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Catalyst Paper & Electricity Rates in BC
Ministry of Energy, Mines & Natural Gas presentation
March 2013
Catalyst Paper in BC
2 Submission to the Rate Review Panel – March 27 2013
Catalyst Overview
3 Submission to the Rate Review Panel – March 27 2013
• Largest producer of specialty
mechanical printing papers and
newsprint in Western North America
• Three world scale mill sites in BC
• Head Office in Richmond; support office
in Nanaimo
• 420,000 sq. ft. Distribution Center in
Surrey
• Recent closures in Snowflake AZ, Elk
Falls & Coquitlam Recycling Division
• Employ 1,600 people in BC and support
5,400 indirect jobs
• Catalyst spending has $2 billion impact
on BC economy
WHY US AND WHY NOW?
Focused Manufacturing Base
4
* No. 1 paper machine at Crofton remains indefinitely curtailed. If it were
to be restarted we do not expect it would produce newsprint.
*
Submission to the Rate Review Panel – March 27 2013
» Major supplier for
Western North American
Customers
» Expertise in light basis
weight production
» Broad product portfolio
to shift with customers
» Only coated paper
producer
» Have environmental
producer offering - Sage
CATALYST PRODUCT RANGE
5 Submission to the Rate Review Panel – March 27 2013
SIGNIFICANT ACHIEVEMENTS
Financial Reorganization
6 Submission to the Rate Review Panel – March 27 2013
Catalyst is Economic Engine for community
Catayst is:
The largest single customer for BC Hydro – Steady sales on existing transmission assets to Vancouver
Island and the Sunshine Coast of 2,700 GWh
The largest shipper on Fortis BC’s gas line to Vancouver Island
The largest consumer of sawmill and logging residuals on Vancouver Island and the Lower Mainland
The largest non-government Marine service user on the BC Coast.
One of the largest shippers of finished products from the Lower Mainland to USA and Pacific Rim
The primary user of trucks returning from the Cache Creek landfill – These shipments reduce the cost of waste disposal for Metro
Vancouver
7 Submission to the Rate Review Panel – March 27 2013
Catalyst Progress and Industry Challenges
8 Submission to the Rate Review Panel – March 27 2013
Challenges Migration to internet-based media
channels Excess Paper and Pulp capacity
into N.A. and Asian markets Competitive landscape
challenges: – Re-introduction of PST – Transportation/Fuel Costs – Carbon tax – Electricity rate increases – Aggressive job and industry
retention policies elsewhere (Port Hawkesbury restart)
– Consolidation of major customers and vendors
Foreign exchange impacts Competition for skilled trades
across sectors
Progress
Fixed our balance sheet, lowered costs and sold non-performing assets
Hired and trained more than 120 employees since January 1, 2012
Entered new market segments, improved market share, developed new and environmental products
Advanced joint infrastructure projects in Powell River, Port Alberni with local communities
Generate green electricity with completion of GTP-funded upgrades
Hosted pilot-scale MicroSludge® plant at Crofton to produce biogas from waste
Leveraged distribution capabilities to expand third-party requirements
Catalyst is a major customer of BC Hydro Energy
9 Submission to the Rate Review Panel – March 27 2013
Catalyst is ~20% of the domestic industrial load
Note
Based on BC Hydro’s sales data in its 2012 Annual Report and Catalyst Paper’s BC Hydro purchases in FY2012 (year ending March 31, 2012)
Energy Costs & Competitiveness
10 Submission to the Rate Review Panel – March 27 2013
Electricity Costs and Catalyst
Catalyst is largest paper producer in BC and exports more than 90% of production outside BC
Major use of electricity in Catalyst operations is for mechanical pulping process
– Electricity is 2nd highest cost component after fiber, comprising 15-20% of production cost 1
– North American paper markets are highly competitive; 70% of mechanical paper industry has had to financially restructure to compete
– BC Hydro rate increases and re-introduction of PST will increase electricity cost to Catalyst by 27% in 3 years 2,3
Catalyst emerged from CCAA protection in September 2012 with support and concessions from all involved parties:
– PST on electricity alone represents ~40% of concessions made by Catalyst employees or over 100% of concessions made by defined benefit pension plan members
Competing jurisdictions providing electricity and tax subsidies to their paper industry(e.g., Nova Scotia & Port Hawkesbury)
11 Submission to the Rate Review Panel – March 27 2013
Notes
1. Source: Catalyst Paper Corp cost statements for Canadian Operations 2012 – Total Paper. (top 3 of manufacturing cash cost items: 36% total
furnish, 19% electricity, 17% labour & salaries)
2. This represents a calculated increase from FY2011 ($100.5M) to FY2014 (April 1, 2013 to March 31, 2014) assuming the same volume of
energy is purchased in both years.
