Loading...
HomeMy WebLinkAbout15 UAMPS Wind Projects Agenda Item #Public Utility District 15 u WORKSHOP To: Board of Directors From: Stephen Hollabaugh Date: May 07, 2008 Subject: Update on the Natural-gas Power Generation Contract, Rye Patch Geothermal and DAMPS Wind Projects 1. WHY THIS MATTER IS BEFORE THE BOARD This matter is before the Board to inform the Board of Natural Gas Power Generation Contract, an update on the Rye Patch Geothermal Project and possible future DAMPS wind projects. 2. HISTORY Natural Gas Power Generation: The Payson natural gas project is a UAMPS project Board and is owned by UAMPS members. This project has been discussed with the Boa 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. Rye Patch Geothermal Project: The District signed power purchase agreement in July of 2007 with Presco Energy who owns the Rye Patch geothermal plant and plans to repower the plant. Wind Generation: The District is a participant in the Resource Project at UAMPS. This project does some initial investigation of new generation resources that the members may be interested in. When a generation project shows interest, it will then enter the study phase. A Wind project in Idaho has been initially investigated. 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 been supplemented with more current spark spread 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 heat rate of this plant is conservatively 8400 which is a good hedge against the electric power market rates. 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. 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 (bonding security) 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. Staff will agendize the Nebo natural gas project transaction for an action item on the June 4th Board meeting. Rye Patch Geothermal Project update: Presco is progressing slowly toward the repowering of the plant. The District has received a progress report in November 2007 and more recently in April 2008. Presco's general contractor was to move to the site in early February. The substation work is moving forward while the transformer is scheduled to be re-gasketed and fixed by the end of May. Presco needs to re-drill the production well as a "kink" in the well was found. Rig availability is a remaining issue for the well work. Currently the earliest date for start-up is late 4th quarter 2008. Wind Generation: The Resource Committee at UAMPS requested letters be sent to members soliciting interest in the Idaho Wind project. (Letter attached) et. The Each participant would pay its pro rata share of the Study Projects initial budget. Idaho Wind project has an initial budget of $50,000. If the Study Project is oversubscribed, the participants' request will be prorated based on the participants' share entitlement in the Resource Project. This project shows good value for a wind project. The District is interested in 6000 kw of the study phase of this project. At a 31% capacity factor this would represent about 2000 kw of output generation. 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. The District will pay UAMPS its prorata portion of the initial budget of $50,000 for the Idaho Wind Study Project. 5. RECOMMENDATION Review this report and provide comments. �A I t•�M l *phenllabaugh, A istant General Michael D. Holley, General Manager Manager �y •r Y 4 o k. a ,h; .s w, N. e , ' "All At a >. F it s r r k=. 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, rage tanks and other ancillary facilities. The Project also includes on- water treatment facilities and sto site pipelines for natural gas and water supply,wastewater discharge piping, site access and parking. dispatch center for UAMPS and has 24-hour video monitoring and The Project provides aback-up 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 blowdown 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. 2 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 FPIant Name Owner (MW) (Btu/kWh) 1,166 ine oc tn wer t 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 West Valley 3 Rocky Mtn.Power 40 9,878 West Valley 4 Rocky Mtn.Power 40 9,878 West Valley 5 Rocky Mtn.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 Gadsby 1 Rocky Mtn.Power 60 13,495 Gadsby 2 Rocky Mtn.Power 75 13,495 Gadsby 3 Rocky Mtn.Power 100 13,495 Little Mountain Rocky Mtn.Power 14 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 $/MM13tu multiplied by the operational heat rate (HR) in Btu/NfWh). UAN1PS conservatively 3 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/M\Vh. 