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Atqasuk Transmission Line Project Preliminary Engineering Report - Jun 2014 - REF Grant 7040023
't� November 30, 2014 Prepared By: Leland A. Johnson & Associates In Association With: Sakata Engineering Services ABR, Inc. Golder Associates, Inc Northern Economics RSA Engineering, Inc. Energy Audits of Alaska Atqasuk Transmission Line Project Preliminary Engineering Phase II Final Report June 30, 2014 Project Sponsors Alaska Energy Authority and North Slope Borough Prepared by: Leland A. Johnson & Associates In association with: Sakata Engineering Services ABR, Inc. Northern Economics Golder Associates, Inc RSA Engineering, Inc. Energy Audits of Alaska Atgasuk Transmission Line Project Executive Summary The North Slope Borough (NSB) is aggressively exploring and developing local energy resources to displace or reduce its dependency on the use of high costs imported fuel oil to meet their communities' heat and power needs. This effort, entitled "Atqasuk Transmission Line, Preliminary Engineering Phase II", is paid for with Alaska Energy Authority (AEA) funds made available through the Alaska Renewable Energy Fund Program, The AEA funds were granted to the NSB who, in turn, contracted with Leland A. Johnson and Associates as the prime contractor on the project. This project is the second phase of a project investigating the concept of connecting Barrow and Atqasuk with a 70 mile transmission line and using electricity produced in Barrow from its local natural gas supply to displace the imported fuel oil used in Atqasuk. The Final Report consists of this main report and a supplemental report entitled "Atqasuk Space Heating Conversion to Electric Heat Supplemental Report ". Due to the large volume of data, the details of the conversion study were placed in a separate final supplemental report The executive summary of the supplemental report is included in this main report as Section 6.0. Purpose and Benefits — The purpose of Phase II was to build on the results of phase I and adequately define the selected preferred power transmission concept so that the owners, end - users, financiers and responsible regulatory agencies could make appropriate decisions about advancing the project to a final design and construction phase. The key results of the study found that the project: • Has no technical "fatal flaws" • Use of a local energy source in Barrow provides significant cost savings over the continued use of imported diesel fuel in Atqasuk • Provides Atqasuk with a long-term steady source of reliable, higher quality power at a stable price • On an environmental level, eliminates particulate and noise pollution; significantly reduces air emissions pollutants responsible for global warming; reduces the potential of costly oil and glycol spills • Economies of scale achieved by the project are estimated to increase both the power load and the natural gas demand in Barrow without the need for additional equipment or personnel, thus reducing the unit cost of producing power and delivering gas in Barrow. Route Selection and Agency Input - The proposed Barrow—Atqasuk Powerline route crosses wetlands and several important avian habitats. These include the main nesting areas of Stellar and Spectacled Eiders, which are listed under the Endangered Species Act. It also includes the habitat of the yellow -billed loon, a species of conservation concern. Of great concern is that the highest concentration of Steller Eiders occurs just south of Barrow. The Eastern Route, developed in Phase I Feasibility Study 2011, was selected as the preferred route due to the fact it was the most friendly to avian habitation. This route was advanced in this study and designated as Option 1. ii Preliminary Engineering — Final Report -Z- .. '• : June 30, 2014 Atclasuk Transmission Line Project The Project Team held two meetings with both the Bureau of Land Management (BLM) and the US Fish and Wildlife Service (USF&W) in attendance. The BLM is reserving their final determinations until they can review the final design. However, they feel strongly that the project will require an Environmental Impact Statement (EIS) instead of a shorter Environmental Assessment (EA). The USF&W, on the other hand, provided the project team with the following written recommendations: 1. Design the line near Barrow to have all three conductor phases in the same elevation. Do not use crossarms. This option resulted in a three -pole structure; 2. Construct the power line with a 40 to 50 feet ground clearance to avoid the common flight altitudes of bird species. Based on USF&W's input, a second option to the Eastern Route was developed. Designated as Option 2, it impacts approximately 30% of the total transmission line distance of 71.9 miles. Capital Costs — Results of the capital cost upgrades are presented in the table below. Costs represent costs associated with Options 1 and 2 and their three alternatives: Table A Estimated Capital Costs of the Proposed Project Alternatives (2013 $) Alternatives Environmental Powerline Construction Powerline Engineering/ Heating Conversion Total Costs Studies Cost Construction Costs Management Option 1 Electric Power Only $670,000 $18,539,225 $2,224,707 $0 $21,433,931 Electric Power and Heat (Residential & Commercial) $670,000 $18,684,185 $2,242,102 $4,676,120 $26,272,407 Electric Power and Heat (Residential only) $670,000 $18,684,185 $2,242,102 $2,800,676 $24,396,963 Option 2 Electric Power Only $670,000 $20,705,790 $2,484,695 $0 $23,860,485 Electric Power and Heat (Residential and Commerci; $670,000 $20,850,750 $2,502,090 $4,676,120 $28,698,960 Electric Power and Heat (Residential only) $670,000 $20,850,750 $2,502,090 $2,800,676 $26,823,516 Preliminary Transmission Line Design Line Voltage: The electric power consumption for Atqasuk was 3,473,400 kWh for FY 13 with a peak load of 6011W. With the project, the total consumption for power and heat equals 13,202,246 kWh with a peak demand of 2,360 kW. For the best line loss characteristics the 69 kV voltage option was selected along with the Hawk/ACSS/AW 477MCM conductor. Together the line loss is calculated at 1.72%. Structure: The modular fiber -reinforced polymer (FRP) utility pole system was selected for this study. Compressive freeze/thaw stress tests and adfreeze bond strength tests were Preliminary Engineering — Final Report -" ••- :• • • June 30, 2014 Atqasuk Transmission Line Project conducted on the FRP and other materials. The FRP pole material was found to be suitable for operation in an Arctic permafrost environment. The light weight and modularity of the FRP poles, in lieu of heavier timber or steel pole systems, provide for ease of transport and installation, resulting in lower cost and reduced time of installation. Foundation: The geotech investigations looked at several FRP pole foundation alternatives. The pole direct set method using drill and slurry was selected as the most cost effective option. Climate change was also considered. Initial estimates based on Modified Berggren analysis indicate an additional 1 to 1.5 feet of surface thaw can occur over the next 30 years within the Barrow/Atqasuk area. Taking this information into account, the drill depth was set at 12 feet below grade for the FRP pole. Economic Analysis - The results of the economic analysis indicate that Engineering Concept Option 1 with electric power and heat for residential and commercial structures has the highest net benefit, with an NPV of cost savings of $62 million over the 35 year life of the project. Table B Net Present Value of Cost Savings of the Proposed Project Alternatives Electricity Generation Alternatives Option 1 Option 2 Electric Power only 38,822,669 36,568,720 Electric Power and Heat (Residential and Commercial Structures) 62,148,917 59,894,967 Electric Power and Heat (Residential Structures Only) 44,830,160 42,576,210 Note: the above analysis assumes a 35 year life. Operations - The NSB will operate and maintain the transmission line. It's estimated the maintenance of the line will cost the Borough about $125,920 annually. The impact of the project on Barrow and Atqasuk's existing energy and power systems are minimal: • There is no appreciable impact of the line on the Barrow Gas Field's reserves or ability to deliver gas at peak demands of the project. • The impact on the Barrow Utilities and Electric Cooperative's (BUECI) Power Plant to meet peak demand caused by the project is also minimal. If desired, peak shaving can be added to the SCADA system to control several NSB facilities heating loads in Atqasuk from the BUECI power plant. • In Atqasuk, since the peak load of the project is estimated at 2359 KW and the existing power plant has a generating capacity of 3,370 KW, the power plant is large enough to provide 100% backup for both electric power and space heat if necessary. • In addition, the homes and buildings will retain their oil fired equipment for additional space heating backup. Recommendations - For both transmission line options, the project is technically feasible. Option 1 provides the greater savings. Option 2 incorporates agency review recommendations. Selection of either option will be determined by the agencies involved �� iv Preliminary Engineering — Final Report- • •• • • June 30, 2014 Atgasuk Transmission Line Project after the project produces a final design. It is recommended the project be advanced to the final design / construction phase. A project development schedule would be as follows: • Initial engineering and geotechnical surveys will be performed in the spring and summer of 2015. Design will continue through 2015, providing the environmental consultants and agencies the design data they need to perform their work. • The environmental permits and studies are assumed to take place during 2015 and 2016. • Construction of the intertie is assumed to take place during 2017 and 2018, with capital costs varying by alternatives as shown in the Table A above. Corresponding engineering and construction management activities will occur over the same period. • The Atqasuk heating equipment conversion would occur in 2018. v Preliminary Engineering — Final Report .'� �•• -• :� June 30, 2014 Atqasuk Transmission Line Project Contents TitlePage.................................................................................................................................... i ExecutiveSummary...................................................................................................................ii Contents.................................................................................................................................... vi 1.0 Introduction...................................................................................................................... 1-1 1.1 Background................................................................................................................ 1-1 1.2 Final Report Organization......................................................................................... 1-4 1.3 Study Approach......................................................................................................... 1-5 1.4 Project Sponsors and Organization............................................................................ 1-5 1.5 Project Description.................................................................................................... 1-7 2.0 Agency Review................................................................................................................ 2-1 2.1 Background................................................................................................................ 2-1 2.2 Agency Meetings....................................................................................................... 2-1 2.3 Agency Recommendations.................................................................. 2-2 3.0 Geotechnical Assessment................................................................................................ 3-1 3.1 Background................................................................................................................ 3-1 3.2 Regional Setting and Climate.................................................................................... 3-1 3.2.1 General Climate Trends.................................................................................... 3-2 3.3 Preliminary Terrain Unit Mapping............................................................................ 3-4 3.3.1 Soil Unit Properties........................................................................................... 3-4 3.3.2 Thaw Bulbs and Thermal Considerations......................................................... 3-8 3.4 Ice Jams and Snow Drifts.......................................................................................... 3-8 3.5 Conclusions.............................................................................................................. 3-11 4.0 FRP Pole Testing............................................................................................................. 4-1 4.1 Background................................................................................................................ 4-1. 4.2 Test Methodology...................................................................................................... 4-1 4.3 FRP Pole Freeze -Thaw Testing Procedure for Compressive Stress .......................... 4-2 4.3.1 Testing Procedure............................................................................................. 4-2 4.3.2 Data Analysis.................................................................................................... 4-7 4.3.3 Results and Conclusions................................................................................... 4-8 4.4 FPR Adfreeze Bond Strength Testing..................................................................... 4-11 4.4.1 Testing Procedure........................................................................................... 4-11 4.4.2 Test Conclusions............................................................................................. 4-15 vi Preliminary Engineering -- Final Report • ••- :r • June 30, 2014 Atgasuk Transmission Line Project 4.5 Pole Foundation....................................................................................................... 4-18 5.0 Pole Height with Regard to Eider Collision Hazard........................................................ 5-1 5.1 Background................................................................................................................ 5-1 5.2 Methodology.............................................................................................................. 5-1 5.3 Powerline Height and Bird Collision......................................................................... 5-2 5.4 Overhead Lines and Bird Behavior........................................................................... 5-3 5.5 Flight Behavior of Birds in the Study Area............................................................... 5-4 5.6 Migration Behavior: Spatial Patterns......................................................................... 5-4 5.7 Migration Behavior: Flight Altitudes........................................................................ 5-5 5.8 Data from Tundra of Northern and Western Alaska ................................................. 5-6 5.9 Conclusions.............................................................................................................. 5-11 6.0 Atgasuk Space Heating Conversion to Electric Heat ...................................................... 6-1 6.1 Background................................................................................................................ 6-1 6.2 Objectives.................................................................................................................. 6-3 6.3 Site Visit and Data Gathering.................................................................................... 6-3 6.3.1 Benchmark Periods for Electric and Fuel Oil Consumption ............................ 6-3 6.3.2 Building Summary ............................................................................................ 6-4 6.3.3 Installed Capacity............................................................................................. 6-5 6.3.4 Conservative Assumptions and Safety Factor .................................................. 6-5 6.4 Existing Conditions — Fuel Oil.................................................................................. 6-8 6.5 Existing Conditions — Electrical.............................................................................. 6-10 6.6 Limitations of this Study......................................................................................... 6-11 6.7 New Power Requirements and Peak Demand......................................................... 6-12 6.8 Sensitivity of Results to Input Variances................................................................. 6-14 6.9 Cost Summary ......................................................................................................... 6-15 6.9.1 Basis of Design — Residences and Small Commercial Buildings ................... 6-15 6.9.2 Basis of Design — Large Commercial Buildings ............................................ 6-16 6.10 Technical Issues..................................................................................................... 6-16 7.0 Update Transmission Line Cost Estimate........................................................................ 7-1 7.1 Background................................................................................................................ 7-1 7.2 Route Selection.......................................................................................................... 7-2 7.2.1 Agency Impact.................................................................................................. 7-4 7.3 Preliminary Engineering Design Basis...................................................................... 7-4 7.3.1 System Voltage................................................................................................. 7-5 7.3.2 Structure Types................................................................................................. 7-5 7.3.3 Pole Installation................................................................................................ 7-8 7.3.4 Conductor Selection.......................................................................................... 7-9 .:' :.. i rrli Preliminary Engineering June 30, 024 A Atqasuk Transmission Line Project 7.3.5 One Line Description for AC Operation........................................................ 7-16 7.4 Estimated Costs of Construction............................................................................. 7-19 7.4.1 Physical Description....................................................................................... 7-19 7.4.2 Basis of Estimate............................................................................................ 7-20 7.4.3 Construction Costs.......................................................................................... 7-21 7.5 Transmission Line Operations and Maintenance.................................................... 7-27 7.5.1 Remote Monitoring and Multiple Boiler Control System .............................. 7-27 7.5.2 Maintenance Program..................................................................................... 7-27 7.5.3 Maintenance Costs.......................................................................................... 7-29 8.0 Power and Energy Supply Evaluation............................................................................. 8-1 8.1 Overview................................................................................................................... 8-1 8.2 Power and Heating Systems in Atqasuk .................................................................... 8-2 8.2.1 Power Plant Description................................................................................... 8-2 8.2.2 Atqasuk Fuel Oil Facilities............................................................................... 8-3 8.2.3 Project Impact................................................................................................... 8-4 8.3 Barrow Electric Power Facilities............................................................................... 8-7 8.3.1 BUECI Plant Description................................................................................. 8-7 8.3.2 Project Impact................................................................................................... 8-8 8.4 Barrow Gas Fields.................................................................................................. 8-10 8.4.1 Gas Fields Description.................................................................................... 8-10 8.4.2 Project Impact................................................................................................. 8-11 8.5 Conclusions.............................................................................................................. 8-12 9.0 Update Economic Analysis.............................................................................................. 9-1 9.1 Overview.................................................................................................................... 9-1 9.2 Methodology and Assumptions................................................................................. 9-5 9.3 "Without Project" Case: Diesel -Based Power Generation and Heating System....... 