scholarly journals Elastic Properties Modeling for Identification of Prospective Reservoir Zones in the Carbonate Reservoir, MRD Field in the North East Java Basin

2019 ◽  
Vol 17 (1) ◽  
pp. 21
Author(s):  
Mordekhai Mordekhai ◽  
Sonny Winardhi
Keyword(s):  
Elastic Properties ◽  
Oil And Gas ◽  
Reservoir Characterization ◽  
Middle Eocene ◽  
Carbonate Reservoir ◽  
Primary Data ◽  
Pore Shape ◽  
Gas Field ◽  
North East ◽  
The North

“MRD” field is an oil and gas field which located in Rembang Zone. One of the hydrocarbon zones in this fieldlies in Ngimbang Formation. Reservoir in this field has a lifespan of Middle Eocene to Early Oligocene. Reservoir of this formation is carbonate rocks and dominated by calcite and dolomite minerals. One of the uniqueness of this kind of reservoir is the pore shape which quite complex. In this study, reservoir characterization which performed on this field is based on elastic properties modelling. Elastic Properties modelling which was conducted in this field can provide an output of the pore shape, aspect ratio, and the fraction of each respective poresforms that exist in this field’s reservoir zone. Therefore the primary data such as petrophysical data, XRD (X-Ray Diffraction), and the data of other reservoir parameters are needed for more accurate resultsobtained with real conditions. The result of this modelling shows that the shape of the pores in the reservoir zone at any depth can be predicted. Distribution of pore shapes that exist in the two wells can be used as a reference for prospective determination of hydrocarbon zones in “MRD” field.  

Impact of tectonic faults on formation of oil-gas traps in Yevlakh-Aghjabedi oil-gas bearing region

2021 ◽  
pp. 4-10
Author(s):  
B.S. Aslanov ◽  
◽  
A.I. Khuduzade ◽  
R.A. Asgerova ◽  
Yu.F. Ismailzade ◽  
...  
Keyword(s):  
Upper Cretaceous ◽  
Oil And Gas ◽  
Middle Eocene ◽  
North West ◽  
North East ◽  
The North ◽  
Industrial Oil ◽  
Geophysical Surveys ◽  
Oil Gas ◽  
Gas Bearing

Via geological-geophysical surveys carried out on the north-east border of Yevlakh-Aghjabedy downfold in the second half of the last century, the oil-gas bearing content of deeply-immersed Mesozoic horizons of Upper Cretaceous, as well as shallow layers of Paleogene and Miocene has been defined. Oil-gas bearing Productive Series have been discovered within Muradkhanly, Zardab, Shykhbaghy and Jafarli structures, which belong to Zardab-Muradkhanly-Jafarli belt. Oil-gas reservoirs are lithologically associated mainly with fractured superfusive and carbonate rocks of Upper Cretaceous, as well as sedimentary-volcanogenic rocks of Middle Eocene and partially terrigenic collectors of Maikop-Chokrak, which are layer-arch type of trap. Some researchers came to the conclusion that within favorable geological circumstances on the north-east border of the downfold, collectors of Mesozoic sediments may contain industrial oil and gas deposits as well. To that end, recently the major capacity of exploration drilling and geoexploration was focused within Yevlakh-Aghjabedy downfold, where Mesozoic structures are widespread alongside with Paleogen-Miocene sediments. Deep structural-tectonic framework and oil-gas bearing content both on south-west and north-east slopes of the downfold was specified via the results of conducted works. It was defined that by hydrocarbon saturation, north-west and south-east slopes sharply differ from each other both in the view of structural-tectonic and oil-gas bearing capacity, probably associated with various cycles of folding of Cenozoic and Mesozoic ages.

Synrift evaporite deposition and structural characterization of the onshore Alagoas subbasin

2019 ◽  
Vol 7 (4) ◽  
pp. SH19-SH31
Author(s):  
Gabriela Salomão Martins ◽  
Webster Ueipass Mohriak ◽  
Nivaldo Destro
Keyword(s):  
Structural Characterization ◽  
Oil And Gas ◽  
Hanging Wall ◽  
Structural Evolution ◽  
Gas Production ◽  
North East ◽  
The North ◽  
Half Graben ◽  
Well Data

