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Jul 2015
In the meantime, GAIL announced it Q1 (April-June) 2015, results today (July 23, 2015) where it recorded a fall of 31.72% in its net profit at Rs 424 crore compared to Rs 621 crore in the corresponding period last year.
8The turnover too went down to Rs 12,519 crore from Rs 13,337 crore seen last year
8The decrease in profit is mainly due to lower price realization of LPG, other liquid hydrocarbons and petrochemicals. Also, the production of LPG and petrochemicals was lower during the quarter due to shut down in the Pata petrochemical plant.
8The lower net profit can also be attributed to increased interest and depreciation charges after commissioning of the petrochemical expansion.
8Revenue from natural gas transmission, during the quarter, was, however, 40% higher at Rs 925 crore compared to Rs 660 crore during the corresponding period in 2014-15. Natural gas transmission during the first quarter stood at 87.48 mmscmd as against 96.91 mmscmd earlier.
8Revenue from LPG transmission was also up 23% to Rs 136 crore from Rs 111 crore earlier. LPG transmission for the first quarter stood at 689 thousand tonnes as against 832 thousand tonnes previously.
8Sales from natural gas marketing stood at Rs 10,581 crore as against Rs 11,669 crore at the same time last year while revenue from petrochemicals was pegged at Rs 516 crore as against Rs 993 crore earlier. Details
8The turnover too went down to Rs 12,519 crore from Rs 13,337 crore seen last year
8The decrease in profit is mainly due to lower price realization of LPG, other liquid hydrocarbons and petrochemicals. Also, the production of LPG and petrochemicals was lower during the quarter due to shut down in the Pata petrochemical plant.
8The lower net profit can also be attributed to increased interest and depreciation charges after commissioning of the petrochemical expansion.
8Revenue from natural gas transmission, during the quarter, was, however, 40% higher at Rs 925 crore compared to Rs 660 crore during the corresponding period in 2014-15. Natural gas transmission during the first quarter stood at 87.48 mmscmd as against 96.91 mmscmd earlier.
8Revenue from LPG transmission was also up 23% to Rs 136 crore from Rs 111 crore earlier. LPG transmission for the first quarter stood at 689 thousand tonnes as against 832 thousand tonnes previously.
8Sales from natural gas marketing stood at Rs 10,581 crore as against Rs 11,669 crore at the same time last year while revenue from petrochemicals was pegged at Rs 516 crore as against Rs 993 crore earlier. Details
The Oilex-GSPC combine's plans are to put all three wells -- Cambay 77, 77H and Bhandut-3 into production.
8In 2015-16, a four well programme will be undertaken, all of them horizontal, and the idea is to eventually convert them into production wells.
8The delivery from these wells are likely to be in the range of 200-250 mcmf of gas
8From 2017 onwards, the idea is to accelerate the drilling plan, using multiple rigs and reach the target figure of 100 wells or more.
8The plan is ambitious: drilled as many as 30 wells every year.
8So for suppliers of equipment and services, big business awaits them in the Cambay block. Enter Introduction Here Details
8In 2015-16, a four well programme will be undertaken, all of them horizontal, and the idea is to eventually convert them into production wells.
8The delivery from these wells are likely to be in the range of 200-250 mcmf of gas
8From 2017 onwards, the idea is to accelerate the drilling plan, using multiple rigs and reach the target figure of 100 wells or more.
8The plan is ambitious: drilled as many as 30 wells every year.
8So for suppliers of equipment and services, big business awaits them in the Cambay block. Enter Introduction Here Details
There was much enthusiasm last year over the success of the Cambay 77H well among the promoters.
8The combine drew parallels between the geologies of the Marcellus filed in the US which went on the become one of the largest US gas fields in the world.
8Any comparison of this nature is a bit ambitious but the combine claims that the comparison helped shorten the learning curve in Cambay.
8The point that is being made is that the directional drilling capacity of the duo will improve as the wells that are to be drilled from here on will be repetitive in nature.
8In the Cambay 77H well, Oilex successfully perforated, isolated and treated eight fractures over four stages and the advantage is that future wells will henceforth have wider free spacing, allowing for more cost savings. Moreover, frac efficiency will improve as more and more wells are drilled in the block.
8The Cambay 77H well proves that the Eocene reservoir is amenable to this kind of exploitation. Details
8The combine drew parallels between the geologies of the Marcellus filed in the US which went on the become one of the largest US gas fields in the world.
8Any comparison of this nature is a bit ambitious but the combine claims that the comparison helped shorten the learning curve in Cambay.
8The point that is being made is that the directional drilling capacity of the duo will improve as the wells that are to be drilled from here on will be repetitive in nature.
8In the Cambay 77H well, Oilex successfully perforated, isolated and treated eight fractures over four stages and the advantage is that future wells will henceforth have wider free spacing, allowing for more cost savings. Moreover, frac efficiency will improve as more and more wells are drilled in the block.
8The Cambay 77H well proves that the Eocene reservoir is amenable to this kind of exploitation. Details
8Production updates from the Cambay-73 well are as follows:
--Cambay-73 averaged 54 BOEPD during the twenty two days from 26 June 2015 to 17 July 2015.
--The well has achieved 100% operational availability during this period.
--Condensate to gas ratio (CGR) is calculated to be 58 barrels per MMSCF, which is 26% higher than the CGR used in the Independent Reserves Report from RISC Operations Pty Ltd.
--Since the introduction of gas from the Cambay Field into the low pressure network, the average daily demand has increased by 28% from 250 MSCFD to 320MSCFD.
--In light of the increasing local gas demand, the Joint Venture is considering some operational efficiencies to better service the market and encourage further demand growth.
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--Cambay-73 averaged 54 BOEPD during the twenty two days from 26 June 2015 to 17 July 2015.
--The well has achieved 100% operational availability during this period.
--Condensate to gas ratio (CGR) is calculated to be 58 barrels per MMSCF, which is 26% higher than the CGR used in the Independent Reserves Report from RISC Operations Pty Ltd.
--Since the introduction of gas from the Cambay Field into the low pressure network, the average daily demand has increased by 28% from 250 MSCFD to 320MSCFD.
--In light of the increasing local gas demand, the Joint Venture is considering some operational efficiencies to better service the market and encourage further demand growth.
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Oilex-GSPC combine seems to be enthused by the success of its Cambay-73 well in Cambay basin in Gujarat.
8The well is producing gas and the important point is that it has been able to find customers for it.
8In all the duo have two other hydrocarbon bearing wells Bhandut-3 and Cambay-77H.
8Oilex is the operator and it plans to to drill between 100 to 200 wells in the block
8The investment plan is ambitious: between $800 million and a massive $2.4 billion over a period of 10 years.
8The production potential of the block is pegged between 75 million barrels of oil equivalent (boe) to 150 million boe over a 10-year period.
8The block is likely to produce gas between 50 mmscf/day to 150 mmscf/day.
8The revenue from the field is estimated between $3.8 billion to $7.6 billion over the 10-year tenure.
Click on Reports for more Details
8The well is producing gas and the important point is that it has been able to find customers for it.
8In all the duo have two other hydrocarbon bearing wells Bhandut-3 and Cambay-77H.
8Oilex is the operator and it plans to to drill between 100 to 200 wells in the block
8The investment plan is ambitious: between $800 million and a massive $2.4 billion over a period of 10 years.
8The production potential of the block is pegged between 75 million barrels of oil equivalent (boe) to 150 million boe over a 10-year period.
8The block is likely to produce gas between 50 mmscf/day to 150 mmscf/day.
8The revenue from the field is estimated between $3.8 billion to $7.6 billion over the 10-year tenure.
Click on Reports for more Details
By most yardsticks, Dharmendra Pradhan is a rookie minister. Given his age and experience, he is indeed lucky to occupy the petroleum minister`s chair. But his inexperience did not seem to have come in the way of delivering a high-impact speech at the recent OPEC summit where he candidly and lucidly highlighted the challenges and opportunities in the Indian hydrocarbon sector. The following are some of the excerpts from his speech:
8While asserting that India`s oil demand would grow at at compounded annual rate of 3.5% up to 2040, and this growth rate is almost double the next highest growth rate, he made it clear that he would "fail in my duty if I do not reflect upon the sentiment of the people of India regarding OPEC".
8Firstly, he said, there was a strong feeling that Asian counties like India should receive an Asian dividend, rather than paying an Asian premium in making bulk purchases of crude. “I will not hesitate to say that the Asian premium was historically never justified and more so not justifiable in the changed-market scenario where Asian countries are the major buyers. Any measure that erodes the advantage of geography for Asian countries and promotes a policy of subsidizing oil traffic to distant destinations is not, and cannot be, in the interests of sustainable development.
8Secondly, he continued, there was also a need to revisit policies related to demand of the letter of credit from regular and bulk buyers and the need to consider extending the credit time for crude imports.
8Thirdly, OPEC Members needed to factor into reality that countries like India had developed cost-effective, modern and complex refining capacity. The average Nelson Complexity Index factor of Indian public sector refineries was ten and for the private refinery about 14, which were higher than the European average of 6.5 and the US average of 9.5. “There is big strength for India in this sector. Hence, it is in everyone’s interest to refine crude in India in the most cost-effective manner. If we receive crude at a fair price without paying the Asian premium, our gross refining margins will improve and it will result in competitively priced petroleum products,” he maintained.
Stirring speech indeed!
Click on Reports for more. Details
8While asserting that India`s oil demand would grow at at compounded annual rate of 3.5% up to 2040, and this growth rate is almost double the next highest growth rate, he made it clear that he would "fail in my duty if I do not reflect upon the sentiment of the people of India regarding OPEC".
8Firstly, he said, there was a strong feeling that Asian counties like India should receive an Asian dividend, rather than paying an Asian premium in making bulk purchases of crude. “I will not hesitate to say that the Asian premium was historically never justified and more so not justifiable in the changed-market scenario where Asian countries are the major buyers. Any measure that erodes the advantage of geography for Asian countries and promotes a policy of subsidizing oil traffic to distant destinations is not, and cannot be, in the interests of sustainable development.
8Secondly, he continued, there was also a need to revisit policies related to demand of the letter of credit from regular and bulk buyers and the need to consider extending the credit time for crude imports.
8Thirdly, OPEC Members needed to factor into reality that countries like India had developed cost-effective, modern and complex refining capacity. The average Nelson Complexity Index factor of Indian public sector refineries was ten and for the private refinery about 14, which were higher than the European average of 6.5 and the US average of 9.5. “There is big strength for India in this sector. Hence, it is in everyone’s interest to refine crude in India in the most cost-effective manner. If we receive crude at a fair price without paying the Asian premium, our gross refining margins will improve and it will result in competitively priced petroleum products,” he maintained.
Stirring speech indeed!
Click on Reports for more. Details
For improvement of distillate yield in the Haldia Refinery, a Delayed Coker Project is under installation in the Haldia refinery.
8Scheduled commissioning of these facilities is envisaged in mid-2017
8List of facilities to be installed under the project are:
--Delayed Coker Unit: 1700 TMTPA
--Coker Gas Oil Hydrotreater Unit: 1400 TMTPA
--Coker LPG MEROX unit: 70 TMTPA
--SRU: 80 TPD
--ARU: 260 TPH
--SWSU: 65 TPH
8For improvement of Gr-II/III LOBS production, a Feed Preparation Unit has also been approved recently, which is an extension of extant OHCU’s product recovery section. The capacity of this section will be 650 TMTPA.
8Scheduled commissioning of this facility is envisaged in late-2016.
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8Scheduled commissioning of these facilities is envisaged in mid-2017
8List of facilities to be installed under the project are:
--Delayed Coker Unit: 1700 TMTPA
--Coker Gas Oil Hydrotreater Unit: 1400 TMTPA
--Coker LPG MEROX unit: 70 TMTPA
--SRU: 80 TPD
--ARU: 260 TPH
--SWSU: 65 TPH
8For improvement of Gr-II/III LOBS production, a Feed Preparation Unit has also been approved recently, which is an extension of extant OHCU’s product recovery section. The capacity of this section will be 650 TMTPA.
8Scheduled commissioning of this facility is envisaged in late-2016.
Click on details for more. Details
GEEC claims that their average production has increased by 10% to 12.81 MMSCFD in FY 2015 from 11.70 MMSCFD in FY 2014.
8Moreover production also increased by 18% to 15.06 MMSCFD in July 2015 from 12.81 MMSCFD average for the 12 months ended 31 March 2015.
8The company says that the improved results can be credited to its production optimization programmes.
8Optimization of the pipeline network has resulted in an increase of 17% in gas flow (by 1,581 MCFD). Out of the total entailed optimization, 50% has been completed. Further improvement in gas flow is anticipated with more optimization being carried out in the pipelines.
