Shell dumps $12.5 billion Louisiana gas-to-liquids project December 9, 2013, oilpatchasia

Royal Dutch Shell plc said Friday it won't move forward with the proposed 140,000 barrels per day Gulf Coast gas-to-liquids (GTL) project in Louisiana and will suspend any further work on the project.

Shell said it has “taken the decision that GTL is not a viable option for Shell in Noeth America, at this time, due to the likely development cost of such a project, uncertainties on long term oil and gas price and differentials and Shell’s strict capital discipline.”

Shell and Governor Bobby Jindal had announced in September this year the site for the project in Ascension Parish. Shell would have spent a minimum of $12.5 billion under agreements with Louisiana for the project, which would have created 740 direct jobs. CEO Peter Voser said Friday, “We are making tough choices here, focusing our efforts and capital on the most attractive opportunities in our world-wide portfolio, to add value for shareholders.”

“Shell thanks the Governor of Louisiana, his staff, Parish officials, regulators and the community for the opportunity to consider locating this project in Louisiana, and the company looks forward to continuing a long, successful relationship with the state,” the company said in a statement.

RAVVA OIL AND GAS FIELD, INDIA

Ravva oil and gas field is located in the shallow offshore area of the Krishna-Godavari basin on the eastern coast of India. It lies in Block PKGM-1.

Ravva oil and gas field is located in the shallow offshore area of the Krishna-Godavari basin on the eastern coast of India. It lies in Block PKGM-1. The field is operated by Cairn India which holds a 22.5% stake in it. Its partners in the field include ONGC (40%), Videocon Petroleum (25%) and Ravva Oil (12.5%).

The Ravva field was initially estimated to produce 100 million barrels of crude oil. It has, however, produced more than 225 million barrels till 2011.

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Fiber Optics Sensors Creating New Possibilities For Optimizing Fracturing

HOUSTON–The United States ranked number one in the world for both crude oil and natural gas production growth last year, and U.S. producers appear to be positioned to defend that title in 2013 and well beyond. As unlikely at it may have seemed only five years ago, the nation has turned around its energy destiny completely, all thanks to unconventional resource plays.

A litany of sophisticated technologies are being deployed in even the most “routine” shale gas and tight oil development projects, but if operators could point to a single technology that has enabled the domestic industry’s rise to global champion of oil and gas production growth it surely would be hydraulic fracturing. Simply put, the ability to economically and safely induce fractures in ultratight hydrocarbon-bearing rock has revolutionized oil and gas development and opened new horizons of recoverable resources, beginning in dry gas shales and migrating into a range of tight liquids formations.

Distributed Fibre Optic Sensing With Hydraulic Fracturing

Unlike conventional reservoir monitoring devices, in which the sensing element is a physical device usually placed at the end of a copper line, with distributed fiber optic sensing, the entire length of glass fiber is turned into thousands of sensing points.

A critical advance has been micro seismic monitoring,which provides an even better subsurface picture of fracture growth and effectiveness, but it still leaves operators with multiple possible interpretations of the results and performance inconsistencies from one stage to another, leading to such questions as: Why is there micro seismic overlap? Is there stage communication in the reservoir? Is a plug leaking or is there poor cement quality in that particular hole section? With distributed fiber optic sensing, by analyzing the laser light reflections from different spots in the fiber, the temperature and strain of the glass can be determined at any point in the well, and the fiber can be turned into a series of distributed microphones or hydrophones.

Whereas in the past, one may have been limited to a couple of sensing points per well, with distributed sensing, the operator effectively has thousands of measurement points covering the entire well bore.

For the large unconventional reservoirs that operators are now targeting, the real value of distributed fiber optic sensing comes in combining multiple subsurface diagnostic techniques with the surface hardware and fluid chemistry to get the most out of each fracturing treatment.

In a project where thousands of wells may be drilled, it is critical to get the well spacing and horizontal orientation correct. If the operator does not have it right, he is either drilling too few wells or stranding valuable reserves, or drilling too many wells spaced too closely together and wasting tens of millions of dollars on drilling and completing wells that are not required.

While distributed fiber optic systems are invaluable in monitoring hydraulic fracture treatments, they also provide value throughout the life of a well. After the frac job, the same distributed sensing fiber can be used to perform production logging or be used for long-term well bore integrity monitoring.

Note: Full Case Study on "Fiber Optics Sensors Creating New Possibilities For Optimizing Fracturing"  Will Be Updated Soon.

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