Tamil Nadu

Journal of Petroleum TechnologyMarch, 2023

McDermott Makes Splash With Manatee FEED

Shell Trinidad and Tobago Ltd. awarded McDermott a front-end engineering design (FEED) contract for the Manatee gas development project. Under the contract scope, McDermott will provide FEED services for a wellhead platform, export pipeline system, shore approach, midstream pipeline, and onshore control room. According to McDermott, the award follows the successful completion of an early contract engagement with Shell. Engineering and execution planning efforts will be led by McDermott's team in Houston with support from Kuala Lumpur; Chennai, India; and Altamira, Mexico. The Manatee field is in Block 6(d) offshore Trinidad and Tobago in water depths of around 91 m.

Journal of Petroleum Technology

Country:

North America > Trinidad and Tobago (0.54)
North America > United States > Gulf of Mexico > Central GOM (0.34)
Asia > Malaysia > Kuala Lumpur > Kuala Lumpur (0.27)
Asia > India > Tamil Nadu > Chennai (0.27)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Green Canyon > Block 155 > Manatee Field (0.99)
North America > Canada > Alberta > Border Field > Anglo Pacific Et Al Czar 11-33-41-5 Well (0.99)

SPE Disciplines:

Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Offshore pipelines (0.60)
Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (0.47)

Chen, Songtao (Computational Marine Hydrodynamics Lab (CMHL), School of Naval Architecture, Ocean and Civil Engineering, Shanghai Jiao Tong University, Shanghai) | Meng, Qingjie (Wuhan Second Ship Design and Research Institute, Wuhan) | Wan, Decheng (Computational Marine Hydrodynamics Lab (CMHL), School of Naval Architecture, Ocean and Civil Engineering, Shanghai Jiao Tong University, Shanghai)

Numerical Study on Breaking Waves Interaction with Vertical Wall Attached with Recurved Parapet

OnePetroJune, 2022

ABSTRACT This paper numerically investigates breaking waves interaction with a vertical wall attached with a recurved parapet in 1:8 model scale. The in-house CFD solver naoe-FOAM-SJTU based on the open source platform OpenFOAM is used to perform the simulation. For wave generation, a novel generating-absorbing boundary condition (GABC) is adopted to replace the time-consuming moving boundary wavemaker. A geometric volume-of-fluid (VOF) method based on piecewise-linear interface calculation (PLIC) is incorporated in the present numerical model to capture the sharp interface and improve the accuracy of the predicted impact pressure. The time histories of the wave elevation and pressure at each probe are presented as well as the frequency analysis. In addition, the evolutions of free surface and pressure distribution are further provided to achieve a better understanding of this complex wave-structure interaction issue. INTRODUCTION Vertical breakwaters are typical coastal structures intended to reduce the effects of incoming waves, especially in extreme sea conditions. In practical design, wave overtopping has been a significant issue of sustained concern for decades. Among the various solutions, a parapet fixed on the top of the vertical wall has been proven effective by deflecting back the up-rushing water seawards. However, according to the previous studies, the shape and parameters of the parapet will significantly influence the impact force and pressure compared with the original vertical wall. In order to provide guidelines to predict the wave impact and wave loading, it is necessary to systematically investigate the variations under different wave conditions, including non-breaking and broken waves. As a representative shape, the recurved parapet has gradually attracted more attention recently. Kortenhaus et al. (2002, 2003) highlighted the effectiveness of the recurves and parapets in wave overtopping through abundant experimental data collected in the wave flume of the Leichtweiβ-Institute. Nevertheless, they pointed out that their existences may increase the wave loadings on the vertical wall. Ravindar et al. (2019) conducted large-scale (1:1) experiments to characterize the impact pressure under different wave breaking conditions at the Coastal Research Centre (FZK), Germany. According to their classification, it can be divided into three conditions: slightly breaking waves (SBW), breaking waves with small air trap (BWSAT), and breaking waves with large air trap (BWLAT). In addition, they reported the significant effect of the entrained air on the impact pressure. On this basis, Ravindar et al. (2021a, b) carried out small-scale (1:8) experiments in the Department of Ocean Engineering at the Indian Institute of Technology Madras, Chennai, Tamil Nadu, India. They analyzed the scale effects and proposed a combined Cuomo-Froude method for scaling up the impact pressure of small-scale results. Besides, they also discussed the impact pressure and forces of different types of parapets under the above-classified wave breaking conditions.