9-6 9.3.1 Existing Atqasuk Energy Profile...................................................................... 9-6 9.3.2 Annual O&M Costs.......................................................................................... 9-7 9.3.3 Replacement and Overhaul Costs for Diesel Generator Units ......................... 9-9 9.3.4 Summary of Cost Flows Associated With the Existing Diesel -Based Power and Heating Systems ("Without Project" Case) .................................................... 9-9 9.4 Proposed Intertie Project Alternatives: "Without Project" Case ............................. 9-10 9.4.1 Estimated Cost of the Proposed Project Alternatives ..................................... 9-11 9.4.1.1 Project Capital Costs.............................................................................. 9-11 9.4.1.2 Annual Maintenance Costs for the Powerline....................................... 9-11 9.4.2 Cost of Purchasing Electricity from Barrow .................................................. 9-12 9.4.3 Annual O&M Costs of Atqasuk Facilities...................................................... 9-13 9.5 Financing Costs....................................................................................................... 9-14 Viii Preliminary Engineering — Final Report 17_1 . .:- ... June 30, 2014 Atclasuk Transmission Line Project 9.5.1 Results of NPV of Cost Savings after Financing Costs .................................. 9-15 9.6 Conclusions.............................................................................................................. 9-16 10.0 Conclusions and Recommendations............................................................................ 10-1 10.1 Conclusions............................................................................................................ 10-1 10.1.1 Overview....................................................................................................... 10-1 10.1.2 Major Issue Facing the Project..................................................................... 10-3 10.1.3 Avian Protective Measures........................................................................... 10-4 10.2 Recommendations.................................................................................................. 10-5 10.2.1 Project Development Schedule..................................................................... 10-6 11.0 References.................................................................................................................... 11-1 Appendix A — Minutes of Oct 28 and Nov 7 Agency Review Meetings Appendix B — USFWS Written Recommendations Appendix C — Federal Permit Form Appendix D — Ice Jam Reports Appendix E — RS Composite Utility Poles Brochure Appendix F — Summary of Particle Size Distribution Results Appendix G - Summary Infrastructure and Main Conclusions of Powerline-Avian Interaction Studies Relevant to the Proposed Barrow-Atqasuk Powerline Appendix H - Conductor Loading and Overload Factors Appendix I — Walakpa Distribution Report Appendix J — Cost Estimate Appendix K - Public Law 98-366 the Barrow Gas Field Transfer Act of 1984 Appendix L — Project Development Schedule List of Tables Table 3-1 Average and Design Thawing and Freezing Indices ....................................... 3-3 Table 3-2 Summary Soil Unit Properties......................................................................... 3-7 Table 3-3 Ice Jams Database for Atqasuk 2006-2012................................................... 3-10 Table 4-1 Freeze/Thaw Test Details................................................................................ 4-7 Table 4-2 Soil Properties of Various Slurry Materials .................................................. 4-12 Table 5-1 Taxonomic Groups Used in Data Summary for Flight Altitudes of Birds in Northern and Western Alaska, 1997-2006................................................................ 5-7 Table 6-1 Total Installed Capacity...................................................................I.............16-5 Table 6-2 Average Fuel Consumption FY2012 & FY2013............................................ 6-8 Table 6-3 Average Electrical Consumption of FY2012 & FY2013 .............................. 6-10 Table 6-4 Power Required by Phase.............................................................................. 6-13 Table 6-5 Summary of Building Conversion Costs ....................................................... 6-15 ix Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project Table 7-1 ACSS/AW Conductor Specifications............................................................ 7-10 Table 7-2 Recommended Conductor Tension Limits .................................................... 7-14 Table 7-3 Conductor Sag and Tension Data.................................................................. 7-15 Table 7-4 Conductor Ground Clearance........................................................................ 7-17 Table 7-5 Cost Estimate Summary for Options 1&2..................................................... 7-26 Table 8-1 Energy Source Comparison............................................................................. 8-1 Table 8-2 Cost per kWh with Project.............................................................................. 8-5 Table 8-3 Atqasuk Annual Air Pollutants Calculations.................................................. 8-6 Table 8-4 BUECI Historical Energy Data....................................................................... 8-9 Table 8-5 Barrow Gas Fields Deliverability.................................................................. 8-12 Table 9-1 Net Present Value of Cost Savings of the Proposed Project Alternatives ...... 9-2 Table 9-2 Benefit -Cost Ratios of the Proposed Project Alternatives .............................. 9-3 Table 9-3 Estimated Payback Periods of the Proposed Project Alternatives .................. 9-5 Table 9-4 Diesel Fuel Consumption in Atqasuk, FY 2013............................................. 9-7 Table 9-5 Annual O&M Costs of NSB Power and Fuel Facilities, FY 2013.................. 9-8 Table 9-6 Annual Costs Incurred in Selected Future Years under the :Without Project" Case (2013 $ millions)............................................................................................. 9-10 Table 9-7 Estimated Capital Costs of the Proposed Project Alternatives (2013 $)....... 9-12 Table 9-8 Annual Electricity Requirements and Cost of Purchased Electricity from Barrow..................................................................................................................... 9-13 Table 9-9 Estimated Annual Fuel Costs for Power and for Heating under Various Scenarios.................................................................................................................. 9-14 Table 9-10 Estimated Annual Non -Fuel Costs for Utility Operations and Maintenance Facilities in Atqasuk under Various Scenarios........................................................ 9-14 Table 9-11 Annual Financing Costs by Project Alternative (2013 $) ........................... 9-15 List of Figures Figure 1-1 NSB Annual Fuel Purchases and Delivery .................................................... 1-2 Figure 1-2 Preferred Routes Selected in 2011 Study ....................................................... 1-8 Figure 3-1 Surficial Geology Map................................................................................... 3-5 Figure 4-1 General Freeze/Thaw Stress Assembly with FRP Test Pole and Strain Gauges........................................................................................................... 4-4 Figure 4-2 Freeze/Thaw Stress Assembly with FRP Test Pole, Sand Slurry and Strain Gauges........................................................................................................... 4-5 Figure 4-3 Freeze/Thaw Stress Assembly with FRP Pole, Silt Slurry and Strain Gauges........................................................................................................... 4-5 Figure 4-4 Compressive Stress vs. Depths and Temperatures ........................................ 4-9 Figure 4-5 Compressive Stress vs. Depth at Constant Temperature ............................... 4-9 Figure 4-6 Direct Shear, FRP/Sand Slurry, Combined Mold Sections ......................... 4-13 x Preliminary Engineering — Final Report • •.- ::. June 30, 2014 Atqasuk Transmission Line Project Figure 4-7 Direct Shear, FRP/Silt Slurry, Separated Mold Sections, FRP Coupon on Left, Frozen Sand Slurry On Right.................................................................... 4-13 Figure 4-8 Direct Shear, FRP/Sand Slurry Removed from Mold ................................. 4-14 Figure 4-9 Direct Shear, FRP/Ice (removed from shear mold) ..................................... 4-14 Figure 4-10 Adfreeze Bond Strength vs. 2,000-psf Consolidation Pressure ................. 4-15 Figure 4-11 Adfreeze Bond Strength vs. 1,000-psf Consolidation Pressure ................. 4-16 Figure 4-12 Shear Load vs. Displacement..................................................................... 4-17 Figure 4-13 Micropile Foundation................................................................................. 4-19 Figure 4-14 Direct Set Pole Foundation........................................................................ 4-19 Figure 5-1 Counts of Bird Groups Flying at Various Flight Altitudes Above Ground Level.............................................................................................................. 5-9 Figure 5-2 Proportions of Bird Groups Flying at Various Flight Altitudes Above GroundLevel............................................................................................... 5-10 Figure 5-3 Proportions of Ptarmigan Groups Flying at Various Flight Altitudes Above GroundLevel............................................................................................... 5-11 Figure 6-1 Fuel Oil Distribution...................................................................................... 6-9 Figure 6-2 Fuel Oil Consumption 2-Year Average (FY2012 & FY2013)- by Type ofUse............................................................................................................ 6-9 Figure 6-3 Distribution of Existing Electrical Consumption by Building Type ........... 6-10 Figure 6-4 Distribution by Customer Type................................................................... 6-11 Figure 7-1 Transmission Line Route............................................................................... 7-3 Figure 7-2 TP-69 Transmission Line Pole Structure....................................................... 7-7 Figure 7-3 Three (3) Pole Transmission Line Structure .................................................. 7-8 Figure 7-4 T2 Conductor............................................................................................... 7-12 Figure 7-5 Electrical One -Line Diagram....................................................................... 7-18 Figure 8-1 Atqasuk Power Plant...................................................................................... 8-2 Figure 8-2 Fuel Delivery Methods from Barrow to Atqasuk.......................................... 8-4 Figure 8-3 Oil Spill Response Drill................................................................................. 8-6 Figure 8-4 BLECI Solar Taurus 5,000 KW Gas Turbine Unit ....................................... 8-8 Figure 9-1 Net Present Value of Cost Savings by Project Alternative ............................ 9-3 Figure 9-2 Variable Costs per kWh. Current Situation versus Project Alternatives ....... 9-4 Figure 9-3 NPV of Cost Savings with Financing Costs ................................................ 9-17 db� xi Preliminary Engineering- Final Report 4 June 30 2014 Atgasuk Transmission Line Project Section 1.0 — Introduction 1.1 Background The North Slope Borough (NSB) is aggressively exploring and developing local energy resources to displace or reduce its dependency on the use of imported fuel oil to meet their communities' heat and power needs. Over the past two decades, the cost of imported oil has been escalating at an alarming rate, impacting the residents of the Borough and the Borough's ability to maintain the services provided to its' citizens. Figure 1-1, shows the NSB's cost for fuel has increased three fold over the past ten years while the quantity purchased remains relatively constant. The NSB is completely contained within the Arctic and constitutes the upper 15% of the State of Alaska. It encompasses eight communities spread out over an area the size of the State of Minnesota. The communities are not interconnected by roads or other infrastructure including electric transmission lines. Consequently, although significant local energy resources are available in some areas of the North Slope, the lack of power transmission facilities or other transportation infrastructure prevents its distribution and use in the region as a whole. The village of Atqasuk, the focus of this report, is an inland community located 60 miles south of Barrow along the banks of the Meade River. Atgasuk's 2010 estimated population was 247. Over the past two decades the Borough has been exploring the development of a transmission line between Barrow and Atqasuk. Atqasuk has one of the highest costs of energy on the North Slope. The goal of a transmission line is to lower the cost and stabilize the price of energy in Atqasuk by replacing their use of imported fuel oil with electric power generated from Barrow's power plant facilities fueled by a local natural gas resource. 1 1 Preliminary Engineering — Final Report ''ofz= June30,2014 Atqasuk Transmission Line Project Figure 1-1 NSB Annual Fuel Purchases and Delivery 25,000,00(l - 22,665,604 70.000,00( 15,000AM 10,000,000 - 5,000,000 � 7.M ------------------------------------------------------ 4,11,Q2Q- 4,706,104 FY 02 FY 03 FY 04 FY 05 FY 06 FY 07 FY 08 FY 09 FY 10 FY 11 FY 12 FY 13 The initial effort to develop a transmission line began in 1981. It was designed to lower and stabilize the cost of electric power only. The engineering study entitled; "Barrow/Atgasuk/Wainwright Transmission Line — Project Planning Report", was prepared by Jack West and Associates. The results showed significant savings. The permitting process was initiated shortly after the report came out. However, the Borough placed the project on hold in 1982. 1-2 Preliminary Engineering — Final Report June 30, 2014 Atclasuk Transmission Line Project In 2008 the Borough completed an NPRA funded study entitled; "Energy Options for the City ofAtgasuk", prepared by Leland A. Johnson and Associates (LAJA). This study took a wide look at many energy options available to Atqasuk. The concept that showed the best economics was the transmission line between Barrow and Atqasuk. Unlike the previous study, this study added the conversion of Atqasuk's oil based heating loads to electric heat. The inclusion of space heating became possible as the price of oil escalated in Atqasuk while electric power rates decreased in Barrow. The most recent effort was a feasibility study sponsored by the Alaska Energy Authority (AEA) Renewable Energy Fund and the NSB entitled, " Atqasuk Transmission Line Feasibility Study". The study was completed in 2011 and concluded the project concept was economically viable. Based on the results of that study, the sponsors agreed to advance the project to the preliminary engineering phase. On July 24, 2013 the NSB entered into an agreement with LAJA to manage this phase of the project. The goal of the preliminary engineering effort was to adequately define the selected preferred power transmission concept so that the owners, end -users, financiers and responsible regulatory agencies could make appropriate decisions to advance the project to a final design and construction phase. The study updated the previous work done in 2011 as well as incorporating new developments and other new information. The Preliminary Engineering Phase tasks are: • Agency Review — present preliminary engineering plans and environmental studies to those agencies involved in the planning and permitting of a transmission line and obtain their feedback. • Conduct geotechnical assessment of the selected route. • Conduct tests on fiber -reinforced polymer (FRP) utility poles to confirm their suitability for use in permafrost soils. • Determine optimum power pole and line heights to avoid eider collision hazard. • Assess the conversion of Atqasuk to electric heat. 2-3 Preliminary Engineering — Final Report 17]`10..: •:. . June 30, 2014 Atqasuk Transmission Line Project + Update construction costs established in the Feasibility Study (2011) to include revisions from this report created by agency review, geotechnical assessment of the route and installation requirements of the pole line structures. + Update economic analysis. The economic analysis of this report did not evaluate retail electric rates. Since this a complex issue requiring accounting information and public input the focus of this effort has been on the cost of power production. If the project develops the Borough will need to negotiate with BUECI for a rate they will pay BUECI for electric power. Having established that the Borough would then conduct an evaluation of retail rates for Atqasuk residential, commercial and governmental subscribers. Initially the rates maybe based on a proforma analysis with options open to revise the rates as more information is generated over months or years. 1.2 Final Report Organization This Final Report is the main report. Companion to this report is a Final Supplemental Report entitled, "Atqasuk Space Heating Conversion to Electric Heat Supplemental Report ". The findings of the Atqasuk space heating conversion study culminated in a task deliverable draft report. Due to the large volume of data and the sheer size of the report, it was decided to present the details of the study in a separate final supplementary report. The Supplemental Report includes a detailed presentation of the methodologies used, all the energy data collected, narrative and calculations performed, facility photographs, mechanical room plan views, manufacturer's specification sheets and estimates of energy loads and construction costs for the conversion of Atqasuk's heating load to electric heat. For report continuity, this main report includes the executive summary from the Supplemental Report, which can be found in Section 6. - . ..- .... 1-4 Preliminary Engineering — Final Report June 30, 2014 Atgasuk Transmission line Project 1.3 Study Approach The Preliminary Engineering Study relied upon past work done by others incorporated into new investigations and analyses. Past studies performed in the Arctic provided a large knowledge base to go forward. Prior work included power line designs and analysis, geotechnical and soils evaluations, product performance tests, avian collision and electrocution guidelines and past Borough fuel and power monthly and annual reports. This in-depth knowledge was combined with a project team that had extensive experience in working in the Arctic, including with the NSB. The structure of the AEA Renewable Energy Fund made it possible to take a design/build approach in which the design, construction and permitting groups were represented throughout the study. As new information was gathered, discussions were held among those disciplines involved, along with utilities, community members and government agencies. By including those impacted or responsible for various aspects of the development of the project, "fatal flaws" were avoided and the preferred options based on technical, economic, environmental and social input selected. This study is a preliminary engineering study. Actual design of the transmission line, if pursued, will generate more detailed information that may impact the route, pole structures and/or agency considerations. This will lead to greater precision on estimating costs. Another important factor influencing cost will be the bid environment at the time bids are requested. 1.4 Project Sponsors and Organization The project was paid for with AEA funds made available through the Alaska Renewable Energy Fund Program. The NSB acquired the grant funds to study the possibility of providing a more economic power supply to the village of Atqasuk. The initial effort, Phase 1 — Feasibility Assessment, was completed in 2011. The current effort, Phase 2 — I- 51 Preliminary Engineering — Final Report R= • ..- :• June 30, 2014 Atqasuk Transmission Line Project Preliminary Engineering, is presented in this report. Key personnel to the effort of the Preliminary Engineering Phase of the project were: • Kirk Warren, AEA Project Manager • Rico SanJose, NSB Project Administrator • Tim Rowe, NSB Grants Administrator In addition to the project leadership several employees of the NSB Departments of Public Works, Accounting and the Grants Division were instrumental in supporting this effort by providing information and insight into the existing energy systems located at Barrow and Atqasuk. The LAJA Team would like to express its appreciation for the cooperation and assistance provided by the following people. • Doug Whiteman, Atqasuk Mayor • Fred Kanayurak, Atqasuk Lead Power Plant Operator • Max Ahgeak, Division Manager, Power & Light • Jozieta Slatton, Fuel Division Manager • Ben Frantz, BUECI General Manager • Jim Murphy, BUECI Operations Manager Kent Grinage of LAJA managed the Atqasuk Study. Specialty services were provided by the following Team: • Sakata Engineering — Electrical Engineering, Albert Sakata EE PE • Eric Worthington EE EA — Construction Feasibility, Method and Cost Estimate • Golder & Associates — Geotechnical Engineering, Richard Mitchells, PE • ABR — Environmental Considerations, Bob Ritchie, Principal/Senior Scientist • Northern Economics Inc. — Economic Analysis, Leah Cuyno, PhD. • Solstice Alaska Consulting Inc. — Permitting Considerations, Robin Reich, PE • RSA Engineering, Inc. — Electrical & Mechanical Engineers, Mark Frishkom, PE • Energy Audits of Alaska — Atqasuk Field Survey & Energy Analysis, Jim Fowler • HMS Inc. — Energy Conversion Construction Estimate ,t..