3. The PST impact is based on the energy rate in FY2014 (when the PST comes into effect)
Key constraints
Why do the Paper and CTMP companies use so much electricity? – About 70% of power used by Catalyst is for Thermal Mechanical Pulping
(TMP) – TMP uses power to drive mechanical refiners to liberate fibres – TMP is energy intensive but wood efficient
• 95% yield vs. Kraft at 45-50% yield on wood
Why not use less? – More energy efficient TMP requires major capital spend in new
technology and payback period is not attractive for investment – Access to Power Smart incentives limited by financial security
requirements of BCH for companies like Catalyst
Why not generate more? – Cogeneration presently maximized, additional generation at simple cycle
is inefficient – Incremental generation is capital intensive and with high cost
incremental hog fuel, would require bioenergy power prices • e.g., the Bioenergy Phase 1 Call price (2008) = $107-114/MWh1
12 Submission to the Rate Review Panel – March 27 2013
1. Source: http://www.bcuc.com/Documents/Proceedings/2009/DOC_21037_B-1_BCH_Bioenerg_Call.pdf
Catalyst Energy Overview - 2012
Purchased Power
73%
Self Generation -
Thermal 14%
Powell River Energy Inc.
13%
2012 Electricity 3,650 GWh
Biomass
47%
Natural Gas
18%
Fuel Oil
1%
Tire Derived
Fuel
0.21%
Black Liquor
34%
2012 Fuel Energy 20.8 Million GJ
Submission to the Rate Review Panel – March 27 2013 13
Power costs are outpacing our market prices
14 Submission to the Rate Review Panel – March 27 2013
BC Hydro’s Projections indicate that rates will be going up
BC Hydro recently submitted their Service Plan for the next 3 years (FY14 - FY16), in it they project: – Domestic Revenues will increase 30% ($1.7 billion) – Domestic Energy sales only increase 6% (4,000 GWh) – This can only happen with higher rates since the revenue is increasing
as a rate 5 times the volume
BCH is not prepared to confirm the rate assumptions used in their service plan
15 Submission to the Rate Review Panel – March 27 2013
F2011 F2012 F2013 F2014 F2015 F2016
Domestic Revenue $ Million 3,438$ 3,692$ 3,971$ 4,214$ 4,729$ 5,147$
Domestic Sales GWh 50,607 GWh 51,487 GWh 51,515 GWh 52,701 GWh 53,024 GWh 54,643 GWh
$/MWh 68$ 72$ 77$ 80$ 89$ 94$
index 100 106 113 118 131 139 revenue/sales ratio
Source material http://www.bchydro.com/etc/medialib/internet/documents/about/company_information/reports/bch_service_plan_2013.Par.0001.File.BCH-
service-plan_web.pdf
BCH projects a surplus from F2017 to F2024
16 Submission to the Rate Review Panel – March 27 2013
Balance returns
Base: F2017
DSM: F2024
LNG: 2019-22
Catalyst’s Load
this surplus in supply is inconsistent with a drive for higher rates
Notes 1. DSM: (Demand Side
Management)
reflects the base case
with the impact of Power
Smart conservation
2. LNG: (Liquefied Natural
Gas) the DSM case
including the impact of
additional load with the
development of LNG in
the province.
Source material: BC Hydro response to Association of Major Power Customers of BC (AMPC) dated January 28, 2013
Costs are being transferred from the residential to the industrial rate class
17 Submission to the Rate Review Panel – March 27 2013
Source material Fully Allocated Cost of Service Study filed with the BCUC January 8, 2013 by BC Hydro (Order No. G-110-10 Compliance Filing)
Notes The Revenue to Cost ratio is calculated by
BC Hydro to track how much revenue is
generated by a customer class relative to the
cost of providing supply.