The 32nd International Ocean and Polar Engineering Conference

ISOPE

ISOPE-I-22-432

air pocket, boundary condition, cfd solver naoe-foam-sjtu, Engineering, free surface, impact pressure, interaction, interface, OpenFOAM, parapet, Probe, recurved parapet, Simulation, Upstream Oil & Gas, vertical wall, wave elevation, wave generation, wave impact, Wave Interaction

Country: Asia > India > Tamil Nadu > Chennai (0.24)

Industry: Energy > Oil & Gas > Upstream (0.89)

SPE Disciplines:

Reservoir Description and Dynamics (1.00)
Data Science & Engineering Analytics > Information Management and Systems (0.89)

Technology: Information Technology (0.89)

Journal of Petroleum TechnologyDecember, 2020

AG&P Breaks Ground on Karaikal Port LNG Facility in South India

Singapore-based gas and LNG logistics company AG&P broke ground on its LNG import facility at Karaikal Port, Puducherry, on Thursday, which is paving the way to broader access to natural gas as a primary fuel in South India. The company said the Karaikal LNG import facility (Karaikal LNG) is expected to commence commercial operations by Q4 2021. "It will become a landmark infrastructure development for the region and is ideally suited for the Karaikal Port, a critical center of trade," said AG&P chief executive JM Sigelman. AG&P president of terminals and logistics, Karthik Sathyamoorthy, added that the company's goal is to bring down the unit cost of regasification terminals for smaller volumes to make LNG commercially viable for scattered and smaller customers. Karaikal LNG is owned and operated by AG&P, which is being built on a 12-hectare site within the Karaikal Port, having the only deepwater access on the East Coast of India south of Chennai.

Journal of Petroleum Technology

ag&p break ground, customer, gas monetization, karaikal lng, karaikal port lng facility, liquified natural gas, LNG, lng import facility, Midstream Oil & Gas, sigelman, south india, tamil nadu, terminal

Country: Asia > India > Tamil Nadu > Chennai (0.31)

Industry: Energy > Oil & Gas > Midstream (1.00)

SPE Disciplines: Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)

A Novel Approach to the Geomechanical Characterization of Basement Fractures- Are Open Fractures Necessarily Critically Stressed

Chakraborty, Srimanta (Baker Hughes, a GE Company) | Kidambi, Tapan (Baker Hughes, a GE Company) | Sharma, Ashish (Baker Hughes, a GE Company) | Sabu, KG (ONGC)

OnePetroNovember, 2019

Abstract This paper attempts to answer a fundamental question pertinent to fracture characterization of unconventional basement reserves using rock mechanics & petrophysics; are open fractures in basements necessary critically stressed? Evaluation of naturally occurring fractures are critical for production as well as reserves estimation. In this regard, a study well was drilled in the basement section of the Cauvery basin to explore unconventional pay zones & characterize the contributing fractures by integrated Geomechanical & Petrophysical analysis. A suite of open hole logs including the basic, acoustic and electrical borehole images were acquired and an integrated approach was taken, including geomechanical analysis to identify the contributing fractures. Standard petrophysical evaluation in basements was inconclusive and porosity quantification from fractures posed a major challenge. Image log analysis involved identification of conductive and resistive fractures in the gauged wellbore and combining Stoneley reflectivity further indicated probable open fractures. Following this, a geomechanical analysis was carried out to determine the current in-situ stress orientation/magnitudes based on observed breakouts. Finally a CSF study was done to check for fracture slip events. Based on the integrated study of Petrophysics and Geomechanics, an optimized workflow was developed and the critically stressed fractures were identified. It was found that, while some fractures strike direction was different from the present day maximum horizontal stress direction (SHmax), in general, most fractures were indeed aligned to SHmax. To check the fluid flowing capability of fracture networks, formation tester was deployed in selective zones for testing and sampling. Successful hydrocarbon sampling from selective fractures with orientation not aligned to SHmax led to the validation of the current study. The results proved that while most critically stressed/open fractures did indeed contribute to flow, a smaller fraction of the naturally occurring fractures while contributing to flow, were not necessarily aligned to the in situ orientations. The results present a discrepancy between observation and the expectation that open fractures are necessarily oriented parallel or nearly parallel to modern-day SHmax. This works highlights the fact that although paleo-stresses may influence the fracture networks, it is the contemporary in-situ stresses that truly dominate fluid flow and only through a detailed understanding of the critically stressed areas, can we come to a decisive conclusion that further improves overall recovery.

doi: 10.2118/197158-MS

Abu Dhabi International Petroleum Exhibition & Conference

SPE-197158-MS

Country: Asia > India > Tamil Nadu > Bay of Bengal (0.26)

