scholarly journals Geophysical technologies for geothermal well field development in sedimentary basins

2012 ◽  
Vol 2012 (1) ◽  
pp. 1-3
Author(s):  
Brett Harris
Keyword(s):  
Sedimentary Basins ◽  
Field Development ◽  
Geothermal Well ◽  
Well Field

Main directions of searching for hydrocarbons in Nadym-Pursk oil and gas region

2021 ◽  
pp. 23-31
Author(s):  
Y. I. Gladysheva
Keyword(s):  
Oil And Gas ◽  
Raw Materials ◽  
Accumulation Rate ◽  
Sedimentary Basins ◽  
Seismic Exploration ◽  
Research Approach ◽  
Field Development ◽  
The North ◽  
The Sixties ◽  
Hydrocarbon Deposits

Nadym-Pursk oil and gas region has been one of the main areas for the production of hydrocarbon raw materials since the sixties of the last century. A significant part of hydrocarbon deposits is at the final stage of field development. An increase in gas and oil production is possible subject to the discovery of new fields. The search for new hydrocarbon deposits must be carried out taking into account an integrated research approach, primarily the interpretation of seismic exploration, the creation of geological models of sedimentary basins, the study of geodynamic processes and thermobaric parameters. Statistical analysis of geological parameters of oil and gas bearing complexes revealed that the most promising direction of search are active zones — blocks with the maximum sedimentary section and accumulation rate. In these zones abnormal reservoir pressures and high reservoir temperatures are recorded. The Cretaceous oil and gas megacomplex is one of the main prospecting targets. New discovery of hydrocarbon deposits are associated with both additional exploration of old fields and the search for new prospects on the shelf of the north. An important area of geological exploration is the productive layer of the Lower-Berezovskaya subformation, in which gas deposits were discovered in unconventional reservoirs.

THE POTENTIAL FOR GEOLOGICAL SEQUESTRATION OF CO2 IN AUSTRALIA: PRELIMINARY FINDINGS AND IMPLICATIONS FOR NEW GAS FIELD DEVELOPMENT

2002 ◽  
Vol 42 (1) ◽  
pp. 25 ◽  
Author(s):  
J. Bradshaw ◽  
B.E. Bradshaw ◽  
G. Allinson ◽  
A.J. Rigg ◽  
V. Nguyen ◽  
...  
Keyword(s):  
Greenhouse Gas Emissions ◽  
Greenhouse Gas ◽  
Greenhouse Gas Emission ◽  
Sedimentary Basins ◽  
Cooperative Research ◽  
Geological Sequestration ◽  
Gas Field ◽  
Gas Emissions ◽  
Field Development ◽  
Source To Sink

Many industries and researchers have been examining ways of substantially reducing greenhouse gas emissions. No single method is likely to be a panacea, although some options do show considerable promise. Geological sequestration is one option that utilises mature technology and has the potential to sequester large volumes of CO2. This technology may have particular relevance to some of Australia’s major gas resources that are relatively high in CO2. In Australia, geological sequestration has been the subject of research within the Australian Petroleum Cooperative Research Centre’s GEODISC program. A portfolio of potential geological sequestration sites (sinks) has been identified across all sedimentary basins in Australia, and these have been compared with nearby known or potential CO2 emission sources, including natural gas resources. These sources have been identified by incorporating detailed analysis of the national greenhouse gas emission databases with other publicly available data, a process that resulted in recognition of eight regional emission nodes. An earlier generic economic model for geological sequestration in Australia has been updated to accommodate the changes arising from this process of source to sink matching. Preliminary findings have established the relative attractiveness of potential injection sites through a ranking approach. It includes the ability to accommodate the volumes of sequesterable greenhouse gas emissions predicted for the adjacent region, the costs involved in transport, sequestration and ongoing operations, and a variety of technical geological risks. Some nodes with high volumes of emissions and low sequestration costs clearly appear to be suitable, whilst others with technical and economic issues appear to be problematic. This assessment may require further refinement once findings are completed from the GEODISC site-specific research currently underway.

Deformation near the Casa Diablo geothermal well field and related processes Long Valley caldera, Eastern California, 1993–2000

2003 ◽  
Vol 127 (3-4) ◽  
pp. 365-390 ◽  
Author(s):  
James F Howle ◽  
John O Langbein ◽  
Christopher D Farrar ◽  
Stuart K Wilkinson
Keyword(s):  
Long Valley Caldera ◽  
Geothermal Well ◽  
Well Field ◽  
Long Valley

scholarly journals Geothermal well-field and power-plant investment-decision analysis

1981 ◽  
Author(s):  
T.A.V. Cassel ◽  
C.B. Amundsen ◽  
R.H. Edelstein ◽  
P.D. Blair
Keyword(s):  
Power Plant ◽  
Decision Analysis ◽  
Investment Decision ◽  
Geothermal Well ◽  
Well Field

Integration of Acoustics and Geomechanical Modelling for Subsurface Characterization in Tectonically Active Sedimentary Basins: A Case Study from Northeast India

2021 ◽  
Author(s):  
Anjana Panchakarla ◽  
Tapan Kidambi ◽  
Ashish Sharma ◽  
Eduardo Cazeneuve ◽  
RBN Singh ◽  
...  
Keyword(s):  
Transition Zone ◽  
Shear Wave ◽  
Sedimentary Basins ◽  
Holistic Approach ◽  
Integrated Approach ◽  
Northeast India ◽  
Tectonic Activity ◽  
Borehole Stability ◽  
Field Development ◽  
Acoustic Anisotropy

