Dams and Hydroelectricity in the Columbia
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BRIDGEPORT STATE PARK Chief Joseph Dam, Washington
BRIDGEPORT STATE PARK Chief Joseph Dam, Washington Sun Shelter and Play Area Group Camp Fire Circle Bridgeport State Park, located on systems; landscaping; and the Columbia River at Chief Joseph sprinkler irrigation. Osborn Pacific Dam, was an existing development Group provided complete design composed of a boat launch, services followed by completion campground, temporary of bid documents for the park and administration area, and day-use recreation amenity features, and group-use areas. The park was buildings, landscape architecture, created subsequent to the Chief and sprinkler irrigation. Joseph Dam construction and was Subconsultants provided civil, Picnic Shelter built by the U.S. Army Corps of structural, mechanical, and Engineers. The park is maintained electrical engineering. Site: Approximately 400 acres of rolling and operated by Washington State arid topography on shore of Rufus Parks. Woods Lake. Approximately 30 acres Project: is developed. Osborn Pacific Group Inc. was Bridgeport State Park Services: Client: retained by the U.S. Army Corps of Final design, construction documents, US Army Corps of Engineers, Seattle and cost estimate of park and Engineers to provide design District recreation amenity features, buildings, services and prepared construction Location: landscape architecture, and sprinkler documents for a $1.4 million park Chief Joseph Dam, Columbia River, irrigation. Contract administration expansion project. Features Washington and coordination for civil, structural, mechanical, and electrical included: upgrading and expanding engineering. recreation vehicle campground area, day-use picnic area and swim beach development; group camp area development; pedestrian and handicapped access trails; ranger residence; maintenance building; restrooms and shelters; roads; water, sanitary, and electrical . -
Kootenay System Operations
Columbia River Treaty Review – Technical Studies Appendix C Kootenay System Operations Operation of the Kootenay River system is complicated as it is administered by several different jurisdictions and the hydroelectric facilities are owned by different agencies/companies. As shown in Figure 1, the Kootenay River originates in the Rocky Mountains not far from Field, BC. The river flows south, within a few km of the source of the Columbia River at Canal Flats, and then continues south into Koocanusa Reservoir, formed behind Libby Dam in Montana, United States. From Libby, the Kootenay River turns west and north, and re-enters British Columbia near the community of Creston, flowing into the south arm of Kootenay Lake. In the northern part of the Kootenay basin, the Duncan River is joined by the Lardeau River just downstream from Duncan Dam, and then flows into the north arm of Kootenay Lake. Water from the north and south arms of Kootenay Lake then flows through the west arm of the lake and past the Corra Linn Dam near Nelson (as well as other dams) en route to the Columbia–Kootenay confluence at Castlegar. The components of this system and various agreements/orders that regulate flows are described in this Appendix. November 29, 2013 1 Columbia River Treaty Review – Technical Studies Figure 1: Kootenay and Columbia Region November 29, 2013 2 Columbia River Treaty Review – Technical Studies 1.0 Coordination of Libby Operations Background Under the terms of the Columbia River Treaty, Canada permitted the U.S. to build the Libby Dam on the Kootenai River (U.S. -
Order in Council 93/2005
PROVINCE OF BRITISH COLUMBIA ORDER OF THE LIEUTENANT GOVERNOR IN COUNCIL Order in Council No. , Approved and Ordered FEB 1 1 2005 et drguustratel Executive Council Chambers, Victoria Administrato On the recommendation of the undersigned, the himagiTtitWebVefflor, by and with the advice and consent of the Executive Council, orders that the Public Sector Employers Regulation, B.C. Reg. 408/93, is amended according to the attached schedule. bi 01 Minister of Finance Presiding . mber the Executive Council (This part is for administrative purposes only and is not part of the Order.) Authority under which Order is made: Act and section:- Public Sector Employers Act, R.S.B.C. 1996, c. 