- :..�. 1-6 Preliminary Engineering — Final Report June 30, 2014 Atgasuk Transmission Line Project 1.5 Project Description The Atqasuk Transmission Line Project entails a design, engineering, permitting, and construction effort that will provide a new power transmission line from Atqasuk to Barrow. The Feasibility Study Phase produced several transmission line alignments that where evaluated for selection of the most environmentally friendly, economically viable, and technically feasible route. The Study selected two routes to be advanced to the preliminary engineering phase of the project, an Eastern Route and a Western Route. Both routes started at the BUECI Power Plant in Barrow. The transmission line proceeded to the Barrow Gas Field Processing Facility, utilizing existing road infrastructure to facilitate construction. The Eastern Route continued along the road to the UIC Gravel Pit, traveled a short distance east and turned south, along a new cross-country route, on single, overhead power poles and terminated at the Community of Atqasuk. The Western Route, from the South Barrow Gas Field, proceeded south and utilized the existing 6" gas line Vertical Support Members (VSM) to support the power cable from the South barrow Gas Field to the existing Gas Line terminus at the Walakpa Gas Field, approximately 16 miles south of Barrow. The final leg of the Western Route travels along a new cross-country route, on single, overhead power poles to Atqasuk. A map of both routes is presented in Figure 1-2 below. In addition to the transmission line and as part of the feasibility phase, the study evaluated the fuel conversion of Atgasuk's space heating equipment to electric heat. This effort resulted in a preliminary cost estimate for conversion and determined the electrical consumption and peak demand load that would be required after the conversion. 1.-7 Preliminary Engineering —Final Report ."'' I• ••- '•• • June 30, 2014 Atgasuk Transmission Line Project Figure 1-2 Preferred Routes Selected in 2011 Studv PROJECT �*a+ LOCATION SARROW _ +: NWW ratbarx. • t; tf.rt ou EXIt3TWO INES Route 2a - Walakpa Power Lane Spur Yk. l�r Western Route 1 . (RT.1) Base Caro' LEGEND Western Route 1 ,. Eastern Route 2 Walakpa Power Lino Spur Route 2R , Eastern Route 2 Existing Gas Lines *' � t (RT.2) ED Native Allottmont ( REFERENCES t '^ 1,) AERIAL IMAGERY 000 DATED AUGUST` 2005 WAS PROVIDE BY USGS AND AAA• ►�• DISTRIBUTED BY ALASKA GEOGRAPHIC"' INFORMATION CENTER y04 - (GINA) ATQASUK r o 11 SCAL F MILFS Ly North Slope Borough 1-8 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project Section 2.0 — Agency Review 2.1 Background The purpose of Section 2.0 Agency Review is to share the preliminary engineering and environmental studies with federal agencies involved in the planning and permitting of the project to solicit their input on design components of the draft development plan. The proposed Barrow—Atqasuk Powerline route crosses several important avian habitats, including habitats for threatened eiders and rare loons, and wetlands in northern Alaska (NSB 2011a). Although preliminary planning and engineering studies have sought to reduce the potential for impacts to these migratory birds and wetland habitats (e.g., siting the transmission line next to existing gaslinelpowerline infrastructure, having wider spans between poles to reduce the number of poles, using reflective conducting wire or marking wires at critical locations), the overhead lines that will be required over a substantial part of its length still present collision risks for birds in flight. 2.2 Agency Meetings On 28 October 2013, personnel representing key resource agencies (U.S. Fish and Wildlife Service (USFWS), U.S. Bureau of Land Management (BLM)), the NSB, LAJA, and ABR, Inc., attended a meeting to describe the proposed powerline and introduce the topics of bird collision and mitigation (Appendix A "Minutes of Oct 28 and Nov 7 Agency Review Meetings"). ABR also met with representatives from the USFWS and the BLM in Fairbanks on 7 November 2013 to focus more on powerline height (Appendix A). At these meetings, the agency representatives discussed attributes that they would like to see incorporated into the overhead powerline design if burial of the line along its entire length was not possible. P;Arn 2-1 Preliminary Engineering — Final Report "' '" ' June 30, 2014 Atqasuk Transmission Line Project 2.2 Agency Recommendations The recommendations included: • following existing infrastructure as much as possible (e.g., utility structures in the Barrow area); • using a horizontal, rather than vertical, line configuration to reduce collision risks; • using T2 conductor, a reflective line, rather than bird -flight diverters (although aircraft marker balls could be used at river crossings), so that there is no need for annual maintenance and replacement of bird -flight diverters; • raising the minimal sag height of the line as much as possible, so that the powerline height is as far from the ground as possible without creating nesting substrates for ravens or dangerous perches for raptors; • providing a cost -benefit analysis of adding more poles and/or different poles to the design to achieve the above objectives; and • considering the potential for future development in the region (e.g., a design that facilitates extending a spur line to Wainwright). More detail on these recommendations is provided in the written comments from the USFWS (Appendix B, "USFWS Written Recommendations"). As the project would cross federal land, it will require approval from the BLM under the National Environmental Policy Act (NEPA). A detailed project design will need to accompany the form required to initiate permitting action with the BLM (Appendix C, "Permit Form"). The BLM Arctic Field Office recommended that once the design of the project is finalized and/or the route selected, the project team should meet with BLM personnel to discuss the permitting process in-depth prior to submitting the application (S. McIntosh, Interdisciplinary Supervisor, BLM Arctic Field Office, Fairbanks, AK; pers. comm.). ,� 2-2 Preliminary Engineering — Final Report ` m_ 't, ' • ••- :• • • June 30, 2014 Atgasuk Transmission Line Project Section 3.0 — Geotechnical Assessment 3.1 Background The purpose of "Section 3 Geotechnical Assessment" is to identify potential geotechnical design criteria to refine feasibility level design and construction constraints. 3.2 Regional Setting and Climate Barrow is located on the coast of the Chukchi Sea near Point Barrow which defines the westerly boundary of the Beaufort Sea. The area is within the Arctic Coastal Plain physiographic province. The near surface geology consists of a series of marine, lagoon and beach deposits. Overburden consists of eolian silt and sand blanketed by surface organic deposits (tundra). Barrow and the surrounding area are situated on Alaska's Arctic Coastal Plain. Gentle topography, ice -bonded permafrost soils, wet tundra (summer), wind -oriented thaw lakes, and braided stream channels typify the region's geomorphology. Shallow thaw lakes cover about 25 to 30 percent of the tundra. Relief near Barrow is generally less than 6 feet; however, river terraces and pingos provide a few areas of greater relief. Surface elevation rises gently to the south, from sea level at the coast. Annual precipitation averages about 5 inches, with 20 inches of annual snowfall. Winds are generally from the northeast. The area between Barrow and Atqasuk is underlain by continuous permafrost that extends to a depth of at least 1,000 feet. Interstitial and massive ice is prevalent in the near -surface soils. Much of the massive ice consists of ice wedges associated with polygons. Polygons are formed when seasonal ground shrinkage during the cold winter tension cracks the ground. The cracks collect melt water in the spring, which then freezes, forming an ice wedge. The following season, the process repeats itself in the 3-1 Preliminary Engineering — Final Report • •• :•�• June 30, 2014 Atqasuk Transmission Line Project same location, until, after a number of years, the ice wedges have grown to be several feet thick at the base of the active zone and more than 10 feet deep. The community of Atqasuk, approximately 60 miles south of Barrow, Alaska, is also located on the Arctic Coastal Plain. The region is relatively flat and characterized by permafrost features such as patterned ground, thaw lakes, and oriented lakes. Nearer the village dune deposits are present, primarily composed of fine sand with variable amounts of non -cohesive silt. The Meade River adjacent to the village is incised below the level of the surrounding plain exposing unconsolidated sediments in some areas. These sediments are considered to be part of the Quaternary Gubik Formation that represents a fluvial and lacustrine deposition environment. In places near the village the river has exposed sedimentary rocks of the Cretaceous Umiat Formation. These rocks are considered a prodelta deposition, consisting of thinly bedded sandstone, siltstone, and shale. Coal has been mined for local use near the village from this formation. Rock exposures range from well -indurated to friable with irregular interbedding and lateral discontinuities. 3.2.1 General Climate Trends Average and design thawing and freezing indices for the general Barrow to Atqasuk area are summarized in Table 3-1. We used the University of Alaska Fairbanks (UAF) Scenarios Network for Alaska and Arctic Planning (SNAP) database to derive the climate indices. Average climate indices are based on 30 year period average. The design indices are based on the average of the three coldest single winter season (design index) or the three warmest single summer season (design index) during the 30 year data period. For planning purposes, SNAP projected climate indices for the 2012 to 2042 period are also provided. The projected climate indices are based on Global Climate Models considered by the SNAP group to be suitable for Alaska coupled with a mid -range carbon emission scenario. 3-2 Preliminary Engineering — Final Report V =• • June 30, 2014 Atgasuk Transmission Line Project Table 3-1 Average and Design Thawing and Freezing Indices 1948 —1978 1979 — 2009 2012 — 2042 (estimated) Average Air Temperature 10.0 °F 12.4 °F 14.3 "F Average Freezing Index 9,300 °F-days 8,630 "F-days 7,910'F-days Average Thawing Index 1,250 'F-days 1,460 °F-days 1,440 °F-days Design Freezing Index 10,340 °F-days 9,580'F-days 9,090 "F-days Design Thawing Index 1,500 'F-days 1,840 °F-days 1,730 °F-days On average, mean annual air temperatures for the Barrow to Atqasuk area have increased since the 1950's and are expected to continue to increase throughout the project's estimated design life. The historic average and design freezing indices exhibit decreasing trends and are anticipated to continue to decrease throughout the expected project design life. The average and design thawing indices trends have increased historically, but are projected to remain relatively stable during the project's design life. This indicates the area may experience a generally similar summer climate relative to current conditions. However, winter climate conditions should be expected to warm during the same period. On average, a warming winter climate is projected throughout much of Alaska's North Slope area. Warming climate trends are expected to result in increased active layer (seasonal thaw) depth and a general warming of the near surface permafrost during the expected project design life. Depending on a variety of factors, deepening surface thaw may exceed annual freezeback depth in the active layer. if so, localized taliks (unfrozen zones between the base of the maximum extent of seasonal frost and the underlying ice -bonded permafrost) may exist. Deepening seasonal thaw may increase the depth to the point of fixity on vertical structures embedded in the permafrost. Warming permafrost may impact the design adfreeze bond strength along adfreeze bonded pile structures. The climate impacts may also influence season frost heave forces acting along embedded pile structures. 3-3 Preliminary Engineering — Final Report • •.- y.: June 30, 2014 Atgasuk Transmission Line Project 3.3 Preliminary Terrain Unit Mapping Preliminary terrain unit mapping was based on published geologic data by the United States Geological Survey (USGS); Williams and Carter (1983), Williams (1984), and the State of Alaska, Reger (2003). All three geologic mapping efforts were based on surface and near surface soil and drainages using aerial or digital imagery. The proposed powerline alignments were superimposed on the public maps by our GIS team, but the relationship between the terrain units and the powerline alignment is considered approximate and has not been field verified under this scope of services, Figure 3-1. Based on the approximate powerline alignment and the publically available geologic data, the following general terrain units may be present along portions for the powerline alignments. 3.3.1 Soil Unit Properties ■ Undifferentiated Alluvium: Alluvium within the study area ranges in composition from silty sand in sluggish streams and deltaic areas to gravelly sand and sandy gravel in the larger rivers such as the Meade, Colville, Kuparuk and Sagavanirktok. Alluvial material is present in the main channels of most streams and is common on low terraces. ■ Dune Sand: Dune Sands on the Arctic Coastal Plain vary in grain size from silt to sand and generally contain very little pebble -sized material. Massive sand dune deposits are present in the vicinity of Atqasuk. These deposits are highly susceptible to wind erosion. ■ Marine Beach Deposits: Beach deposits consist primarily of pebbly sand and of gray fine-grained material (primarily silt and clay), and are intermittently present along the modern Chukchi Sea coastline ■ Deltaic and Lagoonal Deposits: Delta deposits generally consist of a mix of material resulting from the interaction of coastal processes and the continuing transport of alluvial material near the mouth of the larger rivers on the North Slope. Material ranges from alluvial gravelly sand to fine marine and estuarine silt and clay. Eolian sand and silt commonly forms a surface cover together with interbedded organic deposits and peat. 3-4 Preliminary Engineering — Final Report 4: db= June 30, 2014 Atqasuk Transmission Line Project Figure 3-1 Surficial Geology Map N Metes �.�. f. .�•._�(S°,�:�'. - ''�r �;`y .'r. � � 1 ti•°( ,� `� sir lTP c 3 �'•ya" t���lr 1, Y)' ix- ct .- �,.Rr" art' , k k.: ^ � � " ,p �•° -'�^� _- r �E r , `',:tip. �'�.�'. .ti �•.,y,... r tr r.J-e.s..R• J 1 k° ���Jj4 :�•� y; -,�ti. ;� i����'��, P9�..�1,,- r ,M'n} �rrL tJJrr'i;ari R u, Oft T r- QL go w( ii4L LEGEND wow r'mposed Translruss Line - Eastem Roule a-uw�rEwcrerMlmxurww a.- d+- sExehCOPOUTS o...aELwe�umaN,c cEr,oe�1! tlr -fHfw WIF0EPMTft i„-tAWMIk/WtRATEq TMVP(fdcW We REFERENCES t_) SARROW 1250K, W LLIAMSAND CARTER (1903) 2.) MEADE 125CK, WLLUAMS (1904) 3. REGER ETAL. (2003) 4.) BASEMAP HYDROLOGY FROM 1 x000.000 i-t+li ONRLATLAS &) COORDINATE SYSTEM: NAD 1963 3UkPW*AInU 6 FIPS SM e 0 a Miles r�o.scr LAJA BARROW TOAT0A SUK POWERLINE NORTH SLOPE, ALASKA SURFICIAL GEOLOGY MAP 0 MMgN A IIII t1.g111 MW t Gu4ier Assoclates rw. �„ FIGURE.3-1 3-5 Preliminary Engineering— Final Report ' June 30, 2014 Atqasuk Transmission Line Project ■ Thaw Lake Deposits: The deposits within the thaw lake basin depend upon the material available for redeposition in the bed and the banks, and therefore have grain sizes similar to the surrounding landforms. They can include silt, sand and pebble beds and lenses. They also incorporate organic material that has been redeposited from the banks of the lake and materials that grew in situ in the lake basin. ■ Undifferentiated Sedimentary Rocks: Bedrock exposed is primarily a Cretaceous age sedimentary rock consisting chiefly of shale, siltstone, claystone, sandstone, and conglomerate. The "bedrock" mapping symbol is used wherever bedrock is exposed or the colluvial or silt cover is discontinuous or thin. In general, the soils along the alignment are ice rich permafrost with an expected active layer depth in the range of several feet. Massive ice can be present throughout the area, particularly along the margins of the polygonal (patterned) ground. Elevated pore water salinity has been encountered in the area surrounding Barrow. Elevated pore water salinities may be present along portions of the proposed alignments. (See Table 3-2) In general, the shallow soils in Barrow and Atqasuk below the active layer have provided adequate foundation support for buildings and infrastructure and we expect the frozen soils along the alignments would behave in a manner to similar soils encountered elsewhere in Barrow and Atqasuk. However, soils with elevated pore water salinities have resulted in significant foundation performance issues in the Barrow. The potential for unacceptable powerline pole or guy anchor performance can occur if they are founded in soils with elevated pore water salinities, high organic contents or within thawed or unfrozen soils. i 3-6 Preliminary Engineering — Final Report ft • June 30, 2014 Atgasuk Transmission Line Project Table 3-2 Summary Soil Unit Properties Morphology Physical Property Observations Physical Property Interpretations Soil Unit Slope Suspected Cn,fieA ,u Tha w f 5 ,, a e Soil Stratigraphy Classificati Ice Content Areal Distribution lakes Drainage on Soil Types Sorted and layered Active stream and sand, gravelly sand Undifferentiated GW, GP, SW, river beds and low and sandy gravel Gentle Low Few Good Alluvium SP, SM; ML terraces with some silty layers Dunes and reworked or buried well sorted fine dunes of sandy silt sand, silty sand Gentle to Low to Moderate Dune Sand and silty sand; SP, SM, ML, Pt Many and S"It wftiiuricd MUdel ale Moderate t0 Pour commonly organic horizons incorporates thin organic layers Along Chukchi Sea coast with relic beaches parallel to Chukchi and Sand, sand with Flat to Marine Beach SP-SM, 5P Low Few Good Beaufort Sea fine gravel Gentle coastlines; includes offshore spits and islands Mountain peaks, Claystone, Shale, rounded knobs and Gentle to Siltstone, Low to Bedrock ridges, and as steep Near None Good Sandstone, None banks along stream Vertical Conglomerate channels Mix of material resulting from the Low to interaction of Interlayered silty moderate Deltaic and coastal processes sand and sandy silt Gentle to Good to SM, ML, Pt Some Lagoonal and the continuing with occasional Flat Moderate transport of alluvial organic layers Possibly material at river High rn oaths Dependson Found throughout material available SP, SM, ML, Pt, Thaw Lake Flat High All Poor area for redeposition in GW the bed and banks 3-7 Preliminary Engineering— Final Report North Slope Borough War June 30, 2014 Atqasuk Transmission Line Project 3.3.2 Thaw Bulbs and Thermal Considerations This area is currently underlain with continuous permafrost with an estimated active layer thickness between 1 and 3 feet. Major rivers and larger lakes may develop thaw bulbs underneath the active layer, especially when the water body does not freeze entirely during the winter. The size of the thaw bulb depends, among other factors, on the size of the water body and the amount of water that remains unfrozen throughout the year. ■ Rivers: The major rivers of the North Slope most likely have thaw bulbs in the ground underneath certain parts of the river. They occur underneath the thalweg, the deepest channel of the river defining its line of fastest flow. Depending on the amount and duration of flow the thaw bulb can extend downward and outward through the permafrost creating an unfrozen section in a zone of the continuous permafrost. ■ Thaw Lakes: Lakes that are deep enough with sufficient water volume may not freeze all the way to the bottom leaving a zone of unfrozen water that can react with the permafrost and create a thaw bulb. Also, climate forecasts for this area indicated a continued increase in mean annual air temperature and air thawing indices. Likewise the air freezing indices in this are forecasted to decrease, indicating an overall warming trend. Based on the SNAP forecast design air indices presented earlier, initial estimates based on Modified Berggren analysis indicate and additional 1 to 1.5 feet of surface thaw can occur over the next 30 years within the Barrow/Atqasuk area. Forecasted climate impacts should be included as part of the design phase analysis for this project since they can have an impact on the foundation soil performance along the alignment. 