Yellowtail-1 and subsequently led to the drilling of Yellowtail-2.In spite of the intensive exploration to which this small feature has been subjected, the potential for its development remains uncertain. Technical factors which affect the viability of a Yellowtail development are:The low relief of the closure makes the reservoir volume highly sensitive to depth conversion of the seismic data.The complicated velocity field makes precise depth conversion difficult.The thin oil column reduces oil recovery efficiency.The detailed pattern of erosion at the top of the Latrobe Group may be beyond the resolution capability of 3D seismic data.The 3D seismic data may not be capable of defining the distribution of the non-net intervals within the trap.The large anticlinal closures and topographic highs in the Gippsland Basin have been drilled, and the prospects that remain are generally small or high risk. Such exploration demands higher technology in the exploration stage and more wells to define the discoveries, and has no guarantee of success. The Yellowtail discovery is an illustration of one such prospect that the Esso/Hematite joint venture is evaluating.

3d seismic survey design: a reasonable solution for the Douleb oil field-central of Tunisia

2016 ◽  
Author(s):  
Nejmaoui Mohamed ◽  
Mohamed Hedi Inoubli ◽  
Kawthar Sebei ◽  
Mohamed Houssem Kallel
Keyword(s):  
Survey Design ◽  
Oil Field ◽  
Seismic Survey ◽  
3D Seismic ◽  
Reasonable Solution

scholarly journals RESEARCH OF THE MECHANISM OF OIL RECOVERY FROM HYDROCARBON DEPOSITS WITH LOW PERMEABILITY RESERVOIRS

2020 ◽  
Vol 17 (34) ◽  
pp. 892-904
Author(s):  
Zinon A KUANGALIEV ◽  
Gulsin S DOSKASIYEVA ◽  
Altynbek S MARDANOV
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
New Technologies ◽  
High Viscosity ◽  
Economic Feasibility ◽  
Oil Field ◽  
Low Permeability ◽  
Low Grade ◽  
Oil Reserves ◽  
Low Permeability Reservoirs

The main part of Russia's hard-to-recover reserves is 73% for low-grade and carbonate reservoirs, 12% for high-viscosity oil, about 15% of extensive sub-gas zones of oil and gas deposits and 7% of reservoirs lying at great depths. The development of such stocks with the usage of traditional technologies is economically inefficient. It requires the application of new technologies for their development and fundamentally new approaches to design, taking into account the features of extraction of hard-to-extract reserves (HtER). The purpose of this research is to find ways to improve the performance of low-permeability reservoirs. To accomplish this task, the Novobogatinsk South-Eastern Oil Field has been taken as an example and described. The necessary properties of production facilities in the field are highlighted, along with economic feasibility and technological efficiency. The reserves involved in the development are determined and, thanks to the knowledge of the geological oil reserves of the deposits, the potential oil recovery factor is calculated with the existing development technology. As a result of the research, development options were worked out with the results of the calculation of design indicators for the field as a whole. The comparison of oil recovery schedules and ORI, as well as the layout of wells, have been presented. As a result of the study, a description of 3 options for the development of design indicators for the field as a whole is given. The figures show oil production graphs, as well as location patterns. The authors of the study conclude which of the recommended development options can help extract maximum oil reserves.

scholarly journals Evaluation of oil and gas potential of blocks A and B Song Hong basin and suggested exploration plan

2015 ◽  
Vol 18 (4) ◽  
pp. 12-31
Author(s):  
Luan Thi Bui
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Petroleum System ◽  
Basement Rock ◽  
3D Seismic ◽  
Oil Accumulation ◽  
Recovery Coefficient ◽  
Gas Accumulation ◽  
Risk Parameters ◽  
Gas Potential

