HomeMy WebLinkAbout11 UAMPS Pooling Agenda Item # 11
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Public Utility District �
CONSENT
To: Board of Directors
From: Stephen Hollabaugh
Date: June 04, 2008
Subject: Approve and Execute DAMPS Pooling Appendix Concerning
Payson Natural Gas Generation
1. WHY THIS MATTER IS BEFORE THE BOARD
This matter is before the Board for possible approval of the Payson Project Natural
Gas Power Generation described in the UAMPS pooling appendix.
2. HISTORY
The attached information concerning the Payson Project was presented in a
workshop on May 7th.
Natural Gas Power Generation: The Payson natural gas project is a UAMPS project
and is owned by UAMPS members. This project has been discussed with the Board
in 2005 and again during the electric power supply budget meetings in 2007. The
District has also joined the Pool Project of UAMPS that will enable the District to
receive this generation. An attachment "Information Concerning the Payson Project"
was distributed in 2007 and again in this packet. This attachment gives a very good
overview of the project.
3. NEW INFORMATION
Natural Gas Power Generation: The Payson Natural Gas Project has been named
the Nebo power plant. The "Information Concerning the Payson Project" has a final
page which shows a current table of the Mona/Nebo Forward Spark Spread (price of
gas versus market) and Forward Power Price data. This natural gas plant will be a
good fit with the other District's power supply. It gives the District a high load hour
generation source and will give the District a supply to back up wind or geothermal
resources.
The City of Payson is interested in selling a portion of their allocation at the Nebo
power plant. This transaction can be handled through UAMPS and initially through a
pooling appendix. There are five steps for finalizing this transaction and they are:
1. Approve and Execute the Pooling Appendix by City of Payson and Truckee
Donner PUD (this action).
2. Submit the offer to the Payson Project participants (first right of refusal).
3. Negotiate, approve and execute an Assignment and Assumption
Agreement/Power Sales Contract
4. Obtain FSA approval
5. Transfer effective
Attached is a draft of the Pooling Appendix in which 4.118 Mw@ Sweep Spot will be
transferred to Truckee Donner PUD.
The cost to the District will be the All-In Cost of operating the transferred percentage
of the plant plus a one time fee of $164,287 upon consummation of the permanent
entitlement share transfer. The one time fee is what the City of Payson has paid into
the maintenance account for this portion of the plant that may be transferred.
4. FISCAL IMPACT
Nebo Natural Gas Electric Generation project will represent a portion of the Electric
Supply Procurement budget that might otherwise be purchased at from the market.
Current average difference ranges from $1 to $37 MWH below market.
The price of this Nebo natural gas generation is All-In cost plus a one time fee of
$164,287 upon the consummation of the permanent entitlement share transfer.
5. RECOMMENDATION
Approve and authorize the President of the Board to execute the UAMPS pooling
appendix concerning the transfer of 3.6765% Entitlement share of the Payson
Project from the City of Payson to Truckee Donner PUD.
Stephen Hollabaugh, Assistant General Michael D. Holley, General Manager
Manager
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PAYSON PROJECT DESCRIPTION
PROJECT SITE
The Project is located in northwest Payson City on approximately 7 acres of land next to the
Payson City wastewater treatment plant, 50 miles south of Salt Lake City and just west of I-15.
PROJECT DESCRIPTION
The Project consists of a General Electric (GE) Frame 7EA combustion turbine-generator
capable of producing 67 MW of power at 98°F, a duct-fired heat recovery steam generator and a 73
MW dual-pressure steam turbine, to provide gross combined cycle generating capacity of 140.5 MW
(estimated summer net capability is 136 NM at design conditions of 98°F/25%humidity with duct
burners in service and foggers in operation.
The Project utilizes dry low-NOx combustors with selective catalytic reduction ("SCR") and
meets Best Available Control Technology ("BACT") requirements. Oxides of nitrogen ("NOx") and
carbon monoxide ("CO") emissions are controlled to 5.0 parts per million by volume, dry. Other
Project facilities include control and administrative buildings, a wet mechanical-draft cooling tower,
water treatment facilities and storage tanks and other ancillary facilities. The Project also includes on-
site pipelines for natural gas and water supply, wastewater discharge piping, site access and parking.
The Project provides a back-up dispatch center for UAMPS and has 24-hour video monitoring and
surveillance.
The Project was built and is currently operated by Colorado Energy Management of Lafayette,
Colorado.
