Articles

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Enbridge Northern Gateway Pipeline Brief

 The Enbridge Northern Gateway project consists of two parallel pipelines between an inland terminal at Bruderheim, Alberta and a marine terminal near Kitimat, BC, each with a length of 1,177 kilometers (731 mi). Diluted bitumen (dilbit) produced from oil sands, would be transported from Bruderheim to Kitimat, while natural gas condensate would move in the opposite direction in a smaller pipeline.

  

A statistic from the Energy Resources Conservation Board (ERCB) states:   ‘’ It should also be noted that pipelines in Alberta have never been safer. In 2009, Alberta posted a record-low pipeline failure rate of 1.7 pipeline failures per 1,000 km of pipeline (considering all substances), bettering the previous record-low of 2.1 set in both 2008 and 2007.’’    Source

 Please see attachment for the full brief and a sample letter.

 

The Roll of Hatcheries in Steelhead Management - Pollard 2013

The link below is for Pollard's Summary and Recommendations with regards to the roll of hatcheries in steelhead management. The PDF is from the Province of British Columbia's Ministry of Environment in 2013.

NHC BGC Seymour Slide Report

Attached below is an engineering report on the 2014 Slides in Seymour River, from the Seymour Salmonid Society.

BC LNG: A reality check

 

 
 
"  The BC Government has stated that Liquefied Natural Gas (LNG) exports will create a $100 billion dollar “Prosperity Fund” and eliminate the Provincial debt by 2028. Despite current Canadian gas production of just 12.7 billion cubic feet per day (bcf/d), the National Energy Board (NEB) has approved LNG exports from BC of 14.6 bcf/d, with a further 3.4 bcf/d under review.
An analysis of gas production fundamentals in BC reveals that meeting the NEB export approvals would require drilling nearly 50,000 new wells in the next 27 years (double the approximately 25,000 wells drilled in BC since the 1950s). Given the steep production declines associated with shale- and tight-gas, drilling rates of more than 3,000 new wells per year would be required to ramp up production to required export levels, followed by nearly 2000 wells per year to maintain production. Notwithstanding the other well publicized environmental issues with hydraulic fracturing (fracking), which would be the principal completion technology used to produce this gas, water consumption alone during the ramp up phase would exceed that of the City of Calgary, which has more than a million people.
The NEB’s forecasts of gas production in BC through 2035 do not come close to the levels needed for its LNG export approvals. Its reference case forecast for BC is the production of 57 trillion cubic feet (tcf) by 2035, yet 120 tcf are required to meet its approvals (more than three times BC gas reserves). Furthermore, the NEB projects gas production to fall in all provinces except BC through 2035. As Canada’s energy regulator, with a responsibility for ensuring adequate future gas supplies for Canadians, the NEB does not appear to be meeting its mandate. It is uncertain how much of the approved export capacity will be built, but the public would be well advised not to count on an LNG bonanza.  By David Hughes

Potential Impacts of Run-of-River Power Hydroprojects on Salmonids

Pacific Salmon Foundation release the first independent review of IPP Run-of-River Hydro projects in January on this year.

 

Preface

In British Columbia, our electrical power is typically produced, transmitted, and managed by the BC Hydro and Power Authority (BC Hydro).  In recent decades, alternative energy sources have become increasingly important as BC Hydro looks to meet increased demands, manage their costs, and minimize environmental impacts (water and wildlife, climate change effects, and air quality).  British Columbia’s demand for electricity is currently 57,000 GWh/yr and is expected to increase by 40% over 20 years (www.bchydro.com/irp ).  Presently, our supply of electrical power is provided by 34 BC Hydro facilities and 82 other facilities built and managed by Independent Power Producers (IPPs). 
In 2013, IPPs provide 27% of the current supply produced from a variety of energy sources including 44 nonXstorage hydro projects (23% of IPP power, and 6% of BC’s current demand)1. NonXstorage hydro is otherwise referred to as RunXofXRiver (RoR) Hydro projects.  IPPs may also play an important role in meeting the future energy demand.  BC Hydro has signed Electricity Purchase Agreements (EPAs) involving 45 new IPP facilities that are at varying degrees of development2.  NonXstorage hydro projects could play a significant role in these future projects accounting for 30 projects and providing half of the total projected supply of 6,892 GWh/yr.  For comparison, if constructed, BC Hydro’s Site C project on the Peace River is designed to produce 5,100 GWh/yr.  If the new IPPs plus Site C were developed, in aggregate these projects would supply only half of the expected increase of 40% over our current usage!  Each hydroXelectric project in BC will also be associated with an environmental cost.  The scale of impact can vary greatly from large reservoirs flooding timber and agricultural lands to much smaller IPP projects with much more localized effects (except for the Alcan facility at Kemano, built in 1957).  IPP facilities, however, involve more numerous sites and evoke concerns about their cumulative effects across BC.  And, to get to the focus of this review, projects involving streams and rivers in BC also generate immediate concerns for our newest official symbol of British Columbia, the Pacific salmon.