8Successful pump optimization also helped achieve a 176 % increase in gas flow (by 475 MCFD). Further improvement in gas flow is anticipated as a result of regular dewatering.
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8Moreover production also increased by 18% to 15.06 MMSCFD in July 2015 from 12.81 MMSCFD average for the 12 months ended 31 March 2015.
8The company says that the improved results can be credited to its production optimization programmes.
8Optimization of the pipeline network has resulted in an increase of 17% in gas flow (by 1,581 MCFD). Out of the total entailed optimization, 50% has been completed. Further improvement in gas flow is anticipated with more optimization being carried out in the pipelines.
8Successful pump optimization also helped achieve a 176 % increase in gas flow (by 475 MCFD). Further improvement in gas flow is anticipated as a result of regular dewatering.
Click on Reports for more. Details
IOCLs Haldia refinery is planning to conduct a hydrocarbon flare adequacy study of its single hydrocarbon flare stack which is catering to the entire refinery’s flare load.
8Design capacity of the flare system is 796 TPH, with the main flare stack being 100 m in height and 54” in diameter.
8Current HC flare’s adequacy study is based on an earlier study conducted by a reputed vendor in 1998 and subsequent revisit of the same in 2011-12 in view of the once-through hydro-cracker (OHCU) project.
8However, as the refinery has been revamped on a piecemeal basis a number of times and new units have been added to the configuration over the time, the need was felt to carry out a fresh Flare Adequacy Study in the present context.
8The study’s scope will be the existing refinery’s flare network only, as for distillate yield improvement project( DYIP), a separate flare system is envisaged without any interconnectivity with the present system.
8Adequacy checking will include the outside battery limit( OSBL) piping (main flare & sub- flare headers), flare knock out drums (KoDs), water seal drums and the flare riser and stack.
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8Design capacity of the flare system is 796 TPH, with the main flare stack being 100 m in height and 54” in diameter.
8Current HC flare’s adequacy study is based on an earlier study conducted by a reputed vendor in 1998 and subsequent revisit of the same in 2011-12 in view of the once-through hydro-cracker (OHCU) project.
8However, as the refinery has been revamped on a piecemeal basis a number of times and new units have been added to the configuration over the time, the need was felt to carry out a fresh Flare Adequacy Study in the present context.
8The study’s scope will be the existing refinery’s flare network only, as for distillate yield improvement project( DYIP), a separate flare system is envisaged without any interconnectivity with the present system.
8Adequacy checking will include the outside battery limit( OSBL) piping (main flare & sub- flare headers), flare knock out drums (KoDs), water seal drums and the flare riser and stack.
Click on details for more. Details
Maharashtra Natural Gas Limited (MNGL), JV of GAIL and BPCL, is planning to lay down underground steel pipelines in Pune.
8The company is planning to do the laying of the entire network by dividing it into sub-networks to complete the work at the earliest.
8The main pipeline to be laid down will be 10" and 4" in diameter. In addition to these, some tap-off points will also be made on proposed underground steel pipeline.
8The scope of project will include laying, hydrostatic testing, dewatering, swabbing, drying and commissioning of underground steel pipelines. The entire buried pipeline network system will be cathodically protected through a Temporary Cathodic Protection (TCP) system.
8The project time is estimated to about 6 months for mechanical completion of the pipeline system and associated works, including completion of the TCP system. Thereafter, one more month will be required for commissioning of the entire pipeline system. For the monitoring of the TCP system, an additional 6 months would be required from the date of commissioning of the TCP system.
8The company has floated nine tenders for laying of these underground steel pipeline and associated facilities that will cover all the sub-networks. The last submission date for these tenders is August 11, 2015 (15:00 Hrs). Details
8The company is planning to do the laying of the entire network by dividing it into sub-networks to complete the work at the earliest.
8The main pipeline to be laid down will be 10" and 4" in diameter. In addition to these, some tap-off points will also be made on proposed underground steel pipeline.
8The scope of project will include laying, hydrostatic testing, dewatering, swabbing, drying and commissioning of underground steel pipelines. The entire buried pipeline network system will be cathodically protected through a Temporary Cathodic Protection (TCP) system.
8The project time is estimated to about 6 months for mechanical completion of the pipeline system and associated works, including completion of the TCP system. Thereafter, one more month will be required for commissioning of the entire pipeline system. For the monitoring of the TCP system, an additional 6 months would be required from the date of commissioning of the TCP system.
8The company has floated nine tenders for laying of these underground steel pipeline and associated facilities that will cover all the sub-networks. The last submission date for these tenders is August 11, 2015 (15:00 Hrs). Details
The global LNG market is under dramatic transformation now that the US is firmly in the saddle as the principal supplier.
8New business models are rapidly coming up even as the trading patterns and the flow of gas are undergoing wholesale shifts.
8The lines are blurring between buyers, sellers, portfolio players, traders and infrastructure developers.
Different business models include being a:
8Infrastructure provider
8Portfolio player
8LNG trader
8Market developer (FRSU, `one stop shop`)
8Mid-scale supply chain provider
8Break-Bulk/LNG fuel supplier
8Enabler of consolidation and alliances, where buyers and sellers are mixed
Different strategies are also being adopted. There is of course the `traditional` model but there are new concepts such as vertical integration, horizontal integration, scale and alliances, generalization, and specialist niches.
Comment: Now that the Americans are involved, the times are exciting. The fragmentation of the supply chain allows a lot of players with different specializations to co-exist. The `traditional` model of owning either a gasification or a regasification terminal is now passé. It is time for Indian companies to find the right niches in this rapidly evolving industry. There is no doubt that India will remain very dependent on the LNG market and Indian companies of all sizes and disciplines can find their own spaces in this diversifying industry. Bulk buyers too, such as fertilizer or power companis, can begin dabbling in this market, to figure out how best to bring down the cost of gas. They can go over their monopoly supplier, GAIL, and deal straight with the seller or any of the intermediaries in the chain. There seems to be room for everyone in this market today.
Click on our Reports section for more Details
8New business models are rapidly coming up even as the trading patterns and the flow of gas are undergoing wholesale shifts.
8The lines are blurring between buyers, sellers, portfolio players, traders and infrastructure developers.
Different business models include being a:
8Infrastructure provider
8Portfolio player
8LNG trader
8Market developer (FRSU, `one stop shop`)
8Mid-scale supply chain provider
8Break-Bulk/LNG fuel supplier
8Enabler of consolidation and alliances, where buyers and sellers are mixed
Different strategies are also being adopted. There is of course the `traditional` model but there are new concepts such as vertical integration, horizontal integration, scale and alliances, generalization, and specialist niches.
Comment: Now that the Americans are involved, the times are exciting. The fragmentation of the supply chain allows a lot of players with different specializations to co-exist. The `traditional` model of owning either a gasification or a regasification terminal is now passé. It is time for Indian companies to find the right niches in this rapidly evolving industry. There is no doubt that India will remain very dependent on the LNG market and Indian companies of all sizes and disciplines can find their own spaces in this diversifying industry. Bulk buyers too, such as fertilizer or power companis, can begin dabbling in this market, to figure out how best to bring down the cost of gas. They can go over their monopoly supplier, GAIL, and deal straight with the seller or any of the intermediaries in the chain. There seems to be room for everyone in this market today.
Click on our Reports section for more Details
The Panna-Mukta-Tapti (PMT) JV -- consisting of ONGC, RIL and BGEPIL as joint operators -- has started the process for decommissioning of five well head platforms in the Tapti field keeping in mind the fact that the Tapti gas fields have experienced a steep decline in their output and the production is likely to cease within a few months.
8The offshore Tapti block (1,471 km2) contains two fields, namely South Tapti and Mid Tapti, which have five wellhead platforms which are connected to the central processing complex TPP-TCPP via subsea pipelines.
8Each platform consists of a Jacket (steel support structure ~ 25 m in height resting on sea bed and extending above water, ~ 500 tonnes in weight) and the Topsides (above water steel structure welded to the Jacket, carrying few equipment, ~ 600 tonnes in weight).
8These structures are proposed to be removed from the Tapti field and transported to onshore by the PMT JV’s offshore works contractor for further onshore demolition, scrapping and disposal.
8BG, on behalf of the PMT JV, has invited Expression of Interest (EOI) from fabrication yard contractors, scrapping yard contractors or contractors having their own jetties, located on the Indian coast, for disposing the Tapti jackets and topsides (including topsides equipments) as per regulatory requirements. The last date for submission of offers is August 5, 2015.
8The five jackets and topsides each are proposed to be removed from Tapti offshore fields and transported to onshore around post-monsoon 2018 by a separate contractor appointed by the company. Details
8The offshore Tapti block (1,471 km2) contains two fields, namely South Tapti and Mid Tapti, which have five wellhead platforms which are connected to the central processing complex TPP-TCPP via subsea pipelines.
8Each platform consists of a Jacket (steel support structure ~ 25 m in height resting on sea bed and extending above water, ~ 500 tonnes in weight) and the Topsides (above water steel structure welded to the Jacket, carrying few equipment, ~ 600 tonnes in weight).
8These structures are proposed to be removed from the Tapti field and transported to onshore by the PMT JV’s offshore works contractor for further onshore demolition, scrapping and disposal.
8BG, on behalf of the PMT JV, has invited Expression of Interest (EOI) from fabrication yard contractors, scrapping yard contractors or contractors having their own jetties, located on the Indian coast, for disposing the Tapti jackets and topsides (including topsides equipments) as per regulatory requirements. The last date for submission of offers is August 5, 2015.
8The five jackets and topsides each are proposed to be removed from Tapti offshore fields and transported to onshore around post-monsoon 2018 by a separate contractor appointed by the company. Details
8Mercator acquires two more dredgers: Mercator Limited, one of India’s largest marine and energy group, has added two more dredgers to its fleet.
--The company has taken delivery of two European built dredgers; one is a Trailer Suction Hopper Dredger which would be one of the largest capacity dredgers in India and the second is a Bucket Ladder Dredger.
--Both the dredgers would be commissioned around the first week of September this year.
--With the addition of the two dredgers, Mercator’s fleet has grown to nine dredgers, making it the second largest dredging company in India.
8GAIL Q1 result today: GAIL will announce its results for the quarter ended June 30, 2015 (Q1) on July 23, 2015. The other oil and gas companies which will declare their Q1 (April-June) 2015 results during the current month are:
--RIL: July 24, 2015
--Essar Oil: July 29, 2015
--Petronet LNG: July 30, 2015
8Sandeep Poundrik nominated as Government Director on EIL Board: The petroleum ministry, vide its letter dated July 14, 2015, has nominated Sandeep Poundrik, Joint Secretary (Refinery), Ministry of Petroleum & Natural Gas, as the Government Director on the Board of the Company. Details
--The company has taken delivery of two European built dredgers; one is a Trailer Suction Hopper Dredger which would be one of the largest capacity dredgers in India and the second is a Bucket Ladder Dredger.
--Both the dredgers would be commissioned around the first week of September this year.
--With the addition of the two dredgers, Mercator’s fleet has grown to nine dredgers, making it the second largest dredging company in India.
8GAIL Q1 result today: GAIL will announce its results for the quarter ended June 30, 2015 (Q1) on July 23, 2015. The other oil and gas companies which will declare their Q1 (April-June) 2015 results during the current month are:
--RIL: July 24, 2015
--Essar Oil: July 29, 2015
--Petronet LNG: July 30, 2015
8Sandeep Poundrik nominated as Government Director on EIL Board: The petroleum ministry, vide its letter dated July 14, 2015, has nominated Sandeep Poundrik, Joint Secretary (Refinery), Ministry of Petroleum & Natural Gas, as the Government Director on the Board of the Company. Details
While the PMT JV has decided to decommission the five well head platforms in the Tapti field, no decision has yet been taken on the TCPP and TPP platforms which are part of the Tapti field infrastructure.
8ONGC wants to take up the TCPP and TPP platforms to process its gas coming from the Daman fields, including the C-Series gas.
8Approval for taking the gas to the Tapti JV facilities for processing is however yet to be approved by the petroleum ministry.
8As production from the Tapti gas fields is likely to cease within a few months, the equipment and assets which are no longer required for petroleum operations need to be first offered free of cost to the government or its nominee.
8The facilities come free of cost to ONGC as they have already been cost recovered by the PMT JV.
8It was on DGH's request that ONGC evaluated the option of taking over the Tapti JV facilities for production and processing of gas from its C-series discoveries and agreed to take over only the TCPP and TPP platform facilities.
8Along with the two platform facilities, the E&P major will also take over two spur lines (18" and 20") connected to the South Bassein Hazira Trunk (SBHT) lines (42" and 36") for the Daman development project, subject to the understanding that the abandonment and site restoration of balance facilities (wells, unmanned platforms and infield pipelines within the field which ONGC is not taking over) will be carried out by the PMT JV and adequate funds would be transferred to ONGC that would be required to abandon the facilities which ONGC is taking over. Details
8ONGC wants to take up the TCPP and TPP platforms to process its gas coming from the Daman fields, including the C-Series gas.
