scholarly journals The forming mechanisms of Oligocene combination/stratigraphic traps and their reservoir quality in southeast Cuu Long Basin offshore of Vietnam

2019 ◽  
Vol 22 (1) ◽  
pp. 185-195
Author(s):  
Chuc Dinh Nguyen ◽  
Xuan Van Tran ◽  
Kha Xuan Nguyen ◽  
Huy Nhu Tran ◽  
Tan Thanh Mai
Keyword(s):  
Oil And Gas ◽  
Integrated Approach ◽  
Gas Production ◽  
Reservoir Quality ◽  
Hydrocarbon Potential ◽  
Seismic Attribute ◽  
Oil And Gas Production ◽  
Seismic Sequence Stratigraphy ◽  
The One

To date, most of the oil and gas production in Cuu Long Basin (CLB) is contributed from structural traps, making them more and more depleted after years of exploitation. Exploration activities in CLB, therefore, are shifting towards other traps, including stratigraphic and/or combination ones. The results of exploration and appraisal activities in recent years have increasingly discovered more hydrocarbons in the Oligocene section; some of them were discovered in combination/ stratigraphic traps. Many studies on Oligocene targets in Southeast CLB have been carried out but only a few mention nonstructural traps. This leads to uncertainty about the forming mechanisms and distribution, as well as unevaluated hydrocarbon potential of these traps. An integrated approach- utilizing methods of seismic sequence stratigraphy, seismic attribute interpretation, and petrophysical/ petrographical analysis- was applied in this research to identify the forming mechanisms of Oligocene combination/ stratigraphic traps in southeast area of CLB and to evaluate their reservoir quality. The research results show that the key forming factor for stratigraphic traps of sand body is lithology change and the one for pinch-out stratigraphic traps is tapering off of sand layers landward or toward the horsts. The reservoir quality of these traps ranges from moderate to good. By integratedly applying the methods, the forming mechanisms and reservoir quality of Oligocene stratigraphic traps could be delineated. In order to optimize the next-stage exploration strategy in CLB, detailed studies on petroleum system, especially top and bottom seals, and the hydrocarbon potential of these stratigraphic traps, need to be carried out.  

scholarly journals Applying seismic stratigraphy analysis for assessing upper Oligocene stratigraphic traps in Southeastern Cuu Long Basin

2017 ◽  
Vol 20 (K4) ◽  
pp. 48-56
Author(s):  
Chuc Dinh Nguyen ◽  
Tu Van Nguyen ◽  
Hung Quang Nguyen ◽  
Cuong Van Bui ◽  
Thanh Quoc Truong ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Seismic Stratigraphy ◽  
Gas Production ◽  
Hydrocarbon Potential ◽  
Seismic Attribute ◽  
Oil And Gas Production ◽  
Attribute Analysis ◽  
Exploration Drilling ◽  
Seismic Sections ◽  
Log Interpretation

As oil and gas production has been going on over a few decades, conventional plays such as pre-Tertiary fractured basement highs and Cenozoic structural traps become more and more exhausted, and the remaining targets of the same type do not have sufficient reserves for development and production. Exploration activities in Cuu Long basin, therefore, are shifting towards more complicating types of plays which are stratigraphic traps and combination traps. Several researches were conducted in southeastern marginal slope and indicated the possibility of stratigraphic pinch-out traps with insufficient petroleum system and low hydrocarbon potential. In spite of many researches, there are still difficulties in defining the distribution and in evaluating hydrocarbon potential of these traps, so seismic stratigraphy analysis in accompanied with interpretation of seismic attribute and well logs is very necessary to support this problem. Seismic stratigraphic analysis on seismic sections, in agreement with seismic attributes’ and log analysis’ findings, show that the stratigraphic/combination traps in Oligocene C and D were formed during lowstand system tract as sigmoid-oblique clinoforms downlapping onto underlying strata in distributary mouths/delta settings. The integration of seismic attribute analysis and well log interpretation has further defined the fan-shaped distribution of these traps. Thus, using various methods, the stratigraphic traps can be better revealed. Further studies, however, need to be carried out to fully evaluate hydrocarbon potential of these stratigraphic/ combination traps, and minimize risks in exploration drilling.

scholarly journals Impact of Diagenesis on the Reservoir Properties of the Cretaceous Sandstones in the Southern Bredasdorp Basin, Offshore South Africa

