Wednesday, November 18, 2015

Nova Scotia's Electricity Plan: more propaganda than science

A half a year after I wrote about Nova Scotia's energy past and future, Nova Scotia's Electricity Plan (PDF) was released.  While there are a couple promising tidbits in the plan, most of it is propaganda and pseudo-science.

The propaganda starts with the executive summary, with statements like, "By 2040, the province will have moved from among the most carbon-intense electricity generators in the country to a green powerhouse."  Firstly, market predictions 25 years in the future are likely to be as accurate as weather predictions 25 years in the future.  Secondly, becoming a "green powerhouse" is not a priority for Nova Scotians; things like health care, education, and jobs are what voters care about.

Page iv talks about interconnection with NL and NB, with the focus being importing power over the Maritime Link, some of which could then be re-sold to New England.  I've previously expressed my skepticism about the economic benefits to NS, and since then I've only found more evidence to solidify that position.  The Economic Analysis done by Natural Resources Canada is a wealth of information.  The cash flow analysis in section 5 shows an expected export price of C$72/MWh in 2017, and $86 in 2020.  I assert that the opportunity for Nova Scotia, in the next 5 years, to re-sell lower Churchill power to New England, is nil.  As I write this blog post on a mid-November day, the wholesale price of power published by ISO new england is US$17/MWh (C$23/MWh), and New Brunswick is selling power to New England for approximately the same price.

These low power rates are not a fluke; from watching ISO-ne and PJM over the past year, I've seen prices averaging around $25/MWh.  ISO-ne recently announced that power prices in 2015 were the lowest since 2003, and more natural gas power plants continue to be built in and around Pennsylvania.  Appalachian natural gas prices continue to be depressed due to supply exceeding pipeline capacity, even as projects like the REX reversal ramp up.  Companies like Cabot Oil and Gas have cash operating cost as low as 10c/MMTU, reserves are huge, so cheap natural gas will continue for the foreseeable future.

Page 21 of the Electricity Plan discusses the declining production of natural gas in NS, but makes no mention of cheap natural gas produced by our neighbors to the south.  It also makes no mention of the fact that the ban on fracking means NS is unlikely to see a revival in natural gas production.

One positive thing in the plan is better interconnection with NB, in particular the "Joint Dispatch Pilot" discussed on page 16.  The plan mentioned it is intended for balancing demand, but I think it should be expanded for large wholesale power purchases from NB.  The upgraded interconnection infrastructure should be a lot less expensive than the maritime link, and the cost of power would be significantly less than from the lower Churchill.

I'll finish by pointing out some of the climate change fear-mongering in the plan on page 19: ""We are experiencing more floods and more dry spells, and more frequent extreme weather events, which are compounded by rising sea levels."  I could find no research confirming rising sea levels in NS connected to anthropogenic GHG emissions.  What I did find is uncontested research showing natural sea level increases over the past 4000 years.

Tuesday, March 17, 2015

Nova Scotia energy part 2: the future

This is part 2, following my post Nova Scotia energy part 1: the present.

The above graph is taken from ICF's 2014 energy market report, and is their minimum growth forecast.  If correct, Nova Scotia will generate around half of it's power from coal for the next 25 years!  My prediction is that the future to 2020 is unlikely to be much better than ICF's forecast, however after 2020, cheap natural gas will start to play a bigger role in reducing power generation from coal.

ICF is forecasting increasing natural gas prices compared to what they were when the report was written.  Their 2015 forecast was for around $4/mmbu a the henry hub, yet it is currently trading below $3/mmbtu.  The report correctly states that the price paid for gas in the maritimes is tied to the price at the Dracut hub near Boston, MA.  Due to limited pipeline capacity from natural gas producers in PA, the price is higher than the henry hub, especially in winter when it regularly peaks over $20/mmbtu.  Heritage Gas is so convinced these winter price peaks will continue that it has entered into an agreement Alton Natural Gas Storage to build salt caverns to store gas for winter peak use.