384, s. 15 Other (specify):- order in council 1647/93 January 13, 2005 re sub 4-1/2005/13 page 1 of 2 SCHEDULE I The Public Sector Employers Regulation, B.C. Reg. 408/93, is amended in section 2, in the list of employers designated for the purposes of paragraph (b) of the definition of "public sector employer" in the Act, (a) by striking out the following: British Columbia Ferry Corporation Okanagan Valley Tree Fruit Authority Pacific National Exhibition Science Council of British Columbia Victoria Line Ltd. , and (b) by adding the following: BC Games Society BC Immigrant Investment Fund Ltd. BC Innovation Council B.C. Investment Fund Ltd. B.C. Safety Authority BC Transportation Financing Authority BCIF Management Ltd. British Columbia Pavilion Corporation British Columbia Transmission Corporation British Columbia Utilities Commission Columbia Basin Trust Columbia Power Corporation First Peoples' Heritage, Language & Culture Council Forestry Innovation Investment Ltd. Homeowner Protection Office Industry Training Authority Oil & Gas Commission Organized Crime Agency of British Columbia Partnerships British Columbia Inc. -
Electrical Service Information Form
Electrical Service Information Form Date: (DD/MM/YY) Service address (full address and postal code if available) Project name Legal description BC Hydro Reference # Anticipated energization date: Owner information Name Mailing address Email address Address line 2 Phone/Cell # GST# Technical contact persons Name Email address Phone no. Electrical contractor Electrical consultants General contractor Building and electrical details Building state: New Existing Proposed use of building: Permanent service Temporary service Number of hours of operation per day: Number of operational days per week: Main switch size: amps Code peak demand: kW Your Designer may inquire further about your computation 80% rated 100% rated (BC Hydro approval required) for the code demand Voltage: volts Average operating demand: kW Largest motor: hp Time of day of peak demand: AM PM Fire pump: No Yes - Size Building heated by: Gas Electric Heat pump - Locked Rotor Amp A Electric furnace Other On-site customer-owned generation: No Yes—open transition Yes—closed transition Requested service type: Overhead Underground Load details Existing (if applicable) New Electric heating load kW kW Lighting load kW kW Heat pump including geothermal kW kW Air conditioning motor load kW kW Electric vehicle charging load kW kW Other motor load kW kW Other load kW kW Total connected load kW kW Proposed future load kW kW Metering Information Total number of meters Residential: Commercial: Voltage: Meter type: 120/240 120/208 347/600 TBD 1 Phase 3 Phase TBD Meter details Other: Temporary master metering required Number of wires: Yes No Current transformer Bar CT lugs conductor size: x Window TBD CT type: Conductor to CT lugs: Cu Al Energization ○ Energization of the project will be scheduled upon receipt of: • Necessary approvals, permits from appropriate authorities, including municipal, electric inspection and other utilities. -
Idaho Power Company's Fall Chinook Salmon Hatchery
IDAHO POWER COMPANY’S FALL CHINOOK SALMON HATCHERY PROGRAM Stuart Rosenberger, Paul Abbott, James Chandler 1221 W. Idaho St., Boise, Idaho Background The current Idaho Power Company (IPC) fall Chinook salmon program was established to provide mitigation for losses associated with the construction and operation of Brownlee, Oxbow, and Hells Canyon dams which together form the Hells Canyon Complex. IPC’s current mitigation goal is to produce 1 million fall Chinook salmon smolts annually (see Origination of Idaho Power Company’s Hatchery Mitigation Program section for more details). Oxbow Hatchery, funded by IPC and operated by the Idaho Department of Fish and Game, is responsible for the incubation and rearing of up to 200,000 subyearling fall Chinook salmon. The hatchery is located on the Snake River downstream of Oxbow Dam near the IPC village known as Oxbow, Oregon (Figure 1). IPC also contracts with the Oregon Department of Fish and Wildlife (ODFW) for the production of an additional 800,000 subyearling fall Chinook salmon that were originally reared at ODFW’s Umatilla Hatchery and are now reared at ODFWs’ Irrigon Hatchery, both of which are located near the town of Irrigon, Oregon. Fish reared at both Oxbow and Umatilla/Irrigon hatcheries are released into the Snake River directly below Hells Canyon Dam with the exception of brood years 2003 to 2005 in which some of the production was released at the Nez Perce Tribe’s Pittsburg Landing acclimation facility. Similar to other fall Chinook salmon programs in the Snake Basin, Oxbow and Umatilla/Irrigon hatcheries receive eyed eggs from Lyons Ferry Hatchery, as it is one of only two broodstock holding and spawning facilities for fall Chinook salmon in the Snake Basin. -
