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Aug 2015
Punj Liyod has won the Rs 1094 crore Haldia refinery EPCC package that aims to upgrade the sulphur block in the complex.
8The scope of work for the project involves design, detailed engineering study, engineering, procurement, construction and commissioning of the sulphur block.
8The sulphur block will include the sulphur refinery unit (SRU), amine regeneration unit (ARU) and the sour water stripper (SWS) including the utilities and offsite facilities
8With this new win, the group’s order backlog stands at Rs. 20,978 crores.
8The order backlog is the value of unexecuted orders on June 30, 2015 plus new orders received after that date.
8The contract is part of Haldia refinery's plan to upgrade High Sulphur Fuel Oil to higher value products like diesel and LPG which will lead to subsequent improvement in Gross Refinery Margins.
8It will also produce improved quality diesel, conforming to BS-IV specifications.
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8The scope of work for the project involves design, detailed engineering study, engineering, procurement, construction and commissioning of the sulphur block.
8The sulphur block will include the sulphur refinery unit (SRU), amine regeneration unit (ARU) and the sour water stripper (SWS) including the utilities and offsite facilities
8With this new win, the group’s order backlog stands at Rs. 20,978 crores.
8The order backlog is the value of unexecuted orders on June 30, 2015 plus new orders received after that date.
8The contract is part of Haldia refinery's plan to upgrade High Sulphur Fuel Oil to higher value products like diesel and LPG which will lead to subsequent improvement in Gross Refinery Margins.
8It will also produce improved quality diesel, conforming to BS-IV specifications.
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Punj Lloyd has extensive expertise in setting up sulphur blocks in Indian refineries.
8List of locations where sulphur blocks were setup by the company are as follows:
-- BORL’s (Bharat Oman Refinery) grass root Bina refinery,
-- CPCL’s (Chennai Petroleum Corporation) Manali refinery,
-- Kochi refinery,
-- HPC’s (Hindustan Petroleum Corporation) Mahul refinery,
8Punj Lloyd has in the past delivered complex refinery units at Haldia refinery, which includes the MSQ upgradation, the Hydrogen generation and the Hydrocracker unit.
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8List of locations where sulphur blocks were setup by the company are as follows:
-- BORL’s (Bharat Oman Refinery) grass root Bina refinery,
-- CPCL’s (Chennai Petroleum Corporation) Manali refinery,
-- Kochi refinery,
-- HPC’s (Hindustan Petroleum Corporation) Mahul refinery,
8Punj Lloyd has in the past delivered complex refinery units at Haldia refinery, which includes the MSQ upgradation, the Hydrogen generation and the Hydrocracker unit.
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Italian oil and gas major ENI has made a world class super giant gas discovery at its Zohr Prospect, in the deep waters of Egypt.
8The discovery well Zohr 1X NFW is located in the economic waters of Egypt’s Offshore Mediterranean, in 4,757 feet of water depth (1,450 metres), in the Shorouk Block.
8The discovery could hold a potential of 30 trillion cubic feet of lean gas in place (5.5 billion barrels of oil equivalent in place) covering an area of about 100 square kilometres.
8Zohr is the largest gas discovery ever made in Egypt and in the Mediterranean Sea and could become one of the world’s largest natural-gas finds.
8This exploration success will give a major contribution in satisfying Egypt’s natural gas demand for decades.
8Zohr 1X NFW was drilled to a total depth of approximately 13,553 feet (4,131 metres) and hit 2,067 feet (630 metres) of hydrocarbon column in a carbonate sequence of Miocene age with excellent 2 reservoir characteristics (400 metres plus of net pay).
Comment: In today's difficult environment, this is a real piece of good news. Given the massive reserves, the cost of production is expected to be economical. And this will add to the global gas supply matrix and keep prices under check by the time it comes on production. Details
8The discovery well Zohr 1X NFW is located in the economic waters of Egypt’s Offshore Mediterranean, in 4,757 feet of water depth (1,450 metres), in the Shorouk Block.
8The discovery could hold a potential of 30 trillion cubic feet of lean gas in place (5.5 billion barrels of oil equivalent in place) covering an area of about 100 square kilometres.
8Zohr is the largest gas discovery ever made in Egypt and in the Mediterranean Sea and could become one of the world’s largest natural-gas finds.
8This exploration success will give a major contribution in satisfying Egypt’s natural gas demand for decades.
8Zohr 1X NFW was drilled to a total depth of approximately 13,553 feet (4,131 metres) and hit 2,067 feet (630 metres) of hydrocarbon column in a carbonate sequence of Miocene age with excellent 2 reservoir characteristics (400 metres plus of net pay).
Comment: In today's difficult environment, this is a real piece of good news. Given the massive reserves, the cost of production is expected to be economical. And this will add to the global gas supply matrix and keep prices under check by the time it comes on production. Details
During July 2015, sales of Light Diesel Oil (LDO) registered a growth of 9.5%, Naptha too showed a healthy growth rate of 15.3% while Bitumen registered an increases of 15.4%
8LDO consumption recorded a growth during the month due to delay in onset of monsoon, leading to higher use of pumping sets, resumption of mining activities and improved port traffic
8The petrochemicals sector registered growth due to increased demand of naptha by RIL, IOCL,ONGC and APCL for use in their petrochemical plants.
8Cumulatively too, there was a increases of 6.6% for the period April-July 2015, for LDO, where as for naptha it was 10.4%.
8The reason for the decline in sales can be attributed to the government's emphasis on building concrete roads.
8Bitumen consumption also registered an increase of 15.4% in the month of July, 2015.
8Cumulatively, there was a drop of 3.5% between April-July 2015, which was mainly due lack of activity in infrastructure building.
roads.
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8LDO consumption recorded a growth during the month due to delay in onset of monsoon, leading to higher use of pumping sets, resumption of mining activities and improved port traffic
8The petrochemicals sector registered growth due to increased demand of naptha by RIL, IOCL,ONGC and APCL for use in their petrochemical plants.
8Cumulatively too, there was a increases of 6.6% for the period April-July 2015, for LDO, where as for naptha it was 10.4%.
8The reason for the decline in sales can be attributed to the government's emphasis on building concrete roads.
8Bitumen consumption also registered an increase of 15.4% in the month of July, 2015.
8Cumulatively, there was a drop of 3.5% between April-July 2015, which was mainly due lack of activity in infrastructure building.
roads.
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MS (petrol) consumption was up by 12.9% during July 2015 as compared to July 2014 while the comulative growth was12.5% for the period April to July 2015.
8The oil companies had sold around 1700 TMT of petrol during July 2015 .
8Cumulatively, 5,386.2 TMT of petrol was sold during the April-June period, registering a growth of 12.3% as compared to 4,796.3 TMT last year.
8The high growth in MS consumption may be attributed to the increased usage of cars and two wheelers.
8The cumulative growth in passenger vehicle sales has been 7.46 % for the period April to July, 2015.
8Scooter segment also registered a growth of 9.45% on cumulative basis for the period April to July, 2015.
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8The oil companies had sold around 1700 TMT of petrol during July 2015 .
8Cumulatively, 5,386.2 TMT of petrol was sold during the April-June period, registering a growth of 12.3% as compared to 4,796.3 TMT last year.
8The high growth in MS consumption may be attributed to the increased usage of cars and two wheelers.
8The cumulative growth in passenger vehicle sales has been 7.46 % for the period April to July, 2015.
8Scooter segment also registered a growth of 9.45% on cumulative basis for the period April to July, 2015.
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Companies in the Middle East are looking at nanotechnology as a solution to achieve maximum oil recovery.
8The implications of applying nanotechnology to enhance oil and gas recovery are very exciting.
8Nanotechnology may help achieve things that once seemed impossible.
8The right design of nano particles can stabilize foams and emulsions in the reservoir to improve sweep efficiency and recover oil from otherwise bypassed zones.
8Foam flooding as a mechanism to EOR has been intensively studied and is the subject of multiple research groups.
8However, limited stability of surfactant-generated foam in the presence of oil and the low chemical stability of surfactants in the high-temperature and high-salinity conditions of an oil reservoir are among the reasons for foam EOR not being widely applied in the field.
8Shell's studies have suggested that synthesized nano particles with altered surface properties can aid foam generation and increase foam stability in porous media.
8Shell have focused on a silica-based nano particle that is available in large quantities and can be processed economically without separate surface treatment.
8This gives it the potential to become a practical solution in the field.
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8The implications of applying nanotechnology to enhance oil and gas recovery are very exciting.
8Nanotechnology may help achieve things that once seemed impossible.
8The right design of nano particles can stabilize foams and emulsions in the reservoir to improve sweep efficiency and recover oil from otherwise bypassed zones.
8Foam flooding as a mechanism to EOR has been intensively studied and is the subject of multiple research groups.
8However, limited stability of surfactant-generated foam in the presence of oil and the low chemical stability of surfactants in the high-temperature and high-salinity conditions of an oil reservoir are among the reasons for foam EOR not being widely applied in the field.
8Shell's studies have suggested that synthesized nano particles with altered surface properties can aid foam generation and increase foam stability in porous media.
8Shell have focused on a silica-based nano particle that is available in large quantities and can be processed economically without separate surface treatment.
8This gives it the potential to become a practical solution in the field.
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As crude and gas prices plunge worldwide, the attention seems to be to focus on the recovery factor and improve it as far as is possible
The improvement in recovery factor follows from the low convertibility wherein there is a time lag between discovery and production. In this context, operators have to focus on maximizing their recovery factor (RF).
8This paradigm, according to a presentation made by Shell, holds true not just for India but also for the oil and gas industry as a whole as a means to maximize the ultimate recovery from the existing fields.
8With the global average field recovery is currently around 35%, leaving 60% to 70% of the oil in place intact thereby providing a large opportunity to commercially exploit the remaining reserves..