WATER AND WATER TREATMENT
Approximately 400 million gallons of Type 1 treated wastewater is available from the adjacent
sewage treatment plant. This closely approximates the anticipated annual requirements for the
Project cooling needs. However, disparities between hourly flow and utilization characteristics may
require the purchase of up to 45 million gallons of additional water annually. The only significant
waste stream generated by the plant is biowdown from the cooling tower and added to the outflow
of the wastewater treatment plant.
FUEL SUPPLY
The Project is fueled entirely of natural gas. The Project's gas pipeline interconnects with
Questar Pipeline's 104 gas transmission system line at the Nebo Tap.
The Project does not own any primary firm gas transportation on Questar Pipeline's 104 system.
The Project currently contracts for firm natural gas delivery at Nebo Tap from various gas suppliers
in the region. There is every indication that primary gas transportation capacity may become
available through an upgraded system on Questar Pipeline's 104 Line through open-season offerings
or on the secondary market as available should the Project determine a need for its own gas
transportation. The ability to backhaul off the Kern River Gas Line is also available.
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ELECTRIC INTERCONNECTION
The Project lies approximately 8.5 miles southwest of the Southern Utah Valley Power System's
(SUVPS) Dry Creek Substation. The Project interconnects with SUVPS and Rocky Mountain Power
(formerly known as Utah Power) at the Dry Creek Substation via 46kV and 138kV circuits.
MARKET POSITION OF THE PAYSON PROJECT
COMPETITIVE RESOURCE
The Project lies in north-central Utah in the heart of Rocky Mountain Power's Eastern Control
Area, known as PACE. PACE resources consist mostly of base-load, coal-fired power plants in
Wyoming and Utah. There are several old gas-fired resources within the control area to meet
"peaking" needs. The Project was the first gas-fired combined cycle gas resource in the control area.
Rocky Mountain Power has since built two, large, intermediate, gas-fired, combined cycle plants in
the area to meet load growth on the Wasatch Front. The Project is still a competitive resource in the
area despite these new plants.
RELATIVE POSITION IN THE MARKET
The Project can be measured relative to other similar resources by comparing Heat Rates as
listed below in Table 1.
Table 1.
Capacity Heat Rate
Plant Name Owner (MW) (Btu/kWh)
Lakeside oc tn. ower
Currant Creek Rocky Mtn.Power 525 7,462
Nebo Power Station UAMPS 140 8,400
West Valley 1 Rocky Mtn.Power 40 9,878
West Valley 2 Rocky Mtn.Power 40 9,878
West Valley 3 Rocky Mtn.Power 40 9,878
West Valley 4 Rocky Mtn.Power 40 9,878
West Valley 5 Rocky Mto.Power 40 9,878
Gadsby 4 Rocky Mtn.Power 40 10,695
Gadsby 5 Rocky Mtn.Power 40 10,695
Gadsby 6 Rocky Mtn.Power 40 10,695
Ciadsby 1 Rocky Mtn.Power 60 13,495
C�adsby 2 Rocky Mtn.Power 75 13,495
Gadsby 3 Rocky Mtn.Power 100 13,495
Little Mountain lRocky Mtn.Power 1 14 1 16,574
DETERMINING THE PROJECTS RELATIVE VALUE
As a natural gas-fired resource, the proper financial measure of the Project relative value to the
market is formulaically determined by the "spark spread". The spark spread is the theoretical
measure of income (or loss) from buying natural gas and converting it to electricity. Defined, the
spark spread in dollars ($) is equal to the market price for power in $/MWh less the cost of gas in
$/MMBtu multiplied by the operational heat rate (HR) in Btu/MWh). UAMPS conservatively
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estimates a Project Heat Rate of 8,400 Btu/MWh. If the price of natural gas is $5.00/MMBtu, the
fuel cost for Nebo is $41.00/AM. If the market price were $50.00/MWh, the spark spread would
be a positive$9.00.
The relative value of the Project can be determined as far into the future as there is a viably
accurate forward power and gas market,which is usually up to 5 years. Longer term forecasts can be
made based on prudent, but usually conservative assumptions. As an indication, the derived
Mona/Nebo Forward spark spreads as of August 21,2007 are shown below in Table 2.
Table 2.