3.4 Ice Jams and Snow Drifts A phone interview with Mr. Doug Whiteman, mayor of Atqasuk, was conducted on November 20, 2013 to discuss his knowledge and historic information of areas of ice jams in the Meade River and alignment of traditional snow drifts. Mr. Whiteman mentioned that the Meade River has traditionally had ice jams approximately 1 mile 3-8 Preliminary Engineering — Final Report "� ••- '• •�• June 30, 2014 Atqasuk Transmission Line Project upstream from the village of Atqasuk. This is near the USGS stream flow and ice jam monitoring station discussed previously. It is where a large oxbow in the river straightens out before it flows past the village. Other areas along the Meade River also have reported ice jams during the breakup season but it is variable depending on the year. There is no readily available ice jam data on the Meade River near the proposed powerline crossings. However, the ice jam information nearer to Atqasuk indicates larger water impoundments and ice loadings can occur behind the ice jam. Likewise the ice jam breakout can release large volumes of water at potentially large flow rates. Floating ice contained within the outbreak water flow can have large kinetic energy and inertial forces with the potential to damage downstream features and structures. In the past the snow drifted consistently in the East -Northeast orientation and snow fences were erected in the area on the eastern side of the village. Within the past 8 to 10 years, Mr. Whiteman indicated the prevailing wind directions have experience greater variability and snow has been drifting in variable directions, depending on the shift in the winds. There has also become more re -deposition of the accumulated snow due to the shifting winds. Mr. Whiteman also mentioned stream gauge data that can be found on-line on the USGS web site as well as information about the ARM (Atmospheric Radiation Measurement) Climate Research Facility North Slope of Alaska site. It was installed in the summer of 1999 and operated through 2010. Instruments included Ground Radiometers, Infrared Thermometers and Surface Meteorological Instrumentation. A review of US Army Corps of Engineers ice jam database for Atqasuk (2006 to current) indicated seven records related to Meade River ice jams at a gauge station near the village as summarized below in Table 3-3. Ice dynamics of the Meade River drainage have also been reported by Beck, et al, 2010. However, the Beck data is primarily located in the Atqasuk area. Although dated, the US Army Cold Region Research and Engineering Laboratory (CRREL) reported breakup 3-9 Preliminary Engineering -- Final Report sit; • ••- ;• • June 30, 2014 Atqasuk Transmission Line Project Table 3-3 Ice Jam Database for Atqasuk 2006-2012 Date Annual Maximum Peak Stage (feet) Average Daily Discharge, (cubic feet per second (cfs)) May 27, 2012 30.88 2,000 May 29, 2011 33.80 Not Reported June 09, 2010 31.20 20,000 May 23, 2009 30.91 13,000 May 29, 2008 32.80 15,000 June 05, 2007 33.49 39,000 May 29, 2006 32.87 7,000 data for the Meade River in 1967, Johnson and Kistner, 1967. Their data is primarily restricted to current Atqasuk village area. (See Appendix D, "Ice Jam Reports'). The proposed powerline alignment is significantly downstream from the USGS gauge station located near the village and the effects of ice jam release further downstream are difficult to determine without additional modeling and analysis. The size and impacts of possible ice jams further downstream from the village are undetermined. In general, ice jams have the potential to impact the proposed powerline poles by several processes. If the powerline poles are located upstream of an ice jam, floating ice behind the ice dam may drift into the pole section and possibly lodge ice behind the pole structure. Lodged floating ice may increase lateral loads on the powerline poles. Also, during breakout the discharging water may remobilize upstream floating ice with potential for increased momentum and impact to powerline poles. If the powerline poles are located downstream of the ice jam, ice jam breakout forces may develop large momentum forces from discharging water and floating ice that may strike the powerline poles. Also, increased water velocity may erode surface soil at the poles reducing their effective embedment depths. A visual assessment of snow drifts along the proposed powerline alignment was not possible due to the summer 2013 notice to proceed for this effort. Thus, it is 3-10 Preliminary Engineering — Final Report �� �s June 30, 2014 Atqasuk Transmission Line Project undetermined if snow drifts are generated along the proposed powerline alignment that could impact the underlying thermal regime at specific power pole locations. Snow drift can insulate the ground from winter cooling resulting in a deepening of the active layer and a localized warming of the permafrost under the snow drift footprint. As the active layer deepens it may impact the depth of pole embedment and lateral resistance engineering design recommendations relative to areas with minimal snow cover. Depending on the local topography and snow drift impacts, some localized slope instabilities can occur that may impact lateral design loads on the poles. 3.5 Conclusions The proposed project area is underlain with continuous permafrost with an estimated active layer thickness between 1 and 3 feet. The soils in Barrow and Atqasuk below the active layer have provided adequate foundation support for buildings and infrastructure and we expect the frozen soils along the alignment would behave in a similar manner. The mean annual air temperatures for the Barrow to Atqasuk area have increased since the 1950's. This trend is expected to continue. It is estimated that an additional 1 to 1.5 feet of surface thaw can occur over the next 30 years within the Barrow/Atqasuk area. A visual assessment of snow drifts and ice jams along the proposed powerline alignment was not possible due to the late startup of this project. Thus, it is undetermined what impact, if any, snow drifts or ice jams could have the project. As part of the design phase effort a visual reconnaissance survey along the final powerline alignment can be conducted in late spring to map any potential snow drifts and/or ice jams between the village and below the proposed powerline crossing at the Meade River. It is important to understand that additional site -specific geotechnical efforts may be required to refine or confirm our laboratory results during the design phase of this project. 3-11 Preliminary Engineering — Final Report ±; ••- :• •!• June 30, 2014 Atqasuk Transmission Line Project Section 4.0 - FRP Pole Testing 4.1 Background The purpose of "Section 4.0 — FRP Pole Testing" is to confirm the FRP Poles suitability for use in the permafrost soils found in the study area. Conceptual level engineering designs for the powerline piles includes use of modular FRP pole systems in lieu of heavier timber or steel pole systems. Several FRP pole foundation options were considered including driven steel micropiles, larger dimensioned steel or timber adfreeze piles and direct set FRP poles installed using drill. and slurry adfreeze bond methods. For direct set FRP poles, the below grade sections are hollow and can be provided as either open or closed -end sections. The hollow FRP section may be subject to large compressive stresses as the slurry backfill freezes, particularly during seasonal freeze/thaw through the active layer. Minimal design guidance is available to determine compressive stress on FRP poles installed in permafrost areas. Golder proposed to conduct a series of freeze/thaw cycles in their Anchorage cold room and record the strain along the FRP section to support permafrost and cold regions engineering design. 4.2 Test Methodology The laboratory assessment intended to simulate the placement of a hollow FRP pole in a drilled hole, backfilled with soil slurry. This procedure measured compressive strains developed along a FRP test pole section during a series of freeze/thaw cycles using a temperature controlled cold room. In addition, similar slurry materials were used in a cold room direct shear testing apparatus to estimate the adfreeze bond strength on wood, steel and FRP coupons. The intent of this test was to refine the adfreeze bond strengths of the provided RFP coupons relative to timber and steel materials. • ..t ,. , 4-1 Preliminary Engineering— Final Report ��, June 30, 2014 Atgasuk Transmission Line Project For consideration of variation in soil type used in slurry preparation, the freeze/thaw tests were conducted with a sand slurry backfill as well as a silt slurry backfill. For the hoop stress assessment, the strains measured and the resultant stresses calculated were determined to provide an estimate of the compressive stresses the hollow FRP pole is likely to be subjected in the active layer or during initial freezeback below the active layer. The testing results were used to determine the preferred slurry aggregate. The direct shear testing was conducted using frozen slurry aggregate and different coupon materials at a relatively rapid strain rate. The intent of the effort was to estimate ultimate, short-term adfreeze bond strengths between the slurry material and several coupon materials: wood; steel; and FRP. Due to coupon size, the direct shear test results are not considered final design values, but rather the results provide a relative indication of ultimate adfreeze strengths among the various coupon materials. 4.3 FRP Pole Freeze -Thaw Testing Procedure for Compressive Stress 4.3.1 Testing Procedure The objective of the test was to estimate stresses that may develop along a hollow FRP pole installed in permafrost or along the active layer. A cold room freeze/thaw using a production section of a hollow FRP pole set in a rigid steel shell to simulate a rigid body permafrost borehole sidewall state. The following material/equipment was used to create the experimental test setup. The FRP pole sample was obtained from RS Technologies, Inc. based in Calgary, Alberta, Canada. The FRP pole test sample is made from an advanced composite material that combines polyurethane resin and E-glass fiber rovings. More details on the pole and its modularity can be found in (Appendix E "RS Composite Utility Poles Brochure"). The pole is a frustum of a very large cone and hence it has a slight taper. However, for the length of sample tested (3 feet) the taper is minor and considered negligible. The dimensions of the hollow FRP pole sample were: 4-2 Preliminary Engineering — Final Report • "• • ' June 30, 2014 Atqasuk Transmission Line Project ■ Length: 36 inches ■ Outer diameter (top): 18.0 inches ■ Outer diameter (bottom): 18.4 inches ■ FRP Thickness: 0.54 inches (average) The borehole sidewall advanced into the permafrost was simulated as a rigid body with a steel shell (pipe pile) section. The steel test shell is a Schedule 40 steel pipe pile section with the following dimensions: ■ Height: 36 inches ■ Outer Diameter: 30 inches ■ Wall Thickness: 0.35 inches Three different materials were used for the slurry between the FRP test section and the steel shell. The FRP section was sealed along the base with a waterproof membrane to maintain a hollow center section with the slurry hand placed within the annular space between the FRP and steel shell. The three materials were the following materials: Grain size distribution for the sand and silt slurry material are provided in Appendix F, "Summary of Particle Size Distribution Results ". ■ Colorado 10-20 Silica Sand ■ Silt ■ Freshwater The strain gauges used for the testing were: KFG 5-350-C1-11 model gauges manufactured by Kyowa Inc. These are standard 350 Q quarter -bridge gauges with a tolerance limit ±2.1 Q. The gauges begin to have temperature induced strains below 500 Fahrenheit (F). Temperature strain correction measures were applied as detailed later. These foil gauges are 13 µ thick and were installed to the FRP using a bonding agent and a silicone sealant. The gauges were aligned along the circumference of the section, to measure the strain in the compressive hoop stress. The FRP test section was instrumented with 12 gauges at different locations along the FRP section; 8 on 4-3 Preliminary Engineering — Final Report i� June 30, 2014 Atgasuk Transmission Line Project the outer surface of the pole and 4 on the inner side. Additional gauges were placed close to each other to have some redundancy in measurement and to verify the consistency of the measured strain. 109 L model thermistor manufactured by Campbell Scientific Inc. was used to measure the temperature both within the slurry material (two thermistors at different depths within the slurry — 0.5 and 1.5 feet from top of slurry) and one thermistor inside the hollow portion of the FRP test section. The thermistors are able to record temperatures between +176°F to -58°F. More details on the thermistor can be found at http://www.campbellsci.com/109-temperature-specifications. A CR1000 Measurement and Control System manufactured by Campbell Scientific Inc. was used to collect the data from all the sensors instrumented with the test set up. Additional information on the data logger is available at http://www.campbellsci.com/cr1000-datalogger. Representative photographs of the stress test assembly are presented below in Figures 4-1, 4-2, and 4-3. Figure 4-1 General Freeze/Thaw Stress Assembly with FRP Test Pole and Strain Gauges 4-4 Preliminary Engineering — Final Report "= • ••:: • June 30, 2014 Atqasuk Transmission Line Project Figure 4-2 Freeze/Thaw Stress Assembly with FRP Test Pole, Sand Slurry and Strain Gauges Figure 4-3 Freeze/Thaw Stress Assembly with FRP Test Pole, Silt Slurry and Strain Gauges A small disc of the FRP material was instrumented with a strain gauge and used a free body reference during the test process to correct for the temperature induced strain in the gauges through freeze/thaw cycles. Since the disc was not under stress from any other loading, the strains measured by it would be related to the changing temperatures during the test. 4-5 Preliminary Engineering — Final Report • �• •• • June 30, 2014 Atqasuk Transmission Line Project The entire test set up is cycled through Golder's cold room to simulate a series of freeze/thaw cycles. The cold room is set at a temperature of 4°F with a variation of ±1.5' F over a period of 1 day for the hoop stress testing. The steel shell was placed on a mobile insulated wood frame base to access the cold room. The mobile base had a 4-inch thick rigid insulation section under the entire steel shell base extending several inches laterally from the shell perimeter. The rigid insulation under the shell was included to retard the rate of frost advancement from the base of the steel shell in order to concentrate frost penetration from the top, inside, and outside perimeters of the test apparatus. Several inches of thawed slurry material was placed along the base of the steel shell before the instrumented FRP pole is lowered into the tank. The FRP test section was centered and leveled. On average there was an annular gap of about 5.5 inches between the FRP pole and the steel shell. Unfrozen saturated sand slurry was placed and hand tamped in nominal 8-inch thick lifts. A similar slurry placement method was used for the silt slurry. One test was performed with potable water as the annular space back. Once the slurry is placed, the data acquisition system is initiated the prepared steel shell assembly was moved into the cold room. The assembly was monitored visually and with the temperature sensors to determine complete slurry freezeback, usually within 24 to 30 hours. After the slurry temperatures stabilized to the cold room temperature, about 48 hours after initial placement, the steel shell assembly was removed from the cold room and allowed to thaw and warm to ambient air temperatures about 65°F. After the initial thaw, the freeze/thaw cycle was repeated. No axial compression or tension loads were applied to the FRP test specimen. Details for the freeze/thaw tests performed for the different slurry material is summarized in Table 4-1. y y Ion= 4-6 Preliminary Engineering — Final Report June 30, 2014 Atclasuk Transmission Line Project Table 4-1 Freeze/Thaw Tests Details Slurry Type Slurry Moisture Content (% for dry weight) Number of Freeze/Thaw Cycles Number of Circumferential Strain Measurements Sand 14-18 3 6 Silt 35-44 3 6 Water - 2 5 4.3.2 Data Analysis Data was collected from the strain gauges and the thermistors at 12 hour intervals during the testing. For Strain data were measured at nine strain gauges located at depths of 0.5, 0.8, 1.1, 1.3, 1.6 and 2.1 feet on the outer face of the FRP test specimen surface and 0.3, 0.7 and 1.0 feet along the inner face of the FRP surface. Three thermistors recorded temperatures at the top of the pole, and at 0.5 feet and 1.5 feet depths within the slurry. The strain gauges, measuring in micro -strain, are affected by the changes in temperature that the experimental set up is run through during the freeze/thaw cycles. To correct for the contribution of temperature -induced strain to the measured strain, the data obtained from the strain gauge instrumented to the small free body FRP. The strain gauges were exhibited temperature induced impacts below 501 F. The free body strain sensor was used to correct the test section strain gauges for temperature influences for the cold test temperatures. The measured temperature corrected -strains were multiplied by the average modulus of elasticity for the FRP material, 2.9 x 106 pounds per square inch (psi) to derive stress induced on the FRP test specimen. RS Standard provided the material engineering properties for our analysis. The stresses and strains presented in the data typically start from zero then become negative values during the freezing cycle 4-7 Preliminary Engineering — Final Report P_t__A •' '` June 30, 2014 Atqasuk Transmission Line Project representing a compression state. During the thawing cycle the stresses/strains may move past zero to positive values due to initial loading that may have been present either due to preparation and test procedures at the beginning of the test, or residual stress from previous freeze/thaw cycles on the FRP specimen. In any case, the magnitude of peak stress applied during a given cycle is obtained from the absolute difference in maximum and minimum stresses measured on the pole. This is considered a valid assumption since tensile stresses were not imposed on the surface of the FRP test specimen and all load states acting on the FRP test specimen were expected to be compressive. 4.3.3 Results and Conclusions Summary stress data are provided for the sand, silt, and for water slurry materials by strain gauge distances from the top of the FRP test specimen. The stress values are provided for peak compressive stress by the approximate slurry temperature at the peak stress values (See Figure 4-4). Summary compressive stress data are also provided at a nominal 15°F constant temperature to reflect the reasonably expected steady state ground temperature in the proposed development area (See Figure 4-5). The peak stresses for each freeze/thaw cycle were obtained by the absolute difference between values of maximum and minimum stresses measured during the cycle. The largest peak stress among the freeze/thaw cycles was defined as the peak stress for a specific strain gauge location for this analysis. :. :... 4-8 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project Figure 4-4 Compressive Stress vs. Depths and Temperatures Compressive Stress, psi 0 2,000 4,000 6,000 8,000 10,000 0.0 -- IV ----------------------- 1.0 Jt LL —�—Silt C 1.5 -------� --Sand -------------------- ------------------------------------ F —*—Water 0 3 2.0 A ----------- Temperature -------------------------- m •• • s c. 2.5 d 0 3.0 10.0 20.0 30.0 40.0 Test Temperature, F Figure 4-5 Compressive Stress vs. Depth at Constant Temperature Compressive Stress, psi 0 2,000 4,000 6,000 8,000 10,000 0.0 — ------------ w • cL1.0 ---------------------------------------------------------------- LL �``.� —•—Silt o • • • ------------------------------------------------- —•—Sanda 1.5 I-- —Temperature c2.0 Aj ---------------------------------------- --------------------- d m =t+ 2.5------------------------------------ a m 3.0 11 12 13 14 15 16 Test Temperature, F 4-9 Preliminary Engineering - Final Report ; �A. a ••-''' ` June 30,2014 Atqasuk Transmission Line Project As noted in (Figures 4-4 and 4-5), the sand slurry developed a near constant compressive stress at various depths and temperatures. The silt slurry, however, exhibited a significant increase in compressive stress, particularly near the base of the test specimen. Since the base of the steel shell was insulated to retard frost penetration, the marked increase in compressive stress for the silt slurry at depth may infer an increase in pressure due to water migration and ice formation with in the silt soil as the freezing front advanced. This is considered to represent seasonal freeze/thaw conditions in the active layer. Based on our discussions with RS Standard, limited testing has been performed on the FRP poles subject to seasonal freeze/thaw stress in ice -rich cold permafrost areas. However, various compressive strength tests were performed by the manufacturer on the FRP material in accordance with ASTM D695 and Boeing Specification Support Standard BSS 7260 procedures. More details on their stress tests can be found at: http://rspoles. com/sites/default/files/resources/Module%20Testing%2Oand%2OQualit y%20Assurance%200verview%2OV l .2.pdf). These compressive tests used a bolted plate on the pole with loads applied to the plate in the transverse direction, perpendicular to the pole surface. This load orientation varies from our test case where a full radial freezing front around the FRP pole material was used. The manufacturer plate load tests indicate a maximum compressive stress on the order of 14,500-psi were developed. Assuming a reasonable correlation between the manufacturer and our test methods, it appears the silt slurry in our laboratory controlled conditions developed compressive stress of approximately 50-percent of the failure stress levels reported by the manufacturer. The sand slurry developed peak compressive stress of less than 10-percent of the reported failure stress values. Therefore, we recommended that a coarse grained aggregate be used as the slurry backfill for the hollow FRP poles in arctic conditions. 