8Currently, Shell is focusing on developing and implementing improved 4D seismic methods, next-generation sensors and systems for arial and in-well monitoring.
8In particular, fiber-optic solutions for real-time well, reservoir, and pipeline surveillance is also being planned for both onshore and offshore fields.
8However, Shell is of the view that maximizing recovery from mature fields presents a complex technical challenges and the operators must take into account factors such as reservoir depth, oil density, and viscosity while considering recovery.
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The improvement in recovery factor follows from the low convertibility wherein there is a time lag between discovery and production. In this context, operators have to focus on maximizing their recovery factor (RF).
8This paradigm, according to a presentation made by Shell, holds true not just for India but also for the oil and gas industry as a whole as a means to maximize the ultimate recovery from the existing fields.
8With the global average field recovery is currently around 35%, leaving 60% to 70% of the oil in place intact thereby providing a large opportunity to commercially exploit the remaining reserves..
8Currently, Shell is focusing on developing and implementing improved 4D seismic methods, next-generation sensors and systems for arial and in-well monitoring.
8In particular, fiber-optic solutions for real-time well, reservoir, and pipeline surveillance is also being planned for both onshore and offshore fields.
8However, Shell is of the view that maximizing recovery from mature fields presents a complex technical challenges and the operators must take into account factors such as reservoir depth, oil density, and viscosity while considering recovery.
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Domestic petroleum product consumption registered a robust 5.5 % growth in July 2015 as compared to corresponding month in the pervious year.
8POL products here includes LPG, naphtha, MS (petrol), ATF, SKO (kerosene), HSD (diesel), LDO, FO/LSHS, bitumen and lubes as well as greases.
8On a cumulative basis, except for HSD and SKO, all other products have recorded a positive growth.
8The cumulative growth rate is 6.0%.
8The monthly POL consumption was 14 MMT in July 2015.
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8POL products here includes LPG, naphtha, MS (petrol), ATF, SKO (kerosene), HSD (diesel), LDO, FO/LSHS, bitumen and lubes as well as greases.
8On a cumulative basis, except for HSD and SKO, all other products have recorded a positive growth.
8The cumulative growth rate is 6.0%.
8The monthly POL consumption was 14 MMT in July 2015.
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The overall LPG consumption recorded a positive growth of 10.4% during July 2015 and a cumulative growth of 8.8% for the period April-July 2015.
8LPG for domestic consumption registered a 9.6% rise during July 2015 and 7.8% growth for the quarter April-July 2015. This happened mainly due to the release of 59.4 lakh new connections and 35.2 lakh DBCs during April-July 2015.
8LPG for non-domestic consumption registered a growth of 40.7% in July 2015 and a cumulative growth of 36.7% during April-July 2015. There was high growth too in Packed Non-Domestic LPG as a result of curbs in diversion of subsidized domestic cylinders use after the implementation of DBTL.
8Bulk LPG recorded a negative growth of 13.4% during July 2015 and 5.2% during the April-July period, 2015.
8Auto LPG registered a positive growth of 4.7% in July 2015. Cumulatively, for the April-July period, the growth rate stood at 8.5%.
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8LPG for domestic consumption registered a 9.6% rise during July 2015 and 7.8% growth for the quarter April-July 2015. This happened mainly due to the release of 59.4 lakh new connections and 35.2 lakh DBCs during April-July 2015.
8LPG for non-domestic consumption registered a growth of 40.7% in July 2015 and a cumulative growth of 36.7% during April-July 2015. There was high growth too in Packed Non-Domestic LPG as a result of curbs in diversion of subsidized domestic cylinders use after the implementation of DBTL.
8Bulk LPG recorded a negative growth of 13.4% during July 2015 and 5.2% during the April-July period, 2015.
8Auto LPG registered a positive growth of 4.7% in July 2015. Cumulatively, for the April-July period, the growth rate stood at 8.5%.
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Unlike MS, the consumption of of diesel (HSD) fell marginally by 0.5% during July 2015 as against high growth in previous month.
8In July 2015, the total all India sales volume of HSD was around 5800 TMT .
8The price cut in diesel that happened on 1st August, 2015 prompted dealers to drop inventories at retail outlets, resulting in shifting of HSD sales to August, 2015 causing lower sales in July month.
8The other factor that seems have affected sales is the shift of consumer preference from diesel to petrol driven passenger vehicles.
8Commercial vehicles sales registered a growth of 8.4% during July 2015. The medium and heavy commercial vehicles sales continued to record an impressive 29.5 % positive growth in July month.
8Growth of 9.74% was also noticed in port traffic during July, 2015 which was due to the improvement in cargo handling at ports.
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8In July 2015, the total all India sales volume of HSD was around 5800 TMT .
8The price cut in diesel that happened on 1st August, 2015 prompted dealers to drop inventories at retail outlets, resulting in shifting of HSD sales to August, 2015 causing lower sales in July month.
8The other factor that seems have affected sales is the shift of consumer preference from diesel to petrol driven passenger vehicles.
8Commercial vehicles sales registered a growth of 8.4% during July 2015. The medium and heavy commercial vehicles sales continued to record an impressive 29.5 % positive growth in July month.
8Growth of 9.74% was also noticed in port traffic during July, 2015 which was due to the improvement in cargo handling at ports.
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ATF consumption noticed a growth of 2.4% during July 2015. Cumulatively, for the April-July period, the growth was 3.2%.
8The higher sales in ATF can be attributed to a reduction in the number of flights operated by Spicejet which resulted in optimization of operations by other airlines.
8Sales volume during July 2015 stood above 450 TMT.
8Passengers carried by all Indian carriers during the month of July, 2015 recorded a growth of 29.31% at 67.45 lakh passengers during the month as compared to 52.16 lakh during the month of July, 2014.
8The Passenger load factor has been also continuously improving . The average for the calendar year January-December 2014 was 76.4%, but this year till July 2015 the same has increased to 83.1%.
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8The higher sales in ATF can be attributed to a reduction in the number of flights operated by Spicejet which resulted in optimization of operations by other airlines.
8Sales volume during July 2015 stood above 450 TMT.
8Passengers carried by all Indian carriers during the month of July, 2015 recorded a growth of 29.31% at 67.45 lakh passengers during the month as compared to 52.16 lakh during the month of July, 2014.
8The Passenger load factor has been also continuously improving . The average for the calendar year January-December 2014 was 76.4%, but this year till July 2015 the same has increased to 83.1%.
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FO+LSHS registered an impressive growth of sale by 25.4% in July 2015 as compared to July 2014, and pet coke witnessed a positive growth of 7.1% during the month.
8On a cumulative basis too, there was a growth of 6.4% in April to July, 2015 for FO+LSHS whereas the cumulative growth of pet coke was 19.2% during April-July 2015.
8But the cumulative FO+LSHS data hides the fact that there has been a drop in consumption of LSHS. The consumption of LSHS has reduced due to shift to natural gas by major customers like power and fertilizer industries, such as GNFC and NFL.
8The growth consumption of furnace Oil has been 39% whereas LSHS recorded a downward movement of 20.6%.
8Other general trade sectors like petrochemical and steel also registered a growth in the consumption of FO as compared to the previous year.
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8On a cumulative basis too, there was a growth of 6.4% in April to July, 2015 for FO+LSHS whereas the cumulative growth of pet coke was 19.2% during April-July 2015.
8But the cumulative FO+LSHS data hides the fact that there has been a drop in consumption of LSHS. The consumption of LSHS has reduced due to shift to natural gas by major customers like power and fertilizer industries, such as GNFC and NFL.
8The growth consumption of furnace Oil has been 39% whereas LSHS recorded a downward movement of 20.6%.
8Other general trade sectors like petrochemical and steel also registered a growth in the consumption of FO as compared to the previous year.
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Natural gas consumption witnessed an increase of about 4.3% during July 2015, as compared to July 2014.
8In terms of volumes, total consumption during July 2015 was 3,233 MMSCM as compared to 3,100 MMSCM in July 2014
8Cumulatively, gas consumption for the April-July period declined by 6.24% from 12,962 MMSCM as compared to 12,153 MMSCM during the same period last year.
8Fertilizer sector's consumption stood at 1,265 MMSCM showing a growth of 6.9% during July 2015. Cumulatively, consumption by the fertilizer sector increased by 1.59 % to 4,849.63 MMSCM from 4,773.88 MMSCM during Aprill-July 2014..
8Power sector witnessed an overall increases in volumes of around 6% from 676 MMSCM in July 2014 to 719 MMSCM in July 2015. On a cumulative basis, consumption declined by 6.7% to 2861 MMSCM during April-July 2015 from 3,067 MMSCM during April-July 2014.
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8In terms of volumes, total consumption during July 2015 was 3,233 MMSCM as compared to 3,100 MMSCM in July 2014
8Cumulatively, gas consumption for the April-July period declined by 6.24% from 12,962 MMSCM as compared to 12,153 MMSCM during the same period last year.
8Fertilizer sector's consumption stood at 1,265 MMSCM showing a growth of 6.9% during July 2015. Cumulatively, consumption by the fertilizer sector increased by 1.59 % to 4,849.63 MMSCM from 4,773.88 MMSCM during Aprill-July 2014..
8Power sector witnessed an overall increases in volumes of around 6% from 676 MMSCM in July 2014 to 719 MMSCM in July 2015. On a cumulative basis, consumption declined by 6.7% to 2861 MMSCM during April-July 2015 from 3,067 MMSCM during April-July 2014.
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The new model takes into account gas production from unconventional sources such as from shale plays, CBM and Underground Coal Gasification (UCG) is taken into consideration.
8The model takes into estimation of these reserves from research papers and projections which are already available.