Over the coming years, I expect these winter spikes to be significantly reduced, due to a number of factors.  The first is new pipeline construction.  The biggest is Kinder Morgan's Northeast Energy Direct pipeline which will bring over a billion cubic feet per day to the Boston area.  The Constitution pipeline will bring up to 0.65 bcf/d of gas north from Marcellus wells in northeastern PA.  A couple smaller projects will add around another .5 bcf/d of natural gas pipeline capacity to the Boston area.

The reason for these pipeline projects is not just because of unusually high prices in New England, but the combination of those high prices and unusually low prices in central Pennsylvania.  This winter while prices around Boston were peaking over $20/mmbtu, prices at the Leidy hub stayed below $3, and are currently averaging $1.50/mmbtu.  Pipeline builders could charge a tariff double the typical 50-75c/mmbtu and producers would gladly pay it in order to get their gas to markets.  Energy companies like Cabot Oil and Gas have halted completion on many of their natural gas wells while they wait for new pipeline capacity to be built.

Another reason I expect natural gas prices in NS to average lower in the coming years has to do with how events on the other side of the world affect LNG prices.  There are a number of LNG import facilities including Canaport that are able to provide extra gas supplies during the winter peak, but for the past few years they have imported very little.  The reason is unusually high LNG prices following the Fukushima disaster made it unprofitable to import LNG.  New production from LNG plants in Australia has cut LNG prices by more than half in the last year, with prices currently around $7/mmbtu.  Additional LNG production from projects under construction in Australia and the US should push LNG prices in the Atlantic down to the $5/mmbtu range  by 2020.

The combination of new pipelines and lower LNG prices should lead to Dracut natural gas prices below $6/mmbtu during the winter peak and around $3/mmbtu for the rest of the year.  This will eventually lead to lower natural gas prices in Nova Scotia, which will provide the financial incentive for switching more generation from coal to natural gas.  Lower natural gas prices should also mean Nova Scotia will use more power from Muskrat Falls when it is completed.  Nova Scotia Power has locked in about 1.2TWh/yr of power from the project, and will be able to purchase another TW or so at market prices.  Cheap natural gas in New England is pushing down electricity prices, so New England won't have to pay top dollar for power from Muskrat Falls.  This should lead to Nova Scotia to purchase much of the surplus power, and at rates that should be significantly lower than the power it has locked in on a 20 year contract.

Thursday, March 12, 2015

Nova Scotia energy part 1: the present

With 60% of power generation coming from coal in 2014, Nova Scotia has made little progress in reducing the use of coal.  Compare this to places like Ontario where the last of their coal plants were shut down years ago, or New England, where coal generation is down to single-digit percentages of power generation.  Nova Scotia has four coal-fired power plants with a total capacity of 1252MW, and has only one power plant that runs natural gas; Tuffts Cove, with a capacity of 500MW.

It's clear from the above graph that the utilization of natural gas generation is less than coal.  If they were used in proportion to their capacity, natural gas would account for 20% of generation and Coal would account for 50%.  The likely reason for the under-utilization of natural gas capacity is due to the high cost of natural gas during the winter peak period.  While I haven't found published information on the price Nova Scotia Power pays for natural gas, the regulated gas recovery rate charged by Heritage Gas should be a reasonable proxy.  The winter 2014/2015 peak was $15/GJ, and the 2014 summer low was around $9/GJ.  Compare this to the Henry Hub, where prices averaged below C$4/GJ this winter.  The price of thermal coal is around US$50/st which, at around 20 million BTU per short ton, equates to an energy cost of US$2.50/mmbtu or around C$3/GJ.

So why is the price of gas in the maritimes up while at the same time going down in the US?  Production from the Sable offshore energy project is less than half of what it was 5 years ago, and new production from deep panuke has not been enough to offset that drop.  Meanwhile US production, primarily from the Marcellus shale, has increased.

