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Jun 2015

The index of eight core industries, having a combined weight of 37.9% in the Index of Industrial Production (IIP) stood at 178.6 in May 2015, which is 4.4% higher compared to the index of May 2014.
 8Crude Oil
 --Crude oil production (weight of 5.22% in the IIP) increased by 0.8 % in May 2015 over May 2014.
 --The cumulative index of crude oil during April-May, 2015, declined by 1.0 % over the corresponding period of previous year.
 8Natural Gas
 --Natural gas production (weight of 1.71% in the IIP) in May 2015, declined by 3.1% over May 2014. 
 --Cumulative growth of natural gas production during April-May 2015 also declined by 3.3% over the corresponding period of the previous year.
 8Petroleum Refinery Products
 --Petroleum refinery production (weight of 5.94% in the IIP) increased by 7.9 % in May 2015, over May 2014. 
 --In cumulative terms, the growth of petroleum refinery production during April to May 2015, increased by 2.6% over the corresponding period of previous year.
 (Click on Details for more information) Details
ONGC has identified a total of six exploratory locations in its Assam onshore block AA-ONN-2009/3, but plans to drill only three to fulfill its Minimum Work Programme (MWP).
8The E&P major will select the best suitable three locations after carrying out amplified geochemical imaging.
8Accordingly, only three locations have been considered in the company's Environmental Impact Assessment (EIA) which it had submitted to the MOEF for environmental clearance (EC).
8The six locations that have been identified are: Teok-A, Teok-B, Teok-C, Teok-D, Teok-F and Teok-G.
8The block is located in the Teok area of Jorhat, Assam, and is close to the Amguri field, which is not with ONGC presently.
8The exploratory drilling well locations have been identified based on the 2-D and 3-D seismic data acquired in the area.
8The wells will be drilled to a target depth of about 3700-5000 meters by using water-based drilling mud only.
8The NELP-VIII block AA-ONN-2009/3, covers area of 84 sq. kms, was awarded to ONGC and OIL (50% PI) along with the operation ship to ONGC.
8The cost of the proposed exploratory and development drilling planned to be carried out is estimated at around Rs 30-35 crore per well. Details
Here the website carries detailed plan for disaster management at Kharsang Oil Field which is available for existing facilities and extended to proposed activities.
8List of topics covered under this plan are as follows:
--Introduction
--Statutory Requirement
--Causes of the Emergency
--Emergency Classification
--Methodology of DMP Preparation
--Emergency Response Group
--On-site Disaster Managment Plan
--Emergency Procedure
--Offsite Emergency Plan

Click here our Reports section for more details

Details
All 45 wells (40 development and 5 exploratory/appraisal) shall be taken up for drilling under different drilling campaigns in a phase-wise manner.
8Out of 45, sites of 27 drilling wells are located for which Forest Clearance has already been applied .
8The remaining 18 wells shall also be drilled from the identified locations, depending upon the production testing results of the 27 wells and additional studies planned to be carried out in the future to target deeper prospects.
8Changes in exact drilling locations and programme are always likely based on the findings of additional reservoir studies, development drilling.
8The estimated drilling period of each well is about 35-75 days depending upon the drill depth.
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GeoEnpro, plans to go ahead with a 720 crore project of  Development and  Exploratory Drilling project in Kharsang Oil Field at Arunachal Pradesh.
8At present, total well count at Kharsang Oil Field is 70 wells, the crude oil production is around 1000 BOPD and gas production is around 50,000 m3/day.
8It plans to increase its production of crude oil by approximately 4 times to 4000 BOPD
8The Kharsang Oil Field (KOF) comprises of Oil India Limited (OIL) (40%), Geopetrol International Inc (25%), Jubilant Energy India Pvt. Ltd. (25%) and GeoEnpro Petroleum Ltd. (12.5).
8It has proposed to Development Drilling of Forty (40) wells and Exploratory Drilling of five(05) wells.
Click here our Reports section for more details. Details
At present, KOF is equipped with 4 gas fired gensets (1x 500 KVA, 1 x 450 KVA and 2 x 180 KVA) and one diesel fired genset (1 x 170 KVA).
8The power requirements during the site preparation and construction phase will be met by DG Sets.
8For Proposed drilling of development wells, power source of two 500 HP Diesel Engines to be used, each Engine running for 12 hrs per day. For auxiliary power, two 320-500 KVA gensets would be required. Diesel requirement would be around 4-6 KLPD.
8For Proposed drilling exploratory wells, four 1900 HP engine (3 Operating + 1 Standby) will be the power source. For auxiliary power there would be four 1750 KVA gensets. Around 10-12 KLPD of HSD will be fuel requirement.
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Details
The crude oil being produced from the wells flows through a 4” pipe line to the existing Oil Collecting Station (OCS) where it is treated to separate oil, water and gas but for wells of low pressure, fluid is diverted to group tanks (GT) through 2” nom bore pipe lines and then to OCS.
8For the proposed drilling activity at Kharsang Oil Field in a phased manner, additional pipeline to connect the producing wells to OCS shall be laid.
8Processed crude oil is finally stored in the Custody Transfer Tank Farm before dispatch to the refinery.
8There are 8 nos. of fixed roof tanks each having storage capacity of 795 Kls.
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Details of the drilling operations are as follows:
8Well(s) will be drilled using a mobile drilling rig of capacity of around 1000 HP for development drilling and 1500 – 2000 HP for exploratory drilling, equipped with rotary drive system.
8Production testing for developmental wells is 3-5 days whereas for exploratory wells it is 30 days.
8Proposed drilling fluid for both wells is same, Water-based Mud System.
8Anticipated Volume of Drill Cutting for each Well is 100- 200m3.