8Approval for taking the gas to the Tapti JV facilities for processing is however yet to be approved by the petroleum ministry.
8As production from the Tapti gas fields is likely to cease within a few months, the equipment and assets which are no longer required for petroleum operations need to be first offered free of cost to the government or its nominee.
8The facilities come free of cost to ONGC as they have already been cost recovered by the PMT JV.
8It was on DGH's request that ONGC evaluated the option of taking over the Tapti JV facilities for production and processing of gas from its C-series discoveries and agreed to take over only the TCPP and TPP platform facilities.
8Along with the two platform facilities, the E&P major will also take over two spur lines (18" and 20") connected to the South Bassein Hazira Trunk (SBHT) lines (42" and 36") for the Daman development project, subject to the understanding that the abandonment and site restoration of balance facilities (wells, unmanned platforms and infield pipelines within the field which ONGC is not taking over) will be carried out by the PMT JV and adequate funds would be transferred to ONGC that would be required to abandon the facilities which ONGC is taking over. Details
A two-tier mechanism has been envisaged for smooth steering of the collaborative research programme that has been taken up jointly by ONGC and IITs on exploration and exploitation of hydrocarbons and alternate sources of energy.
8The two-tier mechanism comprises of a Programme Advisory Committee (PAC), the apex body which reviews the activities and approves annual budgets, and a Thematic Research Committee (TRC), the nodal body for all research related activities in respective thematic areas.
8Readers will recall that ONGC and Pan-IIT had signed a Memorandum of Collaboration (MoC) on January 19, 2015, at New Delhi to work towards a collective R&D Programme for developing indigenous technologies to enhance exploration and exploitation of hydrocarbons and alternate sources of energy.
8Under the MoC, ONGC’s R&D Institutes and the IITs are to jointly undertake advanced research and development projects for the E&P sector of the country in general and oilfield specific activities of ONGC in particular.
8Within the ambit of the collaboration, ONGC will make its laboratories available to the students and research scholars of IITs. In return, ONGC geoscientists and engineers will have the opportunity to work with the best brains in IITs.
8The IIT Director Kharagpur has been made the Coordinating Director representing the Pan-IIT Forum, while Director (Exploration), ONGC, is the Coordinating Director representing ONGC. Details
8The two-tier mechanism comprises of a Programme Advisory Committee (PAC), the apex body which reviews the activities and approves annual budgets, and a Thematic Research Committee (TRC), the nodal body for all research related activities in respective thematic areas.
8Readers will recall that ONGC and Pan-IIT had signed a Memorandum of Collaboration (MoC) on January 19, 2015, at New Delhi to work towards a collective R&D Programme for developing indigenous technologies to enhance exploration and exploitation of hydrocarbons and alternate sources of energy.
8Under the MoC, ONGC’s R&D Institutes and the IITs are to jointly undertake advanced research and development projects for the E&P sector of the country in general and oilfield specific activities of ONGC in particular.
8Within the ambit of the collaboration, ONGC will make its laboratories available to the students and research scholars of IITs. In return, ONGC geoscientists and engineers will have the opportunity to work with the best brains in IITs.
8The IIT Director Kharagpur has been made the Coordinating Director representing the Pan-IIT Forum, while Director (Exploration), ONGC, is the Coordinating Director representing ONGC. Details
The entry of the US has clearly become the game changer
8The industry has become more nimble and fragmented. The fragmentation is likely to continue until the least common denominator is reached.
8Concepts like latent supply availability are gaining ground. Supply, linked to shale gas production, will be available at given price points and not otherwise. Clearly these are exciting times indeed.
8Liquidity will clearly grow, as the market is currently quite illiquid
8Along with diversifying strategies and new business models, be prepared for a lot of action in the months and years ahead.
Click on our Reports section for more Details
8The industry has become more nimble and fragmented. The fragmentation is likely to continue until the least common denominator is reached.
8Concepts like latent supply availability are gaining ground. Supply, linked to shale gas production, will be available at given price points and not otherwise. Clearly these are exciting times indeed.
8Liquidity will clearly grow, as the market is currently quite illiquid
8Along with diversifying strategies and new business models, be prepared for a lot of action in the months and years ahead.
Click on our Reports section for more Details
The entry of the US has brought about transparency in the costing of LNG.
8With liquidity growing, a FOB Gulf of Mexico benchmark may get set
8Commercial terms are also evolving and an Indian buyer may be able to find the right funding and pricing in this new environment.
8A day will come when a terminal is not linked to an upstream project.
8The regulatory environment is also becoming clear and transparent
8Projects are being developed by specialist utility and infrastructure companies
8Cost based, Henry Hub indexed pricing models are being developed to cover tolling costs
8Destination flexibility concepts are also evolving rapidly.
Click on our Reports section for more Details
8With liquidity growing, a FOB Gulf of Mexico benchmark may get set
8Commercial terms are also evolving and an Indian buyer may be able to find the right funding and pricing in this new environment.
8A day will come when a terminal is not linked to an upstream project.
8The regulatory environment is also becoming clear and transparent
8Projects are being developed by specialist utility and infrastructure companies
8Cost based, Henry Hub indexed pricing models are being developed to cover tolling costs
8Destination flexibility concepts are also evolving rapidly.
Click on our Reports section for more Details
The US has already sold around 50 MMTPA of LNG in the market.
8Capacity holders in LNG terminals are emerging as distinct entities and this capacity is turn is getting resold
8End market mix is changing to traders, international oil companies and actual buyers.
8A whopping 360 MTPA of US non-FTA licensed volume has been proposed for development. This is a massive expansion of capacity.
8The big players are going to be Qatar, Australia and of course the US.
8Asia is of course the biggest market but cost economics is going to be an important determinant.
8The traditional trade flow of LNG has changed dramatically.
8By 2025, new supplies alone will total up to 100 MTPA and between 2014-2015, trade is going to grow at a CAGR of between 4.2 to 5.7.
Click on our Reports section for more Details
8Capacity holders in LNG terminals are emerging as distinct entities and this capacity is turn is getting resold
8End market mix is changing to traders, international oil companies and actual buyers.
8A whopping 360 MTPA of US non-FTA licensed volume has been proposed for development. This is a massive expansion of capacity.
8The big players are going to be Qatar, Australia and of course the US.
8Asia is of course the biggest market but cost economics is going to be an important determinant.
8The traditional trade flow of LNG has changed dramatically.
8By 2025, new supplies alone will total up to 100 MTPA and between 2014-2015, trade is going to grow at a CAGR of between 4.2 to 5.7.
Click on our Reports section for more Details
In the meantime, GAIL has rubbished reports of buying any US shale gas asset for $1.5 billion to meet the future Indian demand.
8The company has sent a clarification to the stock exchange denying that, at present, there is no such "concrete discussion or proposal for buying any US shale gas asset."
8The explanation had come after the Exchange sought clarification from GAIL with respect to a news article appearing in a business daily titled "GAIL plans to buy US shale gas asset for $1.5 billion to meet future Indian demand".
8GAIL has now replied stating "This is to inform that though GAIL operates in all the segments of the gas value chain (i.e. Upstream, Midstream and Downstream) and continues to scout for business opportunities, however, at present, there is no concrete discussion or proposal for buying any US Shale gas asset."
8As per the report, GAIL has plans to spend close to $1.5 billion (about Rs 9,500 crore) to acquire a shale gas asset in the United States to meet future gas demand in India and other markets along with partly offsetting the risk associated with the market-linked pricing of 6 million tonnes of LNG it has contracted to purchase annually from the US, for 20 years, beginning 2017-18.
8The report mentioned that GAIL is looking for an asset that can produce about 3 MMTPA of gas so that it can cover the pricing risk of about 50% of the LNG that it has contracted to buy.
8The ownership of a producing block will mean that any loss arising due to increased prices of contracted LNG can be offset by gains from the producing block. GAIL already holds 20% stake in Carrizo's Eagle Ford Shale acreage in the US. Details
8The company has sent a clarification to the stock exchange denying that, at present, there is no such "concrete discussion or proposal for buying any US shale gas asset."
8The explanation had come after the Exchange sought clarification from GAIL with respect to a news article appearing in a business daily titled "GAIL plans to buy US shale gas asset for $1.5 billion to meet future Indian demand".
8GAIL has now replied stating "This is to inform that though GAIL operates in all the segments of the gas value chain (i.e. Upstream, Midstream and Downstream) and continues to scout for business opportunities, however, at present, there is no concrete discussion or proposal for buying any US Shale gas asset."
8As per the report, GAIL has plans to spend close to $1.5 billion (about Rs 9,500 crore) to acquire a shale gas asset in the United States to meet future gas demand in India and other markets along with partly offsetting the risk associated with the market-linked pricing of 6 million tonnes of LNG it has contracted to purchase annually from the US, for 20 years, beginning 2017-18.
8The report mentioned that GAIL is looking for an asset that can produce about 3 MMTPA of gas so that it can cover the pricing risk of about 50% of the LNG that it has contracted to buy.
8The ownership of a producing block will mean that any loss arising due to increased prices of contracted LNG can be offset by gains from the producing block. GAIL already holds 20% stake in Carrizo's Eagle Ford Shale acreage in the US. Details
The Oil industry Safety Directorate (OISD), which has come out with a report on the fire incident at ONGC`s oil well in Surat (Gujarat) in April 2015, has said that no culpability can be established for incident.
8According to the report, the root cause of the incident in the well -- dubbed Olpad-3 -- was inadequate supervision of the work-over operation by both the operator and the charter-hired rig operational personnel. It was because of the ignorance of basic operational practices by the operational personnel manning the rig that the incident took place.
8Readers will recall that the incident occurred in April when a blow-out preventer (BOP), which is installed on wells to prevent a fire, was being repaired at the well in the Ankleshwar asset.
8The ministry has directed ONGC to ask its sub-committee of the Board on Health, Safety and Environment (HSE) to look into the organizational set up of the committee, compliance to standard operating procedures (SOPs), carrying out of regular safety audits and recommend changes.
8Accordingly, ONGC has informed the ministry that it will deliberated on the matter in the next HSE meeting. Details
8According to the report, the root cause of the incident in the well -- dubbed Olpad-3 -- was inadequate supervision of the work-over operation by both the operator and the charter-hired rig operational personnel. It was because of the ignorance of basic operational practices by the operational personnel manning the rig that the incident took place.
8Readers will recall that the incident occurred in April when a blow-out preventer (BOP), which is installed on wells to prevent a fire, was being repaired at the well in the Ankleshwar asset.
8The ministry has directed ONGC to ask its sub-committee of the Board on Health, Safety and Environment (HSE) to look into the organizational set up of the committee, compliance to standard operating procedures (SOPs), carrying out of regular safety audits and recommend changes.
8Accordingly, ONGC has informed the ministry that it will deliberated on the matter in the next HSE meeting. Details
The CGD network in Pune has been split up into the following sub-networks:
8From Kalewadi Phata to Ravet in Pune city, comprising of 10" dia covering around 6.5 km and 4" dia covering around 0.4 km.
8From Dharmavat Petrol Pump, Pisoli, to Waste Depoy Gate, Manterwadi, comprising of 10" dia covering around 5.8 km and 4" dia covering around 0.4 km and then from waste depot gate to Tekawade Petrol Pump, 10" dia covering around 6 km and 4" dia covering around 0.4 km.
8From Rajaram bridge to Shahid Patel Petrol Pump, Ambegaon, comprising of 10" dia covering around 4.5 km and 4" dia covering around 0.4 km and then again from the Shahid Patil Petrol Pump to Katraj, 10" dia covering around 4 km and 4" dia covering around 0.4 km.
8From Sangamwadi bridge to BPCL COCO near RTO and Chandannagar to DBS Balaji WagholiI, comprising of 10" dia covering around 4.6 km and 4" dia covering around 1.2 km.
8In Pimpri-Chinchwad, Chakan, Talegaon and Hinjewadi, comprising of 10" dia covering around 8 km and 4" dia covering around 3 km.
8From Pimple Gurav to BPCL Petrol Pump, Baner Road, comprising of 10" dia covering around 5.8 km and 4" dia covering around 1 km and then from BPCL Petrol Pump to Regency Classic, Baner, 10" dia covering around 5.8 km and 4" dia covering around 1 km. Details
8From Kalewadi Phata to Ravet in Pune city, comprising of 10" dia covering around 6.5 km and 4" dia covering around 0.4 km.