8As for UGC, the model assumes that India has more than 35% of coal resources locked at depths higher than 300 m which are potentially exploitable. A cumulative 285.86 billion tonnes of geological resources of Coal and 40.90 billion tonnes of of lignite have so far been estimated in the country as in 2011. Out of the above estimates, 6 billion tonnes of lignite and 45 billion tons of coal, totaling 51 billion tones only is extractable. The 35 billion of lignite and 240 billion of coal is still unextractable. The policy paper has called to find ways and means to exploit these unrecoverable coal and lignite reserves of 275.75 billion tonnes.
8Unlike countries like China and the US, India does not have a reliable estimate of shale oil and gas deposits yet. Figures vary from an estimate 300 to 2100 TCF by Schlumberger to 584 TCF by the IEA. But actual estimates are not available as steps have not been taken yet to make a real estimate. ONGC is drilling some wells to find out more about shale plays in its blocks but it take time before realistic estimates are built.
8As for CBM, estimated prognosticated reserve in the country is about 92 TCF. The 33 CBM blocks awarded for exploration of CBM gas have an estimate of about 63 TCF. Reserves have been established in 8 CBM blocks which are in production or development phase. The total established in-place reserves in these these blocks are 9.9 TCF (280.34 BCM).
8There is a lot of potential in gas hydrates but production is still at an experimental stage. A lot reserves have been located in the Krishna Godavari, Mahanadi and Andaman deep waters in numerous complex geologic settings. Studies have prognosticated gas hydrate resources of 1894 TCM for India.
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8The model takes into estimation of these reserves from research papers and projections which are already available.
8As for UGC, the model assumes that India has more than 35% of coal resources locked at depths higher than 300 m which are potentially exploitable. A cumulative 285.86 billion tonnes of geological resources of Coal and 40.90 billion tonnes of of lignite have so far been estimated in the country as in 2011. Out of the above estimates, 6 billion tonnes of lignite and 45 billion tons of coal, totaling 51 billion tones only is extractable. The 35 billion of lignite and 240 billion of coal is still unextractable. The policy paper has called to find ways and means to exploit these unrecoverable coal and lignite reserves of 275.75 billion tonnes.
8Unlike countries like China and the US, India does not have a reliable estimate of shale oil and gas deposits yet. Figures vary from an estimate 300 to 2100 TCF by Schlumberger to 584 TCF by the IEA. But actual estimates are not available as steps have not been taken yet to make a real estimate. ONGC is drilling some wells to find out more about shale plays in its blocks but it take time before realistic estimates are built.
8As for CBM, estimated prognosticated reserve in the country is about 92 TCF. The 33 CBM blocks awarded for exploration of CBM gas have an estimate of about 63 TCF. Reserves have been established in 8 CBM blocks which are in production or development phase. The total established in-place reserves in these these blocks are 9.9 TCF (280.34 BCM).
8There is a lot of potential in gas hydrates but production is still at an experimental stage. A lot reserves have been located in the Krishna Godavari, Mahanadi and Andaman deep waters in numerous complex geologic settings. Studies have prognosticated gas hydrate resources of 1894 TCM for India.
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The government has launched the India Energy Security Scenarios 2047 Version 2.0 -- a predictive software tool under the ambit of NITI Ayog -- that looks at oil and gas demand, supply and possible price movements up to the year 2047 under four different scenarios.
8There is a Level 1 scenario where there is no improvement in recovery factors and no fields come into production barring the ones for which investment decisions have already been taken. The recovery factor has been assumed almost constant, that is 28% for oil and 55% for gas. Level 2 assumes some technological improvements and is called a ‘Determined Effort’ scenario allows for minor improvement in the recovery factor of 30% for oil and 60% for gas. Level 3 is an ‘Aggressive Effort’ scenario, where the recovery of 35% for oil and 70% for gas is assumed. while Level-4 is a ’Heroic Effort’ scenario where the recovery factor is 40% for oil and 80% for gas.
8What is played around with is the recovery factor while keeping the growth rate the initial in-place reserves at the historical level of 2.55%. This figure however may or may not improve depending upon the environment, regulatory regime and investments made in the E&P sector. The share of these reserves is taken as 9.5 billion tonnes of oil (40%) and that of gas at 14.25 billion tonnes (60%).
8Level 1 will eventually allow for a crude production of 34 MMT per annum in 2047, 59 MMT, 68 MMT and 78 MMT respectively under the other three scenarios.
8It is on the gas production front where the four scenarios bring about dramatic results. Annual output will be 81.5 BCM under the business as usual mode in 2047, 127.5 BCM under a determined effort basis, 170.5 BCM if an aggressive effort is put in and 224.5 BCM under the heroic effort scenario.
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8There is a Level 1 scenario where there is no improvement in recovery factors and no fields come into production barring the ones for which investment decisions have already been taken. The recovery factor has been assumed almost constant, that is 28% for oil and 55% for gas. Level 2 assumes some technological improvements and is called a ‘Determined Effort’ scenario allows for minor improvement in the recovery factor of 30% for oil and 60% for gas. Level 3 is an ‘Aggressive Effort’ scenario, where the recovery of 35% for oil and 70% for gas is assumed. while Level-4 is a ’Heroic Effort’ scenario where the recovery factor is 40% for oil and 80% for gas.
8What is played around with is the recovery factor while keeping the growth rate the initial in-place reserves at the historical level of 2.55%. This figure however may or may not improve depending upon the environment, regulatory regime and investments made in the E&P sector. The share of these reserves is taken as 9.5 billion tonnes of oil (40%) and that of gas at 14.25 billion tonnes (60%).
8Level 1 will eventually allow for a crude production of 34 MMT per annum in 2047, 59 MMT, 68 MMT and 78 MMT respectively under the other three scenarios.
8It is on the gas production front where the four scenarios bring about dramatic results. Annual output will be 81.5 BCM under the business as usual mode in 2047, 127.5 BCM under a determined effort basis, 170.5 BCM if an aggressive effort is put in and 224.5 BCM under the heroic effort scenario.
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The KPT also proposes to strengthen its oil jetties --Oil jetty No.1 and Oil jetty No.2—at Kandla port.
8The project envisages, strengthening T shaped oil jetties 1 and 2 by additional piles and conducting dredging alongside the berths.
8The project time schedule is estimated to be around 12 months.
8Strengthening of oil jetty would help KPT to lead traffic growth
Details of the project are as follows:
-- Proposed vessel size to dock at oil jetty 1 will be 65000 DWT as against previous 40000 DWT.
-- Oil jetty 2 will increase its vessel size from 52000 DWT to 65000 DWT.
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8The project envisages, strengthening T shaped oil jetties 1 and 2 by additional piles and conducting dredging alongside the berths.
8The project time schedule is estimated to be around 12 months.
8Strengthening of oil jetty would help KPT to lead traffic growth
Details of the project are as follows:
-- Proposed vessel size to dock at oil jetty 1 will be 65000 DWT as against previous 40000 DWT.
-- Oil jetty 2 will increase its vessel size from 52000 DWT to 65000 DWT.
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NITI Ayog's new model also provides a software tool to evaluate different cost pathways in the oil and gas sector.
8Cost projections have been included in excel sheets as well.
8The projections will have to estimate the price of crude and natural gas paid to the upstream oil and gas producer.
8The cost of processing and transporting crude and in the case of natural gas, merely cost of transportation has to be accounted for.
8As regards imported gas, the cost of tolling at the LNG terminals is taken into account.
8There is however a large uncertainty around prices in the next 3 decades or more, the model allows for three estimates of prices, allowing the user the choice of adopting the cost as may be preferred.
8The model makes it clear that given the recent drastic drop in the prices of crude and gas, there is a large uncertainty around such an exercise but the user can undertake sensitivity analysis on oil and gas costs to derive the big picture on the arbitrage involved in moving away from fossil fuels or continuing with it.
8For an import dependent country like India, the assumption is to err on the side of higher prices as India will need to strategise on protecting public finances, which are affected significantly when crude and gas prices rise given the large dependency on imports.
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8Cost projections have been included in excel sheets as well.
8The projections will have to estimate the price of crude and natural gas paid to the upstream oil and gas producer.
8The cost of processing and transporting crude and in the case of natural gas, merely cost of transportation has to be accounted for.
8As regards imported gas, the cost of tolling at the LNG terminals is taken into account.
8There is however a large uncertainty around prices in the next 3 decades or more, the model allows for three estimates of prices, allowing the user the choice of adopting the cost as may be preferred.
8The model makes it clear that given the recent drastic drop in the prices of crude and gas, there is a large uncertainty around such an exercise but the user can undertake sensitivity analysis on oil and gas costs to derive the big picture on the arbitrage involved in moving away from fossil fuels or continuing with it.
8For an import dependent country like India, the assumption is to err on the side of higher prices as India will need to strategise on protecting public finances, which are affected significantly when crude and gas prices rise given the large dependency on imports.
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8The maximum water consumption during operation (considering capacity expansion) of the plant is 150 m3/day. The water requirement is met through the water supply of Haldia Development Authority (HDA).
8The power requirement for the existing plant is 2800 kVA. For the existing project, power is received from the substation of the WBSEDCL.
8The existing fire fighting facility will be upgraded during the proposed expansion of the Haldia terminal. The existing plant has 2 fire water tanks of 2500kl and 6 fire engines of capacity 410kl/hr.
8The existing fire water network will be extended to form a loop around the tank farm. The proposed bullets and LPG pumps will be provided with Medium Velocity water spray system automatically actuated and fed through the Deluge Valve.
8Ninety three hydrocarbons detectors and twenty six emergency shut down systems are to be installed at 6 strategic locations. Details
8The power requirement for the existing plant is 2800 kVA. For the existing project, power is received from the substation of the WBSEDCL.