Minerals ◽  
2020 ◽  
Vol 10 (9) ◽  
pp. 757
Author(s):  
Temitope Love Baiyegunhi ◽  
Kuiwu Liu ◽  
Oswald Gwavava ◽  
Christopher Baiyegunhi
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Reservoir Quality ◽  
Reservoir Properties ◽  
Oil And Gas Production ◽  
Thin Sections ◽  
Hydrocarbon Reservoir ◽  
Porosity And Permeability ◽  
The Impact

The Cretaceous sandstone in the Bredasdorp Basin is an essential potential hydrocarbon reservoir. In spite of its importance as a reservoir, the impact of diagenesis on the reservoir quality of the sandstones is almost unknown. This study is undertaken to investigate the impact of digenesis on reservoir quality as it pertains to oil and gas production in the basin. The diagenetic characterization of the reservoir is based on XRF, XRD SEM + EDX, and petrographic studies of 106 thin sections of sandstones from exploration wells E-AH1, E-AJ1, E-BA1, E-BB1 and E-D3 in the basin. The main diagenetic processes that have affected the reservoir quality of the sandstones are cementation by authigenic clay, carbonate and silica, growth of authigenic glauconite, dissolution of minerals and load compaction. Based on the framework grain–cement relationships, precipitation of the early calcite cement was either accompanied or followed up by the development of partial pore-lining and pore-filling clay cements, particularly illite. This clay acts as pore choking cement, which reduces porosity and permeability of the reservoir rocks. The scattered plots of porosity and permeability versus cement + clays show good inverse correlations, suggesting that the reservoir quality is mainly controlled by cementation and authigenic clays.

Integrated Approach to Produced Water Disposal Management in a Brown Field: Safeguarding Production, Reducing Cost, Managing Deferment & Reducing HSSE Exposure

2021 ◽  
Author(s):  
Basil Ogbunude ◽  
Aniekan Obot ◽  
Abdul-Wahab Sa'ad ◽  
Sunday Maxwell-Amgbaduba ◽  
Etta Agbor ◽  
...  
Keyword(s):  
Water Management ◽  
Oil And Gas ◽  
Produced Water ◽  
Integrated Approach ◽  
Gas Production ◽  
Plant Oil ◽  
Endurance Time ◽  
Oil And Gas Production ◽  
Liquid Line ◽  
Positive Cash Flow

Abstract Often, the production of oil and gas from underground reservoirs is accompanied by produced water which generally increases with time for a matured field, attributable to natural water encroachment, bottom water ingress, coning effect due to higher production rates, channeling effects, etc. This trend poses a production challenge with respect to increased OPEX cost and environmental considerations of treatment/handling and disposal of the produced water considering the late life performance characterized by low reward margins. Hence, produced water management solutions that reduce OPEX cost is key to extending the field life whilst ensuring a positive cash flow for the asset. SK field is located in the Swamp Area of the Niger Delta, with a capacity of 1.1Bcf gas plant supplying gas to a nearby LNG plant. Oil and gas production from the field is evacuated via the liquid and gas trunk lines respectively. Due to the incessant tampering with oil delivery lines and environmental impact of spillage, the condensate is spiked through the gas trunk line to the LNG plant. Largely, the water/effluent contained in the tank is evacuated through the liquid line. Based on the availability of the liquid line (ca. 40%-60%), the produced water is a constraint to gas production with estimated tank endurance time (ca. 8 days at 500MMscfd). This leads to creaming of gas production and indeed gas deferments due to produced water management, making it difficult to meet the contractual supply obligation to the LNG plant. An interim solution adopted was to barge the produced water to the oil and gas export terminal, with an associated OPEX cost of ca. US$2Mln/month. Upon further review of an alternate barging option, this option was considered too expensive, inefficient and unsustainable with inherent HSSE exposure. Therefore, a produced water re-injection project was scoped and executed as a viable alternative to produced water management. This option was supported by the Regulators as a preferred option for produced water management for the industry.