8From Dharmavat Petrol Pump, Pisoli, to Waste Depoy Gate, Manterwadi, comprising of 10" dia covering around 5.8 km and 4" dia covering around 0.4 km and then from waste depot gate to Tekawade Petrol Pump, 10" dia covering around 6 km and 4" dia covering around 0.4 km.
8From Rajaram bridge to Shahid Patel Petrol Pump, Ambegaon, comprising of 10" dia covering around 4.5 km and 4" dia covering around 0.4 km and then again from the Shahid Patil Petrol Pump to Katraj, 10" dia covering around 4 km and 4" dia covering around 0.4 km.
8From Sangamwadi bridge to BPCL COCO near RTO and Chandannagar to DBS Balaji WagholiI, comprising of 10" dia covering around 4.6 km and 4" dia covering around 1.2 km.
8In Pimpri-Chinchwad, Chakan, Talegaon and Hinjewadi, comprising of 10" dia covering around 8 km and 4" dia covering around 3 km.
8From Pimple Gurav to BPCL Petrol Pump, Baner Road, comprising of 10" dia covering around 5.8 km and 4" dia covering around 1 km and then from BPCL Petrol Pump to Regency Classic, Baner, 10" dia covering around 5.8 km and 4" dia covering around 1 km. Details
Why is it that while GEECL has hit a gold mine in Raniganj, ONGC is struggling with its ONGC blocks?
8ONGC operates four CBM blocks, namely Bokaro, Jharia and North Karanpura in Jharkhand and Raniganj in West Bengal but the public sector giant seems uncomfortable handing them ostensibly because CBM falls outside the realm of ONGC`s mainstream activities in conventional oil and gas exploration and exploitation.
8ONGC found it difficult to deal with land acquisition problems connected with these blocks and felt that a private partner is better able to the handle the complications.
8Then again, overlapping of ONGC blocks with other blocks and coal blocks have come in the way of developing them.
8The public sector E&P major had decided to rope in other CBM players as strategic partners with an eye on inducting new technology and optimizing costs.
8The plans, however, have not been fulfilled so far.
Here is a status update:
8North Karanpura: ONGC has assigned 25% share from its 80% participating interest (PI) to Prabha Energy Private Limited (PPEL). Though a farm-out agreement has been finalized, it is yet to signed by the two parties. IOC, which holds the remaining 20% stake, has given its consent for farming out the stake to PPEL.
8Bokaro: MMS Energy has been offered 25% stake by ONGC in the Bokaro CBM block from its 80% PI. An offer letter in this regard will be sent to it soon but signatures have not happened yet. Initially, the company was offered a 10% stake, but later this was enhanced to 25% after the plan to divest a 25% stake to Dart Energy Ltd did not work out. IOC, which holds 20% stake, has given its consent for farming out the stake to MMS.
8Jharia: ONGC had decided to withdraw its offer of farming out a 10% stake to CCLE. The letter of withdrawal has been prepared and is currently under legal examination. The E&P major has decided to assign 16% PI to Coal India Ltd (CIL) from its 90% stake. If the deal goes through, ONGC stake in the block will get reduced to 74%, while CIL`s stake will go up to 26% (as it already has 10%). The farming out of stake to CIL has not yet been okayed by the government.
8Raniganj: ONGC had decided to withdraw its offer of farming out a 25% stake to the Great Eastern Energy Corporation Ltd (GEECL). The letter of withdrawal has been prepared and is currently under legal examination. The E&P major is exploring other partnership options. ONGC is the operator in the block with a 74% stake, while CIL holds the remaining share.
Click on Reports for more. Details
8ONGC operates four CBM blocks, namely Bokaro, Jharia and North Karanpura in Jharkhand and Raniganj in West Bengal but the public sector giant seems uncomfortable handing them ostensibly because CBM falls outside the realm of ONGC`s mainstream activities in conventional oil and gas exploration and exploitation.
8ONGC found it difficult to deal with land acquisition problems connected with these blocks and felt that a private partner is better able to the handle the complications.
8Then again, overlapping of ONGC blocks with other blocks and coal blocks have come in the way of developing them.
8The public sector E&P major had decided to rope in other CBM players as strategic partners with an eye on inducting new technology and optimizing costs.
8The plans, however, have not been fulfilled so far.
Here is a status update:
8North Karanpura: ONGC has assigned 25% share from its 80% participating interest (PI) to Prabha Energy Private Limited (PPEL). Though a farm-out agreement has been finalized, it is yet to signed by the two parties. IOC, which holds the remaining 20% stake, has given its consent for farming out the stake to PPEL.
8Bokaro: MMS Energy has been offered 25% stake by ONGC in the Bokaro CBM block from its 80% PI. An offer letter in this regard will be sent to it soon but signatures have not happened yet. Initially, the company was offered a 10% stake, but later this was enhanced to 25% after the plan to divest a 25% stake to Dart Energy Ltd did not work out. IOC, which holds 20% stake, has given its consent for farming out the stake to MMS.
8Jharia: ONGC had decided to withdraw its offer of farming out a 10% stake to CCLE. The letter of withdrawal has been prepared and is currently under legal examination. The E&P major has decided to assign 16% PI to Coal India Ltd (CIL) from its 90% stake. If the deal goes through, ONGC stake in the block will get reduced to 74%, while CIL`s stake will go up to 26% (as it already has 10%). The farming out of stake to CIL has not yet been okayed by the government.
8Raniganj: ONGC had decided to withdraw its offer of farming out a 25% stake to the Great Eastern Energy Corporation Ltd (GEECL). The letter of withdrawal has been prepared and is currently under legal examination. The E&P major is exploring other partnership options. ONGC is the operator in the block with a 74% stake, while CIL holds the remaining share.
Click on Reports for more. Details
GEECL has built up attractive valuations around its Raniganj asset, something that other players in the business may also elicit.
8For most players, now that the initial teething troubles are over, the foray into CBM can turn out to be a high value game.
8GEECL has estimated undisputed future net revenues on IP reserves at $1.60 billion, while the estimate against 3P reserves are at $3.38 billion.
8The NPV at a discount rate of 10% is attractive too: at $602 million on IP reserves and $$1.09 billion on 3P reserves.
8The recovery factors are attractive too, at 55% in the lowest case scenario and 74% in the high case, with the best case pegged at 67%.
8The only problem seems to be the government of India. The company's second block is under arbitration while gas pricing may become a factor that may elicit government control-- the Competition Commission is already investigating a complaint of predatory pricing -- or when more supplies come in either of domestic natural gas that is priced lower or low priced LNG.
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8For most players, now that the initial teething troubles are over, the foray into CBM can turn out to be a high value game.
8GEECL has estimated undisputed future net revenues on IP reserves at $1.60 billion, while the estimate against 3P reserves are at $3.38 billion.
8The NPV at a discount rate of 10% is attractive too: at $602 million on IP reserves and $$1.09 billion on 3P reserves.
8The recovery factors are attractive too, at 55% in the lowest case scenario and 74% in the high case, with the best case pegged at 67%.
8The only problem seems to be the government of India. The company's second block is under arbitration while gas pricing may become a factor that may elicit government control-- the Competition Commission is already investigating a complaint of predatory pricing -- or when more supplies come in either of domestic natural gas that is priced lower or low priced LNG.
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While Raniganj is turning out to be a goldmine, the company is now eyeing exploiting the Mannargudi CBM block in Tamil Nadu.
8The company claims that a total of 0.98 TCF Gas-in-Place(GIP) is estimated to be present in their second CBM block, which was awarded in 2010 under CBM IV .
8The Company has received clearance from the MOEF but approval is awaited from the State Government of Tamil Nadu.
8The current minimum work programme consists of 30 pilot production wells and 50 core holes.
8Existing external pipeline infrastructure in place in the block.
8The block however is currently under dispute with the government of India and arbitration proceedings are on, and it will take some time before any progress can be made in it.
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8The company claims that a total of 0.98 TCF Gas-in-Place(GIP) is estimated to be present in their second CBM block, which was awarded in 2010 under CBM IV .
8The Company has received clearance from the MOEF but approval is awaited from the State Government of Tamil Nadu.
8The current minimum work programme consists of 30 pilot production wells and 50 core holes.
8Existing external pipeline infrastructure in place in the block.
8The block however is currently under dispute with the government of India and arbitration proceedings are on, and it will take some time before any progress can be made in it.
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GEEC has planned to drill 144 new wells on the Raniganj (South) block.
8Independent reserve engineers, Advance Resources International, Inc., have increased the Recovery factor to 55% from 30%, in the low estimate and the Original-Gas-In-Place (OGIP) to 2.62 TCF (from 2.44 TCF), an increase of 7.38%.
8The strategy seems to be to continue to maximize production from existing wells and to continue to pursue sales opportunities in the Asansol-Raniganj- Durgapur hinterland through a dedicated pipeline network.
8Potenitial demand in the Asansol - Durgapur region is around 18 MMSMD, which is projected to go up to 50 MMSCMD by 2017, so there is no dearth of buyers in the region and clearly the high selling price does not seem to be coming in its way.
8A total of 156 wells have been drilled in Raniganj (South) block, which, with planned dewatering and optimization measures provides a substantial base for production growth.
Click on Reports for more. Details
8Independent reserve engineers, Advance Resources International, Inc., have increased the Recovery factor to 55% from 30%, in the low estimate and the Original-Gas-In-Place (OGIP) to 2.62 TCF (from 2.44 TCF), an increase of 7.38%.
8The strategy seems to be to continue to maximize production from existing wells and to continue to pursue sales opportunities in the Asansol-Raniganj- Durgapur hinterland through a dedicated pipeline network.
8Potenitial demand in the Asansol - Durgapur region is around 18 MMSMD, which is projected to go up to 50 MMSCMD by 2017, so there is no dearth of buyers in the region and clearly the high selling price does not seem to be coming in its way.
8A total of 156 wells have been drilled in Raniganj (South) block, which, with planned dewatering and optimization measures provides a substantial base for production growth.
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Great Eastern Energy Corporation Limited( GEEC) seems to have made a success out of its CBM operations in India.
8The company sold an average of 10.23 mmscfd of gas and the average price elicited was a handsome $11.04/mmbtu.
8Clearly with this kind of pricing, CBM is an attractive play in India.
8Sales increased by 12% to 3.73 bcf this year compared with 3.33 bcf in the previous year.
8Total revenue increased by 9% to US$ 37.46m as compared to the corresponding previous financial year, while EBITDA increased by 4% to US$ 24.80m.
8Gas is being produced (Coal-Bed Methane gas) from the Raniganj (South) license area, which covers 210 sq. km.
8The Company's second asset is the Mannargudi license situated in the state of Tamil Nadu in India, which covers an area of 667 sq. km.
8The company feels that supply and demand dynamics for CBM remains attractive, and the pricing environment, remains attractive and is likely to remain so for some years to come.
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8The company sold an average of 10.23 mmscfd of gas and the average price elicited was a handsome $11.04/mmbtu.
8Clearly with this kind of pricing, CBM is an attractive play in India.
8Sales increased by 12% to 3.73 bcf this year compared with 3.33 bcf in the previous year.
8Total revenue increased by 9% to US$ 37.46m as compared to the corresponding previous financial year, while EBITDA increased by 4% to US$ 24.80m.
8Gas is being produced (Coal-Bed Methane gas) from the Raniganj (South) license area, which covers 210 sq. km.
8The Company's second asset is the Mannargudi license situated in the state of Tamil Nadu in India, which covers an area of 667 sq. km.
8The company feels that supply and demand dynamics for CBM remains attractive, and the pricing environment, remains attractive and is likely to remain so for some years to come.
Click on Reports section for more. Details
The acquisition system to be used for the 3D survey will involve delta-sigma technology with facilities for recording a minimum 3500 channels per shot record.
8The area of the block will be covered full fold (i.e. 60 fold), along with with proper attributes.
8The two-way time of the primary objective is between 2500 milliseconds to 6000 milliseconds and the apparent frequency content available on the existing seismic section is between 15 to 80 Hz.
8A total of about 200 reference points will be required to be fixed covering the block and surrounding area.
8The data will be recorded on linear tape open (LTO) tape in the SEGD/SEGY format with a sampling rate of 2 ms.
8Shallow refraction or low velocity layer (LVL) and Uphole surveys will be conducted along trace lines and the LVL survey will be done at 500m interval whereas the Up-hole surveys are about 2 km apart along the trace lines.
8The trace lines along which LVL/Upholes will be done will b eabout 1.0-1.2 km apart. The Up-hole survey will be carried out up to a depth of about 35-40 m meters.
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8The area of the block will be covered full fold (i.e. 60 fold), along with with proper attributes.
8The two-way time of the primary objective is between 2500 milliseconds to 6000 milliseconds and the apparent frequency content available on the existing seismic section is between 15 to 80 Hz.
8A total of about 200 reference points will be required to be fixed covering the block and surrounding area.