The Sergipe-Alagoas Basin, situated in the north-east Brazilian margin, has a long tradition of oil and gas production and the presence and distribution of evaporites play an important role in petroleum systems in the basin. However, little research has focused on the structural evolution of the older, synrift evaporitic sections of the basin. We have focused explicitly in the detailed subsurface structural characterization of the rift in the Alagoas subbasin and the distribution of the Early Aptian evaporites. To accomplish this objective, we interpreted selected 2D and 3D seismic and well data located in two areas known as the Varela Low (VL) and Fazenda Guindaste Low (FGL). We identified diverse deformation styles in those two basin depocenters. Our interpretation indicates that VL consists of a half-graben with a significant rollover structure, controlled by two listric northeast–southwest border faults. The deformation in the hanging wall is also accommodated by release faults and minor antithetic faults. In this depocenter, we mapped in the seismic and the well data an older evaporitic sequence within the Coqueiro Seco Fm., known as Horizonte Salt. This evaporitic section occurs in the internal part of the VL half graben, where it is limited by release and antithetic faults. Significant salt strata growing toward the antithetic fault is observed. Whereas, the FGL represents a graben elongated along the north-east direction and is controlled by several types of structures. We recognized normal synthetic and antithetic faults, transfer zones, release faults, and rollover anticlines in the seismic throughout this depocenter. We mapped an evaporitic section within the Maceió Fm., known as Paripueira Salt, which consists of disconnected salt bodies, restricted to the hanging walls of synrift faults.

EXPLORATION AND GEOLOGY OF THE WEST SULU BASIN, PHILIPPINES

1974 ◽  
Vol 14 (1) ◽  
pp. 21 ◽  
Author(s):  
R. M. Bell ◽  
R. G. C. Jessop
Keyword(s):  
Oil And Gas ◽  
The Philippines ◽  
The West ◽  
Sulu Sea ◽  
North East ◽  
The North ◽  
Tectonic Events ◽  
Provisional Identification ◽  
Western Portion ◽  
Made In

The West Sulu Basin lies in the western portion of the Sulu Sea. Republic of the Philippines. It occupies an area in excess of 26,000 square miles (67,000 km2) and is bounded to the west and south by the cordilleran arc extending from the island of Palawan through Sabah and along the Sulu Archipelago to the island of Mindanao. To the north-east, the basin probably extends beyond the edge of the continental shelf in Philippine territorial waters.The basin may be broadly divided into a western platform and an eastern deep: the latter is subdivided by northeast-trending basement ridges into three sub-basins. Sediments deposited in these sub-basins are of Tertiary to Recent age and have been affected by several orogenies and by contemporaneous movements of fault-controlled blocks. This has resulted in truncation and the development of marked erosion surfaces and onlap within the Upper Tertiary section. Many anticlinal features mapped within the basin have resulted from drape over basement highs or from penecontemporaneous growth of these highs.Major unconformities associated with Upper Tertiary tectonic events have been recognized onshore. Extrapolation to offshore areas where these events can be seismically mapped has enabled an interpretative geologic model to be built up. Provisional identification of stratigraphic units and their nature have been made using this model.The Upper Tertiary section within the eastern deep is expected to consist of deltaic and paralic reservoir sands interbedded with, grading into and transgressed by deeper water shale and mudstone with good hydrocarbon source potential. Some limestone lenses may be present.The presence of Lower to Middle Miocene diapiric shale and Plio-Pleistocene intrusives coupled with data of variable quality makes seismic interpretation difficult in some areas. However, several large anticlinal features and a number of stratigraphic and combination traps have been located.A non-commercial discovery of oil and gas has been made in the basin.

Advances in marine electromagnetic (EM) efficiency with a towed acquisition system

2012 ◽  
Vol 52 (2) ◽  
pp. 699
Author(s):  
Folke Engelmark ◽  
Johan Mattsson ◽  
John Linfoot
Keyword(s):  
Oil And Gas ◽  
Field Tests ◽  
Repeated Sequence ◽  
Dipole Source ◽  
Surface Sampling ◽  
Gas Field ◽  
The North ◽  
Simultaneous Acquisition ◽  
Oil And Gas Field ◽  
Source Signal