Abstract Drilling wells in the remote northeastern part of India has always been a tremendous challenge owing to the subsurface complexity. This paper highlights the case of an exploratory well drilled in this region primarily targeting the main hydrocarbon bearing formations. The lithology characterized by mainly shale, siltstone and claystone sequences, are known to project high variance in terms of acoustic anisotropy. Additionally some mixed lithological sequences are also noted at particular depths and have been identified at posing potential problems during drilling operations. Several issues became apparent during the course of drilling the well, the main factor being consistently poor borehole condition. An added factor potentially exacerbating the progressively worsening borehole conditions was attributed to the significant tectonic activity in the area. To address and identify these issues and to pave the way for future operations in this region, a Deep Shear Wave Imaging analysis was commissioned to identify near and far wellbore geological features, in addition to addressing the geomechanical response of these formations. In this regard, acoustic based stress profiling and acoustic anisotropy analysis was carried out to estimate borehole stability for the drilled well section and provide insights for future drilling plans. Significant losses were observed while drilling the well, in addition to secondary problems including tight spots and hold ups and consequently the well had to be back reamed multiple times. Of particular note were the losses observed while transitioning between the main formations of interest. The former consisting relatively lower density claystone/siltstone formations and the latter, somewhat shalier interlayered with sandstones, displaying a generally higher density trend. This transition zone proved to be tricky while drilling, as a high density sandstone patch was encountered further impeding the drilling ROP. Overall, both formations were characterized by significantly low rock strength moduli with the exception of the sandstones projecting characteristically higher strengths. In light of these events, analysis of integrated geological, geomechanical and advanced borehole acoustic data analyses were used to identify the nature of the anisotropy, in terms of either stress induced, or caused by the presence of fractures in the vicinity of the borehole. The extensive analysis further identified sub-seismic features impeding drillability in these lithologies. Further, the holistic approach helped characterize the pressure regimes in different formations and in parallel, based on corroboration from available data, constrained stress magnitudes, indicating a transitional faulting regime. Variances in stress settings corresponded to the depths just above the transition zone, where significant variations were observed in shear wave azimuthal trends thereby indicating the presence of potential fracture clusters, some of which were revealed to be intersecting the borehole thereby causing stress. The analysis shed light on these near well fractures- prone to shear slip, causing mud losses during drilling while drilling with high mud weights. Finally, the encompassing multiple results, an operational mud weight window was devised for the planned casing setting depths. Given the presence of numerous fractures, the upper bound of the operational mud window was constrained further to account for the presence of these fractures. In summary, an integrated approach involving a detailed DSWI study in addition to traditional geomechanics has brought about new perspectives in assessing borehole instability. By actively identifying the sub surface features, (sub seismic faults and fractures) decisions can be taken on mud weight and optimizing drilling parameters dynamically for future field development.

Completion Design and Optimization to Assure Flow in Gas Wells Life Cycle

2021 ◽  
Author(s):  
Fatemeh Mehran ◽  
Purvi Shukla ◽  
Shashank Pandey
Keyword(s):  
Fluid Flow ◽  
Oil And Gas ◽  
Sedimentary Basins ◽  
Holistic Approach ◽  
Oil And Gas Industry ◽  
Electrical Heating ◽  
Data Repository ◽  
Flow Assurance ◽  
Field Development ◽  
Design And Optimization

Abstract There are 26 sedimentary basins in India divided into four categories on the basis of hydrocarbon prospectivity. A total of about 3.14 million square kilometres area is covered by these sedimentary basins which includes both onshore and offshore. One of the most prominent category-1 (commercially producing) basin of India is Krishna Godavari basin with an estimated hydrocarbon potential of about 1130 million metric tonnes. It is is formed by the extensive deltaic plain formed by the two large east coast rivers, Krishna and Godavari. It covers an area of 15000 square kilometres onshore and about 25000 square kilometrs offshore, upto a water depth of about 1000m (National Data Repository, DGH-MoPNG, GOI). It is believed that India relies heavily on KG basin for its energy security. However, one of the major challenges being faced in the KG basin offshore field development is Flow Assurance. Since most of the fields offshore KG basin are in deepwater setting, high pressure and low temperature conditions aggravate flow assurance problems. Flow assurance is identified as a significant deepwater offshore development challenges and hence has emerged as a prominent discipline in the oil and gas industry. There are several definitions of Flow Assurance, one of the most common of which is: Flow Assurance is the analysis of thermal, hydraulic and fluid related threats to flow and product quality and their mitigation using equipment, chemicals and procedure (Makogon T.Y., 2019). It can be understood as an all-encompassing holistic approach of fluid flow from the reservoir to point of sale with an integrated perspective of asset development. In simple terms flow assurance aims to ensure fluid flow irrespective of flow trajectory, fluid chemistry and environmental conditions (Brown L.D., 2002). It has become increasingly important in recent times as the industry has turned to deepwater resources for energy sources. There are multiple examples where the proper utilization of Flow Assurance technology has saved billions of dollars for oil and gas companies. Norske Shell saved approximately 30 billion NOK in the Troll field by resorting to direct electrical heating of produced fluids. The same was utilized by Italian company ENI for its Goliath development and by BP in its Skarv field (Makogon T.Y., 2019). This paper describes a comprehensive workflow to identify and mitigate flow assurance risks for the deepwater block in KG basin.

A general inverse method for modelling extensional sedimentary basins

2000 ◽  
Vol 12 (3-4) ◽  
pp. 219-226 ◽  
Author(s):  
P. Bellingham ◽  
N. White
Keyword(s):  
Inverse Method ◽  
Sedimentary Basins
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