8The data will be recorded on linear tape open (LTO) tape in the SEGD/SEGY format with a sampling rate of 2 ms.
8Shallow refraction or low velocity layer (LVL) and Uphole surveys will be conducted along trace lines and the LVL survey will be done at 500m interval whereas the Up-hole surveys are about 2 km apart along the trace lines.
8The trace lines along which LVL/Upholes will be done will b eabout 1.0-1.2 km apart. The Up-hole survey will be carried out up to a depth of about 35-40 m meters.
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July 21: Oil India Limited (OIL), the operator of the NELP-IX AA-ONN-2010/2 block is planning to conduct a 3D seismic survey in the Karbi-Anglong district of Assam.
8This survey is being conducted as a part of the minimum work programme (MWP) for delineation of hydrocarbon prospects in Neogene-Paleogene formations with depths of 3500m-5000m in the thrust fold area.
8All the necessary work including acquiring, processing and submission of reports with relevant maps will be done in an 18-month period.
8A total of 396 Sq. Km of 3D seismic data will be acquired under the project.
8The block lies within the petroliferous basin of the Dhansiri Valley area of Upper Assam Basin and is geologically located between the Belt of Schuppen towards the south-east and Mikir Hills to its NW.
8There are oil fields nearer to the NE-SW trending trace of the Naga Thrust. Some of these major fields are Nahorkotiya, Digboi, Lakwa, Geleki and Borholla.
8Some of the lows that have sourced these accumulations are Nazira Low, Safrai Low and Charaideo Low. Dimapur Low is another low in the Dhansiri Valley adjacent to the Naga Thrust that can generate hydrocarbons in suitably placed reservoirs and traps.
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8This survey is being conducted as a part of the minimum work programme (MWP) for delineation of hydrocarbon prospects in Neogene-Paleogene formations with depths of 3500m-5000m in the thrust fold area.
8All the necessary work including acquiring, processing and submission of reports with relevant maps will be done in an 18-month period.
8A total of 396 Sq. Km of 3D seismic data will be acquired under the project.
8The block lies within the petroliferous basin of the Dhansiri Valley area of Upper Assam Basin and is geologically located between the Belt of Schuppen towards the south-east and Mikir Hills to its NW.
8There are oil fields nearer to the NE-SW trending trace of the Naga Thrust. Some of these major fields are Nahorkotiya, Digboi, Lakwa, Geleki and Borholla.
8Some of the lows that have sourced these accumulations are Nazira Low, Safrai Low and Charaideo Low. Dimapur Low is another low in the Dhansiri Valley adjacent to the Naga Thrust that can generate hydrocarbons in suitably placed reservoirs and traps.
Click on reports for more. Details
8Clarity and consistency around policy critical to attract international and private players.
8Greater operational autonomy to operators required for accelerated developments and participation in upcoming bid rounds.
8Technical capabilities in evaluating and developing resources key to optimal developments.
8Skill development and local manufacturing to be geared for innovation.
8Intervention by the Government for expeditious resolution of land acquisition issues would boost development of the pipelines.
8Identification and prioritizing potential areas having desired consumer mix is critical to support CGD development.
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8Greater operational autonomy to operators required for accelerated developments and participation in upcoming bid rounds.
8Technical capabilities in evaluating and developing resources key to optimal developments.
8Skill development and local manufacturing to be geared for innovation.
8Intervention by the Government for expeditious resolution of land acquisition issues would boost development of the pipelines.
8Identification and prioritizing potential areas having desired consumer mix is critical to support CGD development.
Click on Reports for more. Details
8Cairn India`s Q1 profit down by 23.6% at Rs 834 crore: Cairn India recorded a steep drop in consolidated net profit for the quarter ended June 2015. During the quarter, the profit of the company declined 23.6% to Rs 834.98 crore from Rs 1,092.9 crore in the same quarter last year.
--Revenues for the quarter declined 41.4% to Rs 2,627.1 crore, compared to Rs 4,482.85 crore for the prior year period.
--The operating margin for the quarter stood at 15.75% as against to 52.03% for the previous year period. The operating income for the quarter was Rs 413.81 crore, compared to Rs 2332.62 crore in the previous year period.
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8More Q1 results: The following companies will declare their Q1 (April-June, 2015) results as under:
--GAIL: July 23, 2015
--RIL: July 24, 2015
--Petronet LNG: July 30, 2015 Details
--Revenues for the quarter declined 41.4% to Rs 2,627.1 crore, compared to Rs 4,482.85 crore for the prior year period.
--The operating margin for the quarter stood at 15.75% as against to 52.03% for the previous year period. The operating income for the quarter was Rs 413.81 crore, compared to Rs 2332.62 crore in the previous year period.
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8More Q1 results: The following companies will declare their Q1 (April-June, 2015) results as under:
--GAIL: July 23, 2015
--RIL: July 24, 2015
--Petronet LNG: July 30, 2015 Details
The DOF has worked out financial restructuring plans for sick public sector fertilizer units as well. Plans have been drawn up for:
8Brahmaputra Valley Fertilizer Corporation Ltd
8FACT
8MFL
There will be requirement for both gas and technology for these units.
Click on Details for more Details
8Brahmaputra Valley Fertilizer Corporation Ltd
8FACT
8MFL
There will be requirement for both gas and technology for these units.
Click on Details for more Details
The Modi government has put together a gigantic revival plan for defunct fertilizer plants. All these new units will together consume more than 25 mmscmd of gas. The government has put these units on the fast track and they are all meant to come up between 2018 and 2019. For suppliers of gas, these units may become reliable customers under the gas pooling regime.
The following timelines and action plan have been set for different units:
8Talcher unit (Odisha): The pre-project activities for revival of the unit by the nominated PSUs namely, RCF, CIL, GAIL and FCIL are in progress to set-up a coal-based fertilizer plant. Selection of coal gasification technology is in process. The project is likely to be completed by end of 2018.
8Ramagundam unit (Telangana): Work by EIL, NFL and FCIL are in progress to set-up a gas-based fertilizer plant.The project is likely to be completed by September 2018.
8Sindri unit (Jharkhand): Cabinet in its meeting held on in May and approved revival of Sindri unit through the ‘bidding route’. An agreement between the successful bidder and FCIL is likely to be completed by end of May 2016.
8Gorakhpur unit (Uttar Pradesh): This unit is planned to serve as an anchor customer for the Jagdishpur (Uttar Pradesh) to Haldia (West Bengal) pipeline built by GAIL. The land for the unit will be given on a lease basis to facilitate the obtaining of loans by the investor, instead of providing the land on ‘right to use’ basis as approved earlier by the CCEA in 2011. The agreement between the successful bidder and HFCL is likely to be completed by end of June 2016.
8Korba unit (Chhattisgarh): The revival of this unit has been deferred
8Barauni unit (Bihar): The government is exploring the feasibility of fast tracking the revival of the unit of HFCL through the ‘bidding route’, which is en-route of the HBJ pipeline. Finalization of the agreement is likely to be completed by end of September 2016.
8Durgapur and Haldia units (Bengal): They were approved for investment through the bidding route but both units have ongoing land disputes with the Asansol Durgapur Development Authority and the Kolkata Port Trust respectively. As soon as the land issues are settled, their revival will be considered based on the prevailing urea requirement of urea in the country
The proposed installed capacity for each of the Talcher, Ramagundam, Gorakhpur, Sindri and the Barauni units is going to be13 lakh metric tonnes (LMT) while the plant to be installed at Brahmaputra Valley Fertilizer Corporation in Assam will have a capacity of 8.646 LMT. The cumulative production of urea in the country will increase by 73.646 LMT. Details
The following timelines and action plan have been set for different units:
8Talcher unit (Odisha): The pre-project activities for revival of the unit by the nominated PSUs namely, RCF, CIL, GAIL and FCIL are in progress to set-up a coal-based fertilizer plant. Selection of coal gasification technology is in process. The project is likely to be completed by end of 2018.
8Ramagundam unit (Telangana): Work by EIL, NFL and FCIL are in progress to set-up a gas-based fertilizer plant.The project is likely to be completed by September 2018.
8Sindri unit (Jharkhand): Cabinet in its meeting held on in May and approved revival of Sindri unit through the ‘bidding route’. An agreement between the successful bidder and FCIL is likely to be completed by end of May 2016.
8Gorakhpur unit (Uttar Pradesh): This unit is planned to serve as an anchor customer for the Jagdishpur (Uttar Pradesh) to Haldia (West Bengal) pipeline built by GAIL. The land for the unit will be given on a lease basis to facilitate the obtaining of loans by the investor, instead of providing the land on ‘right to use’ basis as approved earlier by the CCEA in 2011. The agreement between the successful bidder and HFCL is likely to be completed by end of June 2016.
8Korba unit (Chhattisgarh): The revival of this unit has been deferred
8Barauni unit (Bihar): The government is exploring the feasibility of fast tracking the revival of the unit of HFCL through the ‘bidding route’, which is en-route of the HBJ pipeline. Finalization of the agreement is likely to be completed by end of September 2016.
8Durgapur and Haldia units (Bengal): They were approved for investment through the bidding route but both units have ongoing land disputes with the Asansol Durgapur Development Authority and the Kolkata Port Trust respectively. As soon as the land issues are settled, their revival will be considered based on the prevailing urea requirement of urea in the country
The proposed installed capacity for each of the Talcher, Ramagundam, Gorakhpur, Sindri and the Barauni units is going to be13 lakh metric tonnes (LMT) while the plant to be installed at Brahmaputra Valley Fertilizer Corporation in Assam will have a capacity of 8.646 LMT. The cumulative production of urea in the country will increase by 73.646 LMT. Details
8MPT to be shutdown for maintenance during October-December 2015: A routine operational and statutory maintenance shutdown at the Mangala Processing Terminal is planned for Q3, FY16.
--Though this would have an impact on production, the opportunity will be used to create tie-ins for ongoing new facility enhancements, development projects and future growth projects.
--Last year, the company had successfully completed the de-bottlenecking project relating to the Mangala Processing Terminal after which the liquid handling capacity was ramped up to 800,000 barrels of fluid per day (blpd).
8Kribhco starts getting Raageshwari Deep Gas: Gas sales from the Raageshwari Deep Gas (RDG) field averaged 9 mmscfd in Q1, FY16 and touched a peak of 15 mmscfd towards the end of June.
--The gas was higher during the period as it was allocated to a new buyer, KRIBHCO.
--Total gas sales from the RDG field stood at 0.84 Bscf. Details
--Though this would have an impact on production, the opportunity will be used to create tie-ins for ongoing new facility enhancements, development projects and future growth projects.
--Last year, the company had successfully completed the de-bottlenecking project relating to the Mangala Processing Terminal after which the liquid handling capacity was ramped up to 800,000 barrels of fluid per day (blpd).
8Kribhco starts getting Raageshwari Deep Gas: Gas sales from the Raageshwari Deep Gas (RDG) field averaged 9 mmscfd in Q1, FY16 and touched a peak of 15 mmscfd towards the end of June.
--The gas was higher during the period as it was allocated to a new buyer, KRIBHCO.
--Total gas sales from the RDG field stood at 0.84 Bscf. Details
Crude oil production across the industry during June 2015 stood at 3.101 MMT, representing a 2.99% higher than the planned monthly target of 3.011 MMT.
8The production during the month was 0.67% less than the figure of 3.122 MMT in June last year. The cumulative production during April-June 2015 was 9.305 MMT, which was higher than the target by 2.66%. The targeted production for the cumulative period was 9.065 MMT. Comparative production during the period reveals a 0.86% shortfall over the 9.386 MMT produced in the corresponding period of the last fiscal (2013-14).
8ONGC`s total crude oil production was higher by 0.21% than its monthly target aggregating to 1.854 MMT, as against the planned 1.850 MMT. The cumulative production for the April-June period was also more than its target with the company producing 5.569 MMT of crude as against the targeted 5.552 MMT. The company's production achievements during June 2015, are higher than target and production during corresponding month of last year due to better performance in its offshore field.
8Oil India Limited (OIL) produced 0.271 MMT during the month, which is behind its planned production (0.281 MMT) by 6.03%. During April-June, the company produced 0.837 MMT, which was behind its target of 0.867 MMT. Production was affected because of less than expected increase in well head expenses from drilling operation and loss in well head potential due to rise in water cut and sand ingression problems in few wells in the greater Hapjan field
8Private/JV companies produced more than their crude production targets by 11.89% for June 2015, having produced 0.976 MMT as against the targeted 0.872 MMT. Production over the April-June period stood at 2.900 MMT as against the target of 2.646 MMT. Production was affected due to underperformance of MA wells in KG-DWN-98/3 field. Furthermore, increase in water cut in existing wells in CB-ON/3 field and production operation discontinued as wells are not commercially viable at present in CB-ONN-2002/3 in Gujarat.