Escalation in rates has been compounded by increases in “non energy” components
18 Submission to the Rate Review Panel – March 27 2013
Catalyst - Rate Impacts
19 Submission to the Rate Review Panel – March 27 2013
A 50% increase in electricity rates is not sustainable for Industry
2010-11 2011-12 2012-13 2013-14 2014-15 2015-16
BC Hydro % Increase 8.00% 3.90% 1.44% 6.50% 6.50%
BC Hydro Rate Rider 2.50% 5.00% 5.00% 5.00% 5.00%
effective blended rate impact 8.00% 4.00% 1.44% 6.50% 6.50%
tax 0.28% 0.28% 7.00% 7.00% 7.00%
Catalyst BC Hydro Cost Index
2010-11 Costs = 100100 110 117 127 137 148
PST Impact, $million 8.0$ 8.6$ 9.3$
overall effective rate, $/MWh 38$ 42$ 45$ 49$ 53$ 57$
relative to 2010-2011 -$ 10$ 18$ 28$ 37$ 48$
Mid C Energy Price, $/MWh 28$ 24$ 21$ 29$ 34$ 36$ BC Hydro premium to Mid C, $/MWh 10$ 18$ 24$ 20$ 19$ 21$
BC Hydro Fiscal Year
Note
This is the BC Hydro bill for demand and energy based on a period corresponding with BC Hydro’s fiscal year, inclusive of non-refundable taxes. This amount
assumes the same volume of energy is purchased in that year as in FY2011 to isolate the impact of rate and tax increases. There is no Tier 2 energy purchases
included in these numbers.
BC rates are up 24% over 3 years relative to 6% for the rest of Canada http://www.hydroquebec.com/publications/en/comparison_prices/index.html
20 Submission to the Rate Review Panel – March 27 2013
2003 (note 3) 2006 2007 2008 2009 2010 2011 2012 change 2009-2012
City region $/MWh $/MWh $/MWh $/MWh $/MWh $/MWh $/MWh %
Montréal, QC Montréal,QC 44.00$ 42.60$ 43.50$ 44.70$ 45.30$ 45.50$ 45.30$ 45.10$ -0.4%
Calgary, AB Calgary,AB 93.80$ 50.30$ 68.00$ 82.80$ -11.7%
Charlottetown, PE Charlottetown,PE 70.50$ 63.80$ 74.20$ 87.50$ 107.20$ 95.80$ 83.60$ 83.60$ -22.0%
Edmonton, AB Edmonton,AB 76.50$ 63.10$ 68.80$ 96.90$ 56.90$ 69.80$ 84.90$ 69.70$ 22.5%
Halifax, NS Halifax,NS 65.80$ 67.50$ 70.40$ 70.40$ 77.00$ 76.10$ 80.70$ 90.00$ 16.9%
Moncton, NB Moncton,NB 58.30$ 54.50$ 58.80$ 64.70$ 66.60$ 66.60$ 68.60$ 68.60$ 3.0%
Ottawa, ON Ottawa,ON 72.60$ 77.40$ 81.30$ 86.60$ 81.50$ 86.40$ 95.10$ 105.80$ 29.8%
Regina, SK Regina,SK 53.80$ 49.00$ 51.10$ 51.10$ 51.10$ 60.90$ 62.40$ 56.70$ 11.0%
St. John's, NL St. John's, NL 43.60$ 52.30$ 39.80$ 39.80$ 39.80$ 39.80$ 39.80$ 39.80$ 0.0%
Toronto, ON Toronto,ON 94.20$ 79.30$ 77.40$ 84.60$ 82.90$ 94.00$ 96.40$ 104.60$ 26.2%
Vancouver, BC Vancouver,BC 38.40$ 35.30$ 36.50$ 38.40$ 40.30$ 44.00$ 43.40$ 49.90$ 23.8%Winnipeg, MB Winnipeg,MB 33.60$ 31.20$ 31.90$ 31.90$ 34.50$ 35.50$ 36.20$ 36.90$ 7.0%
Canadian average excluding BC 61.29$ 58.07$ 59.72$ 65.82$ 66.96$ 65.52$ 69.18$ 71.24$ 6.4%Boston, MA Boston,MA 142.50$ 133.00$ 155.10$ 147.60$ 184.80$ 119.80$ 111.40$ 101.30$ -45.2%
Chicago, ILL Chicago,ILL 75.30$ 55.70$ 70.00$ 89.40$ 63.00$ 51.50$ 61.60$ 53.30$ -15.4%
Detroit, MI Detroit,MI 75.40$ 72.30$ 71.00$ 66.50$ 78.70$ 67.60$ 64.40$ 76.90$ -2.3%
Houston, TX Houston,TX 62.90$ 65.50$ 70.20$ 74.50$ 43.80$ 39.00$ 66.20$ 55.50$ 26.7%
Miami, FLA Miami,FLA 85.30$ 91.80$ 85.70$ 75.10$ 99.50$ 63.00$ 62.20$ 60.90$ -38.8%
Nashville, TN Nashville,TN 62.30$ 65.70$ 63.10$ 64.60$ 84.20$ 62.80$ 68.40$ 69.60$ -17.3%
New York, NY New York, NY 234.60$ 136.70$ 177.60$ 151.60$ 152.60$ 122.90$ 126.30$ 115.50$ -24.3%
Portland, OR Portland,OR 54.90$ 43.60$ 46.20$ 43.10$ 58.60$ 50.70$ 57.40$ 59.40$ 1.4%