8Water Requirement for each well is 50 KLD.
8Well Depth for developmental wells is 600-1600 m, and for exploratory wells is 3000-4500 m.

8The estimated drilling period of each well is about 35-75 days depending upon the drill depth.

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Details
Hydrocarbon Operations are generally hazardous in nature by virtue of intrinsic chemical properties of hydrocarbons or their temperature or pressure of operation or a combination of them.
8Here is a list of  topics under the risk assessment report:
--Identification of Hazards in Drilling and Production Testing Operations
--Development & Exploratory Drilling in Kharsang Oil Field
--QRA Approach
--Mitigation Measures
--Occupational Health
--Frequency of Occurrence of Accident Scenario
Click here our Reports section for more details Details
The website carries here, for reference purposes, a snapshot of India's oil and gas data (updated upto May 2015) prepared by the PPAC. The following details are carried in the document which can serve as a ready reckoner:
8Selected indicators of the Indian economy
8Import dependency
8Estimated balance of trade 
8Indigenous crude oil production
8Domestic oil and gas production vis-a-vis overseas production
8CBM development in India
8Company-wise and refinery-wise installed capacity and crude oil processing
8High sulphur (HS) and low sulphur (LS) crude oil processing 
8Gross Refining Margins (GRM) across companies and refineries
8GRM of North-East refineries, excluding excise duty benefit
8Gas production, consumption and import data
8Production and consumption of petroleum products
8Self sufficiency in petroleum products
8Industry marketing infrastructure in terms of number of terminals, depots aviation fuel stations, retail outlets, SKO/LDO dealerships and LPG bottling plants owned by oil companies.
8Company-wise pipeline (gas, crude and other products) infrastructure
8Information on prices, taxes and under recoveries
8Details of conversion factors and volume conversion. Details
With a view to tide over the challenges being faced in the E&P arena, the government has decided to come out with a vision document -- dubbed Hydrocarbon Vision Document for 2050 -- for E&P activities in the offshore areas.
8This announcement was made by the petroleum minister, Dharmendra Pradhan, recently, where he said that the Prime Minister Narendra Modi's vision of reducing import dependence of crude by 10% by 2022 is a daunting ask, but the government is taking various initiatives to achieve this.
8In April 2015, Pradhan had informed the Lok Sabha that a hydrocarbon vision document on the natural resources available in the north-eastern region would be released soon by the government,
8The existing India Hydrocarbon Vision 2025, which is a comprehensive one, was released in 2000.
8The government feels that as the hydrocarbons sector plays a vital role in the economic growth of the country, it is necessary to have a Iong-term policy for the sector, that would facilitate meeting the future needs of the country.
8The Hydrocarbons Vision 2025, lays down the framework which guides the policies relating to the hydrocarbons sector for the 2000-2025 period. Issues such as energy security, use of alternative fuels, interchangeability of technology (to ensure right mix of energy sources) and ensuring availability of economically priced clean and green fuels were covered in the Hydrocarbons Vision 2025.
Click here to access a copy of Hydrocarbons Vision 2025 Details
ONGC has awarded a contract for hiring of Gas Dehydration Systems for five of its production installations to Deep Industries Limited.
8All the five production installations, for which the systems have been hired, are in the ONGC's Rajahmundry asset
8The contract has been signed for a period of three years.
8The financial implication of the contract is Rs 278.19 crore. Details
Crude prices are likely to go up marginally in 2016, as compared to 2015 prices, according to a study carried out by the American Petroleum Institute.
8While the price of WTI crude is expected to increase from $53.35/barrel in 2015 (projected) to $62.04/barrel (projected), the Brent crude is likely to rise from $60.53/barrel to $67.04/barrel in the same period.
8However, these prices are substantially lower then the 2014 and 2013 levels, when the WTI crude was $97.98/barrel and $93.17/barrel, respectively. The Brent crude was $98.89/barrel in 2014 and $108.56/barrel in 2013.
8The prices are expected to go up marginally as the world’s demand for oil is likely to go up from 93.3 million barrels per day in 2015 to 94.6 million in 2016.
8This is despite the fact that the OPEC surplus production capacity is expected to average about 1.8 million barrels per day in 2015 and then increase to 2.1 million barrels per day in 2016.
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 8CDU of RIL's Jamnagar SEZ Refinery to be shut down for routine maintenance: The SEZ unit of RIL's Jamnagar refinery is planning to shut down one crude distillation unit for routine maintenance and inspection (M&I) activities in the first half of July for about 10 days. y
 --The maintenance would also be utilized for carrying out necessary modifications to improve the reliability and performance of the unit.
 --The other three crude distillation units, including major secondary processing units, will operate at their normal throughput.
 --RIL has informed that the planned maintenance turnaround will not have any impact on its commercial commitments.
 8Jindal rig drills 34 wells in MHN field: The rig Virtue-1, which ONGC had hired from Jindal Pipes Ltd (JPL), has drilled a total of 34 wells in the Mumbai High North (MHN) field.
 --Of the total 34 wells, 31 are development wells, two are sidetrack wells and one is a work-over (maintenance of well) well.
 --The rig Virtue-1 is attached to the ONGC's WO-16 platform.
 --The rig has been hired by ONGC for a firm period of five years upto January 2019. Details
Canada's Niko Resources, which has a 10% stake in the KG-D6 block, feels that its efforts to sell its interest in the block in India are unlikely to be successful in the short term.
 8In its Annual Information Form for 2014-15 fiscal filed with Canadian regulatory authorities, Niko, has said that more time is required to pursue a strategic plan to enhance the value from the sale.