(Click on Details for more information) Details
8The production during the month was 0.67% less than the figure of 3.122 MMT in June last year. The cumulative production during April-June 2015 was 9.305 MMT, which was higher than the target by 2.66%. The targeted production for the cumulative period was 9.065 MMT. Comparative production during the period reveals a 0.86% shortfall over the 9.386 MMT produced in the corresponding period of the last fiscal (2013-14).
8ONGC`s total crude oil production was higher by 0.21% than its monthly target aggregating to 1.854 MMT, as against the planned 1.850 MMT. The cumulative production for the April-June period was also more than its target with the company producing 5.569 MMT of crude as against the targeted 5.552 MMT. The company's production achievements during June 2015, are higher than target and production during corresponding month of last year due to better performance in its offshore field.
8Oil India Limited (OIL) produced 0.271 MMT during the month, which is behind its planned production (0.281 MMT) by 6.03%. During April-June, the company produced 0.837 MMT, which was behind its target of 0.867 MMT. Production was affected because of less than expected increase in well head expenses from drilling operation and loss in well head potential due to rise in water cut and sand ingression problems in few wells in the greater Hapjan field
8Private/JV companies produced more than their crude production targets by 11.89% for June 2015, having produced 0.976 MMT as against the targeted 0.872 MMT. Production over the April-June period stood at 2.900 MMT as against the target of 2.646 MMT. Production was affected due to underperformance of MA wells in KG-DWN-98/3 field. Furthermore, increase in water cut in existing wells in CB-ON/3 field and production operation discontinued as wells are not commercially viable at present in CB-ONN-2002/3 in Gujarat.
(Click on Details for more information) Details
Natural gas production across the industry during June 2015 stood at 2,723 MCM , representing a 3.22% shortfall over the planned monthly target of 2,814 MCM.
8The production during the month was 5.93% less than the figure of 2,894 MCM in June last year. The cumulative production during April-June 2015 was 8,244.56 MCM, which fell short of the the target by 1.91%. The targeted production for the cumulative period was 8,406 MCM. Comparative production during the period reveals a 4.2% shortfall over the 8,606 MCM produced in the corresponding period of the last fiscal.
8During the month, ONGC`s gas production stood at 1,803.5 MCM, which was below the monthly target of 1,888 MCM. The company registered a shortfall in its Rajasthan (69.37%), Assam (11.39%), Tripura (25.67%) , Andhra (0.71%) and Tamil Nadu (5.5%) fields while its Gujarat and Mumbai offshore fields outperformed their respective targets by 10.01% and 0.1%. The production was down on account of less offtake by consumers in Rajasthan, Assam and Tripura and closure of wells due to unplanned shut down of GAIL Gas line from Ahmedabad/Kalol to Ramol. Stoppage of gas off-take by GAIL from South Kadi to GAIL GIDC from June 18 onwards.
8OIL's gas production was behind its target by 1.96% at 225.04 MCM during the month as against the planned 230 MCM. A lower than planned production in Arunachal Pradesh and Assam fields led to a lower production level. There was less drawl by Namrup Thermal Power Station (NTPS) and North East Electrical Power Corporation (NEEPCO) due to maintenance break.
8Private/JV firms also registered a shortfall by 0.25%, with total production from these companies coming to 694.37 MCM as against 696 MCM target set for June 2015. Production was affected due to underperformance of MA wells in KG-DWN-98/3 field, wells producing on intermittent basis in CB-ON-2 fields, lining up of new wells for production in RJ-ON/6 and incidental CBM gas being produced in small quantities.
(Click on Details for more information) Details
8The production during the month was 5.93% less than the figure of 2,894 MCM in June last year. The cumulative production during April-June 2015 was 8,244.56 MCM, which fell short of the the target by 1.91%. The targeted production for the cumulative period was 8,406 MCM. Comparative production during the period reveals a 4.2% shortfall over the 8,606 MCM produced in the corresponding period of the last fiscal.
8During the month, ONGC`s gas production stood at 1,803.5 MCM, which was below the monthly target of 1,888 MCM. The company registered a shortfall in its Rajasthan (69.37%), Assam (11.39%), Tripura (25.67%) , Andhra (0.71%) and Tamil Nadu (5.5%) fields while its Gujarat and Mumbai offshore fields outperformed their respective targets by 10.01% and 0.1%. The production was down on account of less offtake by consumers in Rajasthan, Assam and Tripura and closure of wells due to unplanned shut down of GAIL Gas line from Ahmedabad/Kalol to Ramol. Stoppage of gas off-take by GAIL from South Kadi to GAIL GIDC from June 18 onwards.
8OIL's gas production was behind its target by 1.96% at 225.04 MCM during the month as against the planned 230 MCM. A lower than planned production in Arunachal Pradesh and Assam fields led to a lower production level. There was less drawl by Namrup Thermal Power Station (NTPS) and North East Electrical Power Corporation (NEEPCO) due to maintenance break.
8Private/JV firms also registered a shortfall by 0.25%, with total production from these companies coming to 694.37 MCM as against 696 MCM target set for June 2015. Production was affected due to underperformance of MA wells in KG-DWN-98/3 field, wells producing on intermittent basis in CB-ON-2 fields, lining up of new wells for production in RJ-ON/6 and incidental CBM gas being produced in small quantities.
(Click on Details for more information) Details
Indian refineries registered a crude throughput of 19.48 MMT during the month, which is 5.94% higher than the target of 18.39 MMT. Cumulatively, in April-June, these refineries processed 56.27 MMT of crude, which is 2.77% higher the target of 54.76 MMT.
8Despite the overall rise in crude throughput, IOC's Haldia , IOC's Digboi, IOC's Panipat, RIL's SEZ and Essar refineries were below there target.
8In IOC's Barauni, Gujarat and Digboi refinery, the crude throughputs were lower due to planned shutdown of the plants. In Haldia refinery throughput was restricted due to Naphtha containment and in Mathura due to Exchanger problem in the DHDT (Diesel Hydro Deep Treatment Unit) during Apr-June, 2015
8Refinery throughput in IOC's Panipat was effected due to lower MoU as there were high stocks of Naphtha (PNC interruption) and black oil.
8The website also carries a review of refinery production (in terms of crude throughput) for the month of June 2015 as well as for the April-June 2015 period. Data on the corresponding periods in the previous fiscal (2014-15) are also carried here to aid comparison.
(Click on Details for more information) Details
8Despite the overall rise in crude throughput, IOC's Haldia , IOC's Digboi, IOC's Panipat, RIL's SEZ and Essar refineries were below there target.
8In IOC's Barauni, Gujarat and Digboi refinery, the crude throughputs were lower due to planned shutdown of the plants. In Haldia refinery throughput was restricted due to Naphtha containment and in Mathura due to Exchanger problem in the DHDT (Diesel Hydro Deep Treatment Unit) during Apr-June, 2015
8Refinery throughput in IOC's Panipat was effected due to lower MoU as there were high stocks of Naphtha (PNC interruption) and black oil.
8The website also carries a review of refinery production (in terms of crude throughput) for the month of June 2015 as well as for the April-June 2015 period. Data on the corresponding periods in the previous fiscal (2014-15) are also carried here to aid comparison.
(Click on Details for more information) Details
During the month of June 2015, refinery capacity utilization exceeded the target by 10.53% which was higher than what was achieved in the corresponding month of 2014 when planned utilization exceeded planned target by only 2.54%.
8The actual crude throughput for the month stood at 19.483 MMT as against the total prorated installed capacity of 17.628 MMT.
8Cumulatively too, capacity utilization at Indian refineries during April-June 2015, exceeded planned utilization by 5.24% with actual crude throughput standing at 56.27 MMT as against the prorated installed capacity of 53.47 MMT.
8The public sector maintained a prorated installed capacity of 9.841 MMT during June, while the actual crude throughput came to 10.558 MMT, indicating a 107.29% capacity utilization. Cumulatively, capacity utilization for April-June stood at 102.7% with actual crude throughput at 30.588 MMT and prorated installed capacity at 29.85 MMT.
8The private sector on the other hand utilized 113.27% of its installed capacity with a prorated installed capacity of 6.557MMT and crude throughput at 7.426 MMT. Cumulatively, capacity utilization for April-June stood at 109.58% with the actual crude throughput at 21.797 MMT and prorated installed capacity at 19.89 MMT.
(Click on Details for more information) Details
8The actual crude throughput for the month stood at 19.483 MMT as against the total prorated installed capacity of 17.628 MMT.
8Cumulatively too, capacity utilization at Indian refineries during April-June 2015, exceeded planned utilization by 5.24% with actual crude throughput standing at 56.27 MMT as against the prorated installed capacity of 53.47 MMT.
8The public sector maintained a prorated installed capacity of 9.841 MMT during June, while the actual crude throughput came to 10.558 MMT, indicating a 107.29% capacity utilization. Cumulatively, capacity utilization for April-June stood at 102.7% with actual crude throughput at 30.588 MMT and prorated installed capacity at 29.85 MMT.
8The private sector on the other hand utilized 113.27% of its installed capacity with a prorated installed capacity of 6.557MMT and crude throughput at 7.426 MMT. Cumulatively, capacity utilization for April-June stood at 109.58% with the actual crude throughput at 21.797 MMT and prorated installed capacity at 19.89 MMT.
(Click on Details for more information) Details
GAIL Gas Limited (GGL), a wholly-owned subsidiary company of GAIL, is planning to implement CNG and City Gas Distribution (CGD) network in the Geographical Area (GA) of Bengaluru city.
8The project scope covers laying, testing and commissioning of underground polyethylene (PE) main pipelines, along with service pipelines, of size ranging from 20 mm to 125 mm.
8The pipeline network will be used to supply piped natural gas (PNG) from the company's District Regulating Station (DRS) to various consumer premises. The length of network is expected to around 690 km.
8The laying of pipeline will be done by using trench less technology methods, with or without casing pipes, and they will be joined using a Bar coded electro-fusion machine (Automatically Readable) with an in-built memory to store the joining data that can read the bar code of the fittings.
8The scope of project will include preparation of route map for the 32 mm and 20 mm dia pipelines only, as GGL has already prepared drawings of routes of the main pipeline (125/90/63 mm).
8GGL has divided the GA of Bengaluru into three smaller parts -- Part A, B and C -- for better execution of the work. The completion schedule for each part is estimated to take around 15 months.
8GGL has already floated a tender for laying of the underground PE pipeline whose last bid submission date is August 11, 2015. Details
8The project scope covers laying, testing and commissioning of underground polyethylene (PE) main pipelines, along with service pipelines, of size ranging from 20 mm to 125 mm.
8The pipeline network will be used to supply piped natural gas (PNG) from the company's District Regulating Station (DRS) to various consumer premises. The length of network is expected to around 690 km.
8The laying of pipeline will be done by using trench less technology methods, with or without casing pipes, and they will be joined using a Bar coded electro-fusion machine (Automatically Readable) with an in-built memory to store the joining data that can read the bar code of the fittings.
8The scope of project will include preparation of route map for the 32 mm and 20 mm dia pipelines only, as GGL has already prepared drawings of routes of the main pipeline (125/90/63 mm).
8GGL has divided the GA of Bengaluru into three smaller parts -- Part A, B and C -- for better execution of the work. The completion schedule for each part is estimated to take around 15 months.
8GGL has already floated a tender for laying of the underground PE pipeline whose last bid submission date is August 11, 2015. Details
The production from Barmer Hill and Satellite Fields in the Cairn's Rajasthan block RJ-ON-90/1 has come around 5,000 bopd.
8This has been possible due to adoption of innovative application of techniques in the block. Cairn is the first Indian company to deploy the latest unconventional drilling techniques that are being used in North America, which includes drilling of horizontal wells in complex geology.
8The micro seismic hydrofrac monitoring technology was also applied for the first time in India.
8The appraisal phase (Mangala & Aishwariya) in the Barmer Hill has been completed. As of Q4, FY15, nine of the 12 wells were online. In Q1, FY16 the balance three wells were brought online. Hence all 12 wells of the Appraisal Phase are now producing for long term testing.
8The Barmer Hill, including the Satellite Fields, has a large hydrocarbons in-place (HIIP) resource base of around 2 billion boe. The recovery factor is however at 10-15%.
8The Barmer Hill and Satellite Field production contributed around 5.8 kboepd on average in Q1, FY16.
8The Satellite Fields include NI, NE, Guda, Raag S-1 and Small fields Raageshwari and Saraswati.
8The company has now decided to deploy the new techniques to increase gas production from the Raageshwari Deep Gas (RDG) field too. Details
8This has been possible due to adoption of innovative application of techniques in the block. Cairn is the first Indian company to deploy the latest unconventional drilling techniques that are being used in North America, which includes drilling of horizontal wells in complex geology.
