Municipality of Anchorage Community Development Department Kristine Bunnell, Project Manager Carol Wong, Manager, Long Range Planning Page & Turnbull with RSA Engineering Dick Armstrong, PE, CEM Kittelson & Associates HMS Strategic Economics UMED District Plan Update ML&P Meeting August 27, 2013
24
Embed
Municipality of Anchorage Community Development Department Kristine Bunnell, Project Manager Carol Wong, Manager, Long Range Planning Page & Turnbull with.
This document is posted to help you gain knowledge. Please leave a comment to let me know what you think about it! Share it to your friends and learn new things together.
Transcript
Municipality of AnchorageCommunity Development DepartmentKristine Bunnell, Project ManagerCarol Wong, Manager, Long Range Planning
• Miscellaneous other locations– Alyeska Prince Hotel in Girdwood– Fairbanks: 1 C65 – Montana creek DOT station (Mile 82 Steese Highway) 1 C65– Kenai Peninsula (Fort Beluga, Kenai, Happy Valley, Nikiski, Ninilchik): 5 C30’s, – 4 C60’s, 14 C65’s, 4 C200’s, (this fall 2013: 2 C1000’s)– Shemya: 7 C65’s
• Being Installed Now– Oliktok Point: 4 C30’s (Diesel) US DOE Atmos. Radiation Meas. Program
Normal (Base) Mode
Potential Roadblocks to Implementation
• ML&P Interconnection requirements (113) state that cogen units cannot connect to the user’s load, but must be sold back to utility.
– CEA allows the customer to connect a CHP unit on the load side of the meter which reduces their demand charges.
– Financial incentive to use CHP is significanty reduced if customer cannot reduce his demand charges
• Power Back Feed to Grid Concerns
– Interconnecting disconnect device allows for non-utility generation lockout
• Utility Power Quality Concerns
– Protective relays are required to continuously analyzed both the load and the grid to isolate non-utility generation in the event of system disturbances.
• Finding Room Inside Existing or Outside Building for Installation
• Code Restrictions: NFPA, Building Codes, Utility Restrictions
Code Restrictions for Use of Micro-Turbines (Sample)
• NFPA 37: Std for Installation & Use of Gas Turbines– Adopted by reference in 2012 IFGC 616– Adopted by reference in 2012 IMC 915
• Key Provisions (not all inclusive)– Locate where accessible for fire fighters – NFPA 37, 4.1.1.1– No combustible materials stored in room – NFPA 37, 4.1.1.3– Interior walls, floors, ceilings must be 1-hour construction,
except top floor – NFPA 37, 4.1.2.1.1– Ventilation adequate to prevent build up of gasses – NFPA 37, 4.1.2.1.3– Attached engine rooms need 1-hr wall where attached to structures – NFPA 37, 4.1.2.1.4– Noncombustible construction on detached structure – NFPA 37,4.1.2.2.1– Keep detached structures 5’ from main building – NFPA 37, 4.1.4– Natural gas supplies, piping, gas trains, regulators – NFPA37, 5.1– Exhaust systems – NFPA 37, Chapter 8– Controls & Instrumentation of turbines – NFPA, Chapter 9.3– NFPA Chapter 11
• IEEE 1547: Interconnection of Distributed Resources w/grid– Adopted provisions by serving utility– Includes protective relays, utility manual disconnects
ML&P Issues• Rates for purchase of Energy:
– Non-Firm Power Rate $0.03548 /kWh
ML&P Interconnection Guidelines
113 Class C Facilities
Non-utility generator installations from 100 kVA to 1,000 kVA, where the stiffness ratio is at least 30, are Class C installations. The larger capacity of Class C facilities (relative to Classes A and B), and the consequent potential to island large sections of the ML&P electric system is of much greater concern. In addition, Class C installations can significantly influence primary feeder devices and operations.
Class C installations shall have the producer’s non-utility generation equipment connected directly to the ML&P electric power system. Class C installations shall not serve any of the producer’s load(s) normally served by ML&P.