 8Readers will recall that Niko had in February announced plans to sell its 10% stake in the KG-D6 block to pay off $340 million debt. It had planned to sell off the interest by April 30 but later extended it till May 31. Later, it reached reached an understanding with lenders to extend the search till September 15.
 8Niko had blamed lower-than-expected gas price for its decision to sell its stake in the KG-D6 block where a total of 19 oil and gas discoveries had been made and only three of them are in production. The government had in October announced raising natural gas price to $5.61 per million British thermal unit from $4.2. The increase was lower than $8.4 that the industry was expecting and prevailing $5.71 rate applicable to gas from western offshore fields.
 8Niko believes it has sufficient liquidity for the foreseeable future to fund the cash requirements of its operating subsidiaries in India, along with its corporate general and administrative expenses, but requires concessions from its stakeholders to reduce the cash outflows to these stakeholders until the value of the asset can be enhanced.
 8RIL is the operator of the block with 60% interest while 30% is with BP plc of UK. Details
The field development plans (FDPs) for the R-Series and other satellite gas fields in the KG-D6 block might be deferred if the gas price outlook remains uncertain.
 8A total of 19 oil and gas discoveries in the block have been made but, so far, only three -- Dhirubhai-1 and 3 gas and MA oil and gas fields -- have been brought to production.
 FDPs for five other finds, including the significant R-Series, have been approved by the government but the development of these discoveries is dependent on the future economic viability of the required investments, feels Niko.
 8The FDP for the R-Cluster gas discovery was approved by the Government in August 2013. Since then, the partners have completed the concept and front-end engineering design (FEED) for facilities and procurement activities for subsea long leads as well as installation contract for facilities and rig commenced.
 8The FDP for nine satellite discoveries was submitted for approval in July 2008. At the request of the Government, an optimised field development plan (OFDP) for the discoveries was submitted, covering the development of four of the discoveries in the first phase of development and the potential development of the remaining five discoveries in a future phase.
 8The OFDP was approved in January 2012.
 8But Niko feels that bringing the finds to production is "dependent on the future long-term price outlook for gas sales from these projects and the significant uncertainty in this outlook could mean that the development of these reserves could be deferred. Additionally, this might also result in reductions in the company's reported reserves or future net revenues, it said. Details
Niko has informed that RIL, the operator of the KG-D6 block, is working on a program to re-activate certain shut-in wells in the Dhirubhai 1 and 3 (D1-D3) fields.
 8The programme began in the first quarter of fiscal 2016.
 8The total sales volumes from the D6 block in FY 2015 stood at 47 mmcfe/day, which was lower from the sales in FY 2014.
 8The lower sales were primarily due to the impact of natural production declines in the fields in the block, partially offset by incremental production from the MA-8 development well brought on-stream in January 2014, the MA-6H sidetrack well brought on-stream in April 2014, and the MA-5H sidetrack well brought on-stream in March 2015.
 8Three compressors, which are part of the Onshore Terminal Booster Compressor project, were successfully commissioned in the fourth quarter of FY 2015, thereby providing operational flexibility to address the decline in the reservoir pressure.
 8The appraisal of the MJ discovery announced in FY 2014 continued during FY 2015 with the drilling of the second and third appraisal wells and the completion of Phase-I engineering study carried out for potential development of the field. Details
It is proposed that 6 exploration and appraisal wells are drilled within the Ravva Field to assess the presence of hydrocarbons in the identified prospects and further assess the production potential through testing.
8Clearly, more upside is expected from the Ravva field
8Unlike infill drilling, the exploration and appraisal wells will be drilled with independent leg Jack-up rigs. The targeted prospects are anticipated to have high geological pressures and temperatures and thus special precautions will be taken in selection of an appropriate rig, drilling mud characteristics and blow out preventers.
8In order to ascertain the presence of hydrocarbons in these structures and assess the production potential and commercial viability, it is proposed to drill six exploration / appraisal wells.
8All the exploratory wells will have more target depth than the development wells of the range 3000-4500 meters.
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Oil and gas from the existing 48 offshore wells are routed through subsea interconnecting pipelines to the onshore Ravva Terminal Drilling and from there through export pipelines to the SPM to the nearby refinery.
820 development wells are to be drilled : 6 from new RI platform and 14 from existing platforms (4 nos. from RF, 3 nos. from RC, 3 nos. RG and 4 nos. from RE platforms) to to tap the identified resource pools by using fracturing technology.
8The fluids from the proposed wells will be routed to the onshore terminal through subsea infield pipelines that intersperse interconnecting platforms.
8The platforms (RA, RB, RC, RD, RE, RF, RG and RH) are connected through pipelines (of total running length of 192 km) from and to with Onshore Ravva Terminal (RT).
8The development plan envisages laying 3 new interconnecting pipelines (of total 14 km length) in the offshore region from RI platform to existing RB and RG platforms.
8The subsea pipelines will be laid using tow-in, S-lay, J-lay and tow-in methods.
8Maximum depth of 3200-3500 meters will be achieved by the development well at RF paltform.
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The RI platform will be un-manned offshore platform which will consist of multiple decks with minimum facilities.
8Vital controls such as choke adjustment and shutting of wells will be carried out from the control room located at Ravva Onshore Terminal.
8With the support of a barge and necessary marine support vessels, these structures will be installed at the offshore location.
The activities that will be carried out at the location include:
--Piling for erection of jacket legs;
--Installation of modular units and other components;
--Installation of helideck;
--Fabrication and erection of process piping and equipment.
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Cairn India Ltd, the operator of the Ravva Field in the PKGM-1 Block has received permission to go ahead with a $600 million exploration-cum-development plan recently
8The current onshore processing facility has an approved capacity of 50,000 BOPD crude oil and 2.32 MMSMD of natural gas but has been able to produce just 22,000 BOPD of crude oil and 1.44 MMSCMD of natural gas.