8The micro seismic hydrofrac monitoring technology was also applied for the first time in India.
8The appraisal phase (Mangala & Aishwariya) in the Barmer Hill has been completed. As of Q4, FY15, nine of the 12 wells were online. In Q1, FY16 the balance three wells were brought online. Hence all 12 wells of the Appraisal Phase are now producing for long term testing.
8The Barmer Hill, including the Satellite Fields, has a large hydrocarbons in-place (HIIP) resource base of around 2 billion boe. The recovery factor is however at 10-15%.
8The Barmer Hill and Satellite Field production contributed around 5.8 kboepd on average in Q1, FY16.
8The Satellite Fields include NI, NE, Guda, Raag S-1 and Small fields Raageshwari and Saraswati.
8The company has now decided to deploy the new techniques to increase gas production from the Raageshwari Deep Gas (RDG) field too. Details
In order to ramp up production from its Mangala field in the Barmer block, Cairn has increased the quantity of polymer solution injection in the reservoir from 25,000 barrels to 80,000 barrels per day during Q1, FY16.
8The injection ramp up plan is on track and progressive production impact will begin in the second half of the 2015-16 fiscal.
8New wells are being drilled and existing wells are being converted to EOR producers. Along with this, modifications at the Mangala Process Terminal (MPT) are being carried out to process the incremental crude post polymer breakthrough.
8Readers will recall that Cairn India had resorted to polymer injection technique in the Mangala field as part of its most ambitious Enhanced Oil Recovery (EOR) scheme ever attempted.
8The company will spent a whopping $566 million into the EOR project that involves use of polymer flooding techniques to main production levels at the Mangla field.
8As the Mangala reservoir oil is highly viscous (~20 cp), there is an adverse mobility ratio between the displacing fluid (water) and the displaced fluid (oil). In such a situation, polymer helps in controlling the mobility by increasing the viscosity of water for better sweeping of oil in the reservoir.
8The EOR project is expected to improve oil recovery to 32.1% of the Stock Tank Oil Initially In-Place (STOIIP) and yield an incremental production of 70 million barrels by the end of the PSC, that is, by May 2020. Details
8The injection ramp up plan is on track and progressive production impact will begin in the second half of the 2015-16 fiscal.
8New wells are being drilled and existing wells are being converted to EOR producers. Along with this, modifications at the Mangala Process Terminal (MPT) are being carried out to process the incremental crude post polymer breakthrough.
8Readers will recall that Cairn India had resorted to polymer injection technique in the Mangala field as part of its most ambitious Enhanced Oil Recovery (EOR) scheme ever attempted.
8The company will spent a whopping $566 million into the EOR project that involves use of polymer flooding techniques to main production levels at the Mangla field.
8As the Mangala reservoir oil is highly viscous (~20 cp), there is an adverse mobility ratio between the displacing fluid (water) and the displaced fluid (oil). In such a situation, polymer helps in controlling the mobility by increasing the viscosity of water for better sweeping of oil in the reservoir.
8The EOR project is expected to improve oil recovery to 32.1% of the Stock Tank Oil Initially In-Place (STOIIP) and yield an incremental production of 70 million barrels by the end of the PSC, that is, by May 2020. Details
The Petroleum and Natural Gas Regulatory Board (PNGRB) has invited views from any person or entity on H-Energy Pvt. Limited's (HEPL) proposal to lay, build and operate a gas pipeline from Jaigarh to Mangalore.
8H-Energy has already submitted an Expression of Interest (EOI) to the PNGRB for the pipeline to be laid from its upcoming 8.0 MMTPA onshore LNG re-gasification terminal at Jaigarh, (Ratnagiri district) in Maharashtra to Mangalore in Karnataka.
8As the Dahej-Uran-Dabhol-Panvel and the Dabhol-Bangalore pipelines, which will be connected to the Jaigarh LNG Terminal, do not cater to the natural gas requirement in and around the south-western coastal stretch of Panjim, Karwar, Murudeshwar, Udupi and Mangalore, H-Energy plans to lay a gas pipeline from Jaigarh to Mangalore.
8The coastal stretch of Panjim, Karwar, Murudeshwar, Udupi and Mangalore is presently not connected to the gas grid. The demand for natural gas in this region is expected at approximately 7.0 mmscmd by 2019.
8The 635-km-long pipeline will originate from Jaigarh LNG terminal where re-gasified LNG from the LNG terminal will be injected into the pipeline.
8A map depicting the route of the proposed gas pipeline, along with the delivery points, is also carried by the website.
Click here for more Details
8H-Energy has already submitted an Expression of Interest (EOI) to the PNGRB for the pipeline to be laid from its upcoming 8.0 MMTPA onshore LNG re-gasification terminal at Jaigarh, (Ratnagiri district) in Maharashtra to Mangalore in Karnataka.
8As the Dahej-Uran-Dabhol-Panvel and the Dabhol-Bangalore pipelines, which will be connected to the Jaigarh LNG Terminal, do not cater to the natural gas requirement in and around the south-western coastal stretch of Panjim, Karwar, Murudeshwar, Udupi and Mangalore, H-Energy plans to lay a gas pipeline from Jaigarh to Mangalore.
8The coastal stretch of Panjim, Karwar, Murudeshwar, Udupi and Mangalore is presently not connected to the gas grid. The demand for natural gas in this region is expected at approximately 7.0 mmscmd by 2019.
8The 635-km-long pipeline will originate from Jaigarh LNG terminal where re-gasified LNG from the LNG terminal will be injected into the pipeline.
8A map depicting the route of the proposed gas pipeline, along with the delivery points, is also carried by the website.
Click here for more Details
H-Energy's plan to lay a gas pipeline from its upcoming 6 MMTPA Floating Storage and Re-gasification Unit (FSRU) in the offshore Digha region of West Bengal to Dattapulia and Paradip in Odidha had come under fire from Adani, IOC and GAIL.
8As per its initial plan, H-energy had intended to supply LNG to the eastern states of West Bengal, Jharkhand and Bihar through the proposed Jagdishpur-Haldia pipeline (JHPL) of GAIL. But later with its eye on the Odisha market, it drew up a plan to lay the two pipelines from Contai to Dattapulia and Paradip.
8The Adani Group, under the aegis of the Dhamra LNG terminal Pvt Ltd (DLTPL), which is setting up an LNG re-gasification Terminal at Dhamra (Odisha) with initial capacity of 5 MMTPA, informed the PNGRB that the H-Energy's proposed pipeline has not considered the gas source from the re-gas terminal coming up at Dhamra.
8It pointed out that it has already signed MOUs with key offtakers of gas, namely IOC and GAIL, for reserving substantial re-gas capacity in the project and in such a situation it is necessary that all the existing and future gas sources and markets should be considered for deciding on the route of the pipeline to avoid duplication of work and infructuous investments.
8IOC was of the view that the H-Energy's line should be connected to the Dhamra port as well as to the already authorized Kakinada-Srikakularn natural gas pipeline of APGDCL at Srikakulam (Andhra Pradesh). Connecting the pipeline with the Kakinada-Srikakularn pipeline will facilitate the flow of domestic gas from the KG field to Odisha and West Bengal, thereby, giving a boost to development of CGD networks in the two states. It opined that the PNGRB should modify the proposed Contai-Paradip-Dattapulia pipeline route and invite bids for the development of a 920-km-long trunk pipeline (24 mmscmd capacity) from Srikakulam (Andhra Pradesh) to Durgapur (West Bengal) via Bhubaneswar and Howrah with spur lines to Rayagada, Jharsuguda, Paradip, Haldia and Dattapulia.
8GAIL, on the other hand, felt that there is no requirement for laying of the proposed trunk line from Contai to Dattapulia as its Jagdishpur-Haldia pipeline (JHPL) would be able to meet the gas demand in the demand centres more cost effectively. Details
8As per its initial plan, H-energy had intended to supply LNG to the eastern states of West Bengal, Jharkhand and Bihar through the proposed Jagdishpur-Haldia pipeline (JHPL) of GAIL. But later with its eye on the Odisha market, it drew up a plan to lay the two pipelines from Contai to Dattapulia and Paradip.
8The Adani Group, under the aegis of the Dhamra LNG terminal Pvt Ltd (DLTPL), which is setting up an LNG re-gasification Terminal at Dhamra (Odisha) with initial capacity of 5 MMTPA, informed the PNGRB that the H-Energy's proposed pipeline has not considered the gas source from the re-gas terminal coming up at Dhamra.
8It pointed out that it has already signed MOUs with key offtakers of gas, namely IOC and GAIL, for reserving substantial re-gas capacity in the project and in such a situation it is necessary that all the existing and future gas sources and markets should be considered for deciding on the route of the pipeline to avoid duplication of work and infructuous investments.
8IOC was of the view that the H-Energy's line should be connected to the Dhamra port as well as to the already authorized Kakinada-Srikakularn natural gas pipeline of APGDCL at Srikakulam (Andhra Pradesh). Connecting the pipeline with the Kakinada-Srikakularn pipeline will facilitate the flow of domestic gas from the KG field to Odisha and West Bengal, thereby, giving a boost to development of CGD networks in the two states. It opined that the PNGRB should modify the proposed Contai-Paradip-Dattapulia pipeline route and invite bids for the development of a 920-km-long trunk pipeline (24 mmscmd capacity) from Srikakulam (Andhra Pradesh) to Durgapur (West Bengal) via Bhubaneswar and Howrah with spur lines to Rayagada, Jharsuguda, Paradip, Haldia and Dattapulia.
8GAIL, on the other hand, felt that there is no requirement for laying of the proposed trunk line from Contai to Dattapulia as its Jagdishpur-Haldia pipeline (JHPL) would be able to meet the gas demand in the demand centres more cost effectively. Details
Oil & Gas will continue to be the major source of energy to meet India`s growing energy requirements and with the ever widening gap between demand and supply there is a need for concrete remedial measures, according to the paper by Deloitte. Among the findings of the report are:
8Production optimization can increase current production by ~10%.
8Enhanced Oil Recovery can increase recovery of oil by up to 10%
8Full potential of existing fields can be attained through redevelopments and identification of stranded oil pools.
8Significant untapped potential exists as three-fourths of India's sedimentary basins and that needs to be exploited
8Gas fields have not produced to their full potential: if developed properly they are capable of meeting 10% of demand by 2030.
8Discovering the full potential of Indian basins can help India bridge the supply-demand gap in energy requirements in the long term.
8Significant shale resource potential exists in India and a dedicated focus is required to commercialize these.
8Accelerating CBM production is the key to increase in gas uptake at attractive pricing.
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8Production optimization can increase current production by ~10%.
8Enhanced Oil Recovery can increase recovery of oil by up to 10%
8Full potential of existing fields can be attained through redevelopments and identification of stranded oil pools.
8Significant untapped potential exists as three-fourths of India's sedimentary basins and that needs to be exploited
8Gas fields have not produced to their full potential: if developed properly they are capable of meeting 10% of demand by 2030.
8Discovering the full potential of Indian basins can help India bridge the supply-demand gap in energy requirements in the long term.
8Significant shale resource potential exists in India and a dedicated focus is required to commercialize these.
8Accelerating CBM production is the key to increase in gas uptake at attractive pricing.
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During the April-June 2015, period, Cairn made its 38th discovery -- dubbed Raageshwari North -- in the Rajasthan block.
8The well flowed oil at an initial rate of 100 bopd from the Volcanics/Felsics reservoir and opened up a large area for undertaking further appraisal to assess its full potential.
8The discovery well Raageshwari North-1 was originally drilled in Q3, FY15, to test the potential of a separate fault block contiguous to the Raageshwari Deep Main block. However, it flowed oil during Q1 FY 16.
8There are two other appraisal wells -- dubbed Raageshwari Deep Main and Vandana-10A -- which are in various stages of fraccing and testing in the block.
8The appraisal well Raageshwari Deep Main which was also drilled in Q4, FY15, was fracced and tested during the Q1 period. A zone in the Felsic reservoir in this well produced oil at the average rate of 135 bopd with gas rate of 90 mmscfd. This is a new zone, about 300m deeper than the earlier established gas bearing reservoir in the Raageshwari Deep Main field. Two more zones are to be tested in this well in Q2, FY16.
8Another appraisal well -- Vandana-10A -- drilled for the Barmer Hill Turbidite reservoirs in Q3, FY15 was fracced and tested in the lower part of the BHT-10 reservoir and produced oil at 20 bopd, during initial flow back and activation, from a low permeability zone. The upper BHT-10 zones with better reservoir characteristics will be taken up for fraccing and testing in Q3, FY16. Details
8The well flowed oil at an initial rate of 100 bopd from the Volcanics/Felsics reservoir and opened up a large area for undertaking further appraisal to assess its full potential.