8The existing fire fighting facility will be upgraded during the proposed expansion of the Haldia terminal. The existing plant has 2 fire water tanks of 2500kl and 6 fire engines of capacity 410kl/hr.
8The existing fire water network will be extended to form a loop around the tank farm. The proposed bullets and LPG pumps will be provided with Medium Velocity water spray system automatically actuated and fed through the Deluge Valve.
8Ninety three hydrocarbons detectors and twenty six emergency shut down systems are to be installed at 6 strategic locations. Details
The existing Haldia LPG plant has following facilities:
8Receiving facility: Propane & Butane imported by ocean tankers are pumped through pipelines to refrigerated vessels. Propane and Butane mixed in definite proportion and after dosing of Marcaptan is stored in intermediate bullets for transfer to the bulk consumers and filling of cylinders
8Storage facility: 2Two refrigerated vessels of 15000 MT each have been installed. for storage of Propane & Butane.
8Filling operation facility: LPG from a bullet is pumped to the filling plant for bottling through 24 station carousel machine with 24 filling points. The system is capable of bottling 14.2/19.0 kg (net) cylinders. The filling system can turn out in 300 days a year approximately 50000 MTPA of LPG based on one shift per day with 8 effective hours of operation.
8Purging facility: Purging will be required in the following cases:
--New cylinder received are required to be air evacuated and LPG purged before the same are filled.
--Repaired cylinders which have been hydro tested with water are subject to evacuation for removal of moisture and air before refilling.
8The capacity of the LPG Bottling Plant is 28,400 kg. The area earmarked for storing filled LPG cylinders is around 423.36 sq. m where 2000 filled cylinders can be stored. Again the area earmarked for stacking empty cylinders is around 658.56 sq. m where 3000 empty cylinders can be stored. Details
8Receiving facility: Propane & Butane imported by ocean tankers are pumped through pipelines to refrigerated vessels. Propane and Butane mixed in definite proportion and after dosing of Marcaptan is stored in intermediate bullets for transfer to the bulk consumers and filling of cylinders
8Storage facility: 2Two refrigerated vessels of 15000 MT each have been installed. for storage of Propane & Butane.
8Filling operation facility: LPG from a bullet is pumped to the filling plant for bottling through 24 station carousel machine with 24 filling points. The system is capable of bottling 14.2/19.0 kg (net) cylinders. The filling system can turn out in 300 days a year approximately 50000 MTPA of LPG based on one shift per day with 8 effective hours of operation.
8Purging facility: Purging will be required in the following cases:
--New cylinder received are required to be air evacuated and LPG purged before the same are filled.
--Repaired cylinders which have been hydro tested with water are subject to evacuation for removal of moisture and air before refilling.
8The capacity of the LPG Bottling Plant is 28,400 kg. The area earmarked for storing filled LPG cylinders is around 423.36 sq. m where 2000 filled cylinders can be stored. Again the area earmarked for stacking empty cylinders is around 658.56 sq. m where 3000 empty cylinders can be stored. Details
Indian Oil Petronas intends to go in for a capacity expansion of LPG handling terminal at Haldia
8The terminal is capable for storage of propane and butane in refrigerated state for producing LPG
8The existing capacity of the plant is 31500 MT and after installation of three bullets with a capacity of 5400 MT, the total storage capacity will be 36900 MT.
Haldia is about 130 km away from the state capital of Kolkata
8The existing plant is consist of following storage capacities:
--2*15000 MT double wall double integrity.
--2 no of mounded bullets of capacity 6oo MT each.
--2 no of mounded bullets of capacity 150 Mt each.
8The proposed storage capacity the three mounded bullets of capacity 1800 MT each.
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8The terminal is capable for storage of propane and butane in refrigerated state for producing LPG
8The existing capacity of the plant is 31500 MT and after installation of three bullets with a capacity of 5400 MT, the total storage capacity will be 36900 MT.
Haldia is about 130 km away from the state capital of Kolkata
8The existing plant is consist of following storage capacities:
--2*15000 MT double wall double integrity.
--2 no of mounded bullets of capacity 6oo MT each.
--2 no of mounded bullets of capacity 150 Mt each.
8The proposed storage capacity the three mounded bullets of capacity 1800 MT each.
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In order to ease pressure on the existing liquid cargo berths, Kandla Port Trust (KPT) has taken a slew of measures that include development of oil jetties at Old Kandla Port at an estimated cost of Rs. 276.53 Crore.
8Commissioning of the proposed facility will augment the liquid cargo handling capacity of Kandla Port by 3.39 MMT per annum.
8The need of the project can be understood from the demand and supply mismatch at the Kandla Port in terms of the liquid cargo being handled by the existing four jetties.
8The existing capacity of all 4 oil jetties is 8 MMTPA
8After the commissioning of the proposed new oil jetty the total liquid cargo handling capacity at Kandla Port will reach to 11.39 MMTPA.
8The liquid cargo traffic at Kandla Port has increased at a compounded annual growth rate (CAGR) of 6.22 % over the last five years.
8This growth rate has been used for arriving at liquid cargo projections at Kandla Port over the next 30 years.
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8Commissioning of the proposed facility will augment the liquid cargo handling capacity of Kandla Port by 3.39 MMT per annum.
8The need of the project can be understood from the demand and supply mismatch at the Kandla Port in terms of the liquid cargo being handled by the existing four jetties.
8The existing capacity of all 4 oil jetties is 8 MMTPA
8After the commissioning of the proposed new oil jetty the total liquid cargo handling capacity at Kandla Port will reach to 11.39 MMTPA.
8The liquid cargo traffic at Kandla Port has increased at a compounded annual growth rate (CAGR) of 6.22 % over the last five years.
8This growth rate has been used for arriving at liquid cargo projections at Kandla Port over the next 30 years.
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Revamp objectives are planned to be achieved by modifications within the existing Guwahati unit. No additional land or site is required for the proposed capacity augmentation.
Following are the major modifications planned during revamp:
Reactor-Regeneration Section
-- Replacement of existing Reactor cyclones and Regenerator cyclones with new cyclones of higher capacity and efficiency.
-- Replacement of existing Reactor cyclones and Regenerator cyclones with new cyclones of higher capacity and efficiency.
-- Replacement of existing disc-and-doughnut type baffles of reactor stripper by ModGridTM Stripper internals supplied by Lummus Technology Inc.
-- Modification of plugging pattern in the orifice chamber.
Gas Concentration Section
--Replacement of three existing heat exchangers with new high capacity heat exchangers.
--Replacement of two existing pumps with new pumps and addition of two new pumps.
--Replacement of four trays in Main Fractionator column.
--Replacement of control valves.
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Following are the major modifications planned during revamp:
Reactor-Regeneration Section
-- Replacement of existing Reactor cyclones and Regenerator cyclones with new cyclones of higher capacity and efficiency.
-- Replacement of existing Reactor cyclones and Regenerator cyclones with new cyclones of higher capacity and efficiency.
-- Replacement of existing disc-and-doughnut type baffles of reactor stripper by ModGridTM Stripper internals supplied by Lummus Technology Inc.
-- Modification of plugging pattern in the orifice chamber.
Gas Concentration Section
--Replacement of three existing heat exchangers with new high capacity heat exchangers.
--Replacement of two existing pumps with new pumps and addition of two new pumps.
--Replacement of four trays in Main Fractionator column.
--Replacement of control valves.
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IOCL has chalked out a plan to revamp its existing INDMAX unit at Guwahati refinery, and enhance its capacity from 0.1 MMTPA to 0.15 MMTPA.
8The revamp project is being implemented for the improvement of profitability through the production of high value product like LPG and Gasoline.
8In addition to that, with the use of the new feed injectors and stripper internals supplied by Lummus Technology, the yields of high-value products like LPG and gasoline are going to increase after the revamp.
8INDMAX is a catalytic cracking process to produce very high yield of light olefins and high octane gasoline from various hydrocarbon fractions. The INDMAX unit is similar to that of a conventional fluidized catalytic cracking (FCC) unit.
8The original crude oil processing capacity at the refinery was of 0.75 MMTPA which has been subsequently increased to 1.00 MMTPA.
8The crude oil is supplied from Assam fields by OIL through a crosscountry pipeline..
Existing area of the unit is 5200 m2 and there is no additional land required for the project revampment.
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Details
8The revamp project is being implemented for the improvement of profitability through the production of high value product like LPG and Gasoline.
8In addition to that, with the use of the new feed injectors and stripper internals supplied by Lummus Technology, the yields of high-value products like LPG and gasoline are going to increase after the revamp.
8INDMAX is a catalytic cracking process to produce very high yield of light olefins and high octane gasoline from various hydrocarbon fractions. The INDMAX unit is similar to that of a conventional fluidized catalytic cracking (FCC) unit.
8The original crude oil processing capacity at the refinery was of 0.75 MMTPA which has been subsequently increased to 1.00 MMTPA.
8The crude oil is supplied from Assam fields by OIL through a crosscountry pipeline..
Existing area of the unit is 5200 m2 and there is no additional land required for the project revampment.
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Details
Details of the proposed pipelines:
-- 12 inch X 22.8 km pipeline
-- 12 inch X 19.7 km pipeline
-- 6 inch X23.7 km pipeline
-- 4 inch 40.8 km pipeline
The entire workup to the pre-commissioning including mobilization period of one month will be covered within 09 months. Details
-- 12 inch X 22.8 km pipeline
-- 12 inch X 19.7 km pipeline
-- 6 inch X23.7 km pipeline
-- 4 inch 40.8 km pipeline
The entire workup to the pre-commissioning including mobilization period of one month will be covered within 09 months. Details
GAILplans to replace its natural gas pipeline network in the Cauvery basin following audit reports that leaks and accidents may occur because of neglect of safety procedures.