As for renewable energy, wind has just made it into the double-digit percentages, but solar is non-existent. Although the cost of PV is approaching grid parity, the lack of a solar feed-in tariff has likely limited solar PV installations to primarily off-grid projects.  Unlike Ontario where microFit pays about 40c/kWh, Nova Scotia is unlikely to see anything similar.  The reason is that Nova Scotia's peak demand of 2GW is in the winter, while Ontario's peak demand is in the summer.  A solar feed-in tariff in NS would just exacerbate this seasonal demand imbalance.  The economics of solar PV has recently become worse, as import duties will likely increase the cost of PV panels in Canada.

In my next post I'll review Nova Scotia's energy plans and make some predictions for the future.

Sunday, February 22, 2015

2015 heating cost comparisons

A couple years ago I did some calculations to compare heating costs in Nova Scotia.  Since then energy costs have changed a bit, and I have more accurate information on the efficiency of oil boilers and pellet stoves.  As well I intend to add natural gas to the comparisons.

Electric heating costs have not changed much, with the cost of electricity now 14.95c/kWh.  This equates to a cost of 4.38c per thousand BTUs.

Furnace oil is now selling for 95c/L.  In my previous calculations, I assumed a 90% efficient condensing boiler.  These are uncommon in NS, so I'll use the 84% efficiency of an oil fired boiler with a tankless coil.  This equates to a cost of 3.14c/kBTU.  Pie anyone?

Instead of propane which is not commonly used for space heating in NS, I'll look at the cost of natural gas.  The current price of natural gas is $20.69/GJ.  When the $21.87 monthly charges is factored over my estimate of 42GJ/yr of gas consumption for a moderately energy-efficient residence, the total cost per GJ is $26.93/GJ.  With one gigajoule equal to 948 kBTU, and an efficiency equivalent to an oil fired boiler, natural gas heat costs 3.38c/kBTU.

For wood pellets, prices have increased so that 40lb bags are selling for at least $5.50.  I've also found out that wood pellet stove efficiency tops out at around 87%, and for typical units is closer to 75%.  After updating my calculations based on the higher price and lower efficiency, wood pellet heat costs 2.29c/kBTU.

With the recent popularity of air-source heat pumps in Nova Scotia, it is prudent to compare their cost of heat to other sources.  A high-efficiency unit with a COP of 2.4 will provide heat at a cost even lower than pellets - 1.83c/kBTU.  A lower efficiency unit with a COP of 1.4 will provide heat for about the same cost as oil - 3.13c/kBTU.

Tuesday, December 30, 2014

Solar PV economics - approaching grid parity in Nova Scotia

In recent years, the cost of solar PV panels has dropped from over $3/watt to under $1/watt.  The drop in prices has even caused China's LDK Solar to declare bankruptcy.  Surging exports of low-cost Chinese-made PV products has lead to a tariff war that will likely put a halt to big price drops in the US and EU.  Assuming Canada does not follow suit and impose high tariffs on Chinese imports, we should see panel prices of C$0.75/W by the end of 2015.  Even at current prices, I'll explain how PV is getting close to grid parity in places with relatively high electricity costs (15c/kWh).

Most of the solar power industry in Canada is focused on Ontario, due to the high subsidies under the microFit program.  At 39c/kWh, a rooftop PV system is a no-brainer.  The cost of the panels and an inverter to convert the DC power into AC adds up to about $1.50/kWh for a 8kW system.  Installation costs can vary depending on how high and steep the roof is, however I think around $5000 for a 8kW system is a reasonable price.  If a solar installation contractor wants to charge much more than that, I'd consider hiring a roofing contractor to mount the panels and an electrician to install the wiring and inverter.

Although the cost of solar panels has dropped by about 75% in the last five years, there has not been an equivalent reduction in the costs of inverters.  Given the costs of the input materials - the solar wafers, glass, metal frames - I think PV panel costs will bottom out around 50c/W.  With inverters, the technology still has room for significant improvements.  Google's Little Box challenge is one example of incentives to improve inverter technology.  Within the next five years, I expect the cost of grid-tie inverters to drop from over 50c/W to under 20c/W.  This along with more competition on the PV installation market should bring the total installed cost including taxes of a residential PV system to under $1.50/W, compared to around $2.50/W now.