Basing on the structure, stratigraphic, depositional conditions and petroleum system the petroleum prospect, Song Hong northern basin, particularly, blocks A and B was evaluated. SIgnificantly high gas potential areas are Hong Ha, Sapa and Bach Long Bac structural sections. Predominantly oil potential is found in Hau Giang and Vam Co Dong structural areas. Low gas potential is found in Cay Quat and Ben Hai structural sections and low oil potential is found in Vam Co Tay, Chi Linh, Do Son and Tien Lang structural areas. The result of the calculation of a petroleum accumulattion capacity at the local, enhanced recoveral volume, risk parameters for stored gas and oil amount in blocks A and B are the oil potential in Kainozoi basement rock (KZ): oil accumulation volume at the local is 1722.9 million barrels (273.9 million cubic meters); oil recovery coefficient is 0.25 %; oil recoverable amount is 430.7 million barrels (68.5 million cubic meters). The gas potential in Miocene structural areas: gas accumulation volume at the local is 1620 BSCF (45.8 billion cubic meters); gas recoverable amount is 972 BSCF (27.5 billion cubic meters). The coefficient of success is quite low at 0.18 - 0.31 for gas and 0.08 – 0.23 for oil. Suggestion for the exploitation and exploration in further steps is to servey the 3D seismic in a 1500 square kilometer area and drill 2 wells for the exploration.

scholarly journals Review of Oilfield Chemicals Used in Oil and Gas Industry

2021 ◽  
pp. 8-24
Author(s):  
M. Chukunedum Onojake ◽  
T. Angela Waka
Keyword(s):  
Natural Gas ◽  
Crude Oil ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Petroleum Industry ◽  
Oil And Gas Industry ◽  
Oil Field ◽  
Wide Range ◽  
Oilfield Chemicals

The petroleum industry includes the global processes of exploration, extraction, refining, transportation and marketing of natural gas, crude oil and refined petroleum products. The oil industry demands more sophisticated methods for the exploitation of petroleum. As a result, the use of oil field chemicals is becoming increasingly important and has received much attention in recent years due to the vast role they play in the recovery of hydrocarbons which has enormous  commercial benefits. The three main sectors of the petroleum industry are Upstream, Midstream and Downstream. The Upstream deals with exploration and the subsequent production (drilling of exploration wells to recover oil and gas). In the Midstream sector, petroleum produced is transported through pipelines as natural gas, crude oil, and natural gas liquids. Downstream sector is basically involved in the processing of the raw materials obtained from the Upstream sector. The operations comprises of refining of crude oil, processing and purifying of natural gas. Oil field chemicals offers exceptional applications in these sectors with wide range of applications in operations such as improved oil recovery, drilling optimization, corrosion protection, mud loss prevention, drilling fluid stabilization in high pressure and high temperature environment, and many others. Application of a wide range of oilfield chemicals is therefore essential to rectify issues and concerns which may arise from oil and gas operational activities. This review intends to highlight some of the oil field chemicals and  their positive applications in the oil and gas Industries.

scholarly journals To the experience of Shkapovo oilfield development

Georesursy ◽  
2019 ◽  
Vol 21 (4) ◽  
pp. 119-122
Author(s):  
Evgeny V. Lozin
Keyword(s):  
Oil Recovery ◽  
High Performance ◽  
Oil And Gas ◽  
Construction Material ◽  
Oil Field ◽  
Public Works ◽  
Centrifugal Pumps ◽  
Oil Reserves ◽  
Large Platform ◽  
Capital Construction

The article formulates the main conclusions about the development of a large Shkapovsky oil field with an emphasis on the results of the development of the main objects – horizons DI and DIV of the terrigenous Devonian. The field was commissioned following the neighboring Tuimazinsky and Serafimovsky fields, taking into account the experience of a scientifically organized system for the development of these large platform oil fields in the Volga-Ural oil and gas region. It is shown that this experience was not taken into account much, especially in relation to the unsecured needs of oil production with capital construction, material and technical supply and social facilities. The potential of the field was realized in 18 years. Intra-contour and focal flooding, production technologies using electric centrifugal pumps (ESP), chemicalization of oil extraction processes, primary collection and transportation of products, oil, gas and water treatment technologies, etc., accelerated the development. Shkapov engineers and scientists own a number of innovations: realizing high development rates, means of preventing and eliminating salt-paraffin deposits, the introduction of double-barrel drilling, the development of high-performance ESPs, separate development of facilities, etc. At the same time, tasks were solved on eliminating ecological imbalance in the bowels and the environment, housing and public works. The current urgent problem of the field’s additional development is the activation of the production of residual oil reserves from oil and watered zones drilled with an unreasonably rare grid of wells. The final oil recovery coefficients of the Devonian objects are expected to be high, but, according to the author of the article, could reach CU 0.6.

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