Geophysics: Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.48)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > India > Tamil Nadu > Bay of Bengal > Cauvery Basin (0.99)
Europe > Norway > North Sea > Central North Sea > Utsira High > Greater Luno Area > Basement (0.98)

SPE Disciplines:

Well Completion > Hydraulic Fracturing (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)

Technology: Information Technology (1.00)

Reservoir characterization through seismic inversion: A case study

Chetia, Binode (ONGC) | Nagaraju, J. (ONGC) | Sharma, Subhash Kr. (ONGC) | Kumar, Anand (ONGC)

OnePetroSeptember, 2019

ABSTRACT The case study based on the inversion study of an area, situated in Cauvery basin, east cost of India. The objective of this area is to delineate and identification of reservoir sand through seismic inversion. We will discuss here the deterministic and the geostatistical method of seismic inversion and how their results are used for reservoir characterization. The major challenge in reservoir property modeling of Oil industries is to integrate the vertical resolution of petrophysical data with seismic data for lateral as well as vertical extension. In deterministic inversion reservoir properties are directly related with the amplitude of seismic data, but in geo-statistical inversion reservoir properties of wells are populated into the inter well space, simulated with 3D seismic data. Pre-stack deterministic and post-stack geostatistical inversion was carried out for characterization of reservoir properties. Probable litho facies and impedance volumes generated from geostatistical inversion captured distinctively the heterogeneity and small scale variations in the inter-well region that help us to delineate and identification of reservoirs. Presentation Date: Tuesday, September 17, 2019 Session Start Time: 8:30 AM Presentation Start Time: 10:35 AM Location: 217A Presentation Type: Oral

SEG International Exposition and Annual Meeting

doi: 10.1190/segam2019-3216159.1

SEG

SEG-2019-3216159

case study, geostatistical inversion, identification, impedance, inversion, litho facies, log data, realization, Reservoir Characterization, reservoir property, reservoir sand, seg international exposition, seismic data, seismic inversion, Upstream Oil & Gas, vertical resolution

Country: Asia > India > Tamil Nadu > Bay of Bengal (0.25)

Geophysics: Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling > Seismic Inversion (1.00)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Indonesia > Sumatra > Central Sumatra Basin (0.99)
Asia > India > Tamil Nadu > Bay of Bengal > Cauvery Basin (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Seismic modeling (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)

Technology: Information Technology (0.47)

Integration of 1D Geomechanics Modeling and High-Performance Water-Based Mud HPWBM System Design, Improving Cost-Effective Drilling of High-Angle Wells Through Cauvery Shale Sequence: A Case Study from Cauvery Basin, Offshore India

Saha, Sankhajit (Baker Hughes, a GE company) | Gariya, Bhuwan Chandra (Hindustan Oil Exploration Company Ltd) | Panda, Debabrata (Hindustan Oil Exploration Company Ltd) | Perumalla, Satya (Baker Hughes, a GE company) | Podder, Tuhin (Baker Hughes, a GE company) | Thanvi, Shrikant (Baker Hughes, a GE company) | Deshpande, Chandrashekhar (Baker Hughes, a GE company)

OnePetroApril, 2019

Abstract Drilling through the thick shale sequence (Oligocene to Paleocene age) of Cauvery offshore showed severe wellbore instability in the past due to incompatible mud program that increased overall operational cost. While new high-angle sidetrack development wells had been planned, three major challenges need to be addressed. First, proper mud weight recommendation for preventing mechanical instability; second, introduction of a cost-effective mud system preventing time-sensitive failure; and finally, mitigating the environmental impact factor of the mud system. Geomechanical modelling and Hole Stability analysis had been performed based on available dataset. An optimized mud weight (MW) program was developed based on the analysis. Considering the time-dependent failure characteristics of the shale and overall cost effectiveness, just modifying the mud weight does not address all of the challenges delineated above. Consequently, special "high-performance water-based mud system (HPWBM)" was designed instead of oil-based mud (OBM). This HPWBM was formulated based on the nature of shales encountered. While drilling, real-time geomechanics further facilitated controlled drilling conditions and optimized the mud program. The well-based geomechanical model indicated a hydrostatic pore pressure gradient in the region. The relative magnitude of three principle stresses showed a normal fault stress regime and maximum horizontal stress (SHmax) azimuth appeared to be nearly aligned to the N-S direction. Hole Stability analysis showed that a minimum of 12 ppg mud weight was required to drill the 8½" section. The sidetrack holes had a maximum inclination of 75 to 77 degrees. Different polymers and bridging agents were added to prepare the customized HPWBM in order to address shale instability and formation damage due to overbalance. Real-time monitoring during drilling operation utilized logging while drilling (LWD) log data, drilling parameters and mud logging data to promote smooth drilling operations. Through systematic planning and execution, the high-angle sidetrack holes had been drilled with zero non-productive time (NPT) in terms of well bore stability. More than 50% cost reduction was achieved on the mud system. An integrated solution that includes pre-drill geomechanics, HPWBM system design and real-time well monitoring helped to reduce the risks due to model uncertainties while drilling high angle wells through the thick shale section. This approach helped to reduce significant operational cost with an improved success rate.