8The investment is meant to reach to approved design capacity.
8The investment will tap the contingent hydrocarbon resources available in Ravva Field.
8The Ravva JV has participating interests by ONGC(40%), Videocon Industries Limited (25%), Cairn Energy India Pty Ltd (22.5%) and Ravva Oil Pte Ltd (12.5).
The plan involves:
--Installation of one new RI Platform;
--Drilling of 20 developmental wells;
--Drilling of 6 nos. of exploratory/appraisal wells
--Laying of 3 new interconnecting pipelines
Click on our Reports section for more Details
The website carries here details of materials along with their capacities which will be required for development of the new platform and for laying of pipelines.
Classification of items are done as follows:
8Procurement & Fabrication of Platform
--Offshore Jackets
--Piles
--Corrosion protection
--Platform Deck
--Deck components
--Modifications
8Procurement & Fabrication of Pipelines and Risers
--Pipelines
--Risers
--Corrosion protection
8Construction
--Piling
--Jacket Installation
--Deck Installation
--Pipelines
8Production
--Drilling & Well completion
Cilck on details for more. Details
Ravva Field Oil Spill Contingency Plan (OSCP) is intended to cover the response of the authorities to an oil spill incident in the east coast of Andhra Pradesh.
Topics included in the detailed plan are as follows:
8Introduction
--Purpose and scope of OSCP
--oil Spill response Guidelines
--Inspection, Maintenance and Testing of Oil Spill Equipment
8Emergency Response Management
--Emergency Classification
--Notification and Activation of EMT
--Callout
8Oil Spill Response Management
--Oil Spill Tier Classification
--Risk Assessment
--Oil Spill Risk
--Oil Spill Response Actions and Strategies
Click here for more details. Details
Although international regulations stipulate that all merchant and fishing vessels are to keep a minimum distance of 500 metres from an offshore oil and gas installation, sea-farers are known to use offshore platforms as navigational aids. Accidents cannot be ruled out.
The report here includes details on following:
--Personnel involved
--Types of Vessel
--Types of Collisions
--Shipping Data
--Consequence Analysis
--Ship Collision Event Tree
Click on our Reports section for more Details
The hub of the Ravva field is the onshore terminal, located at approximately 1 km from the shore, that takes in well fluid (containing oil, water and gas) from the offshore platforms  through three pipelines which join a common header leading to three crude stabilization trains, each containing a Free Water Knock Out Drum, a HP Separator, an MP Separator and an LP Separator and Flow Splitter.
8The separated oil and gas are further treated for phase separation while separated water, called produced water, is treated in Produced Water Re-injection System (PWRI).
8The stabilized crude oil is sent for storage in one of the three floating roof storage tanks -- T401, T402 and T403 -- each of 45,243 m3 capacity and another tank, T405, of 45,932 m3 capacity.
8The crude from the storage tanks is pumped through two parallel 20 inches subsea pipelines to a Single Point Mooring (SPM) for transportation through offshore tankers to a nearby refinery, whereas natural gas is treated and compressed in associated gas compressors and Third Stage Gas Recovery (TSGR) compressors.
8Water from the separator unit, amounting to 90,000 barrels per day, is co-mingled with approximately 9,170 m3/day of saline groundwater, which is then filtered to remove oil from water and then taken to Crude Oil Wash Tank and ETP respectively.
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Drilling:
8Cairn is proposing use of Water Based Mud (WBM) for upper depths (400 m to 800 m) of drilling while for deeper sections Synthetic Based Mud (SBM) will be used.
8The target depth of the development wells will be from 1600 m to 3500 m while for exploration/appraisal wells it will be 2000 m to 4500 m.
8Drilling will be done in sections with diameters of 30” - 29½” - 22” - 17½” - 17½” – 13 3/8" - 12¼" - 9 5/8". If required, drilling may continue to greater depths by drilling a 8½"hole and running and cementing 7" casings.
8Power requirement for drilling will be met through three of the four on-board diesel generator sets (each of 2,000 KVA i.e. approximately 1600 kW), with one standby diesel generator (500KVA) for emergency purpose.
8On an average a development well will be drilled in 45 days while an exploratory well will be completed in 55 days. Cumulative drilling of wells in a year will be around 8 to 9.
Subsea pipelines:
88” sub sea oil pipeline of 4 km length from new RI Platform to the existing RB Platform for oil production.
84” subsea gas lift pipeline of 4 km length from new RI Platform to the existing RB Platform.
88” subsea gas pipeline of 6 km length from RI Platform to existing offshore RG Platform.
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Following is the list of the utilities present at existing Onshore Ravva Field:
Effluent Treatment Plant (ETP) with a capacity of 3000m3 per day.
8High Pressure (HP) and Low Pressure (LP) Flares to relieve any pressure of vessel and piping works during abnormal conditions.
8Cairn has deputed one supply vessel exclusively for surveillance of existing offshore installations.
Ravva has a gas turbine captive power plant with a capacity of 10 MW ( 4 X 2.5 MW) with an emergency power diesel generator of 1,000 KVA.
8An explosives magazine is also maintained as per licence from the Petroleum and Explosives Safety Organization.
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ONGC has invited quotations for Rate Contracts (RC) for carrying out survey for laying of flow lines of different sizes in various fields in the East-West Godawari and Krishna districts of Andhra Pradesh.
 8The rate contract will be signed for a period of three years (2015-18).
 8The scope of work for the contractor includes carrying out surveys for identification of the route, which would also include reconnaissance and cadastral surveys for the flow pipelines in the state.