San Francisco, CA San Francisco, CA 231.20$ 96.60$ 90.20$ 83.30$ 120.10$ 97.80$ 89.90$ 88.40$ -26.4%
Seattle, WA Seattle,WA 82.40$ 61.60$ 51.60$ 45.80$ 56.40$ 52.30$ 52.50$ 56.00$ -0.7%
US Average 110.68$ 82.25$ 88.07$ 84.15$ 94.17$ 72.74$ 76.03$ 73.68$ -21.8%
BC's ranking 2 2 2 2 3 4 3 4 4
Notes 1. source: http://www.hydroquebec.com/publications/en/comparison_prices/index.html
2. the rates reflect those in effect on May 1 of the year stated
3. data from BCH 2004/5 and 2005/65 RRA
4. calculations based on 50 MW demand, 30.6 GWh/month, service at 138 kV and a load factor of 85%
Other jurisdictions are providing assistance to paper companies
Nova Scotia
– Port Hawkesbury Paper negotiated a Load Retention Rate in 2012 http://0-fs01.cito.gov.ns.ca.legcat.gov.ns.ca/deposit/b10651895.pdf
Washington State
– Port Townsend Paper Corporation signed an amendment to the existing power sales contract through September 2022 with the Bonneville Power Administration (BPA) http://jeffcountychamber.org/bpa-and-port-townsend-paper-sign-long-term-contract-amendment-2/ http://www.bpa.gov/power/pl/regionaldialogue/implementation/Documents/2012/PTPC_EXTENSION_ROD.pdf
– North Pacific Paper Corp(NORPAC) received $21M from the BPA and $4M from the Cowlitz County Public Utility District for a $60M TMP energy reduction and brightness improvement project http://www.bpa.gov/news/newsroom/Pages/Going-big-BPA-Cowlitz-PUD-and-NORPAC-partner-on-largest-ever-energy-efficiency-project.aspx
Ontario
– Northern Industrial Electricity Rate Program
– $20/MWh rebate up to $20 million/year per customer
– Northern Ontario, defined as being within the collective territorial Districts of Kenora, Rainy River, Thunder Bay, Cochrane, Algoma, Sudbury, Timiskaming, Nipissing, Manitoulin, and Parry Sound http://www.mndm.gov.on.ca/en/northern-development/business-support/northern-industrial-electricity-rate-program
21 Submission to the Rate Review Panel – March 27 2013
BC taxation policy compounds the challenge
This creates a tax policy that is:
– Consistent with commitment to re-introduce PST in 2013
– Consistent and equitable for industrial processors in BC
– Keeps BC industries competitive with other North American jurisdictions
– Easy to track and implement by companies
– Proposed modification to PST implementation would obtain support from industrial companies in BC
– Logic of proposed solution and public messages would be straightforward
22 Submission to the Rate Review Panel – March 27 2013
Exempt electricity used in industrial processing from PST
Electricity used for other purposes would be taxed
(Manitoba model)
BC is one of only 2 jurisdictions in North America that tax electricity for industrial processing – Manitoba taxes industrial electricity at 1.4% (BC at 7%)
– PST compounds any future rate increases
– PST on electricity does not contribute to BCH revenues
Policy considerations
23 Submission to the Rate Review Panel – March 27 2013
Retail Access
Catalyst competes with producers in Washington state who have market access to electricity – Market access to some market power provides a competitive
hedge for some of our production
Market prices at Mid C have been significantly lower than BCH Tier 1 rates and market projections appear flat.