doi: 10.2118/194626-MS

SPE Oil and Gas India Conference and Exhibition

SPE-194626-MS

Country: Asia > India > Tamil Nadu > Bay of Bengal (0.51)

Geologic Time:

Phanerozoic > Cenozoic > Paleogene (0.55)
Phanerozoic > Mesozoic (0.46)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > India > Tamil Nadu > Bay of Bengal > Cauvery Basin (0.99)
Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Zubair Formation (0.98)
Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Mishrif Formation (0.98)

SPE Disciplines:

Well Drilling > Wellbore Design > Wellbore integrity (1.00)
Well Drilling > Well Planning > Trajectory design (1.00)
Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
(2 more...)

Technology: Information Technology > Architecture > Real Time Systems (0.97)

Exploiting the Thick Tight Gas Sandstone Formation of Periyakudi Field of India through Fracturing Stimulation - A Challenging Experience

Mahawar, Dheeraj (ONGC) | Kumar, Rajesh (ONGC) | Das, Santanu (ONGC) | Rajendra, K (ONGC) | Nainwal, S P (ONGC)

OnePetroApril, 2017

Abstract This paper discusses the Hydraulic Fracturing (HF) treatment of the Andimadam Sandstone formation of Periyakudi field of India. The Andimadam sandstone is a hydrocarbon bearing formation, with estimated in-place reserves of 47.43 MMt (O+OEG) which was prognosticated after drilling and established hydrocarbon potential. Well PD#A was drilled in Andimadam Sandstone and HF in this well was attempted in order to develop and exploit the full potential of the oil and gas reserves of the field. The fracturing treatment of the tight gas reservoir in one of the deep well in Periyakudi field was performed eld. It was a challenge to carry out HF in well PD#A at such deeper depth formation. There was no previous information available to understand the formation and to predict its behaviour during HF treatment. HF treatment in tight gas Sandstone laid so many challenges. Formation breakdown, succeeding minimum rate required for fracturing and attaining high proppant concentration during job with crosslinking gel under extremely strenuous operational conditions and pressure limitations were some of the major challenges. Delayed cross-linked gel was used to minimize tubing friction pressure. Managing the pumping rate with pressure limitations during HF treatment was one of the major challenges. Execution of the treatment with low pumping rate results in stimulation of small volume of rock comparatively. All these limitations were overcomed by proper job designing, optimization of fracturing fluid and analysis of pre-frac treatments. A substantial amount of fracturing fluid and proppant placed into the formation maintaining all safety standards. Satisfactory flow back of frac fluid with gas was observed and high flow back pressure at surface was noted. This paper discusses challenges to execute hydraulic fracturing treatment in well PD#A and the lessons learned during the execution. In addition, it was the deep well (drilled upto 4945 m) in Periyakudi field with low permeability reservoir. Post analysis of pre-frac treatments done to obtain the reservoir properties and to design the main frac treatment. The results of fracturing treatment are also discussed. The promising hydrocarbon potential of the Andimadam sandstone which are based on post fracturing analysis, encourages further future development of the Periyakudi field, Cauvery Basin, India.

doi: 10.2118/185388-MS

SPE Oil and Gas India Conference and Exhibition

SPE-185388-MS

andimadam sandstone, calibration test, cross-linked gel, dimension, fracturing fluid, fracturing materials, fracturing stimulation, fracturing treatment, friction loss, HF treatment, hydraulic fracturing, India, Periyakudi field, Petroleum Engineer, Pressure Limitation, proppant, reservoir, thick tight gas sandstone formation, Upstream Oil & Gas

Country: Asia > India > Tamil Nadu > Bay of Bengal (0.25)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > India > Tamil Nadu > Bay of Bengal > Cauvery Basin (0.99)

SPE Disciplines:

Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
Reservoir Description and Dynamics (1.00)

Will it or won't it flow!! - A Novel Approach to Understand and Characterize the Fractures for Fluid Conductivity in Basement Reservoirs