A towed marine EM system has been developing since 2004 where both source and receivers are towed behind the same vessel in an arrangement similar to 2D streamer seismic. This is an ideal technology for reducing risk in hydrocarbon targets in general and low saturation gas in particular, as well as the monitoring of CO2 sequestration. The dipole source is 400 or 800 m long and towed at 10 m below the sea surface. The receiver cable is towed at 100 m depth and has receiver offsets between 500 and 8,000 m. A transient source signal is used, allowing deterministic deconvolution of the source signature, which can be of any shape; for example, square wave, PRBS, or optimised repeated sequence (ORS). There are multiple benefits of the towed EM system: Similar in operation to a marine streamer seismic. Improved survey efficiency with source and receivers towed by the same vessel. Real-time monitoring of source and receivers, and quality control of incoming data. Onboard pre-processing. Dense sub-surface sampling. Receivers towed above the seafloor—the influence of strong local anomalies at the seabed is thus minimised. Facilitates simultaneous acquisition of EM and 2D seismic. Successful field tests were conducted in mid-2010 over the Peon gas field and the Troll oil and gas field in the Norwegian sector of the North Sea. A total of 615 line km were acquired during 138 hours, and the data has been successfully processed and inverted to delineate all targets.

scholarly journals Facies Development of Carbonate Rock and System Tract Influence Based on Fullbore Formation Microimager (FMI) and Well Log Analysis on Carbonate Reservoir Tuban Formation, North East Java Basin

2018 ◽  
Vol 73 ◽  
pp. 02021
Author(s):  
Fahrudin ◽  
Eka Sainyakit ◽  
Ahmad Syauqi Hidayatillah ◽  
Purnaning Tuwuh Triwigati ◽  
Muhajir
Keyword(s):  
Carbonate Rocks ◽  
Carbonate Rock ◽  
Gamma Ray ◽  
Research Area ◽  
Carbonate Reservoir ◽  
Log Analysis ◽  
Reef Facies ◽  
North East ◽  
The North ◽  
System Tract

The North East Java Basin is known to be one of the basins that consist of Miocene carbonate rocks, like the reef carbonate of Tuban Formation. It has the potential hydrocarbons that can be explored. Therefore, the FMI log analysis is very important to identify carbonate rocks of Tuban Formation to know facies and characteristics of that carbonate rocks. The method used descriptive and analysis process of FMI and Gamma Ray log to determine facies of the carbonate rock and the system tract. Based on the result of FMI log analysis, there are variations lithofasies include mudstone, wackestone, packstone, grainstone, floatstone, rudstone and claystone. A collection of rock associations can interpret the reef facies. It involves back reef facies, reef core facies, and fore reef facies. The changes of lithofasies and reef facies are caused by sea level fluctuations and subsidence resulting in the system tract. The system tracts generated in the research area include transgressive and highstand system tract.

Application of Probabilistic Neural Network and Rock physics Analysis for Carbonate Reservoir Characterization: A Case Study from Onshore Supergiant Oil Field

2020 ◽  
Author(s):  
Ali Alali ◽  
Karl Stephen
Keyword(s):  
Neural Network ◽  
Elastic Properties ◽  
Acoustic Impedance ◽  
Reservoir Characterization ◽  
Probabilistic Neural Network ◽  
Rock Physics ◽  
Carbonate Reservoir ◽  
High Porosity ◽  
Tidal Channels ◽  
Porosity Distribution

<p>Identification and modeling of the carbonate tidal channels is key for finding sweet spots or areas at higher risk to water breakthroughs which have a significant impact on the development and monitoring of reservoir dynamic performance. However, such these channels cannot be easily characterize by conventional seismic attributes. It is important to decipher the complexity of carbonate tidal channel architecture with integrated multisource data and different approaches.</p><p>A step wise approach has been taken in this work. First, rock physics model was carried out to ensure that elastic properties can be applied for reservoir characterization from the seismic data. Then, post-stack seismic inversion was carried out on the high resolution of 3D seismic dataset. The seismically derived porosity estimation is undertaken using geostatistical method and multiattributes combination was used. Probabilistic neural network training technique was then performed to improve the results for thick reservoir and the result has been used for seismic conditioning of geological models. Finally, the spatial distribution of porosity volume was cautiously assessed through the comparison between input and blind wells, also validated by core data.</p><p>The analysis of rock physics displayed a high correlation between elastic properties and the porosity distribution of the Mishrif channel, three facies were observed. The final interpretation of seismically derived characterization in Mishrif channel, observed a different lateral distribution of inverted elastic properties. These features of Mishrif carbonate tidal channels could be classified into these regions: north, southwest, and east. Related a high porosity with low acoustic impedance appeared mostly in these channels which reflect a good reservoir quality grainstone channels or sholas bodies. While, outside these channels is heavily mud filled by peritidal carbonates and characterized a high acoustic impedance anomaly with low quality of porosity distribution.</p><p>The results provided a new insight into the distribution of the petrophysical properties and reservoir architecture of facies with quantification of their influence on dynamic reservoir behavior in the Mishrif channelized systems and also for similar heterogeneous carbonate reservoirs</p>