4-10 Preliminary Engineering — Final Report •• '• • June 30, 2014 Atqasuk Transmission Line Project 4.4 FRP Adfreeze Bond Strength Testing 4.4.1 Testing Procedure Coupons of the FRP material, Douglas Fir, and steel were tested with silt, sand and water slurry with direct shear testing apparatus under cold room conditions to determine general adfreeze bond strengths. The intent of the testing procedure was to determine the relative differences in adfreeze strengths among the various materials. A considerable body of knowledge is present as research and applied practice for determining the adfreeze bond strengths of sand and silt slurry to timber and steel materials. The objective of this laboratory scale testing was to estimate the relative adfreeze bond strengths of the FRP material for use in conceptual -level engineering design and construction cost estimating for the powerline project. A critical design consideration is determining the minimum required embedment for a drill and slurry construction method for a direct buried FRP pole. Based on initial design data provided by Sakata Engineering, it is reasonable to expect the axial design loads for a direct buried pole of any material property for this project will be seasonal frost uplift forces developed in the active layer. Of the three different coupon materials tested for shear: untreated Douglas Fir; surface roughened steel; and FRP stock material, of note was the FRP stock material. The FRP stock provided by RS Standard appeared to have a rougher surface finish than the FRP pole material used for the compressive strength test. RS Standard was not able to provide a shear test coupon of material used to manufacture the poles, primarily due to the curve geometry of the finished pole material. The shear testing required a flat stock material. The test coupon was placed in the base of a 2.42-inch diameter shear ring mold with the unfrozen slurry materials placed atop the coupon. The shear ring with the coupon and slurry material was placed in a relatively stable temperature cold room and 4-11 Preliminary Engineering-- Final Report 11V' ' June 30, 2014 Atqasuk Transmission Line Project allowed to full freeze. The freezing allowed the slurry material to bond to the coupon surface. General soil properties of the slurry materials are summarized in Table 4-2, with average test values and ranges are noted in parenthesis. Table 4-2 Soil Properties of Various Slurry Materials Slurry Type Slurry Moisture Content (% for dry weight) post Test Frozen Dry Density (pcf) Test Temperature, aF Sand 14.8 (15.6 — 13.0) 97.0 (102.3 — 94.4) 24.6 (25.3 — 23.8) Silt 36.4 (39.8 — 31.3) 72.0 (72.4 — 71.8) 24.6 (25.2 — 24.1) Water N/A 62.4 24.5 After freezing, the shear ring mold was placed in the direct shear apparatus and vertical confining stress was applied. The vertical displacements of the prepared specimen were monitored with LVDTs and once no vertical movement was observed, usually within several minutes, the direct shear load was applied at an approximate strain rate of 0.008 inch/minute. Shearing was conduct at a constant strain rate at an average test temperature of 25°F. Vertical consolidation stresses were applied at nominal 2,000, 1,000, and 500 pound per square foot (psf) values for the various combinations of slurry and coupon material. During the shear straining, LVDTs measured horizontal displacements at 4 to 20 second intervals with a narrow time step through the peak shear stresses than at a less frequent time step to verify residuals shear stress values post peak stress determination. Representative photographs of the direct shear test system for FRP with a sand slurry and a typical FRP/ice after shearing are provided below: In Figures 4-6, 4-7, 4-8 and 4-9. 4-12 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project Figure 4-6 Direct Shear, FRP/Sand Slurry, Combined Mold Sections 601-eer Jo/ 0 al-453il LAJA BARROW T© ATQAsvK f(,VAK VL- TEST#: t f-r -, ,' SAND I-EMf. . 'S OWIAA ni2(dSuRE: ; P54 Figure 4-7 Direct Shear, FRP/Silt Slurry, Separated Mold Sections, FRP Coupon on Left, Frozen Sand Slurry on Right �etser Jot 1t iZ3-95$gI LA)A 9RROW To ATQASUK rCAA IAE- TEST#: `t P' SANL ClsNGSA E'RESSuRE: 0H P.5� Aff�� 4-13 Preliminary Engineering - Final Report =m�;. • ••- -• • ' June 30,2014 Atqasuk Transmission Line Project Figure 4-8 Direct Shear, FRP/Sand Slurry Removed from Mold Figure 4-9 Direct Shear, FRP/Ice (removed from shear mold) 4-14 Preliminary Engineering -- Final Report • ••��� i°��' June 30, 2014 Atqasuk Transmission Line Project 4.4.2 Test Conclusions Adfreeze bond strengths measured at the tested strain rate with direct shear apparatus are considered representative of ultimate of short-term ultimate values. Long-term load state adfreeze bond strengths are typically lower than the ultimate values sine they may be governed by allowable creep generally considered acceptable for foundation movements. Generally accept allowable creep displacements are in the range of 1 inch over 20 years. Accordingly, the ultimate peak adfreeze values summarized below require adjustment for design application. The analysis was conducted at consolidation pressures on the order of 1,000 and 2,000-psf. This range is considered representative of the expected embedment depths of a direct set power pole. As noted in Figure 4-10 summary peak adfreeze bond values for the sand slurry are larger than the silt slurry. Potable water (ice) peak adfreeze strengths are considered unacceptably low. Figure 4-10 Adfreeze Bond Strength vs 2,000-psf Consolidation Pressure - 'S Preliminary Engineering — Final Report rI%AdI== June 30, 2014 Atqasuk Transmission Line Project Interestingly, the FRP and Steel coupons exhibit relatively similar peak strengths for the sand slurry at 2,000-psf consolidation pressure, but greater variation was evident in the sand slurry adfreeze bond strengths at the lower (1,000-psf) consolidation pressure. (See Figure 4-11) Figure 4-11 Adfreeze Bond Strength vs 1,000-psf Consolidation Pressure 100 Q80 --— — — — — — — — — — -- ®FRP �60 ------------- a� m 40----------- oSteel L W a �20----------- a d o Wood 0 Sand Silt Ice Verical Confining Pressure, psf It is important to note the FRP coupon provided by RS Standard had a significantly rougher surface finish than the RFP test specimen used for the compression testing program. This rougher finish may have resulted in an elevated peak adfreeze strength relative to the smoother finished product expected for the production poles. However, RS Standard has advised us they can produce a finish surface on the FRP production poles that will have a surface finish and roughness similar to the FRP coupon used for our adfreeze testing. If so, the roughened surface should not extend into the active layer horizon and the smoother finish should be used within the active layer zone. After the peak adfreeze strengths are developed, the bond strengths rapidly diminish to a de minis level that represents the mobilized bond strength. Based on the 4-16 Preliminary Engineering — Final Report 10"_ '' ' ' June 30, 2014 Atqasuk Transmission Line Project laboratory test results (see Figure 4-12), the mobilized bond strengths are not considered sufficient to control seasonal frost uplift forces unless exceptionally deep embedment along the mobilized sections is used. Figure 4-12 Shear Load vs Displacement 350 300-------------------------------- --------- --------------------------------- ------------------------- 250--------------------------------------------------------------------------------------------------- FRP N = 200--------- ------------------------- ------------------------------------------------------------------ 'a 150 Steel M a� y100 --- -------------------------- ----------------------------------------------------------------- Wood 50 -- ---- ----------------------- ----- ----- --- ------------------- 0 0.00 0.05 0.10 0.15 0.20 0.25 Horizontal Displacement, inches Based on the laboratory findings, the FRP material should be suitable for direct buried power poles along the proposed alignment. The base portion of the FRP poles should be provided by the manufacturer with a roughened surface, a `wiped' finished as described by RS Standard. The portion of the FRP pole extending through the active layer and several feet below the base of the active layer, should have a smoother finish in an effort to reduce seasonal frost bond strength along this portion of the embedded pole. 4-17 Preliminary Engineering -- Final Report • • - :• • • .Tune 30, 2014 Atgasuk Transmission Line Project 4.5 Pole Foundation Three options were considered for the powerline pole foundations at the preliminary engineering phase: ■ FRP pole direct set using drill and slurry methods ■ Driven steel micropile with a common steel pile cap for FRP pole attachment ■ Driven or drill and slurry larger dimensioned single steel timber or steel pile with a pile cap for FRP pole attachment A schematic section of the micropile foundation and direct set options are provided as Figure 4-13 and Figure 4-14. Based on the feasibility phase findings and preliminary construction cost estimates, the FRP pole direct set foundation using drill and slurry methods was considered the most cost effective option. The slurry for the FRP pole direct site option should be granular material, typically sand or sand and gravel mixture with relatively low fines content. The slurry should be placed in fully thawed state in the annular space between the FRP pole and the borehole sidewall, densified and allowed to fully freeze before developing full design loads on the pole sections. The FRP pole embedment depths should be adequate to resist the design loads, both axial and lateral, as well as seasonal frost uplift loads developed along the FRP pole in the active layer. An appropriate factor of safety must be applied to the design loads. In general, FRP pole embedment depths in the range of 12 feet below grade can be considered reasonable for feasibility phase assessment, with the following general constraints: ■ The poles are installed with drill and slurry methods using dry augering methods to advance the boreholes. ■ The poles are set into `cold' ice -rich permafrost with an active layer less than 2.5 feet thick ■ A sand and gravel slurry aggregate is used with the slurry placed in fully thawed and saturated state 4-18 Preliminary Engineering — Final Report ' ' June 30, 2014 Atqasuk Transmission Line Project Figure 4-13 Micropile Foundation POLE BASE - PILE CAP PILE CAP LEVELING -POLE STUDS (BY POLE MFr.) 20 `'SEACH V"SCH40 OPEN END PIPE AT 1H 2W PLAN VIEW I 10e PROFILE VIEW wT.a (By POLE MFG) rPOLE BASE 18-24 m 6 . SCH. 40 OPEN END PIPE SET INPREORRIED BOREHOLE (DEPTH PER DESIGN) Figure 4-14 Direct Set Pole Foundation POLE (BY POLE MFG) -BOREHOLE DIAMETER 6-8 in. GREATER THAN POLE SANDIGRAVEL SLURRY EMBEDMENT (DEPTH PER DESIGN) 4-19 Preliminary Engineering — Final Report TFA-77-Iffam June 30, 2014 Atqasuk Transmission Line Project ■ No pore water salinity is present in the in -place permafrost soils within the pole embedment depths ■ Construction activity does not damage the intact tundra around the alignment ■ Guy anchors, if used, are founded in the permafrost in at a geometry that does not develop moments or lateral loads only the guy foundation members ■ Axial loads on the FRP poles will not exceed reasonably expected seasonal frost forces developed within the active layer ■ Lateral loads from ice jams, ice jams breakout, slope movements, snow, and other sources are not developed along the FRP poles For feasibility level effort, the point of fixity for the direct set FRP poles can be considered approximately 0.5 feet below the base of seasonal thaw. Based on reasonably expected field conditions, the point of fixity should be about 3 feet below the undisturbed tundra surface. However this design parameter requires field data verification. The point of fixity 3 feet below grade is considered a relatively short period during late summer/early fall when the depth of seasonal thaw is at a maximum and seasonal frost has not significantly advanced into the soil near the pole. As seasonal frost advances downward from the ground surface surrounding the direct set pole, the point of fixity will thin to about 0.5 feet below existing grade as the active layer refreeze. It is possible larger lateral design loads may be developed along the powerline poles prior to active layer freezeback due to fall ice storms and other conditions. Final foundation design will require additional site assessment and characterization coupled with a comprehensive design team evaluation of the design loads, construction means, methods, and schedules, and a refined evaluation of the proposed powerline alignment. Slurry Aggregate Material Source Assessment Granular slurry aggregate sources should be identified along the proposed final alignment. Material aggregate sources nearer the proposed development are expected to reduce construction cost relative to aggregate transport from established borrow sites in Barrow and Atqasuk. Concurrent with the field geotechnical program for the powerpoles, hand operated power equipment probes (Hilti or similar) could be advanced 4-20 Preliminary Engineering — Final Report 4 . .. :.. . June 30, 2014 Atqasuk Transmission Line Project at expected shallow granular material deposits to determine their suitability as slurry aggregate. Shallow probes using this method can be completed with smaller helicopters during the summer. Potential field targets for material sources may be identified with higher quality imagery interpretation by an experienced geologist and by use of LIDAR imagery. Pre -field screening for potential granular material target areas by geologists with updated imagery is recommended to reduce field exploration time and costs. 4-21 Preliminary Engineering— Final Report June 30, 2014 Atagsuk Transmission Line Project Section 5.0 — Pole Height with Regard to Eider Collision Hazard 5.1 Background The purpose of Section 5.0 is to determine the optimum pole height vis-a-vis eider collision hazard. The proposed Barrow—Atqasuk Powerline routes cross several important avian habitats, including habitats for threatened eiders and rare loons, and wetlands in northern Alaska (NSB 2011 a). Although preliminary planning and engineering studies have sought to reduce the potential for impacts to these migratory birds and wetland habitats (e.g., siting the transmission line next to existing powerline infrastructure, having wider spans between poles to reduce the number of poles, using reflective conducting wire or marking wires at critical locations), the overhead lines that will be required over a substantial part of its length still present collision risks for birds in flight. 5.2 Methodology To help configure sections of the proposed above -ground powerline, we reviewed the scientific literature to see whether powerlines at heights different from those proposed (the minimal height of the lowest line will range from 24 ft to —45 ft, with the range due to sag between poles; NSB 201la) could reduce the risk for collisions with birds, particularly rare and threatened species using the region (Spectacled Eider, Steller's Eider, and Yellow -billed Loon). We searched published and unpublished literature and questioned researchers with expertise in studying avian collision risk at overhead transmission lines. Our literature search also included assessments of the impacts of wire heights on collision rates of birds. Major sources of information included study syntheses and the extensive bibliography in Reducing Avian Collision with Powerlines: The State of the Art in 2012 (APLIC 2012), plus flight -altitude data from migration and powerline research that has been conducted in western and northern Alaska by ABR personnel (Day et al. 2001, 2003, 2004, 2005a, 2005b; Boisvert et al. 2004; Boisvert and Day 2005; Gall ...... 5-1 Preliminary Engineering — Final Report V_ June 30, 2014 AN4 Ataasuk Transmission Line Project and Day 2007). This report is intended to provide additional information to an earlier synthesis on avian resources in the region (NSB 2011a). 5.3 Powerline Height and Bird Collision Our results are inconclusive to date regarding a correlation of height with avian collision risks. It appears that research attempting to verify different risks or impacts of powerlines at different heights is limited (e.g., APLIC 2012; R. Harness, EDM, Fort Collins, CO, in litt.; Table 1). The few studies that surveyed powerlines of varying heights within the same study and related their findings to numbers of bird fatalities at each powerline sample found habitat features (e.g., presence of lake shoreline, distance to forest edge or coastline), not powerline heights or bird crossing rates, to be the primary factor influencing collision rates (Faanes 1987, Cooper and Day 1998, Bevanger and Broseth 2004). In another study assessing the impacts of different powerlines on shearwaters in Hawaii, height of the uppermost line was not of primary importance, but the number of lines and depth of the vertical array were significant, in that wide spacing between vertically oriented lines increased collision rates (Podolsky et al. 1998). In the same location, spatial patterns of fatalities were strongly non-random and were related to habitat: —80% of all birds were killed at the —10% of powerlines that were located less than 100 in from the coastline (Cooper and Day 1998). Results of studies of avian collisions along powerlines in Prudhoe Bay and Barrow offer additional information to help assess the collision potential of the proposed powerline from Barrow to Atqasuk (Prudhoe Bay —Anderson and Murphy 1988; Barrow—NSB 201lb). Importantly, line heights for the Prudhoe Bay lines were higher than those proposed for the Barrow—Atqasuk project (see Appendix G, "Summary Infrastructure and Main Conclusions of Powerline-Avian Interaction Studies Relevant to the Proposed Barrow-Atgasuk Powerline, '). 5-2 Preliminary Engineering — Final Report fl)-.92=0 June 30, 2014 Atgasuk Transmission Line Project Collision rates at Prudhoe Bay were considered lower (<1 bird/1,000 overflights) than those for other North American locations (Anderson and Murphy 1988). Gulls, jaegers, and terns were the most represented species -groups in the sample of carcasses at Prudhoe Bay; however, at least 1 unknown eider, other waterfowl, and a loon also were recorded during surveys (Anderson and Murphy 1988). Both Steller's (2) and Spectacled Eiders (1) have been found dead beneath lower powerlines near Barrow (NSB 201 lb, A. Nestby, BUECI, Barrow, AK, pers. comm.), indicating that at least some of these threatened species fly at heights that will put them at risk of collision with the proposed Barrow— Atqasuk powerline. 5.4 Overhead Lines and Bird Behavior Those studies discussed above and numerous investigations summarized in the most recent APLIC (2012) publication indicate that structural aspects of powerlines and bird behaviors influence fatality rates more than line height does. Structural elements such as line diameter, presence of an unmarked ground (static) line, placement of lines in relation to specific avian habitats, spatial orientation of lines (parallel to vs. crossing migration or flight corridors), line configuration (vertical vs. horizontal), and lighting of lines were considered to be critical in affecting collision or fatality rates, whereas line height was not. Flight behaviors of birds using areas near powerlines also were considered more important than was powerline height in identifying potential collision risks and mitigation measures for those powerlines. For example, shearwaters in Hawaii flew at significantly lower flight altitudes in the morning, when they were flying from inland nesting colonies in the mountains to feeding areas at sea, than in the evening, when they were flying from the ocean to inland nesting colonies (Day and Cooper 1995). Flight behaviors that influence collision risk include whether or not the species flocks, movement types and flight altitudes (daily movements vs. long-distance migration), status and potential for habituation to lines (local vs. migrant species), and flight abilities of young birds (Drewitt and Langston 2008, APLIC 2012). 5-3 Preliminary Engineering — Final Report dft= June 30, 2014 Ataasuk Transmission Line Project 5.5 Flight Behavior of Birds in the Study Area The following narrative describes bird behavior in the Barrow—Atqasuk area and discusses how behaviors might influence collision rates with the proposed overhead transmission line and with high (>50 ft) vs. low lines (<50 ft). A brief description of other features of overhead lines (e.g., horizontal or vertical configuration, orientation across or parallel to migration pathway, and proximity to numerous lakes and ponds) is also provided. More thorough explanations of these structural elements of powerlines and their effects on birds are summarized in APLIC (2012). 