Putting on partisan glasses: Political identity, quality of life, and oil and gas production in Colorado

Energy Policy ◽  
2019 ◽  
Vol 129 ◽  
pp. 738-748 ◽  
Author(s):  
Stephanie A. Malin ◽  
Adam Mayer ◽  
James L. Crooks ◽  
Lisa McKenzie ◽  
Jennifer L. Peel ◽  
...  
Keyword(s):  
Quality Of Life ◽  
Oil And Gas ◽  
Political Identity ◽  
Gas Production ◽  
Oil And Gas Production

Efficiency Criteria of Operations in the Marine Resuce Support for Hydrocarbons Production and Transportation in the Arctic Zone of the Russian Federation

2021 ◽  
Author(s):  
Tatyana Ivanovna Lapteva ◽  
Lyudmila Anatolyevna Kopaeva ◽  
Marat Nabievich Mansurov ◽  
Vladimir Ivanovich Efremov ◽  
Viktor Nikolayevich Ilyuhin
Keyword(s):  
Russian Federation ◽  
Oil And Gas ◽  
Practical Importance ◽  
Gas Production ◽  
The Arctic ◽  
Mathematical Methods ◽  
Arctic Seas ◽  
Oil And Gas Production ◽  
The Russian Federation

Abstract The creation of an effective system of rescue support (the abbreviation ASO is adopted on the territory of the Russian Federation) in the implementation of the processes of oil and gas production and transportation in the Arctic seas of Russia is an urgent and difficult task. The feasibility of creating such a system for offshore oil and gas production facilities is due to the statistics of accidents and incidents at such facilities, as well as the fact that the Merchant Shipping Code of the Russian Federation, in essence, does not consider the applicability of the existing system of rescue operations on platforms that are exploring and developing mineral and other non-living resources the seabed and its bowels. The successful solution of numerous problems of rescue support, including the requirements for the quality of the system, indicators and criteria for the effectiveness of the operations carried out, can be significantly increased by using mathematical models that make it possible to identify patterns in the processes of performing urgent work, improve the quality of planning, and, consequently, the efficiency of management of various organizational systems. Applied in many areas of activity, the scientific direction "research of operations" is advisable to use when system generation of rescue support within the framework of improving the system of technical regulation of oil and gas enterprises. Determining the effectiveness of a purposeful process quantitatively will allow, on a scientific basis, with the involvement of modern mathematical methods, to solve the problem of increasing the effectiveness of the use of forces and means of the marine rescue support, including the functioning of the emergency support system in the mode of daily and emergency activities, as well as the preparation of the necessary forces and means. The novelty of the presented work lies in the application of the provisions of the theory and the apparatus of operations research to assessing the effectiveness of the system of the marine rescue support, which will further serve as a methodological basis for the development of a number of documents and provisions that are of practical importance: methods, requirements for the system of rescue support, documents in the field of control over the rescue system, etc.

scholarly journals OPTIMIZATION OF THE OIL AND GAS PRODUCTION PROCESS IN THE CONCEPT DIGITAL DEPOSITS

2021 ◽  
Vol 1 (1) ◽  
pp. 213-214
Author(s):  
Oleg Arsent'ev ◽  
Dmitriy Ivanov ◽  
Kristina Saharovskaya
Keyword(s):  
Production Process ◽  
Intelligent Systems ◽  
Oil And Gas ◽  
Digital Technologies ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Technological Processes ◽  
Quality Of Products

The possibilities of using digital technologies in oil and gas production within the framework of the "Digital Field" concept are considered, and it is determined that the introduction of intelligent systems in technological processes increases the volume and quality of products while reducing their cost.

scholarly journals Energise or De-Energise to Trip?

2008 ◽  
Vol 41 (9) ◽  
pp. 276-281
Author(s):  
A G Foord ◽  
C R Howard
Keyword(s):  
Failure Modes ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Common Cause ◽  
Power Stations ◽  
Protection Systems ◽  
Common Cause Failures ◽  
Testing Policies

“De-energise to trip” is a long established principle because of the danger of common cause failures. Although there is little published on this topic, it is covered in the section “Protection systems (trips and interlocks)” in the HSE Technical Measure Document for COMAH sites, but the quality of UPS, diagnostics etc. is now very different from the last century. As well as the obvious effects of architecture, failure modes and frequency on the number of spurious trips and failures to dangers, we have also studied the relationships between design policies, (for example, overrides and diagnostic coverage), testing policies, repair policies, operating policies and their effects on common cause failures. The effects of different policies on spurious trips and failures to danger would be illustrated with practical examples from the energy industry: oil and gas production and power stations.