New Forms of Work and Employment in an `Old Industrial Region'? The Offshore Construction Industry in the North East of England

1994 ◽  
Vol 8 (4) ◽  
pp. 531-552 ◽  
Author(s):  
Andy Cumbers
Keyword(s):  
Labour Market ◽  
Construction Industry ◽  
Oil And Gas ◽  
Evolutionary Process ◽  
The Past ◽  
North East ◽  
The North ◽  
Local Labour ◽  
New Forms Of Work ◽  
Work And Employment

This paper examines the nature of the new forms of work and employment brought to the North East of England by the development of offshore construction activities, serving the North Sea's oil and gas industries in the period since the early 1970s. In particular, it assesses the extent to which these activities differ from traditional forms of work and employment organisation within the region. The results of this analysis suggest the need to interpret contemporary patterns of restructuring, both in a particular local labour market context and more generally, as part of an on-going evolutionary process, rather than as a decisive break (or shift) from the past.

A long history of wet gas pipelines in Victoria

2015 ◽  
Vol 55 (2) ◽  
pp. 415
Author(s):  
Steve Henzell
Keyword(s):  
Oil And Gas ◽  
Gas Pipelines ◽  
Gas Field ◽  
Initial Development ◽  
The North ◽  
Wet Gas ◽  
Industry Practice ◽  
Offshore Oil And Gas ◽  
The 1960S ◽  
Marginal Field

Australia's relative isolation and the harsh environment in Bass Strait have led to many innovations in offshore oil and gas developments. The initial developers were moving into frontier territory when Bass Strait was developed, with the harsh sea state and the water depths presenting major challenges. The original development of Bass Strait in the 1960s was tied to a wet gas pipeline philosophy, which was a novel step-out from normal industry practice. For example, the North Sea developments, which started shortly after Bass Strait, adopted dry gas export pipelines and required substantially larger platforms to process the gas for export. The cold waters of Bass Strait require an active hydrate management strategy and the success of hydrate inhibitors has been a key element in using wet gas pipelines. The initial development relied on methanol for hydrate inhibition, but this changed to a glycol-based hydrate inhibitor within 10 years of production start-up, due to challenges in the onshore production facilities. The use of mono-ethylene glycol for management of wet gas pipelines was demonstrated in Bass Strait. The success of the initial developments has given operators the confidence to pursue marginal field developments that rely on wet gas transport to the beach. The Minerva, Casino, Thylacine and Longtom gas field developments in Bass Strait have all adopted the same strategy, in part because of the confidence provided from operating the initial developments for many years.

AVO inversion using pseudoisotropic elastic properties

2021 ◽  
Vol 40 (1) ◽  
pp. 52-59
Author(s):  
Michinori Asaka
Keyword(s):  
Elastic Properties ◽  
Oil And Gas ◽  
Reservoir Characterization ◽  
Elastic Anisotropy ◽  
Data Set ◽  
Amplitude Variation With Offset ◽  
Avo Inversion ◽  
Characterization Study ◽  
Anisotropy Parameters ◽  
Using Data

Amplitude variation with offset (AVO) inversion of an anisotropic data set is a challenging task. Nonnegligible differences in the anisotropy parameters between the various lithologies make the seismic data AVO response completely different from the isotropic synthetic seismogram. In this case, it is difficult to invert for VP/VS and density consistent with well-log data. AVO inversion using pseudoisotropic elastic properties is a practical solution to this problem. Verification of this method was performed using data from an offshore Western Australia field. It was found that wavelet extraction and density inversion are improved significantly by replacing the isotropic elastic properties with the pseudoisotropic properties. Inverted density shows reasonable quality and therefore can be included in the reservoir characterization study. Postinversion analyses can be performed effectively on the pseudoisotropic elastic properties because crossplot analysis shows the increased separation of different lithofacies due to contrasts in anisotropy parameters. This result could have significant implications for other fields, as shale constitutes most of the overburden in conventional oil and gas fields and often shows strong elastic anisotropy.

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