8The pipeline major has engaged MECON to undertake the project management and consultancy services associated with the replacement project.
8To do so it has been decided to replace and rectify the selected old pipelines of the natural gas distribution networks in the Cauvery basin region.
8The basin region is presently hosting around 278 Kms of pipeline network which includes the main line and the spur line.
8The project will also include the conversion of existing various non-piggable gas pipelines to piggable pipelines.
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8The pipeline major has engaged MECON to undertake the project management and consultancy services associated with the replacement project.
8To do so it has been decided to replace and rectify the selected old pipelines of the natural gas distribution networks in the Cauvery basin region.
8The basin region is presently hosting around 278 Kms of pipeline network which includes the main line and the spur line.
8The project will also include the conversion of existing various non-piggable gas pipelines to piggable pipelines.
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Details of the pipeline to be laid are as follows:
-- 36 inch pipeline for first 1200 meters and 30 inch pipeline for the rest 130 meters.
-- 42 inch pipeline for a length of 160 meters.
-- 42 inch pipeline for a length of 12,300 meter (including crossing Length).
-- 42 inch pipeline for a length of 3000 meter.
The project is planned in three parts, each part will take 12 months to complete.
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-- 36 inch pipeline for first 1200 meters and 30 inch pipeline for the rest 130 meters.
-- 42 inch pipeline for a length of 160 meters.
-- 42 inch pipeline for a length of 12,300 meter (including crossing Length).
-- 42 inch pipeline for a length of 3000 meter.
The project is planned in three parts, each part will take 12 months to complete.
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Chennai Petroleum Corporation Limited (CPCL) proposes to lay a 42 inch crude oil pipe line from Chennai Port to its refinery at Manali.
8This will replace the existing 30” crude oil pipeline and will help improve productivity and cater to expanded refinery capacity.
8The station pipeline will be laid from the Bharti dock (BD-III) to BD-I (above ground) and then from BD-I to the land fall point.
8In addition to that, another station pipeline will be laid from the landfall point to the scrapper launching barrel area (above/underground).
8This will be followed by another pipeline laid from the scrapper receiving barrel (SRB) station boundary to the Hook-up point.
8Whereas the main line will be laid from scrapper launching barrel (SLB) inside Chennai Port Trust to the scrapper receiving barrel (SRB) station inside the CPCL, Manali Refinery.
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8This will replace the existing 30” crude oil pipeline and will help improve productivity and cater to expanded refinery capacity.
8The station pipeline will be laid from the Bharti dock (BD-III) to BD-I (above ground) and then from BD-I to the land fall point.
8In addition to that, another station pipeline will be laid from the landfall point to the scrapper launching barrel area (above/underground).
8This will be followed by another pipeline laid from the scrapper receiving barrel (SRB) station boundary to the Hook-up point.
8Whereas the main line will be laid from scrapper launching barrel (SLB) inside Chennai Port Trust to the scrapper receiving barrel (SRB) station inside the CPCL, Manali Refinery.
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The following cost estimates are taken into account by the NITI Ayog model for calculation of costs:
8The Point Estimate for 2017 domestic price is calculated by moderately increasing the prevailing domestic gas price of $4.66/mmbtu by 20%. The low estimate for 2017 domestic price is computed by increasing the domestic gas price of $4.27/mmbtu (as it prevailed in 2012) by 20%. The high estimate for 2017 domestic price is calculated by increasing the price in proportion with low and point estimates. Pertinently, domestic and imported gas prices vary till 2022 after which they become alike as explained above.
8The crude prices have been derived from the International Energy Agency’s (IEA) World Energy Outlook (WEO) which describes three policy scenarios
Rs 417 million/Mtoe/year is taken as the high estimate and Rs 333 million/Mtoe/year as low estimate for capital cost. The point estimate for capital cost of refinery is taken as the average of high and low cost estimates. The high, point and low estimates for operating cost of 1 Mtoe refinery excluding fuel costs is taken as 4.4% of the high, point and low estimates of capital cost respectively.
8The high and low estimate of the total cost of pumping and transporting 1 Mtoe of crude oil through pipeline is taken as INR 1400 and 1200 per Km per 1000 tons.
8The high, point and low estimate of capital cost for import docking of 1 Mtoe of crude oil through pipeline is taken as Rs 190 million/Mtoe derived after consulting with industry.
8The high and low estimate of the total cost of transporting gas through pipeline is taken as $1/mmbtu and $0.4/mmbtu respectively while the point estimate is taken as the average of the high and low cost estimates. The high, point and low estimate of the total cost of 1 Mtoe LNG import terminal in India is taken as INR 45/mmbtu after consultion with LNG terminal operators.
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8The Point Estimate for 2017 domestic price is calculated by moderately increasing the prevailing domestic gas price of $4.66/mmbtu by 20%. The low estimate for 2017 domestic price is computed by increasing the domestic gas price of $4.27/mmbtu (as it prevailed in 2012) by 20%. The high estimate for 2017 domestic price is calculated by increasing the price in proportion with low and point estimates. Pertinently, domestic and imported gas prices vary till 2022 after which they become alike as explained above.
8The crude prices have been derived from the International Energy Agency’s (IEA) World Energy Outlook (WEO) which describes three policy scenarios
Rs 417 million/Mtoe/year is taken as the high estimate and Rs 333 million/Mtoe/year as low estimate for capital cost. The point estimate for capital cost of refinery is taken as the average of high and low cost estimates. The high, point and low estimates for operating cost of 1 Mtoe refinery excluding fuel costs is taken as 4.4% of the high, point and low estimates of capital cost respectively.
8The high and low estimate of the total cost of pumping and transporting 1 Mtoe of crude oil through pipeline is taken as INR 1400 and 1200 per Km per 1000 tons.
8The high, point and low estimate of capital cost for import docking of 1 Mtoe of crude oil through pipeline is taken as Rs 190 million/Mtoe derived after consulting with industry.
8The high and low estimate of the total cost of transporting gas through pipeline is taken as $1/mmbtu and $0.4/mmbtu respectively while the point estimate is taken as the average of the high and low cost estimates. The high, point and low estimate of the total cost of 1 Mtoe LNG import terminal in India is taken as INR 45/mmbtu after consultion with LNG terminal operators.
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The India Energy Security Scenarios 2047 Version 2.0 provides for demand side modeling too.
8The demand for oil and gas in the Indian economy is generated from all consuming sectors through the software.
8The user can fine tune the demand using technology and energy efficiency choices.
8The algorithm in the tool then deploys domestic oil and gas production in meeting the demand. The balance demand is then sourced by the excel model from imports, which would be separately shown as numbers/percentage of the supply being imported.
8It is obvious that the level of petroleum imports would be dependent both on demand and supply scenarios.
8The new software version creates import scenarios for demand and supply combinations.
8It helps the policy maker to remain aware of the steps that need to be taken to bring import levels down and enhance India’s energy security.
8The likely oil and gas demand would be 587 MMT and 308 BCM in 2047 considering Level 2 (Determined Effort) which is the default scenario, respectively.
8On the other hand the likely production of oil and gas has been estimated to be 59 MMT and 127 BCM in 2047 under Level 2.
8Thus Level 2 a robust increase in demand but only moderate increase in domestic and gas supply.
8Resultantly, when taking into account the likely demand for petroleum products as envisaged by the software, the oil and gas import shares (against consumption) could be between 88% and 60% in 2047.
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8The demand for oil and gas in the Indian economy is generated from all consuming sectors through the software.
8The user can fine tune the demand using technology and energy efficiency choices.
8The algorithm in the tool then deploys domestic oil and gas production in meeting the demand. The balance demand is then sourced by the excel model from imports, which would be separately shown as numbers/percentage of the supply being imported.
8It is obvious that the level of petroleum imports would be dependent both on demand and supply scenarios.
8The new software version creates import scenarios for demand and supply combinations.
8It helps the policy maker to remain aware of the steps that need to be taken to bring import levels down and enhance India’s energy security.
8The likely oil and gas demand would be 587 MMT and 308 BCM in 2047 considering Level 2 (Determined Effort) which is the default scenario, respectively.
8On the other hand the likely production of oil and gas has been estimated to be 59 MMT and 127 BCM in 2047 under Level 2.
8Thus Level 2 a robust increase in demand but only moderate increase in domestic and gas supply.
8Resultantly, when taking into account the likely demand for petroleum products as envisaged by the software, the oil and gas import shares (against consumption) could be between 88% and 60% in 2047.
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The target seems to be to push the recovery factor to 40% for oil from 28%.
8The government claims that achieving a 40% recovery should not be a problem as the recovery factor of more than 45% has been achieved for oil in North Sea fields and in the USA.
8But achieving a recovery of 40% would require huge investments, technology collaborations, and a better policy framework.
8Raising the recovery for gas reserves from current levels of 55% to 80% however may be a tad ambitious but that seems to be the attempt here.
8The NITI Ayog exercise is meant to highlight the ‘problems’ faced by the E&P sector in their inability to convert discoveries into production, and the likely ‘upsides’ to crude/gas production by putting in place suitable policies to enhance recoveries.
8The idea seems to look at a policy framework that can free up the reserves and raise output significantly.
8A new software model has also been released that helps the user make choices in the determination of different crude oil and gas production trajectories until the year 2047.
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8The government claims that achieving a 40% recovery should not be a problem as the recovery factor of more than 45% has been achieved for oil in North Sea fields and in the USA.
8But achieving a recovery of 40% would require huge investments, technology collaborations, and a better policy framework.
8Raising the recovery for gas reserves from current levels of 55% to 80% however may be a tad ambitious but that seems to be the attempt here.
8The NITI Ayog exercise is meant to highlight the ‘problems’ faced by the E&P sector in their inability to convert discoveries into production, and the likely ‘upsides’ to crude/gas production by putting in place suitable policies to enhance recoveries.