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 Q4-07 Q1-08 Q2-08 2008 2009 2010 8.00 $ 44.27 32.20 24.49 10.69 12.10 13.97 16.53 14.64 13.61 SS 8.20 $ 43.66 31.58 23.68 9.61 10.78 12.66 15.15 13.14 12.10 SS 8.30 $ 43.35 31.26 23.27 9.07 10.12 12.01 14.46 12.39 11.35 Full 8.40 $ 43.05 30.95 22.86 8.53 9.46 11.36 13.78 11.65 10.59 Full 8.45 $ 42,89 30.79 22.66 8.26 9.13 11.03 13.43 11.27 10.22 8.50 $ 42.74 30.64 22.46 7.99 8.80 10.70 13.09 10.90 9.84 tGrey= 12.50 $ 30.50 18.11 6.20 (13.67) (17.65) (15.44) (14.40) (18.98) (20.31) bo SweetSpot Full=Fully Loaded SC=Simple Cycle Green=ln the Money Red=Out of the Money 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 ('TV") 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 Ql-08 Q2.08 2008 2009 2010 2011 2012 2013 2014 2015 2016 OnPeak Mona $ 68.75 $57.25 $ 57.04 $54.00 $ 65.00 $66.25 $ 71.50 $74.40 $73.90 $72.15 $73.15 $73.90 $74.15 $74.65 $75.15 Weak Mona $ 47.00 $43.75 $ 44.00 $42.35 $ 52.00 $44.50 $ 50.50 $52.75 $52.25 $51,50 $52.00 $52.50 $52.75 $53.25 $54.00 Flat Mona $ 59.23 $51.34 $ 51.31 $48.90 $ 59.31 $56.73 $ 62.31 $64.93 $64.43 $63.12 $63.90 $64.54 $64.79 $65.29 $65.90 Flat PV $ 59.23 $51.34 $ 51.31 $50.34 $ 59.31 $56.73 $ 62.31 $64.93 $64.43 $63.12 $63.90 $64.54 $64.79 $65.29 $65.90 Flat MidC $ 53.66 $52.30 $ 53.69 $57.36 $ 63.50 $4522 $ 61.53 $63.93 $64.04 $62.82 $63.88 $64.38 $64.85 $65.35 $6s.10 4 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 Overall, UAMPS believes that the Project is a prudent market purchases of energy during HLH. 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. 5 Mona/ Nebo Spark Spread (On-Peak) (as of April 2008) ea Rate May June July Q3-08 Q4-08 Q1-09 2009 2010 20 8.2 5.48 13.08 37.85 32.26 6.58 8.40 17.79 16.21 13.7 SS 8.3 4.50 12.09 36.87 31.31 5.61 7.44 16.99 14.68 12.94 SS 8. 3.52 11.11 35.89 30.36 4.65 6 Full 8. 2.54 10.13 34.90 29.41 3.68 5.23 15.39 7.39 13-91 6.25 11.3 3.4 Full 9.5 (7.28) 0.29 25.07 19.93 (6.01) (4.02) 3.39 2.43 (0.45 10 (12.19) (4.63) 20.15 15.18 (10.85) (8.80) Sc 12. (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 Q4-08 2009 2010 2011 OnPeak Mona $ 78.00 $ 84.00 $ 93.00 $ 87.10 $ 113.50 $ 85.50 $ 84.60 $ 81.25 $ 81.25 54.25 OffPeak Mona $ 50.00 $ 52.00 $ 57.00 $ 53.00 $ 66.00 $ 58.00 $ 56.50 $ 53.22 $ 69 44 Flat Mona $ 65.75 $ 70.00 $ 77.25 $ 72.18 $ 92.72 $ 73.47 $ 72.31 $ 68.94 $ 69.16 Flat PV $ 65.75 $ 70.00 $ 77.25 $ 71.62 $ 91.03 $ 72.63 $ 72.0� $ 67.89 $ 69.31 Flat MidC $ 58.22 $ 46.69 $ 47.38 $ 51.07 $ 82.33 $ 79.20 $ 69 $ X8+24 LLH,January through December For WECC Standard Products:6X16,HLH;and 6 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 resourceup is m available to DAMPS, the resource will be purchased by the UAMPS all-in pool at all cos p 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 1W UAMWO 2825 E.Cottonwood Parkway Suite 200 Salt Lake City,Utah 84121-7077 Phone:801-566-3938 Toll Free:800-872-5961 Fax:801-561-2687 April 23,2008 SENT VIA E-MAIL Dear Resource Project Participant: The Resource Committee requested letters be sent to the Members soliciting interest in the Two Elks project located in Campbell County,20 miles southeast of Wright,Wyoming("Two Elks Study Project")and the Idaho Wind project (Idaho Wind Study"Project"). Two Elks Study Project a Coal fired power plant a 76 MW available a Mine mouth,non-commercial waste coal a Dry cooled a Take-and Pay Contract a 30 year term with optional purchase at year 10 Purchase price to be mutually agreed upon $100,000 initial budget Idaho Wind Study Prp ect 20 MW could possible increase to 50-60 MW a 31.41%capacity factor a UAMPS would procure,construct and own $50,000 initial budget Each Participant would pay its pro rata share of the Study Projects'initial budgets. If either of the Study Projects is oversubscribed,the Participants'request will be prorated based on the Participants'share entitlement in the Resource Project. Please indicate your interest in participating in the Two Elks Study Project and the Idaho Wind Study Project on the attached form and return the form via fax to me no later than May 16,2008. If you have any questions or need additional information,please contact me. Sincerely, ��ackie Coombs Customer Services Administrator Enclosure TWO ELKS AND IDAHO WIND STUDY PROJECTS Member: >� Please indicate below your desires to participate in: Two Elks Study Project [ ] We would like to participate in the investigation into Two Elks project at kW. We understand that we will be responsible for our pro rata share of the study costs incurred during the investigation. We also understand that if the project is oversubscribed it will be prorated based on our Resource Project Entitlement Share. �] We are not interested in participating in the Two Elks Study Project at this time. Idaho Wind Studv P roiect ] We would like to participate in the investigation of the Idaho Wind project 60M kW. We understand that we will be responsible for our pro rata share of the study costs incurred during the investigation. We also understand that if the project is oversubscribed it will be prorated based on our Resource Project Entitlement Share. [ ] We are not interested in participating in the Idaho Wind Study Project at this time. By its Date ©