 8The scope also covers the minimum requirements of the topographical survey, along the pipelines route, including locating the contour line of the pipeline alignment on the ground, constructing survey monuments and measuring the field for profiles and preparation of drawings and documents.
 8Soil investigation will also be done to find out the soil receptivity, PH value, bacteria content and chemical analysis along the pipeline route.
 8The contractor will have to identify three alternate feasible routes so that most economical route can be selected.
 8The tender documents can be purchased before July 14, 2015 (13:59:59 hrs).
 8The last date of submission of online bids is July 14, 2015 (14:00 hrs).
  Click here for more information Details
The details of the GAIL`s proposed tie-in connectively scheme are:
 8Laying of a 12.5 km long, 16-inch pipeline from Cairn’s facilities at Suvali to Kribhco, along with a pig launcher receiver and other associated facilities.
 8Installation of a single stream check meter (1.2 MMSCMD) and a KoD with condensate handling facilities at Cairn`s facilities.
 8Installation of a custody transfer metering comprising of a filter, a PRS and a meter with a flow control valve of 1.2 MMSCMD at the existing terminal of Kribhco and hook-up with the existing downstream RLNG skid.
 8Laying of another 1 km  long, 16-inch pipeline to NTPC, Kawas, from the proposed pipeline.
 8Installation of a custody transfer metering comprising a filter, a PRS and a meter with a flow control valve of 1.2 MMSCMD at NTPC, Kawas, and hook-up of the proposed skid with the existing 12-inch pipeline connectivity to NTPC Kawas from GAIL, Hazira. Details
Keeping in mind the increasing production from ONGC`s North Tapti field (in western offshore)  in near future, GAIL is planning to connect the field with its Hazira-Vijaipur-Jagdishpur (HVJ) and the Dahej-Uran Pipeline (DUPL) network.
 8As the gas availability from the North Tapti field is likely to be increased from 0.68 to 1.2 MMSCMD, GAIL, which is responsible for transport and market of the gas, feels that a new long-term arrangement is required for the evacuation of the total quantity.
 8Currently, the gas from the North Tapti field is supplied to allottees by way of a swapping arrangement with the PMT PSC allocation of GSPL in Gujarat. GSPL too has its pipeline in the vicinity, other than the GAIL`s HVJ and DUPL pipelines.
 8The gas from the North Tapti field is currently available at the Cairn-operated Suvali terminal (Block CB-OS/2) in Gujarat. This is because the marginal North Tapti field does not have its own processing facility and the gas is processed at the CB/OS-2 block.
 8Though the block CB/OS-2 is operated by Cairn, ONGC also has a stake in it. The petroleum ministry has allowed ONGC to utilize the infrastructure of the block CB/OS-2 for processing of its North Tapti gas.
 8The total cost of the tie-in pipeline is estimated at Rs 38.81 crore. Details
For reference purposes, the website caries here the details of the comprehensive disaster management plan for the crude oil storage and SPM facilities related to BORL.
The disaster plan has the following elements:
8Types of Hazards
8Sesmic events
8Possible risk reduction measures
8Gujarat Disaster Management Policy
8Information on emergency
8Management plan for unprecedented incidents
8Oil Spill Management Plan
8Risk Analysis and Causes of Spill
8Weathering Effects of Split Crude Oil
8Disaster Plan for Vadinar Resource Agencies
8Handling SPM Emergency
Click here reports for details Details
BORL is now working on an interconnection with the neighbouring crude oil terminal of Indian Oil Corporation so as to be able to ensure that there is never any problem when it comes to storage of crude.
Between IOC and BROL, the crude storage capacity at Vadinar will be very large indeed.
In fact the entire landscape around the area is dotted with SPMs and crude storage terminals.
At present, there are 10 SPMs operating in the Gulf of Kutch
IOC has three, Reliance five -- two for crude oil and three for products -- Essar and BORL have one each.
The BORL crude oil handling was commissioned in the year 2009 with 8 storage each of 60000 KL capacity.
Click here for details Details
BORL is planning to set up a blending unit at Vadinar crude oil terminal because of space constraint in the Bina Refinery
8The blended crude has to stored in separate tanks, this would imply utilizing two of the eight new tanks for this purpose.
The blending unit is a series of pipelines from various tanks brought to the Blending unit which has a set of control valves, which can produce the required blended mix..
The blended crude , of course , has to be stored in separate tanks for pumping to Bina.
In fact the suggestion was to have nine new tanks instead of eight  as blending will always require two tanks and downtime must be taken into account for repairs and maintenance.
Eventually however a decision was taken to stick to eight new tanks instead of nine.
Click here for details Details
BORL is now building doubling its crude storage and handling capacity in Vadinar where VLCCs unload their cargoes for onward transportation to the refinery.
Six additional crude storage tanks of 60,000 cubic metres are to be built and two more tanks that will store blended crude.
8 Currently there are 8 tanks of  60,000 m3 and the problem is that while a VLCC generally takes 18 hours to discharge, the rate of evacuation through the pipeline is only 890 m3/h requiring 15 days to pumping at 22 hours a day.
8A VLCC load of crude oil occupies as many as 6 tanks, and any mismatch in successive VLCC arrival will mean that the tanker will have to wait and this case demurrage will have to be paid. .
8Moreover if two different types of crude are to be stored, it will entail a waiting  of more than 15 days before it is fully emptied .
8With the extra tanks in place, the company can keep demurrages at acceptable levels.
Click here for details Details
Is Bharat Oman Refinery Limited (BORL) planning to step up its capacity from 6 MMTPA to 15 MMTPA?
8The company has dropped hints that the expansion will happen after it completes de-bottlenecking exercise that`s going to take its capacity from 6 MMTPA to 7.5 MMTPA.