The hydrocarbon potential of the 2015 Offshore Acreage Release Areas for petroleum exploration

2015 ◽  
Vol 55 (1) ◽  
pp. 71
Author(s):  
Thomas Bernecker ◽  
Tehani Kuske ◽  
Bridgette Lewis ◽  
Tegan Smith
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Petroleum Exploration ◽  
Hydrocarbon Potential ◽  
Large Area ◽  
Oil And Gas Production ◽  
North West ◽  
Work Program ◽  
Northern Carnarvon Basin ◽  
Gippsland Basin

The Australian Government formally releases new offshore exploration areas at the annual APPEA conference. These areas are located across various offshore hydrocarbon provinces ranging from mature basins with ongoing oil and gas production to exploration frontiers. A total of 23 areas are released for work-program bidding and six areas for cash bidding (Fig. 1). The two work-program bidding rounds will remain open until 29 October 2015 and 21 April 2016, respectively, while cash bid submissions will close on 4 February 2016. The 2015 Release Areas are located in 13 distinct geological provinces across eight basins and all were supported by industry nominations. Six areas are located in the Bonaparte Basin, two of which are cash bid areas over the Turtle/Barnett oil accumulations. In the Browse Basin, three areas in the Caswell Sub-basin and one area on the Yampi Shelf are released. In support of recent exploration activities and success, one large area has been gazetted in the central Roebuck Basin. The Northern Carnarvon Basin offering comprises 11 areas on the Exmouth Plateau and in the Dampier Sub-basin, including four for cash bidding. This year, the usual predominance of North West Shelf Release Areas is counterbalanced by seven large areas in the Bight, Otway, Sorell and Gippsland basins. This includes one area in the Ceduna Sub-basin, three areas in the deepwater Otway Basin, one area in the northern Sorell Basin and two areas in the southeastern Gippsland Basin. The nominations received for these areas highlights the industry’s interest in evaluating the hydrocarbon potential of Australia’s underexplored southern margin. Geoscience Australia continues to support industry activities by acquiring, interpreting and integrating pre-competitive datasets that are made freely available as part of the agency’s regional petroleum geological studies.

Applying a new concept of corrosion protection in the presence of water: hydrojetting application – effectiveness lab test

2017 ◽  
Vol 64 (1) ◽  
pp. 109-117 ◽  
Author(s):  
Mario Celso Genovez ◽  
Luiz Henrique Araujo ◽  
Tiago Dinis Pinto ◽  
Radim Hrdina
Keyword(s):  
Oil And Gas ◽  
Water Solution ◽  
Gas Production ◽  
Organic Chemical ◽  
Oil And Gas Production ◽  
Content Type ◽  
Practical Applications ◽  
New Formulation ◽  
Paint Adhesion

Purpose This paper aims to describe the results of lab testing of a newly developed organic inhibitor V-active VCIs. The findings demonstrate that it is possible to eliminate or reduce the oxidizing action of water, thereby extending the allowable time before painting after hydrojetting, and that the new corrosion inhibitor technology does not interfere with the final quality of paint adhesion. Design/methodology/approach Metallic specimens were treated/washed in standard lab condition. A 2 per cent V-active VCI SPH1712 water solution was prepared by diluting the inhibitor in industrial water. Metal sample plates were examined after blasting and after subsequent drying, and were submitted to the paint adhesion tests, cathodic disbondment, total soluble salts, time for formation of flash rust and cyclic corrosion test type III (20 cycles), to evaluate the duration of temporary protection and oxidation prevention and influence on paint adherence. Findings Using the V-active VCI proposed technology, it was possible to minimize or eliminate the oxidizing action of the water when the metal is exposed to saline moisture in a closed environment, extending the acceptable time before painting without interfering with the final quality of painting. Practical implications The proposed technology allows an increase in the prepared (wet blasted) steel surface during cleaning and preparation, thereby reducing labor and product costs, and reduces water consumption during the preparation process. Practical applications in the shipbuilding, ship maintenance and oil and gas production industries include the preservation of internal tubes and pipes, protection during hydrostatic test processes and cleaning with water and corrosion prevention in diesel tanks contaminated with water. Originality/value The intent of this paper is to present the obtained results for a new formulation of organic chemical inhibitors that use water as the application medium. In addition to this property, this group of organic inhibitors maintains the properties of volatile inhibitors. Thus, these compounds are generically known as V-active VCIs.

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