Mona/ Nebo Spark Spread (On-Peak)
Heat Rate Aug Sept Oct 04-07 01-08 Q2-08 2008 2009 2010
8.00 $ 44.27 32.20 24.49 10.69 2.10 13.97 16.53 14.64 13.61
SS 8.20 $ 43.66 "i.58 23.68 9.61 i0.78 1266 15.15 i3.14 i2'lit
SS 8.30 $ 43.35 31,26 23.27 9.07 0.12 12.01 14.46 t2.39 ;1,35
Full 8.40 $ 30,95 22.66 8.53 9.46 11.36 13.78 1165 1n.59
Full 8.45 $ 42.8L, 30.79 22.06 8.26 9.93 t 1.03 13.43 1'127 4!0.22
8.50 $ 4274 5CO.64 22.46 7.99 3.50 10610 M30o l090 9.84
SC 12.50 $ 30.50 18.11 6,20 113.67) (17.65) (15.44) (1440) (18-98) (20.31)
SS=Nebo SweetSpot Full=Fully Loaded SC=Simple Cycle Green=in the Money Red=Out of the Money
Grey=Marginal Call
PROJECTED FORWARD POWER AND GAS MARKETS
For the Project, the most accurate and relative power and gas markets are Mona Substation
("Mona") and Opal Plant ("Opal"), respectively. Mona is generally recognized and transactable
power hub physically located approximately 13 miles south of the Project. Mona is relatively illiquid
in the forward markets due to the lack of parties that trade there and is usually priced as a derivative
of the more liquid hub of Palo Verde {"PV") located just west of Phoenix,Arizona. Opal is a natural
gas processing plant operated by Williams and is located in southwest Wyoming. Gas is traded
physically and financially at Opal with several viable and published indices. Opal is less physically
related to the Project but acts as a legitimate proxy to the Project's Nebo Tap. Nebo Tap, on the
Questar Pipeline 104 system is not a generally accepted market hub and is only used for the Project.
Nevertheless,Nebo Tap has in the past and is expected in the future to price at least equal to or at a
discount to Opal due to the system constraints on the Questar Pipeline 104 system. The most recent
indicative forward power prices in the region, specifically Mona hub, as of August 21, 2007 are
shown below in Table 3.
Table 3.
HUB Aug Sept Oct Q4-07 Q1-08 Q2.08 2008 2009 2010 2011 2012 2013 2014 2015 2016
OnPeak Mona $ 68.75 $ 57.25 $ 57.00 $500 $ 65.00 $66.25 $ 71.50 $74.40 $73.90 $72.15 $73.15 $73.90 $74.15 $74.65 $75.15
CffPeak Mona $ e}'00 $ 43.75 I$ 44,01, S 4235 $ 52,00 $44.50 $ 50.50 $52J5 S 52.25 $51,R $52.00 $5150 w 52 � $53.25 $54 04
Flat Mona $ 5913 $ 51.34 $ 51.31 $ 48.90 $ 59.31 $56.73 $ 62.31 $64,93 $64.43 $63.12 $63.90 $54.54 $64.79 $65.29 $65.90
Flat PV $ 59.23 $51.341$ 51.31 $50.34 $ 59.31 $56.73 $ 62.31 $64.93 $64.43 $63.12 $63.90 $64.54 $6439 $65.29 $65.90
Flat MidC $ 53.66 $52.30 $ 53.69 $57.36 $ 63.50 $45.22 $ 61.53 $63.93 $64.04 $62.82 $63.88 $64.3B $64.85 $65.35 $66.10
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INTENDED USE OF THE PAYSON PROJECT
The Project was constructed to meet Participant's needs for an additional power supply resource
that would be reliable, economical and cost-based supply of electric energy. While the Project is
available all hours of the year it tends to provide power supply during the "high load hours"
("HLH")—the 112 hours each week covered by the period from 7:00 AM to 11:00 PM; Monday
through Sunday. Such a resource is characterized as an"Intermediate"Resource.
ANALYSES OF PAYSON PROJECT
The Project is an important development for UAMPS that has provided a significant new power
supply resource. UAMPS' analyses of the Project operations indicate that the cost of energy from
the Project compares favorably with projected forward market prices of electricity. UAMPS expects
that the Project will produce significant benefits for the Participants by reducing their exposure to
market purchases of energy during HLH. Overall, UAMPS believes that the Project is a prudent
investment by the Participants that will enable them to achieve greater price stability and enhanced
reliability in their wholesale power supplies.
RECENT OPERATIONS OF PAYSON PROJECT
While not without some difficulties since commencing commercial operations in June of 2004,
the Project has proven effective and much in-line with the pro-forma analyses performed by
UAMPS. Like many new projects for relatively small organizations such as UAMPS, some
Participants are experiencing excess capacity produced on the front end of the Project's expected life
has been a challenge. UAMPS and the Participants have used various means,including power sales
and tolls to address that challenge.
Price volatility has also been a challenge due to the volatility in the gas markets, especially with
the effects of Hurricane Katrina. Nevertheless, the Project has proven to provide much better prices
relative to the corresponding power markets.