8In fact, the company`s SPM in the Gulf of Kutch is capable of pumping as much as 30 MMTPA of crude per annum but the pipeline that ferries the crude all the way to its refinery has a limited capacity.
8The pipeline is being upgraded now to cater to a 7.5 MMTPA throughput after the de-bottlenecking takes place but plans are afoot to move to the 15 MMTPA mark, both for the pipeline and the refinery.
8Clearly the thinking is that a 6 MMTPA refinery is of uneconomical size and a much higher capacity is required for the refinery to reap the economies of scale to compete in the market with the likes of Reliance and Essar.
Click here for details Details
The state-of-the-art Japanese vessel -- dubbed Chikyu -- hired for exploring gas hydrates in India has been put into operation in the high sea off Visakhapatnam coast.
8The vessel has been hired from the Japan Drilling Company Ltd (JDC) to look for gas hydrates at 20 locations in Krishna-Godawari and Mahanadi offshore areas.
8The total cost of hiring of the vessel, including service tax and customs duty, works out to Rs 616.95 crore.
8Before deciding to award the contract to JDC for hiring of the rig, ONGC had also obtained budgetary estimates from another company Siem Offshore (Overseas Drilling Ltd) for its vessel -- dubbed Joides Resolution -- as well.
8However, later it decided to hire the vessel Chikyu as it is much more technologically advanced than the other vessel and was also readily available.
8Recently, the petroleum minister, Dharmendra Pradhan, visited the vessel, Chikyu, to take stock of the India's National Gas Hydrate Programme Expedition-02 (also called NGHP-02).
8It has been established by international surveys that India has huge potential of gas hydrates and if cost-effectively produced, it can be a game changer and bring a gas revolution in India.
8Indian experts from DGH, ONGC, OIL, GAIL and several scientific institutions like CSIR, the National Institute of Ocean Technology (NIOT) and the the National Geophysical Research Institute (NGRI) are working in collaboration with scientists from Japan and the US to develop gas hydrate on a commercial scale. Details
The Japanese vessel -- dubbed Chikyu -- is the first ocean drilling vessel specifically designed for scientific research.
 8Chikyu is a Japanese scientific drilling ship designed to ultimately drill seven kilometres beneath the seabed in a riser mode and can drill in water depths upto 10,000 meters in a riserless mode.
 8Chikyu was built by the Mitsui Engineering & Shipbuilding and launched on January 18, 2002, in Nagasaki, Nagasaki. The ship was outfitted by the Mitsubishi Heavy Industries and delivered to JAMSTEC on July 29, 2005.
 8The hull of the ship is 210 meters long, 38 meters in width, 16.2 meters high, and has an approximate gross tonnage of about 57,000 tonnes. The ship has a maximum cruising speed of 12 knots.
 Click here for detailed specifications of the Chikyu vessel Details
The website carries here, for reference purposes, the name of all the Directors on the Board of oil and gas PSUs, namely ONGC, GAIL, IOC, BPCL, HPCL, OIL, EIL, MRPL, CPCL, NRL, OVL, Bharat Petro Resources Ltd, Biecco Lawrie, Balmer Lawrie Investment Ltd  and Balmer Lawrie & Company Ltd.
8The name of the Directors have been given along with their functions such as Finance, P&BD, HR, Marketing, Refineries, R&D and Pipelines.
8Along with this, the name of the Government Directors and Non-Official Part-Time (NOPT) Directors on the Board is also given.
8The date of their joining, along with the tenure, is also given for all the Directors.
8The total number of sanctioned posts of Directors (functional and non-official), including Chairman/CMD/MD, is given, along with the number of vacancies, if any.
Click here for detailed list Details
Taking a cue from the recent success in USA and Canada in commercially producing oil and natural gas from otherwise tight and ultra-low permeable shale formations, ONGC too has decided to drill a total of 17 R&D wells to assess the shale gas/oil potential in Cambay, Krishna-Godavari and Cauvery basins.
8Earlier, the E&P major had identified 50 nomination blocks for exploration and exploitation of shale gas and oil in Cambay, Krishna-Godavari, Cauvery and Assam & Arakan basins. However, as of now, the company has decided to go ahead with 17 priority blocks and locations for exclusive shale gas and shale oil wells to be drilled as part of Phase-I work.
8Of the 17 wells, 11 wells are in the Cambay basin, five in the KG basin and one in the Cauvery basin.
8It is pertinent to mention here that an R&D well (or an Assessment well) for shale gas or oil is not different from a typical conventional exploratory well in the sense that initial shale gas wells are primarily vertical like any other conventional exploratory well.
8Last year, the ministry had announced a policy for shale gas and oil exploration by national oil companies (NOCs) in only nomination blocks. Under this policy, ONGC has to identify and submit proposals for 50 for PEL/PML blocks.
Click here for more information. Details
The cost of drilling of the 17 R&D shale wells is estimated at Rs 625 crore.
8The depth of the wells is in the range of 2,000-4,500 metres.
8As exploratory drilling is a temporary activity, each well will take around 60-90 days for drilling.
8As ONGC has already been granted an environment clearance (EC) for drilling in the Cambay, Krishna-Godavari and Cauvery basins, it has requested the MOEF to amend the existing EC so that it can go ahead with the assessment of the shale gas/oil potential in the 17 locations.
8If the exploratory drilling is successful, ONGC will go for developmental activities for which it will make separate applications for EC.
Click here for more information. Details
ONGC has invited quotations for Rate Contracts (RC) for carrying out survey for laying of underground pipelines of different sizes in various fields of Cauvery asset.
8The duration of the contract will be three years.