So at current prices, a 8kW system would have a total installed cost of about $20,000.   How long that cost is amortized over has a big impact on the economics.  Solar panel warranties are usually 25 years.  Their efficiency drops over time as well; after 25 years about 80% of the installed efficiency is common.  Warranties on inverters are much less - 5 or 10 years.  For financing, the longest amortization for mortgages available in Canada now is 25 years.  Therefore, I think a 25-year amortization makes the most sense.

Interest on a 10yr fixed mortgage with a 25 year amortization is about 4.4%, and the monthly payments on that mortgage would be $109/month.  The PV pontential of most of Eastern Canada is around 1000kWh/kW.  That means a 8kW system would generate about 8000kWh of electricity per year.  With a cost of electricity of 15c/kWh, that would generate an average of  $100 worth of electricity per month, almost covering the $109/mth costs of the system.

One caveat for Nova Scotia is that the current grid-tie tariff does not allow you to produce more electricity than you use.  An energy-efficient house, unless it uses electric heat, would likely use less than 8000kWh of electricity per year.  Smaller systems have less economies of scale, so a 5kW system would likely have a cost of $3/W.  Grid parity may not be here yet in Eastern Canada, but it is coming soon.

Sunday, September 28, 2014

Mini split heat pumps

My regional electric utility has been promoting air-source heat pumps, and  my friend Dan who works installing these types of units tells me they have become quite popular over the last few years.  I discussed the efficiency of geothermal heat pumps in my heating costs comparison post a few years ago, so I figured it's time I did a similar analysis of air-source heat pumps.

As with any type of heat pump, the bigger the temperature difference (called lift), the lower the efficiency of the heat pump.  The efficiency rating for air-source heat pumps is usually given as a heating seasonal performance factors (HSPF).  This is a seasonal average of BTUs of heat provided per watt of energy consumed.  To convert HSPF to COP that is the usual performance rating for geothermal heat pumps, divide the HSPF by 3.4 - the number of BTUs per Watt.

HSPF by itself is not a useful performance measure, since it depends on the heating season outside temperature.  If the unit does not specify the temperature for the HSPF, it is likely 8.3C (47F for those who don't think in metric).  This might be a useful measure for someone living in Vancouver, BC, but not so much for someone living in Halifax, NS where the average January temperature is about -5C.

NrCan states:
At 10°C, the coefficient of performance (COP) of air-source heat pumps is typically about 3.3. This means that 3.3 kilowatt hours (kWh) of heat are transferred for every kWh of electricity supplied to the heat pump. At –8.3°C, the COP is typically 2.3.

A COP of 3.3 equals a HSPF of 11.2, and a COP of 2.3 equals a HSPF of 7.8.  So if your heat pump has a HSPF rating of >7 at -8.3C (17F), it will produce heat for less than half the cost of an electric resistance heater.  The hard part is finding out that efficiency rating.

Mitsubishi Mr. Slim is a popular mini split system, so I tried to find the full specifications for it's efficiency.  I couldn't find them on Mitsubishi's web site, but I was able to find them on a Mitsubishi reseller's web site.  Page 13 has a chart with the efficiency of several of the heat pump models, but the HSPF is only given for 17F.  There are performance numbers given at other temperatures, and since HSPF is BTUs per Watt times 3.4, the HSPF can be calculated at different temperatures.

I started with the GE24NA, a nominal 2 ton unit with a HSPF of 10 at 8.3C.  At -8.3C, it outputs 16,000BTU and consumes 3290W, for a HSPF of only 4.9.  This equates to a COP of 1.4, far short of the typical 2.3 COP stated by NrCan.  Compare that to the D30NA, a nominal 2.5 ton unit with a lower HSPF of 8.2 at 8.3C.  At -8.3C, it outputs 19,500BTU and consumes 2400W, for a HSPF of 8.1 (2.4 COP).  For heating a home in Nova Scotia, the D30NA is a much more efficient unit.