OnePetroMarch, 2017

Abstract Madanam field in Cauvery basin in the east coast of India, has fractured gneissic basement. As exploration focus moved to unconventional reservoirs, the gneissic basement of Madanam was seen as a potential reservoir. However, ambiguity existed about the fluid flow through the basement. For example, in Madanam field, one well (well A) flowed whereas another well (well B) located 8.5 km away had minor flow from the basement reservoir that lasted 2 days. The main purpose of this study was to find possible reasons for this anomalous behavior. This study was conducted by integrating sonic and image measurements with a geomechanics workflow to identify critically stressed open fractures. Further, this work aims to provide a fit-for-purpose solution to optimize and prioritize testing zone selection in near real time.

doi: 10.2118/183702-MS

SPE Middle East Oil & Gas Show and Conference

SPE-183702-MS

basement reservoir, dip azimuth, envelope, evaluation, failure envelope, fluid conductivity, fracture, fracture plane, hydraulic fracturing, identify critically, mohr-coulomb failure envelope, Novel Approach, orientation, Petroleum Engineer, Reservoir Characterization, reservoir geomechanics, Stoneley response, stress state, Upstream Oil & Gas

Country: Asia > India > Tamil Nadu > Bay of Bengal (0.25)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > India > Tamil Nadu > Bay of Bengal > Cauvery Basin (0.99)
Europe > Norway > North Sea > Central North Sea > Utsira High > Greater Luno Area > Basement (0.98)

SPE Disciplines:

Well Drilling (1.00)
Well Completion > Hydraulic Fracturing (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)

Technology: Information Technology (0.87)

Applying Rock Physics Analysis to De-Risk Exploration Prospects in Mannar Basin, Sri Lanka

OnePetroNovember, 2015

Abstract The study area, block SL-2007-01-001, operated by Cairn India Ltd., is located in the Mannar basin of NW offshore Sri Lankan (blue polygone in Figure-1) and contains a sedimentary section exceeding 7km, the age of which ranges from Jurassic to Recent. The large number of oil and gas discoveries in the contiguous Cauvery Basin, both in Cretaceous and Tertiary sections, makes this frontier basin an attractive candidate for exploration. In 2010 Cairn Lanka acquired 1753 sq km of 3D seismic data in order to assess the exploration potential of this deep water block. This paper focuses on the role that rock physics analysis played in the assessment, risking, and ranking of the key leads identified in the basin. Of the numerous leads identified, three were high-graded in large part due to their DHI characteristics, resulting in the Dorado and Barracuda gas discoveries (Well-A & Well-C in Figure-1, respectively), the first hydrocarbons to be discovered in the Mannar Basin. The third well, Well-B, was a dry hole. De-risking of exploration prospects was based on quantitative seismic interpretation supported by rock physics analysis. This paper emphasizes how rock physics can add value in an exploration project to influence business decisions by reducing subsurface uncertainties. The nearest well, CY-DWN-2, that provided data for depth trends and rock physics analysis is located approximately fifty kilometers south west of the study area. Although this was a dry hole, it provided significant information on the sedimentary sequence, rock properties, and their associated seismic responses. Various "what if" scenarios were created to understand associated seismic responses. The analsyis explained the dry hole at CY-DWN-2 and highgraded the prospectivity of the Dorado lead. The latter was subsequently drilled, leading to the Dorado discovery.

doi: 10.2118/178060-MS

SPE Oil & Gas India Conference and Exhibition

SPE-178060-MS

amplitude, AVO response, de-risk exploration prospect, discovery, dorado prospect, gas reservoir, information, Mannar Basin, p-impedance, prospect, Reservoir Characterization, rock physics analysis, sediment, sequence, shale, Sri Lanka, structural geology, Upstream Oil & Gas

Country:

Asia > Sri Lanka > Palk Strait (0.86)
Asia > Sri Lanka > Laccadive Sea (0.86)
Asia > Sri Lanka > Bay of Bengal (0.86)
Asia > India > Tamil Nadu > Bay of Bengal (0.25)

Geologic Time:

Phanerozoic > Cenozoic (1.00)
Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.48)

Geophysics:

Geophysics > Seismic Surveying > Seismic Interpretation > Seismic Reservoir Characterization > Amplitude vs Offset (AVO) (0.96)
Geophysics > Seismic Surveying > Seismic Modeling (0.94)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Sri Lanka > Palk Strait > Mannar Basin (0.99)
Asia > Sri Lanka > Laccadive Sea > Mannar Basin (0.99)
Asia > Sri Lanka > Bay of Bengal > Mannar Basin (0.99)
(3 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)