8The surveys will be carried in a total of five zones: Area-I (NRM, TVR), Area-II (AKM, KMP), Area-III (KUT, BVG), Area-IV (RMD) and Area-V (KVK, TA-1, NLM, KN3 & PU).
8The scope of work for the contractor includes carrying out surveys for identification of the route, which would also include reconnaissance and cadastral surveys, carrying out soil resistivity survey, locating the co-ordinates of the laid pipelines and preparation of "as built" drawings.
8Soil investigation will also be done to find out the soil resistivity, PH value, bacteria content and chemical analysis along the pipeline route.
8The contractor will have to identify two or more alternate feasible routes (with type of crossings and its approximate length) so that most economical route can be selected. The purpose of reconnaissance survey is to identify the most optimum route for carrying out the detailed survey, including soil resistivity and cadastral surveys for laying the gas and oil pipelines.
Click here for more information. Details
Does hydraulic fracturing lead to changes in the quality of drinking water near shale oil and gas production wells?
8The answer is "yes" if we go by the report -- titled "Assessment of the Potential Impacts of Hydraulic Fracturing for Oil and Gas on Drinking Water Resources" -- prepared by the US  Environmental Protection Agency (EPA).
8Since the early 2000s, oil and natural gas production in the United States has been transformed through technological innovation. Hydraulic fracturing, combined with advanced directional
drilling techniques, made it possible to economically extract oil and gas resources previously inaccessible.
8However, the growth in domestic oil and gas production also raised concerns about potential impacts to human health and the environment, including potential effects on the quality and quantity of drinking water resources. Some residents living close to oil and gas production wells reported changes in the quality of drinking water and asserted that hydraulic fracturing was responsible for these changes.
8The U.S. Congress urged the U.S. Environmental Protection Agency (EPA) to study the relationship between hydraulic fracturing and drinking water. The US EPA prepared a report synthesizing the available scientific literature and data and came to the conclusion that hydraulic fracturing activities (both above and below ground) do have the potential to impact drinking water resources near production wells.
8The study, however, did not find evidence of any widespread systemic impacts on the drinking water resources in the United States.
Click here to access the US EPA report Details
8Deep Industries invites EOI for sale of CO2 from its Bankia facility in Rajasthan: Deep Industries Ltd (DIL) has invited Expression of Interests (EOI) from interested parties for outright purchase of CO2 from its gas collection and processing plant at Bankia (Dist Jaisalmer) in Rajasthan.
--The bidder will have to set up its own infrastructure outside DIL, Bankia facility, for transportation of the CO2 beyond the point of delivery.
--Bidders who are interested to participate in the above mentioned EOI should adhere to the below mentioned points.
--Around 20 Metric Tonnes Per Day (MTPD) of CO2 is available for sale.
--Interested buyers can send their responses latest by June 30, 2014.
8More tenders: Some more tenders floated by oil and gas companies are:
--Supply of corrosion inhibitor for stripper section of diesel hydro-treating unit, Guwahati Refinery [IOC] Details
--Civil preparatory works for drilling locations, Assam [OIL] Details
--Modification of existing chemical injection system at wellhead platform, KG-OSN-2001/3 Block [GSPC] Details
--Hiring of services for mutation of ROU records for pipelines under Dibiyapur and Agra region [GAIL] Details
--ARC for calibration checking of mass flow meter in LPG plant, Vijaipur [GAIL] Details Details
According to the data furnished by the PPAC for May 2015, domestic petroleum product sales registered a 2.9% growth as compared to corresponding month in the pervious year.
 8Notably, POL products include LPG, naphtha, MS (petrol), ATF, SKO (kerosene), HSD (diesel), LDO, FO/LSHS, bitumen and lubes as well as greases.
 8Total POL sales for May 2015 stood at 15,069 TMT as opposed to 14,652 TMT last year.
 8Cumulatively, POL sales touched 29,686.4 TMT during the April-May 2015 period, registering a growth of 5.7% as against the sale of 28,088.8 TMT during same period in 2014.
 8Except for LPG, Naphtha, MS, Lubes, ATF and Pet Coke, all other products recorded a negative growth during the month Details
GAIL, which has also signed an MOU with the Adani company for offtake of gas from the Dhamra port, feels that there is no requirement for laying of the proposed trunk line from Contai to Dattapulia (along with its spur-lines to Kolkata, Haldia, Kolaghat and Uluberia) as its Jagdishpur-Haldia pipeline (JHPL) would be able to meet the gas demand in the demand centres more cost effectively.
8The gas major`s argument is that the gas demand at Paradip, Bhubaneshwar, Cuttack, Haldia and Kolkata has already been considered on its two authorized gas pipelines: Jagdishpur-Haldia Pipeline (JHPL) and the Surat- Paradip Pipeline (SPPL). Moreover, other load centers like Kolaghat and Uluberia are also within the 50 kms tariff corridor of the JHPL.
8In case of any future requirement of supply of natural gas to Bangladesh, the demand can be met through laying of a spur line (about 80 kms) from JHPL to Dattapulia, GAIL has argued.
8On a ball-park estimate basis, laying down about 250 kms of trunkline (from Contai to Dattapulia) and about 49 kms of spur-lines (to Kolkata, Haldia, Kolaghat and Uluberia) would entail an investment to the tune of Rs 900-1,000 crore, whereas, laying down of an additional 30 kms of spurline from JHPL (upto Dattapulia) and a few spurlines from JHPL to cover Kolaghat and Uluberia would entail an investment to the tune of only Rs 350 crore. Details
It is not only the Adani Group company which is critical of H-Energy`s plan to lay a gas pipeline from Contai to Dattapulia and Paradip, but also the public sector IOC which has its own reservations.
8IOC and GAIL have already booked re-gasification capacity at the upcoming Dhamra liquefied natural gas (LNG) terminal in Odisha.