5.6 Migration Behavior: Spatial Patterns Avian migration studies in northern Alaska have been concentrated primarily in coastal areas, and none have intensively monitored bird flights in inland areas, including the region between Barrow and Atqasuk. For example, numerous studies have documented waterbird migration past the northernmost tip of Alaska at Barrow (Myres 1958, Woodby and Divoky 1982; Suydam et al. 1997, 2006; Day et al. 2001, 2004; Quakenbush and Suydam 2004) and at other coastal locations along the North Slope (Gollop and Davis 1972, Lehnhausen and Quinlan 1981, Richardson and Johnson 1981). Most of these studies focused on the abundance, timing, and location of migrating waterfowl, rather than on flight behavior and flight altitudes. Although the migration of waterbirds, especially eiders, past Barrow is concentrated along the coast, where open leads (spring) and sheltered bays (fall) provide habitat for resting and foraging, there is evidence that the migration route is broader than that: along with other waterbird species, eiders migrate over inland routes as well. Spring migration, both easterly and westerly, along Alaska's northern coast is a broad -front phenomenon, as recorded at the Distant Early Warning radar installation at 4liktok Point, where radar tracking detected flocks of waterbirds migrating up to 50 km inland and 50 km offshore (Richardson and Johnson 5-4 Preliminary Engineering — Final Report • • - =• June 30, 2014 Atgasuk Transmission Line Project 1981). Flight altitudes of these flocks could not be determined by radar, but one can assume that the more -distant flocks were flying at substantial flight altitudes (i.e., greater than the height of the proposed Barrow—Atgasuk powerline). Unfortunately, low-level flights would not have been identified by the radar at great distances because they would be shielded by the curvature of the earth, so it is impossible to determine how many of the flocks migrating at that time were flying at low altitudes. Other evidence also supports a substantial amount of inland migration. Under certain weather conditions during spring migration, eiders may fly far inland from the coast. Myres (1958) reported flocks of eiders migrating eastward along the Meade and Inaru rivers, across the coastal plain south of Barrow. In addition, Woodby and Divoky (1982) noted a lack of Brant, loons, Sabine's Gulls, and jaegers observed at Barrow in spring and suggested that those species were migrating inland to bypass a longer flight around the coast. Further, substantial passages of Pomarine and Parasitic jaegers and Long-tailed Ducks have been observed flying downriver along the upper Colville River at Etivluk during spring migration (Kessel and Cade 1958), and Brower indicated that there is a substantial spring migration of Surf Scoters down the Colville River (Bailey 1948). Finally, recent investigations using data from telemetry studies indicate that numerous local breeding birds (including loons and eiders) often fly from their inland breeding habitats on the North Slope directly across the Barrow—Atqasuk study area to the coast of the Chukchi Sea in the fall (TERA 2003, NSB 2011; J. Schmutz, USGS, Anchorage, AK, pers. comm.). 5.7 Migration Behavior: Flight Altitudes Birds tend to fly higher if they are migrating long distances and, therefore, may have the least exposure to collision with low powerlines such as those described for the proposed Barrow—Atgasuk Powerline (APLIC 2012). However, many migrants on the North Slope, ..- :... 5-5 Preliminary Engineering — Final Report pl�A_rdJune 30, 2014 Atagsuk Transmission Line Project including threatened eiders and loons, might best be described as shorter -distant migrants that take numerous stops to rest and feed during portions of their large-scale migration (Lehnhausen and Quinlan 1981, Alerstam and Gudmundsson 1999, Peterson et al. 2000, Oppel et al. 2008; P. D. Martin, U.S. Fish and Wildlife Service, Fairbanks, AK, unpubl. data). Consequently, their flight altitudes on the North Slope probably are lower than those of true long-distance migrants. During the breeding season, birds including threatened eiders and loons regularly fly at low flight altitudes through the proposed Barrow—Atgasuk powerline corridor during the breeding season (late April through September). Flight altitudes of most of these local movements probably occur within the elevational range of the proposed Barrow—Atqasuk powerline and most powerlines in the United States (50-200 ft; APLIC 2012). Waterfowl and waterbirds conduct courtship behaviors (e.g., aerial displays, pursuit flights), feeding flights to and from nesting areas, and fledgling flights near their breeding lakes, all at low flight altitudes, during the breeding season, increasing their potential for collision with low-level wires (APLIC 2012). 5.8 Data from Tundra of Northern and Western Alaska Because specific information on flight altitudes of eiders and loons breeding in the proposed Barrow—Atgasuk powerline corridor generally is qualitative and mostly consists of anecdotal references, data from research on studies concentrating on flight behaviors of birds approaching or crossing transmission lines and other structures in northern and western Alaska are useful for assessing collision risks along the proposed Atgasuk— Barrow powerline. In the Prudhoe Bay oilfields, Anderson and Murphy (1988) studied bird reactions to newly constructed powerlines in the Lisburne Development Area. Transmission lines ranged from 14 to 24 in (46 to 79 ft) above ground level (agl), and support poles ranged from 15 to 25 in (49 to 82 ft) tall; the lines were in a horizontal configuration with a crossbar and an unmarked ground line. Researchers found that 89% of bird flights crossing the transmission lines passed over the lines, leaving only 11 % passing underneath the lines. Aft= 5-6 Preliminary Engineering — Final Report %7*_June 30, 2014 Ataqsuk Transmission Line Project More than half of the geese and swans crossing the powerlines exhibited collision - avoidance behavior (either gaining or losing flight altitude), indicating awareness of the collision hazard. Loons were judged to have the least potential for collision due to their crossing altitudes of >5 in (>16 ft) over the lines, even though they are not very maneuverable in the air; indeed, <15% of all loons that crossed the powerline exhibited anti -collision behaviors, presumably because their crossing altitudes were so high. Although gulls, jaegers, and terns showed a high percentage (45-55%) of collision - avoidance behaviors, the group still was considered at risk of collisions because many crossed <5 1n (<16 ft) from the lines and because gulls in other locations have substantial collision rates (Faanes 1987). Data on flight altitudes of birds in tundra areas of northern and western Alaska also are available from field studies conducted by ABR personnel from 1997 to 2006 (Day et al. 2001, 2003, 2004, 2005a, 2005b; Boisvert et al. 2004; Boisvert and Day 2005; Gall and Day 2007). We pooled data across all studies and summarized them by taxonomic group (see Table 5.1) after excluding data for birds seen flying >100 in (>328 ft) above ground level (agl; <1% of all observations) or flying only over the ocean. Table 5-1 Taxonomic Groups Used in Data Summary for Flight Altitudes of Birds in Northern and Western Alaska, 1997-2006. Taxonomic group Species/taxa Geese Greater White -fronted Goose, Emperor Goose, Snow Goose, Brant, Cackling Goose, Canada Goose, unidentified goose Dabbling ducks American Wigeon, Mallard, Northern Shoveler, Northern Pintail, Green -winged Teal Eiders Steller's Eider, Spectacled Eider, King Eider, Common Eider, unidentified eider Other diving ducks Greater Scaup, Harlequin Duck, Surf Scoter, White -winged Scoter, Black Scoter, unidentified scoter, Long-tailed Duck Waterfowl Tundra Swan, unidentified duck Ptarmigan Willow Ptarmigan, Rock Ptarmigan, unidentified ptarmigan Loons Red -throated Loon, Pacific Loon, Common Loon, Yellow -billed Loon, unidentified loon (large), unidentified loon Raptors Osprey, Northern Harrier, Rough -legged Hawk, unidentified hawk, Golden Eagle, Merlin, Gyrfalcon, Peregrine Falcon, Snowy Owl, Short -eared Owl Cranes Sandhill Crane (continued) 5-7 Preliminary Engineering — Final Report _s l June 30, 2014 Atagsuk Transmission Line Project Table 5-2 (continued) Shorebirds Black -bellied Plover, American Golden -Plover, Pacific Golden -Plover, unidentified Pluvialis plover, Semipalmated Plover, unidentified Charadrius plover, Bar -tailed Godwit, unidentified godwit, Ruddy Turnstone, Black Turnstone, unidentified turnstone, Semipalmated Sandpiper, Western Sandpiper, Least Sandpiper, Baird's Sandpiper, unidentified sandpiper (small), Rock Sandpiper, Dunlin, Long -billed Dowitcher, Wilson's Snipe, Red -necked Phalarope, unidentified phalarope, unidentified shorebird (small), unidentified shorebird (medium), unidentified shorebird (large), unidentified shorebird Larids (jaegers/gulls) Black -legged Kittiwake, Sabine's Gull, Mew Gull, Herring Gull, Slaty -backed Gull, Glaucous -winged Gull, Glaucous Gull, unidentified gull (small), unidentified gull, Arctic Tern, Pomarine Jaeger, Parasitic Jaeger, Long-tailed Jaeger, unidentified jaeger Corvids Common Raven Other passerines Horned Lark, Tree Swallow, Bank Swallow, unidentified swallow, Arctic Warbler, Northern Wheatear, Hermit Thrush, American Robin, Varied Thrush, Eastern Yellow Wagtail, American Pipit, Lapland Longspur, Snow Bunting, McKay's Bunting, Yellow Warbler, Wilson's Warbler, unidentified warbler, Savannah Sparrow, Fox Sparrow, White -crowned Sparrow, Golden -crowned Sparrow, unidentified sparrow, Dark -eyed Junco, Common Redpoll, Hoary Redpoll, unidentified rdpoll, unidentified passerine We present the data for birds flying up to 100 in (328 ft) agl to show where the majority fly within the air -column, then present detailed data for birds flying up to 50 in (164 ft) agl because that is the zone of interest in which the Barrow—Atgasuk powerline actually will occur. We present the data for observations (i.e., groups of 1 or more birds) because the behavior (and, by extension, the flight altitude) of birds within a flock is not independent. When the data are binned (combined) into 10-m flight -altitude categories, there is pronounced taxonomic variation in flight altitudes (see Figure 5.1). Most groups fly primarily at or below 30 in (98 ft) agl (the maximal height of the proposed powerlines and poles, to the nearest 10-m bin). These low -flying groups include: geese (n = 514 groups), dabbling ducks (n = 210 groups), eiders (n = 17 groups), other diving ducks (n = 41 groups), other waterfowl (n = 105 groups), ptarmigan (n = 19 groups), raptors (n = 74 groups), shorebirds (n = 150 groups), larids (n = 939 groups), corvids (n = 481 groups), and other passerines (n = 764 groups). However, loons (n = 122 groups) and cranes (n = 285 groups) fly primarily above 30 in (98 ft) agl. 5-8 Preliminary Engineering — Final Report • ••- :• • June 30, 2014 Ataqsuk Transmission Line Project Figure 5-1 Counts of Bird Groups Flying at Various Flight Altitudes Above Ground Level (m agl). Geese Dabbling Ducks Eiders Other Diving Ducks 75 - 50 - 25 - 0- Waterfowl Ptarmigan Loons Raptors 100 - 75 50 - E 25 - aD Cranes Shorebirds Lards Corvids 10u - s 75 - 50 - Passerines 100 - 75 - 50 - 25 - 0- 0 100 200 300 Count Note: Data are from birds studied in tundra areas of westeni and northern Alaska 1997-2006 and are summarized only for birds flying at or below 100 m agl. Axk, AdEftobb, 5-9 Preliminary Engineering — Final Report a.. :... June 30, 2014 Ataqsuk Transmission Line Project When the statistical distributions of the actual (i.e., non -binned) data for birds flying at or below 50 in (164 ft) agl are modeled, most taxonomic groups fly below the height of the powerline (Figure 5-2). Figure 5-2 Proportions of Bird Groups Flying at Various Flight Altitudes Above Ground Level (m agl). Geese Dabbling Ducks Eiders Other Diving Ducks 50 - 40 - 30 - 20 - 0- WaterfoM Loons Raptors Cranes Shorebirds Larids Corvids Passerines 50 - 0 - 30 - 20 - 10_ 0.. t I i I I i I I I i I i 0 00 0.02 0.04 0.00 0.02 0.04 0.00 0.02 0.04 0.00 0.02 0.04 Proportion Note: Data are from birds studied in tundra areas of western and northern Alaska 1997-2006 and are summarized only for birds flying at or below 50 m agl; curves are modeled from actual density data, rather than 10-m bins; horizontal bar represents the median flight altitude. 5-10 Preliminary Engineering — Final Report `' •- �• : June 30, 2014 Atagsuk Transmission Line Project If we assume that the maximal height of the powerlines and poles will be around 20-25 in (65-82 ft), the medians for geese, dabbling ducks, eiders, other diving ducks, shorebirds, larids, corvids, and other passerines all lie below that range, whereas the medians for loons and cranes lie above that range. Only the medians for other waterfowl and raptors occur in and near that height range. Because our data suggest that essentially all ptarmigan fly near the ground, we had to generate that plot separately, (see Figure 5- 3), to display the data at an appropriate scale along the X-axis. Figure 5-3 Proportions of Ptarmigan Groups Flying at Various Flight Altitudes Above Ground Level (m agl). Ptarmigan E40` a� Co LL10 t Proportion Note: Data are from birds studied in tundra areas of western and northern Alaska 1997-2006 and are summarized only for birds flying at or below 50 m agl; curves are modeled from actual density data, rather than 10-m bins; horizontal bar represents the median. 5.9 Conclusions In summary, quantitative information on the effects of powerline height on bird collision rates is limited. Instead, the literature and best practices for building powerlines suggest MhM= 5-11 Preliminary Engineering — Final Report June 30, 2014 Ataqsuk Transmission Line Project that the impact of a powerline varies in relation to the type of bird use (resident or migrant), value of nearby habitats (e.g., shielding trees, wetland feeding areas), topography, structural characteristics of the powerline (e.g., wire array), and factors influencing bird movements (e.g., behavior, weather and associated visibility). Based on knowledge of flight and migration behaviors of birds in the study area, especially threatened eiders and the Yellow -billed Loon, we suggest that the proposed heights of the Barrow—Atgasuk Powerline may affect local movements of breeding birds more than it will affect migrants, except in conditions of poor visibility, when migrants also may be at greater risk. Proposed heights of the wires (24 to —45 ft) fall within the wire heights of other powerlines where waterbird mortalities have been recorded elsewhere in northern Alaska during the breeding season (Anderson and Murphy 1988, NSB 201lb; USFWS, unpubl. collision database, Fairbanks, AK). The USFWS reviewed data on flight altitudes provided by ABR, Inc. and recommended that powerlines be constructed at a minimum of 40-50 ft agl to avoid the common flight altitudes of bird species flying over coastal northern and Western Alaska. The following recommendations for transmission line configuration could reduce collision risk to threatened and migratory birds: • maximize the overall detectability and height of the powerline (40-50 ft minimum height, depending on habitat) by incorporating more and/or taller poles in its design; • use existing infrastructure (e.g., natural gas lines) and follow existing powerline corridors wherever possible; • increase the visibility of the line (use of reflective line and/or bird flight diverters); • reduce the proximity of the line to bird take -off and landing areas (micro - alignments of poles); and • keep the vertical arrangement of wires to a minimum (i.e., consider horizontal alignment), which will also increase the height of the powerline. Finally, burying sections of the line where other mitigation measures cannot be implemented should be considered. By configuring the line with careful consideration for avoiding bird collision, the North Slope Borough can maximize the environmental benefits of supplying Atqasuk with electricity generated from natural gas. 5-12 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project Section 6.0 - Atqasuk Space Heating Conversion to Electric Heat 6.1 Background Power and heat energy in the NSB are provided by community based utilities that are electrically isolated from each other. Power and heat in Barrow, Alaska is fueled by a nearby local natural gas resource, whereas power and heat in Atqasuk, Alaska is fueled by imported fuel oil. Unlike Barrow, Atqasuk's reliance on imported fuel oil has contributed to very high and unstable energy costs. The village of Atqasuk is one of two in the NSB which is not directly accessible to fuel oil delivery by barge. Each year, approximately 500,000 gallons of fuel oil is purchased and delivered by barge to the NSB Barrow Fuel Storage Facility. From Barrow the fuel is either flown in or brought into Atqasuk by rolligons. The cost of purchase and delivery of fuel to Atqasuk averaged $6.70 FOB ATQ in FY 13. The use of imported fuel oil has a number of other problems including dramatic fluctuations in fuel price, fuel handling concerns and potential spills, potential interruption in fuel delivery, and noise and air pollution emissions from the diesel generators. In 2008 the Borough completed an NPRA funded study entitled; "Energy Options for the City of Atqasuk" prepared by LAJA. The study looked at converting Atqasuk's space heating loads to electric heat along with the City's power demand. The inclusion of space heating conversion to electric heat was possible as oil prices increased in Atqasuk while local electric power rates in Barrow decreased. Since 1981 imported fuel oil more than quadrupled in price while the cost of electric power in Barrow decreased from $0.15/kWh to $ 0.11/kWh. The 2008 study estimated the annual O & M savings of a complete power and heating 6-1 Preliminary Engineering — Final Report •• • June 30, 2014 Atgasuk Transmission Line Project fuel conversion in ATQ via this transmission line at $1.47 million, a 61% cost reduction from then -existing O & M costs. Further, with a larger connected load base, the power and natural gas produced in Barrow should also be lower, providing cost savings to both utility customers in Atgasuk and Barrow. In the 2011 study entitled, "Atgasuk Transmission Line feasibility Study the conversion of oil fired space heating equipment to electric energy was again touched on. However as the study concluded a more in-depth effort to identify capital costs and electrical demands created by the conversions were needed. This section takes on the in-depth look at the technical and economic issues related to the conversion. This section has been prepared in association with three other firms, all of which have done several projects in the City of Atqasuk. RSA Engineering, Inc., Energy Audits of Alaska and HMS Inc. RSA was contractually responsible to LAJA for this portion of the study and provided electrical and mechanical engineering services. Jim Fowler of Energy Audits of Alaska led the effort and performed the field survey and energy analyses. HMS Inc. conducted the construction estimate. The study effort culminated into a task deliverable report. The large size of the task report led to a stand-alone supplemental document entitled, "Atgasuk Space Heating Conversion to Electric Heat Supplemental Report ". The document is companion to this main report. For report continuity the main report includes the executive summary from the Supplemental Report. The Supplemental Report presents the methodologies used, all the energy data collected, narrative and calculations used, facility photographs, mechanical room plan views, manufacturer's specification sheets and estimates of energy loads and construction costs of each facility type. This report is also a stand-alone document involving just the conversion of Atqasuk's building structures to electric heat and would be invaluable if This part of the project should be developed. . ..- :.. . 6-2 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project 6.2 Objectives Section 6.0 was commissioned to achieve three objectives: 1. Power requirements - determine the electrical consumption and electrical peak demand load that would be required after this fuel conversion, broken down between residential and commercial consumers of electricity. 2. 5% Design and Costing - produce "one -line" schematics of the proposed HVAC systems for sample buildings and estimate the costs for conversion equipment and its installation. 3. Identify noteworthy technical issues that could affect the conversion process. 6.3 Site Visit and Data Gathering The village visit and building surveys took place over 4 days from August 18, 2013 through August 22, 2013. The school, fire station and USDW building in this village received investment grade energy audits (performed by Energy Audits of Alaska) through an AHFC managed program which was funded by American Recovery and Reinvestment Act grants in 2011 and 2012. These audits provided useful information in this study. 6.3.1 Benchmark Periods for Electric and Fuel Oil Consumption The only instance where fuel oil consumption is actually measured in this village is the generator plant fuel storage tanks, where the plant operator measures fuel oil levels daily. In all other cases, "fuel oil consumption" is actually the amount of fuel oil delivered to the building's fuel tanks. It is assumed in this report, that all fuel oil delivered in a benchmark year is consumed in the same benchmark year. For simplicity, the terms "fuel oil consumption" and "fuel oil delivered" are considered to be the same. 6-3 Preliminary Engineering — Final Report t June 30, 2014 Atgasuk Transmission Line Project For the buildings in this study, fuel oil consumption data is from the 24 month period from January 2011 through December 2012. The generator plant fuel oil consumption and kWh output data used in this study was the 24 month period from July 2011 through June 2013, which is FY 2012 and FY 2013. In this study, residential buildings include dedicated itinerant and school personnel housing, single and multi -family residences. Commercial buildings include all non- residential, federal, state, all community buildings and generator plant station loads and/or consumption. 