8The idea seems to look at a policy framework that can free up the reserves and raise output significantly.
8A new software model has also been released that helps the user make choices in the determination of different crude oil and gas production trajectories until the year 2047.
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Aug 30 : Modi government's new oil & gas model-II: Raising recovery factor seems to be the new focus
The India Energy Security Scenarios 2047 Version 2.0 has highlighted what it believes is a fundamental flaw in the oil and gas exploration business in India.
8The problem has been that while India has been reporting discovery of new resources, production has been stagnant.
8There is definitely a time lag between discovery and production, but in India’s case, the discoveries seem to be getting monetized only partially. It is purported that the production levels are being maintained by exploiting new discoveries in existing acreages by IOR and EOR. The situation remains ever confusing.
8At the same time, both ONGC and OIL have been reporting healthy new finds thereby achieving Reserve-Replacement-Ratio (RRR) of 1 and above. Similarly, under NELP, even private sector companies (public, too) have reported multiple oil and gas discoveries.
8But only 4-5 discoveries have been brought under production in spite of the fact that NELP blocks had been auctioned away for the last 15 years.
8Should these discoveries be monetized, a vast scope appears for improving production. As of now, growth in production of oil and gas is near static or on decline.
8The in-place reserves are rising but the proven reserves and production is static. The analysis indicates that with the likely growth in initial in place (IIP) reserves, if India were to make ‘heroic efforts’ or induct technology and encourage policy environment.
8The focus, as the India Energy Security Scenarios 2047 Version 2.0 suggest, should be on raising the recovery factor of all the reserves that the public sector and some private sector companies have been adding up.
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8The problem has been that while India has been reporting discovery of new resources, production has been stagnant.
8There is definitely a time lag between discovery and production, but in India’s case, the discoveries seem to be getting monetized only partially. It is purported that the production levels are being maintained by exploiting new discoveries in existing acreages by IOR and EOR. The situation remains ever confusing.
8At the same time, both ONGC and OIL have been reporting healthy new finds thereby achieving Reserve-Replacement-Ratio (RRR) of 1 and above. Similarly, under NELP, even private sector companies (public, too) have reported multiple oil and gas discoveries.
8But only 4-5 discoveries have been brought under production in spite of the fact that NELP blocks had been auctioned away for the last 15 years.
8Should these discoveries be monetized, a vast scope appears for improving production. As of now, growth in production of oil and gas is near static or on decline.
8The in-place reserves are rising but the proven reserves and production is static. The analysis indicates that with the likely growth in initial in place (IIP) reserves, if India were to make ‘heroic efforts’ or induct technology and encourage policy environment.
8The focus, as the India Energy Security Scenarios 2047 Version 2.0 suggest, should be on raising the recovery factor of all the reserves that the public sector and some private sector companies have been adding up.
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Clearly the low crude prices have knocked the bottom of HOEC's ambitions to tap its offshore Caveery assets.
8If the price cycle improves, it will perhaps restart work there.
8For the time being the bet seems to be only in Assam.
8What is next for HOEC?
8The company says it will participate in the next marginal field bidding round, and explore low risk investments in the South East Asia region.
8The point that is not quite understandable is why ENI Is holding on to the company. The Italian major is so large, that it just does not make sense to be invested in HOEC.
8But then oil and gas companies have strange ways of doing business and ENI Is perhaps no exception.
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8If the price cycle improves, it will perhaps restart work there.
8For the time being the bet seems to be only in Assam.
8What is next for HOEC?
8The company says it will participate in the next marginal field bidding round, and explore low risk investments in the South East Asia region.
8The point that is not quite understandable is why ENI Is holding on to the company. The Italian major is so large, that it just does not make sense to be invested in HOEC.
8But then oil and gas companies have strange ways of doing business and ENI Is perhaps no exception.
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There is nothing much for HOEC to look ahead with its other assets for the time being.
8The PY 3 field has been shut down since July, 2011 and last production was at 3,300 barrels per day.
8Clearly current prices are unviable but the company wants to keep the option of at an optimized cost and at an appropriate price.
8Then again, CB-OS/1 is another block in the Cambay basin where HOEC is invested but the present price seems to make the development of the field unviable even though the Management Committee had approved a development plan given by ONGC, the operator, in JUne, 2014.
8The cost economics are currently unfavorable for any development to take place.
8The company has three marginal fields -- Asjol, North Balol and CB-ON-7 -- where the production is low but they have high netbacks of between $16 and going up to $30 or so despite falling prices.
8But these fields cannot be flogged beyond a point.
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8The PY 3 field has been shut down since July, 2011 and last production was at 3,300 barrels per day.
8Clearly current prices are unviable but the company wants to keep the option of at an optimized cost and at an appropriate price.
8Then again, CB-OS/1 is another block in the Cambay basin where HOEC is invested but the present price seems to make the development of the field unviable even though the Management Committee had approved a development plan given by ONGC, the operator, in JUne, 2014.
8The cost economics are currently unfavorable for any development to take place.
8The company has three marginal fields -- Asjol, North Balol and CB-ON-7 -- where the production is low but they have high netbacks of between $16 and going up to $30 or so despite falling prices.
8But these fields cannot be flogged beyond a point.
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While the Assam block has made the all important difference, HOEC's PY-1 field is showing signs of terminal decline as of now.
8The company has made money out of it but after spending around $400 million in four development wells and an offshore platform. A 55 mmscf processing plant has also been set up
8But production is down to just 3 mmscfd in 2014-15 on account of heavy water cut.
8Attempts will be made to salvage the field with a rig-less Coil tubing job in one well an rig based workovers later.
8The company is now betting on yet to be recovered resource base of 31.5 BCF of 2P reserves as assessed by a third party.
8Options to partially farm out its 100% PI will be attempted.
8Also, new well will possibly be drilled to target undrilled prospects at the right time.
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8The company has made money out of it but after spending around $400 million in four development wells and an offshore platform. A 55 mmscf processing plant has also been set up
8But production is down to just 3 mmscfd in 2014-15 on account of heavy water cut.
8Attempts will be made to salvage the field with a rig-less Coil tubing job in one well an rig based workovers later.
8The company is now betting on yet to be recovered resource base of 31.5 BCF of 2P reserves as assessed by a third party.
8Options to partially farm out its 100% PI will be attempted.
8Also, new well will possibly be drilled to target undrilled prospects at the right time.
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The Assam block seems to be making the all important to HOEC.
8Revenues are expected to climb from the existing levels of Rs 47.90 crore in 2014-15 from its other fields to Rs 100 crore.
8Moreover, only $85 million would be required for development as against $100 million already incurred for exploration
8No cess and royalty is payable to the government and profit share with the government for the first 6 years is minimal due to cost carry.
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8Revenues are expected to climb from the existing levels of Rs 47.90 crore in 2014-15 from its other fields to Rs 100 crore.
8Moreover, only $85 million would be required for development as against $100 million already incurred for exploration
8No cess and royalty is payable to the government and profit share with the government for the first 6 years is minimal due to cost carry.
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Given the circumstances, no one knows better than HOEC that the E&P sector is fraught with risks but the struggle cant be given up midway.
8Only one good prospect is needed to amke the all important difference in the E&P business
8And HOEC seems to have found a sweets spot in its AAP-ON-94/1 block in Assam, where it is an operator with a 27% stake.
8After a $100 million E&P budget by the JV, it has been able to establish a Gas-Initially-in-Place(GIIP) of 244 BCF (100%), with recoverable reserves of 134 BCF
8This provides a minimum plateau rate of production of 20mmscfd for a 15 year period, with a n economic life of 20 years.
8The interesting part is that there can be a upside potential in the prolific Tipam and Barali formation as well as in the North Dirok structures that are yet to be explored.
8The risks seem to have paid of.
8What is more, evacuation is not a problem as the gas can be pumped into an Oil India pipeline that ferries gas to the Assam gas cracker complex.
8The problem however is the low price of gas, at $4.66/mmbtu but HOEC is lucky to find a customer in this remote region. What is more, the PSC is structured to allow for cost recovery for the first six years before profit sharing kicks in.
8The company is now fast tracking the production of gas, with the drilling and completion of two wells.
First gas is expected in Q-4 2016-17.
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8Only one good prospect is needed to amke the all important difference in the E&P business
8And HOEC seems to have found a sweets spot in its AAP-ON-94/1 block in Assam, where it is an operator with a 27% stake.
8After a $100 million E&P budget by the JV, it has been able to establish a Gas-Initially-in-Place(GIIP) of 244 BCF (100%), with recoverable reserves of 134 BCF
8This provides a minimum plateau rate of production of 20mmscfd for a 15 year period, with a n economic life of 20 years.
8The interesting part is that there can be a upside potential in the prolific Tipam and Barali formation as well as in the North Dirok structures that are yet to be explored.
8The risks seem to have paid of.
8What is more, evacuation is not a problem as the gas can be pumped into an Oil India pipeline that ferries gas to the Assam gas cracker complex.
8The problem however is the low price of gas, at $4.66/mmbtu but HOEC is lucky to find a customer in this remote region. What is more, the PSC is structured to allow for cost recovery for the first six years before profit sharing kicks in.
8The company is now fast tracking the production of gas, with the drilling and completion of two wells.
First gas is expected in Q-4 2016-17.
Click on the Reports section for more. Details
A cursory look at HOEC's balance sheet will show a whole lot of red ink splashed all over it.
Losses were at an incredible Rs 1221 crore on revenues of mere Rs 47.9 crore.
8This was on account of an impairment load of a massive Rs 1163 crore resulting from a re-estimation of reserves in PY field where production has shut down and because the PY-3 and CB-OS-1 fields were uneconomical to develop because of the crash in crude prices.