8IOC has argued that in the proposed pipeline route only one gas source has been considered, that is, H-Energy`s FSRU project off Digha (Haldia). However, as there are other gas sources in the vicinity of the proposed pipeline route, there is a need to integrate all the networks.
8The PSU feels 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.
8IOC is of the view that the PNGRB should modify the proposed Contai-Paradip-Dattapulia pipeline route and invite bids for the development of the following routes:
--A 920-km-long trunk pipeline (24 mmscmd capacity) from Srikakulam (Andhra Pradesh) to Durgapur (West Bengal) via Bhubaneswar and Howrah.
--Spur lines to Rayagada, Odisha (106 km), Jharsuguda, Odisha (301 km), Paradip, Odisha (50 km), Haldia, West Bengal (31 km) and Dattapulia, West Bengal (51 km)
8The new trunk and spur lines will get gas from the following sources: FSRU at offshore of Haldia, West Bengal, LNG Terminal at Dhamra Port, Odisha, Kakinada-Srikakulam natural gas pipeline in Andhra Pradesh and CBM gas fields in Raniganj-Asansol areas in west Bengal.
8Sounding a word of caution, IOC has suggested that once the new pipelines are authorized to connect to the proposed FSRUs off West Bengal and the LNG terminal in Odisha, no other pipeline in future should be allowed to connect to these terminals for evacuation of gas as huge amount is invested in a pipeline and by allowing connectivity to other pipelines, the financial viability of the former pipeline is threatened. Details
The Adani Group, which is setting up an LNG re-gasification Terminal at Dhamra (Odisha) with initial capacity of 5 MMTPA, is getting jittery over H-Energy`s plan to lay a gas pipeline from Contai to Dattapulia and Paradip.
8The Dhamra LNG terminal Pvt Ltd (DLTPL), the Adani Group company which is setting up the LNG terminal, has requested the PNGRB to call a meeting of all stakeholders on the subject before taking a final decision on the laying of the H-Energy`s pipeline.
8DLPTL feels that the H-Energy`s proposed pipeline has not considered the gas source from the re-gas terminal coming up at Dhamra.
8DLPTL has informed the PNGRB that as the Dhamra project will cater to the natural gas demand in the same markets of West Bengal, Odisha and Andhra Pradesh, MOUs with key offtakers of gas, namely IOC and GAIL, have already been signed for reserving substantial re-gas capacity in the project.
8In view of the various project coming up on the east cost and the need to develop an integrated pipeline infrastructure, DLPTL feels that 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. Details
After securing the crucial coastal regulation zone (CRZ) approval for its 6 MMTPA Floating Storage and Re-gasification Unit (FSRU) in the offshore Digha region of West Bengal, H-Energy has submitted an Expression of Interest (EOI) for laying of a natural gas pipeline from Contai (Purba Medinipur district, West Bengal) to Dattapulia (Nadia district, West Bengal) and Paradip (Jagatsinghpur district, Odisha).
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 now with its eye on the Odisha market, the company has drawn up a plan to lay the two pipelines from Contai to Dattapulia and Paradip.
8The proposed pipeline from Contai will reach Haipur (West Bengal) from where it will go to Paradip, with spur lines to Cuttack and Bhubaneswar and also to Dattapulia with spur lines to Haldia, Kolaghat, Uluberia and Kolkata.
8The FSRU will be set up 100 km offshore of Contai (near Digha, West Bengal). As part of the project, the company will also lay a 115 km sub-sea pipeline from the FSRU to its onshore terminal at Contai.
8The LNG plant is expected to be operational by 2018-19. Details
8FO+LSHS
--FO+LSHS consumption registered a de-growth of -10% during May 2015.
--On a cumulative basis, there was a de-growth of -1% for the period April to May, 2015.
--The decline has been mainly because of drop in consumption of LSHS. The consumption of LSHS has reduced due to shift to natural gas by major customers like power and fertilizer industries, such as GNFC and NFL.
--Other sectors like petrochemicals and steel registered a growth in the consumption of the product as compared to the previous year.
8Pet coke
--Pet coke consumption continued to register consistent growth of 7.8% during May 2015, at 1199.2 TMT as compared to 1112.4 TMT in May 2014.

--Cumulatively, sales for the April-May 2015, period, stood at 2302.2 TMT, registering a growth of 11.8% from 2058.7 TMT witnessed during the same period in the previous year.

Details
While Aviation turbine fuel (ATF) sales for May 2015, registered a 3.7% growth over May 2014, naphtha witnessed a decline of 20.7%.
8ATF
--ATF consumption growth was 3.7% during May 2015. Cumulatively, for the April-May period, the growth was 3.1%.
--Consequent to reduction in the number of flights by Spicejet, other airlines optimized their operations and increased their passenger load factor.
--Sales volume during May 2015 stood at 493.9 TMT as compared to 476.4 TMT. Cumulatively, for the April-May 2015, period, ATF sales registered a growth of 3.1% from 939.5 TMT to 968.7 TMT. 

8Naphtha

--Offtake of naphtha by fertilizer, petrochemicals and power companies during May 2015 was 1220.7 TMT, as compared to 1011.0 TMT in the corresponding month of the previous year.

--Cumulatively, sales registered a growth of 15.7% to 2176.7 TMT as against sales of 1881.5 TMT during same period in 2014.
--The main reason for high growth during the month was higher offtake by petrochemical industries. Petrochemical sector registered growth due to increased demand by RIL, IOC, ONGC and APCL`s petrochemical plants.
--Also, there was a minor increase in consumption by power sector units, mainly that of RIL and BSES Ernakulum.

Details
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