Spring Chinook Salmon Dworshak National Fish Hatchery Clearwater River, Idaho
Spring Chinook Salmon Dworshak National Fish Hatchery Clearwater River, Idaho Howard Burge Ray Jones U.S. Fish and Wildlife Service Idaho Fishery Resource Office Ahsahka, Idaho Idaho Washington NF Clearwater River Clearwater Lower Hatchery Columbia Lower Little Goose Granite Monumental Dam Dam Dam Dworshak Dam Clearwater R Dworshak Lochsa R River Snake NFH River Lewiston Kooskia IDFG Ice Harbor NFH Satellites Dam Selway River Rapid R Hatchery Hells Canyon Dam Oxbow Dam SF Clearwater McNary Brownlee Dam Dam Oregon Salmon River Program Goals 9,135 adults above Lower Granite Dam Harvest of 36,500 in ocean, Columbia River, and Lower Snake River fisheries Original production goal of 1.4 mil smolts Current production goal of 1.05 mil smolts - changed in 1996 Management Objectives Provide sport & tribal fishing opportunities in the Lower Clearwater River Return adequate broodstock to meet production needs Minimize impacts to natural populations Assist other programs in the Clearwater basin M & E Objectives Evaluate the effectiveness of the program so that it can be managed adaptively Determine the total adult return to assess if the program is meeting its mitigation goals Document and communicate programs success at meeting its program and management goals Coordinate hatchery and R,M & E activities Lewiston Dam 1929-1972 Leavenworth NFH 1983 - 86 Little White NFH 1983 & 85 1989 - 2010 Dworshak NFH Kooskia NFH 1995 Rapid River SH 1987 & 88 Broodstock sources and years Dworshak Spring Chinook Broodstock 50:50 ratio of males to females Approximately 65% of returning adults are 2-ocean Average size of a 2-ocean adult is 29 inches Average pre-spawn mortality (1995-2010) 3.1% Chinook arrive ~ May - August Spawning ~ late Aug - early Sept Juvenile Performance Rearing ~ approx. -
INDC TR-2018-02, "Exterior Lighting for Navigation Locks and Dams
03 - 2018 - INDC TR Standardization and Sustainability Initiative Renewable Energy Applications for Locks and Dams Standardization and Sustainability Charlie Allen, Nicholas M. Josefik, Edith Martinez-Guerra, March 2018 and Stefan Miller Center McNary Dam, Oregon Inland Navigation Design Design Navigation Inland Approved for public release; distribution is unlimited. The Inland Navigation Design Center (INDC) develops solutions to complex en- gineering problems for the nation’s inland waterways to serve the Army, the Depart- ment of Defense, Federal Agencies and the Nation. To find out more about the Inland Navigation Design Center please visit: https://apps.usace.army.mil/sites/TEN/IND/Pages/default.aspx Standardization and Sustainability Initiative INDC TR-2018-03 March 2018 Renewable Energy Applications for Locks and Dams Standardization and Sustainability Gerald C. Allen Hydroelectric Design Center U.S. Army Corps of Engineers Portland District 333 SW 1st Ave Portland, OR 97204-1290 Nicholas M. Josefik U.S. Army Engineer Research and Development Center (ERDC) Cold Regions Research and Engineering Laboratory (CRREL) 72 Lyme Road Hanover, NH 03755-1290 Edith Martinez-Guerra U.S. Army Engineer Research and Development Center (ERDC) Environmental Laboratory (EL) Waterways Experiment Station, 3909 Halls Ferry Road Vicksburg, MS 39180-6199 Stefan M. Miller U.S. Army Corps of Engineers Mississippi Valley Division New Orleans District 7400 Leake Ave. New Orleans, LA 70118-3651 Final Report Approved for public release; distribution is unlimited. Prepared for U.S. Army Corps of Engineers Washington, DC 20314-1000 Monitored by USACE Inland Navigation Design Center INDC TR-2018-03 ii Abstract This report provides a standardized approach for gauging the feasibility of potential solar, wind, and hydropower projects for application at U.S. -