Market access also provides customers with an alternative to BCH pricing and commercial terms
We recognize that there needs to be a clear framework to address the issues with customers moving demand out of, and re-entering, the BCH system – These issues have been addressed in other jurisdictions so this
should not be insurmountable – The suspended Retail Access program provides a good starting
point
24 Submission to the Rate Review Panel – March 27 2013
There is a material gap in market prices and industrial rates
25 Submission to the Rate Review Panel – March 27 2013
Notes Mid C: (Mid Columbia) this is the
local trading hub for market electricity
in the Pacific Northwest.
Rate Design Discussion
Stepped Rates are fine – Tier 1 is not a DSM barrier – most of the issues have been
addressed in the TS74 amendments in front of the BCUC
– Tier 2 is a barrier for restart for previously idled equipment
Intensity Based Rates would be difficult to manage – MWh/EBITDA vs. MWh/MT vs. MWh/m2 vs ?
– It would introduce complexity and uncertainty for both the utility and the customer
End Use Rates are great for us but unrealistic from an equity perspective
Other Rates may provide opportunities for high intensity, high load factor industries while benefitting the rest of the system, like: – Time of Use rates (e.g., “3 x 12 table” used by BCH
acquisitions)
– Real Time pricing
– Interruptible rates
26 Submission to the Rate Review Panel – March 27 2013
Customer issues and conclusions
27 Submission to the Rate Review Panel – March 27 2013
Key Issues for Catalyst as a BCH Customer
1. Rate increases for Catalyst and industry – Rapidly becoming uncompetitive in our end paper products
2. Credit terms - Catalyst – Current BCH credit terms are constraining liquidity for Catalyst
3. PST exemption for industrial processing – All electricity used in the manufacturing of products should be PST exempt
4. Power Smart incentives – financial requirement – BCH has required Catalyst to provide letter of credit for conservation projects
which many other BCH customers are not required to do
5. Ability to buy some of our energy at a market rate – A hedge against our competition in Washington State that have market access
to power at the Mid Columbia trading hub (e.g., Nippon Port Angeles, NORPAC Longview)
– Provides healthy competition for BCH, a real price comparison
6. Mandatory Reliability Standards – Catalyst has diverted limited resources to support regulatory requirements
that is handled by the utility in other jurisdictions
7. Deferal account balance (regulatory accounts) – Size of the regulatory balances is approaching $ 5 billion, greater than the
total revenues from BCH in 2013 – Resolution of the Deferral Account balance is unclear and poses a risk for all
ratepayers and the share holder in the longer term.
28 Submission to the Rate Review Panel – March 27 2013
Ideally…
Rate stability – Small increases, if required
– Provide adequate notice and minimize use of interim rates
Return Catalyst to normal trade credit
PST exemption for industrial processing
Access to Power Smart incentives for conservation projects without Letter of Credit requirement
Ability to access the market for some power
Industrial Rate structures to maximize the value of installed (& future) capital
29 Submission to the Rate Review Panel – March 27 2013
Stable, cost effective electricity in the near term is necessary to give industry a chance to transform to
thrive in the long term.