8But the silver lining comes from the fact that the Italian oil major ENI, which has a 47.18% stake in HOEC, has waived off the loan of Rs 960 crore, which was transferred to capital reserves in FY15.
The Q1 2015-16 figures are now looking better with a profit of just 50 lacs on a revenue base of 10.06 crore.
8The advantage is that the company has a debit free balance sheet where operating revenues are now meeting opex and it has got a BBB+ rating from ICRA for a Rs 100 crore long term debt propsal.
8The working capital position as of now is a positive Rs 130 crore.
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Losses were at an incredible Rs 1221 crore on revenues of mere Rs 47.9 crore.
8This was on account of an impairment load of a massive Rs 1163 crore resulting from a re-estimation of reserves in PY field where production has shut down and because the PY-3 and CB-OS-1 fields were uneconomical to develop because of the crash in crude prices.
8But the silver lining comes from the fact that the Italian oil major ENI, which has a 47.18% stake in HOEC, has waived off the loan of Rs 960 crore, which was transferred to capital reserves in FY15.
The Q1 2015-16 figures are now looking better with a profit of just 50 lacs on a revenue base of 10.06 crore.
8The advantage is that the company has a debit free balance sheet where operating revenues are now meeting opex and it has got a BBB+ rating from ICRA for a Rs 100 crore long term debt propsal.
8The working capital position as of now is a positive Rs 130 crore.
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The GAIL pipeline blast killed 22 people while they sleeping on June 27, 2014. Twenty two people died and 40 were injured.
8An investigation was done and GAIL was found responsible for severe lapses.
8The gas major was found to be repairing the pipeline on a regular basis using temporary measures.
8The pipeline was designed for dry gas while wet gas was allowed to be plied.
8A dehydration plant was meant to set up but never was.
8There were suggestions made to use corrosion inhibitor but that was ignored by GAIL
8Scrapper pigging was not carried out in the pipeline even though that was essential to take out water and condensate
8No procedures were laid down on how temporary repairs should be carried out and this was the main reason why the blast occurred.
8A rig residue analysis, which is important to understand the health of a pipeline system, was never carried out
8Worst was that the command control structure that was an essential part of the safety regulations was there only on paper.
8What were the consequences: 22 innocent people were burnt to death in their sleep and many more were injured.
8What action action was taken against the management of GAIL: Nothing at all!
8Did anyone go to jail for loss of lives on account of willful neglect: No!
8Was there a criminal charge on any GAIL official for loss of lives No!
8Was anyone punished or sacked: No!
8This incident and its aftermath is a telling commentary on how the oil and gas industry functions in India.
8And the Modi government needs to fix this anomaly with utmost urgency.
Click on Details and also on our Reports section for more Details
8An investigation was done and GAIL was found responsible for severe lapses.
8The gas major was found to be repairing the pipeline on a regular basis using temporary measures.
8The pipeline was designed for dry gas while wet gas was allowed to be plied.
8A dehydration plant was meant to set up but never was.
8There were suggestions made to use corrosion inhibitor but that was ignored by GAIL
8Scrapper pigging was not carried out in the pipeline even though that was essential to take out water and condensate
8No procedures were laid down on how temporary repairs should be carried out and this was the main reason why the blast occurred.
8A rig residue analysis, which is important to understand the health of a pipeline system, was never carried out
8Worst was that the command control structure that was an essential part of the safety regulations was there only on paper.
8What were the consequences: 22 innocent people were burnt to death in their sleep and many more were injured.
8What action action was taken against the management of GAIL: Nothing at all!
8Did anyone go to jail for loss of lives on account of willful neglect: No!
8Was there a criminal charge on any GAIL official for loss of lives No!
8Was anyone punished or sacked: No!
8This incident and its aftermath is a telling commentary on how the oil and gas industry functions in India.
8And the Modi government needs to fix this anomaly with utmost urgency.
Click on Details and also on our Reports section for more Details
The cabinet committee on Economic Affairs has approved the proposal for payment of differential royalty to the state governments concerned with 28 discovered fields.
8The Indian Government had awarded 28 discovered fields to different companies during the year 1994-95,2001 and 2004.
8These 28 discovered fields were located in the states of Arunachal Predesh,Assam and Gujrat.
8The payment will provided by the budgetary allocation instead of oil industry development board fund from the year 2015 -2016.
8The expected expenditure for the year 2015-16 has been estimated at Rs.56 crore comprising of Rs.30 crore for Arunachal and Rs. 26 crore for Gujrat.
8The state Governments are currently getting royalty based on the Oilfields Act,1948 and Petroleum & Natural gas rules 1959.
8The budgetary allocation will ensure the proper utilization of OIDB fund.
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8The Indian Government had awarded 28 discovered fields to different companies during the year 1994-95,2001 and 2004.
8These 28 discovered fields were located in the states of Arunachal Predesh,Assam and Gujrat.
8The payment will provided by the budgetary allocation instead of oil industry development board fund from the year 2015 -2016.
8The expected expenditure for the year 2015-16 has been estimated at Rs.56 crore comprising of Rs.30 crore for Arunachal and Rs. 26 crore for Gujrat.
8The state Governments are currently getting royalty based on the Oilfields Act,1948 and Petroleum & Natural gas rules 1959.
8The budgetary allocation will ensure the proper utilization of OIDB fund.
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For those who are interested, the website carries here complete details of GAIL's gas processing stations, gas compressors and major pipeline networks in terms of:
8Process plants
8Compressor stations (Location and numnber)
8Permanent installations
8Pipeline networks
8Secondary lines
8Sub network likes
Click on our Reports section for more Details
8Process plants
8Compressor stations (Location and numnber)
8Permanent installations
8Pipeline networks
8Secondary lines
8Sub network likes
Click on our Reports section for more Details
Subsequent to a series of deaths for mishaps directly accountable to criminal neglect of safety norms, the Gas Authority of India (GAIL) brass is undertaking a series of safety audits of all its installations.
8The gas major is now now embarking on a tighter safety audit of its accident prone gas processing units, including associated facilities.
8All national gas compressor stations and their associated facilities will also be audited.
8Audit will also be carried out of pipelines and installations related to pipelines
8The gas processing plants in Vijaipur, Gandhar and Vaghodia will be audited once every year for next two years.
8Audits will also be undertaken in compressor stations and its associated facilities at 8 locations, involving Hazira, Jhabua, Khera, Vijaipur, Vaghodia, Dibiyapur, Kailaras and Chainsa.
8Audit will be carried out once every year over the next three years
Click on the Reports for more. Details
8The gas major is now now embarking on a tighter safety audit of its accident prone gas processing units, including associated facilities.
8All national gas compressor stations and their associated facilities will also be audited.
8Audit will also be carried out of pipelines and installations related to pipelines
8The gas processing plants in Vijaipur, Gandhar and Vaghodia will be audited once every year for next two years.
8Audits will also be undertaken in compressor stations and its associated facilities at 8 locations, involving Hazira, Jhabua, Khera, Vijaipur, Vaghodia, Dibiyapur, Kailaras and Chainsa.
8Audit will be carried out once every year over the next three years
Click on the Reports for more. Details
The problem is not with the tender but with the viability of the ethanol blending programme now that global crude prices have collapsed.
8The problem is that with crude prices at around $40, the price to be paid for ethanol cannot be very high.
8The ethanol price paid to distilleries last time around was Rs 39 per litre and that was when the price of crude was 85.87/bbl.
8The sugar industry had always accused the oil marketing companies of pocketing a neat margin -- the industry claims that it can go as high as Rs 9 per litre -- but assuming that this margin is passed on to the sugar distilleries, even then, the viability of supply at current crude prices will remain a serious problem.
8Given that the sugar industry has strong political backing, will the Modi government want to subsidize the purchase of ethanol?
8May be that is possible but that is of course something that the government will have to decide. Details
8The problem is that with crude prices at around $40, the price to be paid for ethanol cannot be very high.
8The ethanol price paid to distilleries last time around was Rs 39 per litre and that was when the price of crude was 85.87/bbl.
8The sugar industry had always accused the oil marketing companies of pocketing a neat margin -- the industry claims that it can go as high as Rs 9 per litre -- but assuming that this margin is passed on to the sugar distilleries, even then, the viability of supply at current crude prices will remain a serious problem.
8Given that the sugar industry has strong political backing, will the Modi government want to subsidize the purchase of ethanol?
8May be that is possible but that is of course something that the government will have to decide. Details
So how will the supply integration happen?
8This will be done by constructing a heat traced pipeline in Mumbai and Kochi to transfer these high pour point, high viscosity products.
8The pipeline from the BPCL's Mumbai refinery will take it to the local port and then ferried by coastal shipping to Kochi where a similar pipeline will take it into the refinery.
8During turnarounds, in case of a shortfall, products will move from Kochi to Mumbai if there is a requirement.
8The existing pipelines to the ports from the two refineries transfer only low poor intermediates
8Only a heat traced pipeline can transfer high viscosity products.
8Around 400 TMT of HSVR (roughly about 34 TMT a month), 170 to 220 TMT of LSHS (14 to 18 TMT per month) will be loaded from the Mumbai refinery for arrival at Kochi through the new electrically traced pipeline at the Old Prpau jetty.
Kick on Reports for more Details
8This will be done by constructing a heat traced pipeline in Mumbai and Kochi to transfer these high pour point, high viscosity products.
8The pipeline from the BPCL's Mumbai refinery will take it to the local port and then ferried by coastal shipping to Kochi where a similar pipeline will take it into the refinery.
8During turnarounds, in case of a shortfall, products will move from Kochi to Mumbai if there is a requirement.
8The existing pipelines to the ports from the two refineries transfer only low poor intermediates
8Only a heat traced pipeline can transfer high viscosity products.