6.3.2 Building Summary A listing of all of the village electric meters was provided by village personnel. Each meter has an associated building number (some of which were inaccurate) and organization name, in the case of commercial buildings. This listing, used to read meters and invoice the building owners each month, was used as a master list to conduct surveys and compile the total number of village buildings. In summary, there are 72 single family residences, two duplexes, one 4-plex and a single family house adjacent to the school using the school's heating system, for a total of 76 residential buildings. There are 9 small commercial buildings and 15 large commercial buildings. Additionally, there are another 15 buildings which do not utilize fuel oil either because they do not have heat or because they use electric heat; included in these are several connexs at the airport. There is some question regarding the accuracy of these figures because there are a number of structures on the list which do not appear to be in use, and several which appeared to be in use but were not on the master meter list provided. During the village survey, this list was updated to be as accurate as possible. The list is found in Appendix A of the Supplemental Report. J_9F 6-4 Preliminary Engineering — Final Report � June 30, 2014 Atqasuk Transmission Line Project 6.3.3 Installed Capacity Table 6-1 below shows the total existing installed diesel fueled heating and Domestic Hot Water, (DHW), capacity in the village, and the post -conversion electric heating and DHW capacities. The new electric heating capacities below were calculated using 75% of the nameplate net output of the existing diesel fueled boilers and/or furnaces (nameplate net output is typically 80% or 86% of the gross input). Table 6-1 Total Installed Capacity TOTAL INSTALLED CAPACITY - GROSS INPUT VALUES (no waste heat considered) Existing diesel fueled heating & DHW New Electric Heating New Electric DHW M BH kW kW kW Residential 1,738 509 288 54 Small Commercial 588 172 101 0 Large Commercial 21,192 6,209 4,006 200 Totals 23,518 6,891 4,395 254 6.3.4 Conservative Assumptions and Safety Factor Conservative assumptions have been made throughout the calculations and estimates in this study; all assumptions are listed below. Additionally, a 10% safety factor was added to the final calculations of total village electric consumption and peak demand loads. • A gallon of # 1 diesel fuel contains 138,000 BTU. A gallon of # 1 diesel fuel can contain anywhere from 132,000 BTU to 138,000 BTU depending on its refinement and what additives have been used. Additives adjust the fuel's cloud and pour temperature points based on the climate it will be used. The high 138,000 BTU value was chosen so that all fuel oil to kW and kWh energy conversions were conservative. • 1 kWh = 3413 BTU (assumes site energy, not source energy) .. .. • 6-5 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project • In all cases except the generator plant, fuel oil gallon figures are gallons delivered to the building, so "fuel oil consumed" assumes that all delivered oil is consumed in the same benchmark year as it was delivered. In the case of the generator plant, the operator records consumption daily and those figures were used. • 2.90 MNMTU of energy is used in an average rural residence for DHW production in climate zone 8; ATQ is in climate zone 9, but there is no significant difference in energy use. • Hydronic heating systems with diesel fueled boilers have 86% thermal efficiency (default value if nameplate efficiency is unknown) and 90% distribution efficiency. It is understood that due to standby losses and cycling, most operating boilers and furnaces will have actual thermal efficiencies less than their nameplate ratings. Their nameplate ratings were used as a conservative conversion factor to calculate the electrical power needed to replace the fuel oil energy. • Forced air heating systems with diesel fueled furnaces have 80% thermal efficiency (default value if nameplate efficiency is unknown) and 75% distribution efficiency. Same comment as above applies to furnaces. • Hydronic heating systems with electric fueled boilers have 99% thermal efficiency and 90% distribution efficiency. • Electric finned tube baseboard heaters and electric unit heaters have 99% thermal efficiency and 100% distribution efficiency. • Conversion calculations from diesel fueled forced air systems and diesel fueled hydronic systems (residences only) take distribution inefficiencies into account by de -rating the net heat output into living spaces, per gallon of fuel. • For residences and small commercial buildings, the inputs used in AkWarm-C and/or in the heat load equations are: ■ 67F temperature set point (this temperature was required to calibrate actual fuel oil consumption to AkWarm-C models) ■ .25 cfm per floor SF infiltration rate ■ R-19 wall insulation 6-6 Preliminary Engineering — Final Report June 30, 2014 Atgasuk Transmission Line Project ■ R-38 floor and roof insulation ■ Built on pilings (exposed floor) ■ U-.26 windows ■ U-.49 exterior doors ■ All have 4 rooms, and therefore 4-zones of heating ■ Minimum heating element step in a zone is 2 kW (one baseboard unit) • For large commercial buildings, the inputs used for AkWarm-C models and heat load calculation equations are: ■ 67F temperature set point (this temperature was required to calibrate actual fuel oil consumption to AkWarm-C models) ■ .25 cfm per floor SF infiltration rate ■ Minimum heating element step in a zone is 15 kW • The peak demand load in a single zone building with electric heat will be equal to the building's heat load on a design day with no building diversity • The peak demand load in a multi -zone building with electric heat will be equal to the building's heat load on a design day, multiplied by a building diversity factor (since not all zones will be active at the same time). The minimum peak load must take into consideration, the minimum element step size (kW) used in the heating system — the peak demand load cannot be less than the minimum element step size, and must be rounded up to the nearest element step. • Peak demand resulting from production of DHW is simply the heating capacity of the HWH, as it is assumed that at some time, all elements will be on to supply "design day" DHW. • The diversity factors for a building (in this report, called "building diversity factor") will be different from the diversity factors for the village (in this report, called "village diversity factor") and the village diversity factor for heating will be different from the village diversity factor for DHW production. • For peak demand load calculations the following assumptions were made regarding diversity factors. These are considered conservative figures: 6-7 Preliminary Engineering — Final Report %� June 30, 2014 Atqasuk Transmission Line Project ■ Building heating diversity factor for a multi -zone building is 80% ■ Building heating diversity factor for a single -zone building is 100% (i.e. no diversity) ■ No diversity factor (i.e. 100%) between Hot Water Heater, (HWH), and heating within a building (i.e. they can both be on at the same time) ■ Village heating diversity factor is 100% (to be determined by utility provider) ■ Village DHW diversity factor is 100% (to be determined by utility provider) 6.4 Existing Conditions — Fuel Oil The fuel oil consumption and distribution in Atqasuk are shown in Table 6-2, Figures 6-1 and Figure 6-2 below. Because waste heat from the village power generation equipment is recovered and used to heat buildings (and for process heat in the water treatment plant), it displaces additional fuel oil so its energy content will add to the transmission line's required capacity. For this reason, it is included in Table 6-2. Table 6-2 — Average Fuel Consumption FY2012 & FY2013 ConsumptionFuel . Residential 72,334 Commercial 142,037 Electricity Generation 265,324 Transportation 15,723 Other 1,979 Use of waste heat (avoided use of fuel oil) 19,610 Total 517,007 Note: 1) source of building fuel data: daily village delivery ticket logs; 2) source of generation fuel data: operator's daily logs; and 3) source of waste heat data: 30% of maximum recoverable energy from kWh produced by generators. 6-8 Preliminary Engineering — Final Report \ ' ' June 30, 2014 Atclasuk Transmission Line Project Figure 6-1 Fuel Oil Distribution 3.0% 3.8% s 14% used for residential heat & DWH ■ 27.5% used for commercial heat & DWH 51.3% used for power generation (source: operator daily logs) ■ .4% Unknown or questionable tickets a 3% presumed to be used for (diesel) transportation 3.8% Use of waste heat (avoided use of fuel oil) Figure 6-2 Fuel Oil Consumption 2-Year Average (FY2012 &FY 2013) — by Type of Use 6-9 Preliminary Engineering — Final Report .._�� • • June 30, 2014 Atqasuk Transmission Line Project 6.5 Existing Conditions — Electrical Electrical Consumption and distribution are shown below in Table 6-3, Figure 6-3 and Figure 6-4 Table 6-3 — Average Electrical Consumption of FY2012 & FY2013 Electrical Consumption (kWh) Peak Demand (kW) Residential Buildings 607,116 601 Commercial buildings 2,866,282 Total 3,473,398 601 Note: source: aenerator plant onerator°s daily loos Figure 6-3 Distribution of Existing Electrical Consumption by Building Type to Residential Buildings M Commercial buildings 6-10 Preliminary Engineering— Final Report L June 30, 2014 Atqasuk Transmission Line Project Figure 6-4 - Distribution by Customer Type M 2.2% Unbilled (Station 0.3% load) 9117.6% Residential & Seniors/Handicapped 0.3% Federal/State im 78% Commercial 1.8% Community Facilities 6.6 Limitations of this Study There are a number of significant factors which limit the accuracy of this study, all are discussed in more detail in the Supplemental document; they are summarized below: • Inaccurate and/or inconsistent tracking and recording of fuel oil. use for each building in the village throughout the benchmark period. • The Village diversit factor which significantly affects the total peak demand in the village is difficult to estimate. The peak demand for each building is calculated, but the unknown village diversity factor is the percentage of the 100 buildings in the village that have their heat, hot water heater, lights, ventilation and other electrical components in use at the same time, on a design day when the outside temperature is -41F. No village diversity factor was used to calculate peak demand; the utility provider should determine an appropriate factor. . ntt; am 6-11 Preliminary Engineering — Final Report June 30, 2014 Atclasuk Transmission Line Project • Due to budgetary limitations, it was not feasible to survey every one of the 76 residential dwellings. The 72 single family houses were categorized into 8 house types, plus 5 "unique" houses which did not fall into any house type. One each of the 8 house types was surveyed, as well as 2 of the unique houses. It is upon this sampling that the power calculations and cost estimates are based. Heat loads for every building. In order to determine peak demand loads and to properly size the heating equipment in a building, heat calculations must be performed based on exact insulation values, square footage, window and door areas and infiltration. It was not possible, within the scope of this study, to acquire this information for all 100 heated village buildings, so assumptions were made regarding wall, floor and roof insulation values and village maps and Google maps were used to estimate building sizes where they were not measured. A sample of houses were measured to obtain outside dimensions. (3) commercial buildings were previously audited (by the author), and therefore have accurate heat load calculations. • Individual building peak demand loads. There is a direct linear relationship between the accuracy of heat load calculations and the accuracy of peak demand load calculations. Heat loads were calculated for each building, but the accuracy of the resulting peak demand load calculations is subject to the variables listed above. • As previously mentioned, the master list of buildings provided by village personnel contained inaccuracies which will affect calculations in this report. 6.7 New Power Requirements and Peak Demand It is currently proposed that in the initial phase of the power transmission line project, power will be fed into the existing village power grid and only replace the existing generation capacity in the village. A second phase would convert all diesel -fueled heating 6-: s Preliminary Engineering — Final Report J'AMM=June 30, 2014 Atgasuk Transmission Line Project and DHW production to electric -fuel. Table 6-4 summarizes the power required for each phase. A 10% safety factor has been added to Phase 2 consumption and operating and cold start peak demand figures. Table 6-4 — Power Required by Phase - i u-/o sarety ractor mcivaea The first phase peak demand simply replaces the existing peak demand measured at the generator plant. The second phase peak demand is presented in Table 6-4 two ways: as an "operating peak demand" and as a "cold start peak demand". The operating peak demand is a calculation of the forecasted power generation capacity required under normal operating conditions. Village -wide diversity factors for heating and DHW reduce the operating peak demand load. The utility provider determines village heating and DWH diversity factors for a specific community. Table 6-4 uses a village wide diversity factor of 100% (i.e. no diversity). For the purposes of this report, the "cold start" peak demand load is considered to be the sum of all of the newly -installed heating and DHW capacity in the village. It is considered an absolute, worst case figure used for bracketing purposes — it is not expected that this peak demand would be experienced. z .._ ... 6-13 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project The "cold start" peak demand is the theoretical generation capacity which would be required to "cold start" the village after an interruption of power from the main transmission line into the village. It assumes that each building in the village has been "cold soaked" and therefore all heating and all DHW is active immediately upon restoration of power. The design of the village grid, including its sub -feeds and switching equipment, and the utility's start-up protocol after a power interruption will determine the actual start-up peak demand load. From this point forward in this report, "peak demand load" is used to describe the operating peak demand load, not the cold soak peak demand load. 6.8 Sensitivity of Results to Input Variances There is a wide range of accuracy and variance in the input data used to make the calculations presented in this report. The three groups of data most highly suspect, and therefore with the largest impact on results were determined to be: • Fuel oil consumption data • The amount of waste heat actually used by building's on the waste heat system • Actual building envelope insulation values. Because an 11% sample size of single family residential houses was used, fuel oil consumption data has a magnified impact on the results in this category. A larger, 38% sample size was used to calculate the average fuel oil consumption values, and therefore reduce the impact of source data variances. The extrapolated consumption correlates to within 94% of the actual consumption. Variations in the rest of the factors listed above have a linear relationship with the accuracy of calculated results, so it is their range of inaccuracy which determines the range of inaccuracy of the results. In all cases data was correlated on a year over year basis. Calculation results were compared to the results obtained by other independent 6-14 Preliminary Engineering -- Final Report June 30, 2014 Atqasuk Transmission Line Project methods and sensitivity analyses performed to determine a valid range of accuracy of the final results. For additional detail refer to the Supplemental Report, Section 3.4. 6.9 Cost Summary Cost estimates for the heating and DHW equipment and associated building electrical service costs are summarized in Table 6-5 below. These estimates are based on a 5% design, which includes sufficient concept development to acquire rough costs, but little or no engineering. "One line" schematics for each of the two design concepts described below are also found in the Supplemental Report, Section 4.0. Table 6-5 Summary of Building Conversion Costs COST ESTIMATE SUMMARY Quantity Subtotal Cost Each Extended Cost Residences 76 $36,851 $2,800,676 Small Commercial Buildings 9 $20 776 $186,984 Large Commercial Buildings 15 $112,564 $1,688,460 Village Total $4,676,120 6.9.1 Basis of Design - Residences and Small Commercial Buildings The 73 single family residences and 2 duplexes were assumed, based on sample surveys, to have either diesel fueled forced air furnaces and diesel fueled HWH's or hydronic boilers with HWG's, (Hot Water Generator), and hydronic finned tube baseboard heaters. The 4-plex and 9 small commercial buildings all have hydronic boilers and either no DHW or electric HWH's. In all 85 of these cases, new finned tube electric baseboard heaters will be installed above existing heaters or in the typical wall/floor location in each room. In all normally occupied buildings (excluding for example, the Search & Rescue and ASTAC buildings) programmable 7-day thermostats will be installed in each room and all new wiring will be run in surface conduit from a new electric service entering the building via a new disconnect with a utility grade meter installed adjacent to the existing unit. In the cases where 6-15 Preliminary Engineering — Final Report ohm= June 30, 2014 Atgasuk Transmission Line Project either a diesel fueled HWH or a HWG is in use, an electric HWH will be installed adjacent to the existing unit. In all cases, existing equipment will be left in place and will serve as backup in case of power interruptions. 6.9.2 Basis of Design - Large Commercial Buildings There are 15 large commercial buildings with hydronic boilers. In all cases, new electric boilers will be installed and piped into the existing hydronic distribution system and a new boiler controller with outside air temperature reset capability will be installed. In cases where diesel fueled unit heaters and/or ventilators are in use, electric units will be installed adjacent to the existing units. New wiring will be run in surface conduit from a new electric service entering the building via a new disconnect with a utility grade meter, installed adjacent to the existing unit. In the cases where either a diesel fueled HWH or a HWG is in use, an electric HWH will be installed adjacent to the existing unit. In all cases, existing equipment will be left in place and will serve as backup in case of power interruptions. Using this basis of design, a schedule of equipment and the one -line schematics, costs were estimated by HMS, Inc., a construction estimating firm located in Anchorage. Additional detail can be found in the Supplemental Report, Section 5.0 and the full HMS, Inc. cost estimates are found in Supplemental Report, Appendix F. 6.10 Technical Issues The author spent 4 days in the village surveying buildings for this study in August 2013 and 3 days in the village auditing buildings in 2011. During the most recent visit, he spoke with a significant number of residents whose general position on the transmission line was very receptive and positive. The most common question was, "When will it be in place?" 6-16 Preliminary Engineering — Final Report `i . •._ i.. . June 30, 2014 Atqasuk Transmission Line Project With regard to the conversion of buildings from diesel fuel to electric heat and DHW, there were no significant technical issues observed. Some of the minor issues are: • There are several buildings which do not have ample space in their existing mechanical rooms to accept an additional electrical boiler, but there is adequate space elsewhere. This will result in additional piping, but will not create a serious technical concern. • Several residences will have limited wall space above the existing hydronic baseboard heaters, but again, workarounds can be made. • Every building will have to be surveyed, preferably by an installer and design engineer. • Although most of the residences and small commercial buildings will have a similar design solution, each will have unique aspects and must be considered individually, as will every large commercial building. • The capacity of village transformers serving the houses, and the service to the houses will have to be checked and probably upsized to carry the additional load that will be imposed by electric heat and hot water, since these are significant loads. Another issue will be maintaining "mothballed" diesel fueled boilers, furnaces, HWG's and HWH's in ready -to -run condition to serve during power interruptions. The same issue applies to the village generators. Additionally, the generators will require jacket heat year round to assure they are in operable condition to quickly pick up the load in the event of lost power from Barrow. Training will have to be provided to village personnel to maintain the electric HVAC equipment as well as the new electric switch gear, transformers and transmission equipment. A new, different spare parts inventory will have to be maintained alongside the old diesel equipment spare parts inventory. 