Additional Slides
30 Submission to the Rate Review Panel – March 27 2013
Service plan analysis detail
31 Submission to the Rate Review Panel – March 27 2013
F2011 F2014 F2015 F2016
Domestic Revenue $ Million 3,438$ 4,214$ 4,729$ 5,147$ 776$ 23% 1,709$ 50%Domestic Sales GWh 50,607 GWh 52,701 GWh 53,024 GWh 54,643 GWh 2,094 GWh 4% 4,036 GWh 8%Average Mid C price $/MWh 28.02$ 29.23$ 33.52$ 35.80$ 1.21$ 4% 8$ 28%Net Long-Term Debt $ Million 11,520$ 15,701$ 17,509$ 18,709$ 4,181$ 36% 7,189$ 62%Capital Spending $ Million 1,519$ 2,031$ 2,445$ 2,457$ 512$ 34% 938$ 62%Surplus Energy GWh 53 GWh 3,837 GWh 3,210 GWh 3,326 GWh 3,784 GWh 7140% 3,273 GWh 6175%Total Expense $ Million 3,427$ 4,380$ 4,887$ 5,238$ 953$ 28% 1,811 GWh 53%Rate increase % 0.00% 1.44% 6.50% 6.50%
$/MWh 28.17$ 33.19$ 35.88$ 38.74$ 5.03$ 18% 10.58$ 38%
index 100 118 127 138
Deferral Account Balance $ Million 2,160$ 4,211$ 4,211$ 4,211$ 2,051$ 95% 2,051$ 95%
$/MWh 67.94$ 79.96$ 89.19$ 94.19$ 12$ 18% 26$ 39%index 100 118 131 139
Impact, F11-F16Impact F11-F14
revenue/sales ratio
Tier 1 Rate
Rate Impact detail
32 Submission to the Rate Review Panel – March 27 2013
Year 0 Year 1 Year 2 Year 3 Year 4 Year 5
2010-11 2011-12 2012-13 2013-14 2014-15 2015-16
BC Hydro % Increase 8.00% 3.90% 1.44% 6.50% 6.50%
BC Hydro Rate Rider 2.50% 5.00% 5.00% 5.00% 5.00%
year over year rate rider change 0.00% 2.50% 0.00% 0.00% 0.00%
effective blended rate impact 8.00% 4.00% 1.44% 6.50% 6.50%
tax 0.28% 0.28% 7.00% 7.00% 7.00%
overall rate increase 9.75% 7.01% 8.53% 7.72% 7.86%
cumulative 9.7% 17.4% 27.5% 37.3% 48.1%
Blended 8.0% 12.3% 13.9% 21.3% 29.2%
Tier 1 10.3% 15.8% 17.8% 27.4% 37.6%
Tier 1 Rates, $/MWh 28.17$ 31.07$ 32.60$ 33.19$ 35.88$ 38.74$
loaded 29.29$ 31.94$ 34.33$ 37.29$ 40.31$ 43.53$
Tier 2 Rates 73.60$ 73.60$ 73.60$ 73.60$ 73.60$ 73.60$
loaded 76.54$ 75.65$ 77.50$ 82.69$ 82.69$ 82.69$
Demand 5.58$ 6.03$ 6.26$ 6.35$ 6.77$ 7.21$
loaded 5.80$ 6.20$ 6.59$ 7.14$ 7.60$ 8.10$
conservation incentive 45.44$ 42.53$ 41.00$ 40.41$ 37.72$ 34.86$
Catalyst Energy Bill, $million 100.5$ 110.3$ 118.0$ 128.1$ 138.0$ 148.8$
Year over Year increase, $million 9.8$ 7.7$ 10.1$ 9.9$ 10.8$
Catalyst BC Hydro Cost Index
2010-11 Costs = 100100 110 117 127 137 148
PST Impact, $million 8.0$ 8.6$ 9.3$ GWh from Hydro 2,618,017 2,618,017 2,618,017 2,618,017 2,618,017 2,618,017
overall effective rate, $/MWh 38$ 42$ 45$ 49$ 53$ 57$
relative to 2010-2011 -$ 10$ 18$ 28$ 37$ 48$
Mid C Energy Price, $/MWh 28$ 24$ 21$ 29$ 34$ 36$ BC Hydro premium to Mid C, $/MWh 10$ 18$ 24$ 20$ 19$ 21$
BC Hydro Fiscal Year