Coe Portland District (Nwp) Hydropower Projects
Updated March 30, 2021. Use the appropriate district distribution list below when submitting a System Operational Request (SOR). COE PORTLAND DISTRICT (NWP) HYDROPOWER PROJECTS COE SEATTLE DISTRICT (NWS) HYDROPOWER PROJECTS Bonneville Dam & Lake on Columbia River Libby Dam & Lake Koocanusa on Kootenai River The Dalles Dam & Lake Celilo on Columbia River Hungry Horse Dam & Lake on South Fork Flathead River John Day Dam & Lake Umatilla on Columbia River Albeni Falls Dam & Pend Oreille Lake on Pend Oreille River Chief Joseph Dam and Rufus Woods Lake on Columbia River Corps of Engineers Northwestern Division (NWD) Corps of Engineers Northwestern Division (NWD) SEATTLE DISTRICT (NWS) PORTLAND DISTRICT (NWP) TO: TO: BG Pete Helmlinger COE-NWD-ZA Commander BG Pete Helmlinger COE-NWD-ZA Commander COL Alexander Bullock COE-NWS Commander COL Mike Helton COE-NWP Commander Jim Fredericks COE-NWD-PDD Chief Jim Fredericks COE-NWD-PDD Chief Steven Barton COE-NWD-PDW Chief Steven Barton COE-NWD-PDW Chief Tim Dykstra COE-NWD-PDD Tim Dykstra COE-NWD-PDD Julie Ammann COE-NWD-PDW-R Julie Ammann COE-NWD-PDW-R Doug Baus COE-NWD-PDW-R Doug Baus COE-NWD-PDW-R Aaron Marshall COE-NWD-PDW-R Aaron Marshall COE-NWD-PDW-R Lisa Wright COE-NWD-PDW-R Lisa Wright COE-NWD-PDW-R Jon Moen COE-NWS-ENH-W Tammy Mackey COE-NWP-OD Mary Karen Scullion COE-NWP-EC-HR Lorri Gray USBR-PN Regional Director Lorri Gray USBR-PN Regional Director John Roache USBR-PN-6208 John Roache USBR-PN-6208 Joel Fenolio USBR-PN-6204 Joel Fenolio USBR-PN-6204 John Hairston BPA Administrator Kieran Connolly BPA-PG-5 John Hairston BPA Administrator Scott Armentrout BPA-E-4 Kieran Connolly BPA-PG-5 Jason Sweet BPA-PGB-5 Scott Armentrout BPA-E-4 Eve James BPA-PGPO-5 Jason Sweet BPA-PGB-5 Tony Norris BPA-PGPO-5 Eve James BPA-PGPO-5 Scott Bettin BPA-EWP-4 Tony Norris BPA-PGPO-5 Tribal Liaisons: Jr. -
2018 Integrated Resource Plan
DRAFT 2018 Integrated Resource Plan Public Utility District No. 1 of Benton County PREPARED IN COLLABORATION WITH Resolution No. XXXX Contents Chapter 1: Executive Summary ..................................................................................................................... 1 Obligations and Resources ........................................................................................................................ 1 Preferred Portfolio .................................................................................................................................... 4 Chapter 2: Load Forecast .............................................................................................................................. 6 Chapter 3: Current Resources ....................................................................................................................... 7 Overview of Existing Long-term Purchased Power Agreements ............................................................... 7 Frederickson 1 Generating Station ........................................................................................................ 7 Nine Canyon Wind ................................................................................................................................. 7 White Creek Wind Generation Project .................................................................................................. 8 Packwood Lake Hydro Project .............................................................................................................. -
BC Hydro's Response to Intervener Information Requests Round 4
Fred James Chief Regulatory Officer Phone: 604-623-4046 Fax: 604-623-4407 [email protected] November 14, 2019 Mr. Patrick Wruck Commission Secretary and Manager Regulatory Support British Columbia Utilities Commission Suite 410, 900 Howe Street Vancouver, BC V6Z 2N3 Dear Mr. Wruck: RE: Project No. 1598990 British Columbia Utilities Commission (BCUC or Commission) British Columbia Hydro and Power Authority (BC Hydro) Fiscal 2020 to Fiscal 2021 Revenue Requirements Application (the Application) BC Hydro writes in compliance with Commission Order No. G-279-19 to provide its responses to Round 4 information requests as follows: Exhibit B-22 Responses to Commission IRs (Public