CEA Interconnection Guidelines 163 Class C Facilities Non-utility generator installations of 100 kVA to 1,000 kVA, where the stiffness ratio is at least 30, are identified as Class C installations. Given the larger capacity of Class C facilities (relative to Classes A and B), the potential to island large sections of the Chugach electric system is of much greater concern. In addition, Class C installations can significantly influence primary feeder devices and operations. Accordingly, the probability of interference with Chugach consumers and system equipment is high enough to necessitate more stringent interconnection requirements.
ML&P Does NOT Permit Connecting CHP to Building Load
CEA Allows Connecting Cogen to Building Load
Demand Savings – Single 200 kW CHP
Minimum Monthly Charge $12.88
*Single or three-phase 60 Hertz alternating current at 120/240, 120/208Y, 208Y/120, 240/120, or 408Y/277 volts as available.
General Service: Large at Secondary Voltage
Any service with a demand exceeding 20 kW for three consecutive months and metered at secondary voltage.*
Schedule 22
(Monthly Charge)
Customer Charge $ 44.15
Demand Charge $ 13.64 /kW
Energy Charge 3.8840 ¢ /kWh
Cost of Power Adjustment 2.974 ¢ /kWh
Regulatory Cost Charge 0.0578 ¢ /kWh
Total Per kWh 6.9158 ¢
MOA Underground Surcharge 2% on all charges/rates except RCC
Minimum Monthly Charge $44.15
*Demand is determined by using the maximum average rate of energy use for any 15-minute interval. The billing demand shall be the greater of the following: the recorded maximum demand for the month, or 80 percent of the maximum demand recorded during the preceding 11 months, or the customer demand, under a special contract for a customer with on-site generation.
200 kW CHP could reduce demand charges by $ 32,736/year
Demand Savings – Single 200 kW CHP
General Service: Large At Primary Voltage
Any service with a demand exceeding 20 kW for three consecutive months and metered at Primary Voltage.* The following monthly rates are subject to adjustment each quarter and are based on the total kWh usage.
Schedule 23
(Monthly Charge)
Customer Charge $ 159.55
Demand Charge $ 15.34 /kW
Energy Charge 3.6580 ¢ /kWh
Cost of Power Adjustment 2.974 ¢ /kWh
Regulatory Cost Charge 0.0578 ¢ /kWh
Total Per kWh 6.6898 ¢
MOA Underground Surcharge 2% on all charges/rates except RCC
200 kW CHP could reduce demand charges by $ 36,816/year
2. Base load CHPs to feed heat & power to building.**
3. Size CHPs to feed heat, power to ML&P grid – no demand reduction
4. CHPs in buildings that can be totally off grid via backup generation, or ML&P backup with open transition transfer switch. Pay 12 months demand at ($13.64/kW to $15.64/kW) if using ML&P for >15 minutes.
5. Carry the entire facility campus using CHP generators, interconnected using smart grid to meet all thermal loads, and maximize efficiency by turning down lightly loaded units. Provide backup using diesel micro- turbine or existing diesel recip generators. Completely sever connection to ML&P, or work out a mutual backup agreement.
6. Pick 1-2 buildings per stakeholder to test a proof of concept CHP to determine if they integrate to the system, work as desired and save as expected.**
** Requires Interconnection Requirements Section 113 relief from ML&P
Recommendations
• Request that ML&P remove Interconnection Requirement Section 113 that prohibits demand reduction and requires selling all power back to ML&P. Permit connection of CHP on customer side of meter.
• Size distributed CHP units to pick up thermal loads, use power as base load and demand reduction.
• Priority locate CHP units in high thermal load buildings.
• Consider smart grid variable loading in primary metered locations.
• Use steam micro-turbines if high pressure steam (150 psi) is available to be reduced to 15 psi.
Stakeholder Feedback
• Most Want to Try a Proof of Concept CHP Unit
• Example Potential POC Locations:– Native Hospital mechanical room using steam micro turbine– SCF data room– UAA Integrated Science building– UAA Sports Complex– UAA Energy Modules– APU Mosley Pool Building– API boiler room– MYC boiler room– PAMC boiler room
• Most Prefer to Base Load CHP, Sized to Pick up Thermal Load
• All Would Prefer to Continue Service with ML&P
• All Want to See Relief on Connection Requirement to Reduce Demand
• Some Would Like to Use Smart Grid Behind Primary Metered Grid