8The discovery well Raageshwari North-1 was originally drilled in Q3, FY15, to test the potential of a separate fault block contiguous to the Raageshwari Deep Main block. However, it flowed oil during Q1 FY 16.
8There are two other appraisal wells -- dubbed Raageshwari Deep Main and Vandana-10A -- which are in various stages of fraccing and testing in the block.
8The appraisal well Raageshwari Deep Main which was also drilled in Q4, FY15, was fracced and tested during the Q1 period. A zone in the Felsic reservoir in this well produced oil at the average rate of 135 bopd with gas rate of 90 mmscfd. This is a new zone, about 300m deeper than the earlier established gas bearing reservoir in the Raageshwari Deep Main field. Two more zones are to be tested in this well in Q2, FY16.
8Another appraisal well -- Vandana-10A -- drilled for the Barmer Hill Turbidite reservoirs in Q3, FY15 was fracced and tested in the lower part of the BHT-10 reservoir and produced oil at 20 bopd, during initial flow back and activation, from a low permeability zone. The upper BHT-10 zones with better reservoir characteristics will be taken up for fraccing and testing in Q3, FY16. Details
BPCl is also looking for the replacement of tubes for the Thermax boiler installed at its Budge Budge installation in West Bengal. Boiler tubes would be supplied by the BPCL.
8Various activities to be carried out during replacement are as follows:
--Hydro testing
--Tube replacement/plugging
--Erection and and supply of steel tubular scaffolding
--Boiler or boiler accessory tube removal
--Erection and welding of new turbines
--Welding of plugs
--Stress Relieving and Radiography
Click on Tender for more details Details
8Various activities to be carried out during replacement are as follows:
--Hydro testing
--Tube replacement/plugging
--Erection and and supply of steel tubular scaffolding
--Boiler or boiler accessory tube removal
--Erection and welding of new turbines
--Welding of plugs
--Stress Relieving and Radiography
Click on Tender for more details Details
Where does India stand today with respect to the Farzad block in Iran -- where an OVL lead consortium found a massive 12.5 TCF of gas -- now that US sanctions are on the way out?
Nowhere, really.
8The reason for that is simple: Iran claims that a deal for development of the block was not hammered out with OVL and therefore it is free to call for an auction of the block. In fact, the block has already been put up for auction even before the nuclear deal was hammered out much to the disappointment of India.
8The Indian consortium of OVL and IOC together had shared 40% each of the $38 million that was spent in exploration work in the block while OIL had a 20% share.
8Both Iran and India blame each other for the inability to go forward with the development of the block. There was clearly a trust deficit, for to begin with, the Iranians accused OVL of trying to change the terms and conditions attached to the block, by seeking a production sharing contract rather than a service contract that was agreed earlier.An exploration service contract was granted in December, 2002 and ONGC had submitted a Master Development Plan for a gas discovery subsequently.
8Later the Iranians did agree to work on a Production Sharing Contract but then there was a change of regime in Tehran. The earlier government had not just agreed to offer a PSC regime for the development of the Farzad B gas field, but had also committed to bring about a legislative change to usher in a PSC model. but the new government rejected the PSC format and instead insisted on a service contract format.
8There was also talk of a package deal covering development of Farzad-B gas field with the swapping of the gas produced (from Farzad-B) with other Iranian gas at Chabahar port and the laying of Iran-India gas pipeline for transportation of the swapped gas to India under a Special Package Contract (SPC) but clearly nothing came out of the deal.
Eventually the block was put up for auction on a service contract basis.
8Now that some of the world's biggest companies are queuing up for a piece of the Iranian oil and gas pie, India will not have a particular advantage in jockeying to keep the Farzad block to itself because it failed to build the goodwill at a time when Iran needed technology and funding.
8The Indian combine will have to work hard to match aggressive bids given by the others.
8And if it loses, it will have to work hard to get its investment back with interest. That should not really be a problem as the money can deducted against outstanding payments due to Iran for import of crude. Details
Nowhere, really.
8The reason for that is simple: Iran claims that a deal for development of the block was not hammered out with OVL and therefore it is free to call for an auction of the block. In fact, the block has already been put up for auction even before the nuclear deal was hammered out much to the disappointment of India.
8The Indian consortium of OVL and IOC together had shared 40% each of the $38 million that was spent in exploration work in the block while OIL had a 20% share.
8Both Iran and India blame each other for the inability to go forward with the development of the block. There was clearly a trust deficit, for to begin with, the Iranians accused OVL of trying to change the terms and conditions attached to the block, by seeking a production sharing contract rather than a service contract that was agreed earlier.An exploration service contract was granted in December, 2002 and ONGC had submitted a Master Development Plan for a gas discovery subsequently.
8Later the Iranians did agree to work on a Production Sharing Contract but then there was a change of regime in Tehran. The earlier government had not just agreed to offer a PSC regime for the development of the Farzad B gas field, but had also committed to bring about a legislative change to usher in a PSC model. but the new government rejected the PSC format and instead insisted on a service contract format.
8There was also talk of a package deal covering development of Farzad-B gas field with the swapping of the gas produced (from Farzad-B) with other Iranian gas at Chabahar port and the laying of Iran-India gas pipeline for transportation of the swapped gas to India under a Special Package Contract (SPC) but clearly nothing came out of the deal.
Eventually the block was put up for auction on a service contract basis.
8Now that some of the world's biggest companies are queuing up for a piece of the Iranian oil and gas pie, India will not have a particular advantage in jockeying to keep the Farzad block to itself because it failed to build the goodwill at a time when Iran needed technology and funding.
8The Indian combine will have to work hard to match aggressive bids given by the others.
8And if it loses, it will have to work hard to get its investment back with interest. That should not really be a problem as the money can deducted against outstanding payments due to Iran for import of crude. Details
The website carries here, a presentation on the Middle-East to India Deepwater Pipeline (MEIDP) by SAGE. The presentation includes details relating to the following:
8MOUs and agreements signed by SAGE, so far, to develop the MEIDP project
8Various gas routes from Middle East to India
8Pipeline route profile, in terms of distance and depth, at various locations
8Other route options and survey blocks
8India's demand-supply balance (from 2015-16 to 2019-30)
8Details of various pipelay vessels
8Emergency pipeline repair systems
8List of current and planned long distance pipelines
8Transnational gas pipeline regions
8Recent and planned deepwater projects
8Project development schedule
8Project cost and pipeline metrics
8Other similar projects in the region
8Funding options
Click here to access the presentation Details
8MOUs and agreements signed by SAGE, so far, to develop the MEIDP project
8Various gas routes from Middle East to India
8Pipeline route profile, in terms of distance and depth, at various locations
8Other route options and survey blocks
8India's demand-supply balance (from 2015-16 to 2019-30)
8Details of various pipelay vessels
8Emergency pipeline repair systems
8List of current and planned long distance pipelines
8Transnational gas pipeline regions
8Recent and planned deepwater projects
8Project development schedule
8Project cost and pipeline metrics
8Other similar projects in the region
8Funding options
Click here to access the presentation Details
The HOEC led consortium has chalked out the following activities in the block:
8Existing three wells (Dirok 1, Dirok 2 and Dirok 4) will be put on production
8Three new development wells (Dirok 5, 6, 7) will be drilled and completed as producer wells
8Setting up of the Gas Gathering Station (GGS) within the premises of existing Dirok 4 well site.
8Setting up of the Gas Processing Plant (GPP) at Golai.
8Laying of a pipeline from Dirok GGS to Golai GPP to evacuate gas from Dirok field.
8Building another line from from Golai GPP to existing OIL operated GGS at Kusijan.
8Laying of a pipeline from Golai GPP to existing IOCL refinery at Digboi for oil condensate.
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8Existing three wells (Dirok 1, Dirok 2 and Dirok 4) will be put on production
8Three new development wells (Dirok 5, 6, 7) will be drilled and completed as producer wells
8Setting up of the Gas Gathering Station (GGS) within the premises of existing Dirok 4 well site.
8Setting up of the Gas Processing Plant (GPP) at Golai.
8Laying of a pipeline from Dirok GGS to Golai GPP to evacuate gas from Dirok field.
8Building another line from from Golai GPP to existing OIL operated GGS at Kusijan.
8Laying of a pipeline from Golai GPP to existing IOCL refinery at Digboi for oil condensate.
Click on Reports for more. Details
The proposed alternative Right of Way routes are as follows:
ROW-1
8This route will pass from Golai to Digboi along the ROW of NH 38, then along the ROW of Digboi – Duliajan road and will enter the Kusijan GGS through the ROW of approach road of Kusijan GGS from the Digboi – Duliajan road.
8Total length of this pipeline will be close to 10 km. About 1.8 km of the pipeline will pass through forest land, before entering the Kusijan GGS.
8Densely populated settlements of Digboi comes within this ROW.
ROW-2
8Another 5km pipeline ROW route was considered from Golai GPP to Kusijan GGS. About 500m of this pipeline passes though agricultural land and then it enters forest land.
8About 4.5 km of this pipeline will pass through the Digboi R.F. and Upper Dehing (West Block) R.F. before entering the Kusijan GGS. No settlements are located along this ROW.
8As the pipeline will be carrying pressurized gas, peeping under consideration the safety of people living in the bustling Digboi town and the settlements along Digboi – Duliajan road and to keep the pipeline away from the national highway, ROW-2 was selected over ROW-1.
8Moreover selecting ROW-2 will reduce the length of the Golai GPP to Kusijan GGS pipeline by 5 km. That will reduce the overall footprint of the project on the landscape.
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ROW-1
8This route will pass from Golai to Digboi along the ROW of NH 38, then along the ROW of Digboi – Duliajan road and will enter the Kusijan GGS through the ROW of approach road of Kusijan GGS from the Digboi – Duliajan road.
8Total length of this pipeline will be close to 10 km. About 1.8 km of the pipeline will pass through forest land, before entering the Kusijan GGS.
8Densely populated settlements of Digboi comes within this ROW.
ROW-2
8Another 5km pipeline ROW route was considered from Golai GPP to Kusijan GGS. About 500m of this pipeline passes though agricultural land and then it enters forest land.
8About 4.5 km of this pipeline will pass through the Digboi R.F. and Upper Dehing (West Block) R.F. before entering the Kusijan GGS. No settlements are located along this ROW.
8As the pipeline will be carrying pressurized gas, peeping under consideration the safety of people living in the bustling Digboi town and the settlements along Digboi – Duliajan road and to keep the pipeline away from the national highway, ROW-2 was selected over ROW-1.
8Moreover selecting ROW-2 will reduce the length of the Golai GPP to Kusijan GGS pipeline by 5 km. That will reduce the overall footprint of the project on the landscape.
Click on Reports for more. Details
Hindustan Oil Exploration Company Limited (HOEC), the operator of the block AP-ON-94/1 has proposed Right of Way (ROW) alternatives for the gas pipeline from the proposed HOEC gas processing plant (GPP) to the existing gas gathering station (GGS) as the pipeline traverses through designated forest land.
While HOIEC is the operator for the pre-NELP block, Oil India Ltd (OIL) is the licensee.
8The OIL operated Kusijan (GGS) will be the buyers` off-take point for the gas which will otherwise be processed at HOEC`s GPP at Golai near Digboi.
8As Kusijan GGS is located within the Upper Dehing (west block) reserve forest, so laying the pipeline through the forest land is absolutely unavoidable.
8For this purpose two right of way (ROW) routes were analysed for laying the underground pipeline from Golai GPP to Kusijan GGS.
8The Joint Venture (JV) Consortium of the Block comprises of Hindustan Oil Exploration Company Limited (HOEC), Oil India Limited (OIL) and Indian Oil Corporation Ltd (IOCL).
8The petroleum ministry has approved the block as "commercial" after the Dirok Discovery in it and subsequent drilling of appraisal wells in the block, which produced hydrocarbon from multiple sands from Girujan formation.
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While HOIEC is the operator for the pre-NELP block, Oil India Ltd (OIL) is the licensee.
8The OIL operated Kusijan (GGS) will be the buyers` off-take point for the gas which will otherwise be processed at HOEC`s GPP at Golai near Digboi.
8As Kusijan GGS is located within the Upper Dehing (west block) reserve forest, so laying the pipeline through the forest land is absolutely unavoidable.
8For this purpose two right of way (ROW) routes were analysed for laying the underground pipeline from Golai GPP to Kusijan GGS.
8The Joint Venture (JV) Consortium of the Block comprises of Hindustan Oil Exploration Company Limited (HOEC), Oil India Limited (OIL) and Indian Oil Corporation Ltd (IOCL).
8The petroleum ministry has approved the block as "commercial" after the Dirok Discovery in it and subsequent drilling of appraisal wells in the block, which produced hydrocarbon from multiple sands from Girujan formation.
Click on Reports for more. Details