Version) Exhibit B-22-1 Responses to Commission IRs (Confidential Version) Exhibit B-23 Responses to Intervener IRs (Public Version) Exhibit B-23-1 Responses to Intervener IRs (Confidential Version) BC Hydro is filing a number of IR responses and/or attachments to responses confidentially with the Commission. In each instance, an explanation for the request for confidential treatment is provided in the public version of the IR response. BC Hydro seeks this confidential treatment pursuant to section 42 of the Administrative Tribunals Act and Part 4 of the Commission’s Rules of Practice and Procedure. Overall, BC Hydro received 327 Round 4 information requests. Responses to 260 of those information requests are included in this filing. Thirty-four information requests are the subject of BC Hydro’s letter of November 8, 2019 (the information requests at issue are listed in the attachment to that letter). They are being addressed through the comment process established by Order No. -
BC Hydro and Power Authority 2021/22
BC Hydro and Power Authority 2021/22 – 2023/24 Service Plan April 2021 For more information on BC Hydro contact: 333 Dunsmuir Street Vancouver, BC V6B 5R3 Lower Mainland 604 BCHYDRO (604 224 9376) Outside Lower Mainland 1 800 BCHYDRO (1 800 224 9376)] Or visit our website at bchydro.com Published by BC Hydro BC Hydro and Power Authority Board Chair’s Accountability Statement The 2021/22 – 2023/24 BC Hydro Service Plan was prepared under the Board’s direction in accordance with the Budget Transparency and Accountability Act. The plan is consistent with government’s strategic priorities and fiscal plan. The Board is accountable for the contents of the plan, including what has been included in the plan and how it has been reported. The Board is responsible for the validity and reliability of the information included in the plan. All significant assumptions, policy decisions, events and identified risks, as of February 28, 2021 have been considered in preparing the plan. The performance measures presented are consistent with the Budget Transparency and Accountability Act, BC Hydro’s mandate and goals, and focus on aspects critical to the organization’s performance. The targets in this plan have been determined based on an assessment of BC Hydro’s operating environment, forecast conditions, risk assessment and past performance. Doug Allen Board Chair 2021/22 – 2023/24 Service Plan Page | 3 BC Hydro and Power Authority Table of Contents Board Chair’s Accountability Statement ....................................................................................... -
Hells Canyon Complex Total Dissolved Gas Study
Hells Canyon Complex Total Dissolved Gas Study Ralph Myers Project Limnologist Sharon E. Parkinson Principal Engineer Technical Report Appendix E.2.2-4 March 2002 Revised July 2003 Hells Canyon Complex FERC No. 1971 Copyright © 2003 by Idaho Power Company Idaho Power Company Hells Canyon Complex Total Dissolved Gas Study TABLE OF CONTENTS Table of Contents ............................................................................................................................. i List of Tables...................................................................................................................................ii List of Figures .................................................................................................................................ii List of Appendices .........................................................................................................................iii Abstract ........................................................................................................................................... 1 1. Introduction ................................................................................................................................ 2 2. Study Area.................................................................................................................................. 3 3. Plant Operations ......................................................................................................................... 4 4. Methods.....................................................................................................................................