FUTURE OPERATIONS OF PAYSON PROJECT
As Project Participant loads continue to grow, and as new Participants step into the surplus
capacity it is fully expected that the Project will be utilized for internal needs.
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Mona/Nebo Spark Spread (On-Peak) (as of April 2008)
ea
Rate May June July Q3-08 Q4-08 Q1-09 2009 2010 2011
8.2 5.48 13.08 37.85 32.26 6.58 8.40 1779 16.21 13.73
SS 8.3 4.50 12.09 36.87 31.31 5.61 7.44 16.99 15.44 12,94
SS 8.4 3.52 11 11 35.89 30.36 4.65 6.49 16.19 14.68 12,15
Full 8.5 2.54 10.13 34.90 29.41 3.68 5.53 15.39 13.91 11.37
Full 9.5 (7.28) 0.29 25.07 19.93 (6.01) (4.02) 7.39 6.25 3.49
10 (12.19) (4.63) 20.15 15.18 (10.85) (8.80) 3,39 2.43 (0.45)
SC 12.5 (36.74) (29.23) (4.44) (8.53) (35.06) (32.69) (16.61) (16.72) (20.16)
SS=Nebo SweetSpot Full=Fully Loaded SC=Simple Cycle Green=ln the Money Red=Out of the Money Grey=Marginal Call
WECC FORWARD POWER PRICES (As of 3/13/2008)
HUB Apr May June Q2-08 Q3-08 04-08 2009 2010 2011
OnPeak Mona $ 78.00 $ 84.00 $ 93.00 $ 87.10 $ 113.50 $ 85.50 $ 84.60 $ 81.25 $ 81.25
OffPeak Mona $ 50.00 $ 52.00 $ 57.00 $ 53.00 $ 66.00 $ 58.00 $ 56.50 $ 53.75 $ 54.25
Flat Mona $ 65.75 $ 70.00 $ 77.25 $ 72.18 $ 92.72 $ 73.47 $ 72.31 $ 69.22 $ 69.44
Flat PV $ 65.75 1 $ 70.00 1 $ 77.25 $ 71.62 $ 91.03 $ 72.63 $ 72.03 $ 68.94 $ 69.16
Flat MidC $ 58.22 1 $ 46.69 1 $ 47.38 $ 51.07 1 $ 82.33 $ 79.20 $ 69.77
For WECC Standard Products:6X16,HLH;and 6X8+24 LLH,January through December
POOLING APPENDIX
This Appendix to the UAMPS Power Pooling Agreement to which all Parties to this Appendix are
signatories provide for the following transactions. The parties to this Appendix agree to the
following provisions and agree to pay all costs of this transaction through the UAMPS Pool.
SELLER: Payson City
BUYER: Truckee Donner PUD
TERM: Initially beginning June 16, 2008 through June 30, 2008 and shall thereafter
automatically renew for an additional one month term and will continue thereafter
for successive one month terms until a Payson Project permanent entitlement
share can be consummated pursuant to the terms and conditions in the Payson
Project Power Sales Contract
AMOUNT: 31.2974% of Payson's 11.7470% Payson Project Entitlement Share giving
Truckee Donner 3.6765% Entitlement Share and leaving Payson with 8.0705%
Entitlement Share
4,118 kW @ Sweet Spot(112 MW)
5,000 kW @ PMAX(136 MW)
PRICE: Nebo All-In Cost plus a one time fee of$164,287 upon consummation of the
permanent entitlement share transfer
OTHER PROVISIONS:
Seller agrees that it will reserve the above noted amount of its Payson Project Entitlement Share
for Buyer
Buyer must abide by the provisions of the Payson Power Sales Contract and Operating and
Scheduling Procedures (attached).
Buyer will pay the UAMPS transmission rate, administration and scheduling fees as adopted by the
Board of Directors from time to time and any other costs, if any, that UAMPS may incur in the
performance of this Pooling Appendix.
In the case of the loss of available transmission capacity or lack of a displacement resource that is
available to UAMPS, the resource will be purchased by the UAMPS all-in pool at all-in cost up to
the aggregate needs of the UAMPS All-In Pool or the UAMPS unplanned pool at the UAMPS Mona
"market sell" price. Buyer will also be responsible to pay costs of ancillary services such as
Reserves, if any, required for or associated with firm delivery pursuant to Sierra Pacific delivery
requirements.
Buyer will be responsible for 5.8% transmission losses on the Northern Transmission System
(Mona to Gonder)for delivery to Truckee's Point of Receipt at Gonder on their Network Service
Agreement with SPPC.
This Appendix may be signed in counterpart.
Dated this day of , 2008.
SELLER: BUYER:
APPROVED BY:
UAMPS