Another reason the D30NA is a much better choice is because at 19,500BTU it will be able to provide more of your heating needs than the GE24NA at 16,000.  Both units will probably need supplemental heat on the coldest winter days.  If you heat your house with electricity, you can look at your electric bill to figure out your heat load, remembering that 1 Watt is 3.4 BTUs.  If you can't find your bill details, but remember your electricity costs, you can figure it out from that.  For example a $450 electricity bill in January when electricity costs 15c/kWh means your consumption was 3000kWh, or 10.2 million BTUs of energy.  Dividing by the number of hours in the month gives an average of 14,000 BTUs per hour.  During a January winter storm with high winds and temperatures of -20C, you'll likely need more heat than the GE24NA can put out.

To analyze the economics, it helps to look back at my heating costs comparison post.  Electricity and oil are slightly more expensive than they were two years ago, but not by much; heating oil is selling for $1.07 per litre.  Wood pellets can still be found for $5/bag.  That puts the cost of a BTU of heat from electricity at about 1.4 times oil and 2.5 times wood pellets.  The conclusion is that a decent air-source heat pump is cheaper than heating with oil, and about as cheap as heating with wood pellets.  If you can get the time-of-day tariff and use a smart thermostat to avoid using electricity during peak time, the heat pump will be even cheaper than wood pellets.

Monday, June 24, 2013

Nuclear furnace for home heating

Since I was a teenager I've been interested in cheap energy sources.  In the past couple years, I've read a few articles and seen a couple Ted talks on thorium reactors.  I thought it would be simpler, cheaper, and more efficient to use the heat from a nuclear reactor directly in the home instead of converting it to electricity first.  As a result, I'm planning to test it out.

I had read about a kid who used lantern mantles as a source of thorium, but that seemed like too much work.  Then I read about thoriated tungsten welding rods.  A local welding supply shop sells a 10-pack of 2.4mm x 175mm rods for under $40.  Each rod has a volume of 0.8cm^2, and .3g of Th.  Based on the articles I've read on thorium reactors, the heat generated from the nuclear reaction of 1g of Th is 36 million BTUs.  So if I can consume all the thorium from 10 rods (3g), I'd generate 108 million BTUs of heat, at a cost of under 40 cents per million BTUs.
In my post on costs of heating in NS, I calculated that heat from electricity costs a little over $40 per million BTUs.  So the cost of heating with a thorium nuclear furnace should be about 100x cheaper than electricity!  Besides thorium, the other thing I need to make a nuclear furnace is a neutron source.  The liquid salt thorium reactor articles talk about using uranium-233, which I can't (legally) obtain.  Ka-Ngo Leung and his colleagues in Berkeley Labs have invented a cheap way to generate neutrons, but it's not commercially available yet.  The radioactive boy scout stories say he used radioactive americium-241 from smoke detectors as his neutron source.  He wrapped it in aluminum, which absorbs the alpha particles from the americium and spits out neutrons.  I'll try the same thing.

I also need a neutron moderator to slow down the neutrons so they'll be captured by the thorium atoms to start the nuclear reaction.  Hydrogen, carbon, and to some extent oxygen all make good moderators.  Candu reactors use heavy water, but that's hard to get and it's expensive.  Most nuclear ractors use regular water.  The radioactive boy scout used charcoal (carbon).  Paraffin wax is mostly carbon and hydrogen atoms, and so makes a good moderator.  I'd like to be able to easily remove the neutron source (to turn off the furnace).  Paraffin wax would melt when the furnace heats up, so my first attempt will be to wrap the neutron source with some charcoal using some aluminum foil.  I'll attach a wire, and drop the cylindrical neutron generator into a tube that is surrounded by the thoriated tungsten rods.

I'd love to hear from any physics heads on what the rate of the reaction should be.  Protactinium-233, the decay product of Th-233 has a half-life of 27 days and beta-decays into U-233.  So I'd guess it will take a couple weeks to approach full temperature.