8Around 400 TMT of HSVR (roughly about 34 TMT a month), 170 to 220 TMT of LSHS (14 to 18 TMT per month) will be loaded from the Mumbai refinery for arrival at Kochi through the new electrically traced pipeline at the Old Prpau jetty.
Kick on Reports for more Details
BPCL's attempt to join the supply chain between Mumbai and Kochi refineries will have other advantages as well.
8During normal operation, the VGO in a refinery is usally processed in its FCCU or in the VGO hydro-treating units.
8But a problem can arise during turnarounds when there is a possibility that due tankage constraints either at BPCL's Kochi or Mumbai refineries, they may be required to reduce their crude throughput.
8This can happen because of VGO containment issues.
8Now that the supply chain is going to be integrated, the VGO can be transferred between the refineries on a case to case basis thereby avoiding loss of crude processing capacities in both refineries.
8Then again, bbitumen from the Mumbai refinery is being evacuated through Tank lorries but with production likely to increase in the future with increased processing of heavy crudes the feasibility of loading bitumen into Tankers through the same pipeline is also planned.
Click on Reports for more Details
8During normal operation, the VGO in a refinery is usally processed in its FCCU or in the VGO hydro-treating units.
8But a problem can arise during turnarounds when there is a possibility that due tankage constraints either at BPCL's Kochi or Mumbai refineries, they may be required to reduce their crude throughput.
8This can happen because of VGO containment issues.
8Now that the supply chain is going to be integrated, the VGO can be transferred between the refineries on a case to case basis thereby avoiding loss of crude processing capacities in both refineries.
8Then again, bbitumen from the Mumbai refinery is being evacuated through Tank lorries but with production likely to increase in the future with increased processing of heavy crudes the feasibility of loading bitumen into Tankers through the same pipeline is also planned.
Click on Reports for more Details
BPCL has put together a ambitious plan to supply massive quantities of high pour point and high viscosity intermediates such as Low and High Sulphur Vaccum Residues (HSVR), Low Sulphur Heavy Stock (LSHS) and Vaccum Gas Oil (VGO) from its Mumbai refinery to the new revamped and expanded Kochi refinery.
8The Mumbai refinery will transfer as much as 400 TMT of HSVR per annum to Kochi
8HSVR in fact is a blend of vacuum residues with 10 % to 15 % heavy kerosene which will be stored separately for transfer to Kochi
8The HSVR will be processed in the DCU in Kochi for more value added products.
8Then again, the total plant fuel requirement in Kochi subsequent to its expansion and revamp is estimated at 422 TMT of which around 120 TMT will be internally generated, leaving a gap of 322 TMT of low sulphur plant fuel to be imported by the refinery. This gap can be plugged by Mumbai refinery by supplying 170 to 200 TMT of LSHS to the Kochi refinery, with only the balance 122 TMT of low sulphur fuel oil left to be imported by Kochi.
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8The Mumbai refinery will transfer as much as 400 TMT of HSVR per annum to Kochi
8HSVR in fact is a blend of vacuum residues with 10 % to 15 % heavy kerosene which will be stored separately for transfer to Kochi
8The HSVR will be processed in the DCU in Kochi for more value added products.
8Then again, the total plant fuel requirement in Kochi subsequent to its expansion and revamp is estimated at 422 TMT of which around 120 TMT will be internally generated, leaving a gap of 322 TMT of low sulphur plant fuel to be imported by the refinery. This gap can be plugged by Mumbai refinery by supplying 170 to 200 TMT of LSHS to the Kochi refinery, with only the balance 122 TMT of low sulphur fuel oil left to be imported by Kochi.
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Oil India Limited intends to drill seven Extended Reach Drilling (ERD) wells in Baghjan area in the prospective Tinsukia district in Assam.
8The price tag is Rs 280 crore.
8The wells are being drilled below the Dibru-Saikhowa national park with the Dangori river in the south and Brahmaputra in north.
8The part is out of bounds for drilling and that's the reason why the ERDs are being drilled.
8Oil India Ltd is of the view that there is a strong possibility that there are hydrocarbons below the park and beyond the mining lease demarcation of the Bhagjan block.
8Currently 5000 bbl of oil has been produced from 19 wells in Baghjan region per day.
8The seven locations are planned from the existing three well plinths
8The wells will extend 2 km into the forest
8Thetarget depth is 3950 m.
8A total in-place resource of 11.5 MMSKLS has been estimated for the identified prospects. The recoverable resources are estimated at 3.45 MMSKLS.
Click on the Reports for more. Details
8The price tag is Rs 280 crore.
8The wells are being drilled below the Dibru-Saikhowa national park with the Dangori river in the south and Brahmaputra in north.
8The part is out of bounds for drilling and that's the reason why the ERDs are being drilled.
8Oil India Ltd is of the view that there is a strong possibility that there are hydrocarbons below the park and beyond the mining lease demarcation of the Bhagjan block.
8Currently 5000 bbl of oil has been produced from 19 wells in Baghjan region per day.
8The seven locations are planned from the existing three well plinths
8The wells will extend 2 km into the forest
8Thetarget depth is 3950 m.
8A total in-place resource of 11.5 MMSKLS has been estimated for the identified prospects. The recoverable resources are estimated at 3.45 MMSKLS.
Click on the Reports for more. Details
OIL had tapped oil and gas in the Baghjan region as late as 2003 and so far it has drilled 19 wells.
8The structure itself has been identified way back in 1991 based on limited seismic data and later re-defined based on additional 2D seismics in 1999-2000 .
8When the wells were first drilled, gas was discovered in two sands within the Lakadong+Therria structure. Minor amounts of light oil and condensate was also found.
8The Baghjan area was covered with 3D seismic for further development of the field in 2004-2005.
8OIL is planning to drill the ERD wells with high technology to drill the ERD wells
8The petroleum system present in Baghjan region is essentially a Langpar and Lakadong+Theria formation and all wells at Baghjan encountered this formation, consisting mainly of rich organic matter which have TAI values of more than 2.0.
Click on the Reports for more. Details
8The structure itself has been identified way back in 1991 based on limited seismic data and later re-defined based on additional 2D seismics in 1999-2000 .
8When the wells were first drilled, gas was discovered in two sands within the Lakadong+Therria structure. Minor amounts of light oil and condensate was also found.
8The Baghjan area was covered with 3D seismic for further development of the field in 2004-2005.
8OIL is planning to drill the ERD wells with high technology to drill the ERD wells
8The petroleum system present in Baghjan region is essentially a Langpar and Lakadong+Theria formation and all wells at Baghjan encountered this formation, consisting mainly of rich organic matter which have TAI values of more than 2.0.
Click on the Reports for more. Details
BPCL has planned to install two mounded storage vessels within its existing LPG plant in Hisar,Haryana.
8The existing plant has a total of five storage facilities with a combined capacity of 560 MT( 4 x 125 MT,1 x 60 MT).
8The proposed installation of 2x300 MT mounded vessels will take place after the dismantling of three mounded bullets of 125 MT capacity each.
8Plant receives its LPG mostly from Dahej (Gujarat) and some part from the Bharat Oman refinery at Bina.
8The power requirement for the LPG bottling plant is 190 kW and is obtained from grid power supply.
8The project implementation schedule is 15 months from zero date.
Click on the Reports section for more. Details
8The existing plant has a total of five storage facilities with a combined capacity of 560 MT( 4 x 125 MT,1 x 60 MT).
8The proposed installation of 2x300 MT mounded vessels will take place after the dismantling of three mounded bullets of 125 MT capacity each.
8Plant receives its LPG mostly from Dahej (Gujarat) and some part from the Bharat Oman refinery at Bina.
8The power requirement for the LPG bottling plant is 190 kW and is obtained from grid power supply.
8The project implementation schedule is 15 months from zero date.
Click on the Reports section for more. Details
Aegis logistics Ltd plans to spend a substantial Rs 400 crore to create ‘necklace’ of LPG and bulk liquid port terminals around the coastline of India.
8The investment will be made over the next 18-24 months.
8The company has firmed up new and additional storages in its already exiting facilities at Pipavav, Kochi and Haldia
8The Aegis group owns and operates India’s largest integrated bulk liquid cum LPG terminal in the port of Mumbai and also the largest private bulk liquid terminal at the Kochi port along with liquid and pressurized LPG Storage terminal at the Pipavav port.
8Then again, in Haldia, it owns a liquid bulk storage terminal while in Kheda in Gujarat it has a LPG bottling unit.
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8The investment will be made over the next 18-24 months.
8The company has firmed up new and additional storages in its already exiting facilities at Pipavav, Kochi and Haldia
8The Aegis group owns and operates India’s largest integrated bulk liquid cum LPG terminal in the port of Mumbai and also the largest private bulk liquid terminal at the Kochi port along with liquid and pressurized LPG Storage terminal at the Pipavav port.
8Then again, in Haldia, it owns a liquid bulk storage terminal while in Kheda in Gujarat it has a LPG bottling unit.
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PNGRB has again reminded its authorized CGD entities to expeditiously complete GIS mapping of their pipeline and other installation networks within the given deadline.
8As per regulations, the entities are required to implement GIS mapping within 3 years from the date of notification, which was released on May 16, 2013.
8The GIS details will be shared with the respective state authorities so as to make them aware of the co-ordinates of the networks.
8The entities are also advised to web host the relevant information so as to reduce the chances of third party damage to the network.
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8As per regulations, the entities are required to implement GIS mapping within 3 years from the date of notification, which was released on May 16, 2013.
8The GIS details will be shared with the respective state authorities so as to make them aware of the co-ordinates of the networks.
8The entities are also advised to web host the relevant information so as to reduce the chances of third party damage to the network.
Click on the Reports for more. Details