6-17 Preliminary Engineering — Final Report �AAIM= June 30,2014 Atqasuk Transmission tine Project Section 7.0 Update Transmission Line Cost Estimate 7.1 Background The purpose of Section 7.0 Transmission Line Cost Estimate is to update the line component costs developed in the Atqasuk Transmission Line Feasibility Study completed in 2011. Impacting those costs, other than time, where technical, environmental and social issues identified in the 2011 study. Those issues where addressed throughout this report and if they affected costs where evaluated in this section. Significant issues where evaluated for costs impact on the project. Those issues appear in the following sections: • Section 2.0 Agencies Review — evaluated impact of the Endangered Species Act and NEPA environmental studies on project • Section 3.0 Geotechnical Assessment — assessed Arctic environment, ice jams, global warming, pole installation and slurry. • Section 4.0 FRP Pole Testing — determined adequacy of installing FRP pole technology in permafrost. • Section 5.0 Determine Power Pole Height — evaluated pole and wire height potential for avian collisions. • Section 6.0 Atqasuk Space Heating - assessed the electric power and electric heat load requirements of the Community of Atqasuk. The new information generated from those sections, that impacted construction costs of the line, where integrated into this Section. Also cost impacts from changes to any construction methods, scheduling, labor costs or material selection where included in this Section as well. 7-1 Preliminary Engineering — Final Report I? + b- : • • June 30, 2014 Atqasuk Transmission Line Project 7.2 Route Selection Critical to the Cost of this project was the selection of a transmission line alignment from Barrow to Atqasuk. It consumed many hours and meetings to select a preferred route. Critical to the evaluation was to minimize infringement upon known, densely populated, avian nesting areas and avoid established native allotments. Also to avoid as much as possible lakes, surface ponds, and river drainages. The result of the Feasibility Phase route analysis was the selection of two routes, Eastern and Western routes. The selected routes appear in Figure 1-2. The Western Route utilized the existing 6" gas line VSMs to support the power cable from the South Gas Field to the existing Gas Line terminus at the Walakpa Gas Field, approximately 16 miles south of Barrow. This route was chosen as an attempt to reduce the amount of overhead power lines from Barrow to Walakpa thus avoiding the potential of Stellar Eider pole line collisions. The highest concentration of Steller Eiders occurs just south of Barrow. However, early in the Preliminary Engineering Phase it was determined to eliminate the Western Route from further evaluation. The reasons were: 1) the construction cost of the Western Route was estimated at $31.4 million while the Eastern Route came in at $15.1 million. The Western Route estimate was double that of the Eastern Route due to the high cost of running a large high voltage power cable attached to the gas line VSMs; 2) there were safety concerns expressed by the NSB Gas Field Operators. They did not feel installing a high voltage power line directly above the high pressure gas pipeline would be safe; and 3) the close proximity of a high voltage power line to a 6" steel gas line and steel VSMs would create a corrosive condition. These factors eliminated the Western Route from further study. The Eastern Route (see Figure 7-1) was selected as the preferred route for the remainder of this study with one change from the feasibility study. The existing power line from the 7-2 Preliminary Engineering — Final Report �l-`) June 30, 2014 91MM Atqasuk Transmission Line Project Figure 7-1 Transmission Line Route 7-3 Preliminary Engineering — Final Report North Slope Borough June 30, 2014 Atqasuk Transmission Line Project last house on Cakeater Road in Barrow to the South Barrow Gas Field Processing Facilities needs to be replaced. Built in the 50's this section of pole line was built with shorter than acceptable poles and where installed in a swampy area approximately 50 to 150 yards to the west of the existing service road to South Barrow Gas field. By replacing the line with a new line that runs along the service road alignment, maintenance of the line would be significantly improved and the service road could be lighted by street lighting therefore alleviating a bad condition along the service road to the Gas Fields during the dark months of winter. This new line would be about 2.25 miles long. The entire length of the Eastern Route is approximately 71.9 miles. 7.2.1 Agency Impact During the Preliminary Engineering Phase the ATL Project Team held two meetings with the BLM and USFWS, (see Section 2.0). Based on USFWS input, it was decided to present a second option to the Eastern Route to assess the cost impact of their recommended structural changes. Those changes included: designing the line near Barrow to have all three conductor phases in the same elevation without the use of crossarms. This option resulted in a three pole structure, each pole carrying one phase from The UIC Gravel Pit to the Walakpa intersection and including the powerline spur to Walakpa.; and the powerlines be constructed with a minimum of 40 to 50 feet ground clearance to avoid the common flight altitudes of bird species flying over coastal northern and Western Alaska. These recommendations impacted approximately 30% of the total transmission line distance. 7.3 Preliminary Engineering Design Basis The tasks undertaken for the Preliminary Engineering Phase are described below: • Provide design engineering to select the line parameters that can provide the least environmental impact to avian populations and also determine the most economic transmission line from Barrow to Atqasuk. 7-4 Preliminary Engineering — Final Report 17JI. db= June 30, 2014 Atqasuk Transmission Line Project • Minimize footprint of new facilities and utilize as much existing infrastructure as possible to avoid impact to sensitive flora. • Determine design parameters for wind and ice loads in arctic conditions. • Develop the design of a power transmission system that will serve Atqasuk and also facilitate a future expansion to Wainwright. • Provide cost estimates for the two transmission line Options 7.3.1 System Voltage The 2010 Feasibility Study looked at two Voltages. The line could operate at 34.5 kV initially if only the Atqasuk power load were considered. If the electric heat load was added the line would be upgraded to operate at 69 kV. The 69kV was selected for this project due to better line loss characteristics. The Line is designed with 115kV Insulators to avoid flashover from salt contamination. Therefore the only changes to upgrade the Voltage from 34.5kV to 69 kV would be a change in the transformer sizes at both ends of the power line. From Section 6.0, " Atqasuk Space Heating", Atqasuk had a peak load demand of 601 kW in FY 2013; with an average daily demand of 384 kW. If electric space heating is added to the power peak electrical load the load increases to 2,360 kW. If power is extended to Wainwright in the future, (no electric space heating load), the peak load would be increased by 1.0 MW bringing the total peak load between the two communities to 3.4 MW. The 69kV line voltage would handle the additional Wainwright load without a need for any increase in the voltage. 7.3.2 Structure Type The utility pole type for the transmission line was identified and selected as part of this study. The selected pole was the Fiber Reinforced Polymer (FRP) pole. For 7-5 Preliminary Engineering — Final Report "`� • ••- :• • June 30, 2014 Atgasuk Transmission Line Project details see Appendix E, RS Composite Utility Poles Brochure. The FRP pole was chosen based on the test results presented in Section 4.0 that established the technology as suitable for installation in permafrost. In addition the FRP pole does not require scheduled maintenance; maintains its strength to -76.6 degrees F; the weight of a 64.5' FRP pole is 1,295 pounds compared to that of a 65' wood pole at 3,973 pounds; and the FRP pole has twice the strength of a wood pole. The light weight and modularity of the pole makes the FRP pole easier to install and transport. It is estimated that it will take 13.5 hours to install a RFP pole compared to 18 hours to install a wood pole. Ease of installation and transportation along with lower transport costs offset the higher cost of the FRP pole compared to wood. A 64.5" F-0250 FRP pole cost $3,989.70 each and a 65' H2 wood pole cost $2,014.00. The modular design offers several options to obtain the same length of pole but at different strengths as shown in Appendix E. The Feasibility Study selected the 62.4' F-0104 RLS Composite pole. However after applying Arctic weather parameters to a structural deflection analysis the pole manufacturer determined a stiffer pole section would be required to minimize pole deflection. The 64.5' F-0250 RLS Composite Pole replaced the F-0104 pole. In comparison the F-0104 pole has a stiffness ratio rating of 12.7 lbs./in. and a base O.D. of 18.27 in.. Compared to the F-0250 pole which has a stiffness ratio rating of 18.8 lbs./in. and a base O.D. of 21.28 in. The F- 0250 pole cost $820 per pole more than the F-0104 pole. The additional cost of the F- 0250 pole still proved more economic than wood or steel pole options because of the lesser weight and lower costs to transport and install. The structure type selected for Option 1 was the TP-69 Transmission Line Structure as shown in Figure 7-2. As determined from the available historical weather data, the isokeraunic levels are low, so the design does not require the use of any overhead ground wire for lightning protection. The TP-69 structure carries three wires and consists of two offset high strength fiberglass insulators mounted on either side of the 7-6 Preliminary Engineering — Final Report • ••- :• June 30, 2014 Atqasuk Transmission Line Project pole and a single vertical high strength insulator mounted at the top of a single F- 0250 pole. This structure is capable of supporting transmission lines that approach the structure at small angles, with the provision of a side guy wire retaining anchor. This structure proved to be the most economical alternative compared to other structures examined since it is easier to construct in the field. Figure 7-2 TP-69 Transmission Line Pole Structure ... O. OF .O� � l�II � i !i The diagram to the left shows the dimensions of an insta{{ed 1'P-69 Pole Structure using a I'RP Composite Pole, F-02�0, GROUND LINEwith an overa{{ height of G..S feet and embedded 12' into the ground. The recommended structure for Option 2 is a three pole configuration that would have all three conductor phases in the same elevation thus reducing the potential for Avian power line collisions. Also the structure does not use crossarms which the agencies feared would provide nesting opportunities for Ravens. See Figure 7-3. This structure consist of three F-0104 poles spread about 15' apart from one another and each pole carrying a single phase. 7-7 Preliminary Engineering -- Final Report q-dM== June 30, 2014 Atqasuk Transmission Line Project Figure 7-3 Three (3) Pole Transmission Line Structure 7.3.3 Pole Installation Three options were considered for the pole foundations (see Section 4.5, "Pole Foundation." ). The pole direct set method using drill and slurry was selected as the most cost effective option. Compacted backfill with ad freeze slurry will be used to aid in providing lateral and uplift resistance of the pole. While jacking and creep are two issues requiring regular maintenance review, in the cold permafrost, north of the Brooks Range, over drilling has worked well to nearly eliminate this problem. The method was instituted to place the power pole supports well below the active layer at the NSB power grids. For this project the drill depth was set at 12 feet below grade. This is deeper than poles normally set on the North Slope, (BUECI sets poles at 10 feet), but takes into account the heavier loads, impact of the effects of global warming into the future and an added safety factor. Q7-8 Preliminary Engineering — Final Report MOMM June 30, 2014 Atgasuk Transmission tine Project The foundation fill material selected is sand and gravel slurry aggregate instead of slurry utilizing drilling fines. The foundation fill material requirement increased the cost estimate by $1.16 million. The special fill material will need to be purchased and hauled along the route during construction. If suitable material is discovered along or near the route during design field surveys that cost could be reduced. The modularity of the poles will provide the opportunity to dispose of the drilling fines. The lower section or base of the pole is 18' in height. This section is also hollow and will be able to hold the entire drilling fines. 7.3.4 Conductor Selection Weather Data Parameters Weather plays an important role in selecting powerlines. As determined from the available historical weather data, the isokeraunic levels are low, so the design does not require the use of any overhead ground wire for lightning protection. As a result, the design calls for 3 wires installed on a single pole structure type TP-69, or a three pole structure with each pole carrying one phase. Based on research of historical weather data, the following design criterion are applied for the conductor loading and anchoring design: • Per NESC, Heavy Loading District Condition — Load = 0.5" ice with 4 lbs. /sf. Wind Load = 40 mph on the exposed conductor. • Wind Load = 110 mph or 31 lbs/sf with no ice on the exposed conductor. • Wind Load on Insulator Swings = 49 mph or 6 lbs/sf with no ice on the exposed conductor, for use as basis in horizontal clearance calculations. 7-9 Preliminary Engineering —Final Report • • :• • June 30, 2014 Atclasuk Transmission Line Project Conductors Selection of the conductor is one of the most important design decisions made, as it is the critical component of any power transmission system. The factors considered when determining the conductor selection are as follows: • corrosion considerations — resistance or allowance • material strength • voltage drop properties resistance • thermal capability • economics of use During the selection process two conductor sizes surfaced as viable alternatives for this project. They are the Hawk/ACSS/AW 477 MCM and the Lark/ACSS/AW 397.5 MCM. Both have adequate resistance properties, adequate strength, and exhibit good corrosion resistance. The specifications of both conductors are summarized in Table 7-1. Table 7-1 ACSS/AW Conductor Specifications Source: Southwire Company, Carrolton, Ga. Based on an analysis of the two conductors, The 397.5 MCM Conductor is slightly lighter, stronger, and smaller in diameter than the 477 MCM cable. The construction cost comparison of the two conductors installed per mile is: • 477 MCM = $73,000 / mile • 397.5 MCM = $71,400 / mile North Slope Borough 7-10 Preliminary Engineering — Final Report June 30, 2014 Atgasuk Transmission Line Project The 477 MCM conductor has about a 2% increase in construction cost over the 397.5 MCM conductor. The annual line loss operating costs for the two cables are: • 477 MCM = $34,275.43 / year • 397.5 MCM = $39,104.64 / year The 397.5 conductor line loss is 14% greater than the 477 MCM conductor. Both conductor sizes are suitable for this project. Since the 477 MCM has less line loss and greater capacity it was ultimately selected for this phase of the project. Further analysis of the 477 MCM ACSS/AW standard conductor led to the discovery of the 477 MCM ACSS/AW specialized T2 type conductor or VR2 vibration resistant cable. (see Figure 7-4). This specialized conductor is designed to resist wind induced motion that causes galloping, Aeolian vibration and sub -conductor oscillation in transmission lines. For this project it has another application. The T2 is a pair of stranded aluminum, steel reinforced conductors twisted around each other at nine foot intervals. They differ from standard conductor that has a smooth appearance and is not twisted. It is this twisting that provides light reflections allowing birds to see the conductor eliminating conductor bird collisions. It is proposed to install T2 conductor on the two outer wirelines on the pole structure for the length of the transmission line for both Options 1 and 2. Line Loss at 69 kV Since there are several variable factors that influence line loss, such as, conductor size, line voltage, transformation, distance and temperature, line loss for the transmission line is presented in four cases. Case 1 and 2 involve Atqasuk only and 7-11 Preliminary Engineering — Final Report • •• =' June 30, 2014 Atqasuk Transmission Line Project Figure 7-4 T2 Conductor The T2 conductor is not a single conductor but two conductors twisted around each other every 9 feet as pictured below. The twisting of the T2 conductor gives out light reflections, as shown in the photograph, allowing birds to see the conductor reducing the potential of conductor bird collisions. Source: General Cable, Highland Heights, KY looks at the peak and average anticipated loads. Case 3 and 4 involve Atqasuk and Wainaright and looks at the peak and average loads. Common to all cases is the use of 69 kV line voltage and the use of 477 MCM conductor. Case 1, Atqasuk, maximum load at 2,500 kW, with a transmission distance of 70 miles. Line loss =1.73 % Case 2, Atqasuk, average load at 1,600 kW, with a transmission distance of 70 miles. Line loss =1.72 % Case 3, Atqasuk and Wainwright, maximum load at 3,500 kW with a transmission distance of 70 miles for Atqasuk and 120 miles for Wainwright. Line Loss = 2.38% Case 4, Atqasuk and Wainwright, average load at 2,300 kW, with a transmission distance of 70 miles for Atqasuk and 120 miles for Wainwright. Line Loss = 2.02% 7- J 2 Preliminary Engineering— Final Report • •• �• • June 30, 2014 Atgasuk Transmission Line Project Aeolian Vibration There are two types of Aeolian Vibration to be considered during the design effort. They are Aeolian Vibration and Galloping Vibration. Occurrence of Aeolian vibration is typically encountered in high tensioned power lines. Per the design, this type of vibration is not expected, but as a precaution Armor Grip Suspension (AGS) will be installed on all conductor attachments to minimize the potential for this problem. It should be noted that this project will not utilize high tensioned power lines and the use of T2 wire will also reduce Aeolian and galloping vibration. To address Galloping Vibration, which is expected, the longest spans for a single pole structure will be designed to be no longer than 700 feet in length, installed at, and no longer than 1200 feet in length, installed at three (3) pole structures. The conductors will be subjected to Double Loop Galloping Vibration where the required clearance is maintained. Sag and Tension The recommended, applied tension limit to the conductor is shown in Table 7-2. From the Table 7-2, under Tension Condition number 3, Standard Loaded, the tension limit, as a percentage of rated breaking strength is 50%. Conductor Sag and Tension charts with a 50% tension limit and per NESC Load Cases, is presented in Table 7-3. The following factors are used in each case. • Span Basis 700 feet and 1200 feet respectively. • Conductor Basis 477 MCM ACSS/AW. With the conductor temperature at 60 F, at a 700 foot span, the resultant sag is expected to be 14.72 feet, and expected NESC Load Case tension equaling 7,004 lbs. _i Preliminary Engineering — Final Report • .- : June 30, 2014 Atqasuk Transmission Line Project Table 7-2 Recommended Conductor Tension Limits Temperatures • Tension limits for conditions 1, 2 and 3 below are to be met at the following temperatures: Heavy loading district 0° F Medium loading district 15' F Light loading district 300 F • Tension limits for condition 4 are to be met at the temperature at which the extreme wind is expected. • Tension limits for condition 5 & 6 are to be met at 32' F Tension Condition Tension Limits (See section 9.6.2 for (percentage of rated breaking strength) Conductor OHGW High OHGW Extra High explanation) Strength Steel Strength Steel 1. Maximum initial unloaded 33.3 (Note C) 25 20 2. Maximum final unloaded 25 (Note D) 25 20 3. Standard Loaded (usually NESC 50 50 50 district loading) 4. Maximum extreme wind (Note A) 70 (Note E) 80 80 5. Maximum extreme ice (Note A) 70 (Note E) 80 80 6. Extreme ice with concurrent wind 70 (Note E) 80 80 Notes: (A) These limits are for tension only. When conductor stringing sags are to be determined, tension limits 1, 2 and 3 should be considered as longs as tensions at conditions 4, 5 and 6 are satisfactory. (B) Tension limits do not apply for self -damping and other special conductors. (C) In areas prone to aeolian vibration, a value of approximately 20 percent at the average annual minimum temperature is recommended, if vibration dampers or other means of controlling vibration are not used (see section 9.9 for further details). (D) For 6201 AAAC, a value of 20 percent is recommended. (E) (E) For ACSR only. For 6201 Aluminum, use 60 percent. Source: Rural Utility System Design Manual for High Voltage Transmission Line, Table 9-3, Bulletin 1724E-200, page 9-10 7-14 Preliminary Engineering — Final Report June 30, 2014 Atgasuk Transmission Line Project Table 7-3 Conductor Sag and Tension Data t } L t;/} .� .a,.Y a a.5t .-t CV � c-- M tA3 .-■ s-4 } i .-a c-C rt t . • .c-i .--• CV cV ^ t a 'C3 t? -a•i t C,la f• CV L:_. } M act r.,r? fit• ,.v - t+ ais KY "� i-- M M t+�7 CV EK •ri R(7 R f } } +y. cat t'V fV .r-} M a:rt .e-f �t .-i <-i C7. t?1 - R7." -t-■ qi M t3'. C^4 ac' arCI> cCla r V CIScv cv -4 .-e / r ■ CV } ! fYt EYa � ■ C..'"'71 f- G7Fs -• rJ'i� aa'7 } .y. ciA a-- t } ,_,,, d,a i f-► M M cv �' y cV CV +.-■ H i e M ata� at'7 c- t t v_i RO C/) Rr+. L t t Lii --•r } ay f ^- c^ [--- .. t Ct' r-• ^cf� ar�'e G ■ Crti } cV +C3 N�y •... oz .-+ 0 3 ta-. t act c-- M os [-- M c--- As C-- ass �a ati C^4 -C. Ct-r "�•^ M tys us f-- c-- t0 ar'> -� M 3-. ` � gyp. '.�•! a++ �? ■ M M M M cV V .- a e--f +c. .u. VY ts9: •r-`L a•.. co; tit 1 -::" M M fV ■ - cV c31 V"a C• a+Ga Ic. at} a} act 4� cV act c'V Kf � 04 SS E� •--i E a:ct ass +s <s• «r c+'f a�'� +ry cv Eay t rt } - { ^•.A R._--'•. [-_ till R.f'i a.Ga i-- -S' �C. at:wa •.i tT 1 •;/Y � i-t ■ act �. M f'-- M CT ['-� M f V LY tO i_-.- c•�• [-•_ 4� ca.r 4s c-i 1 f-� :3 .� a-t - L• c> V c.i ...... .a•.l { CIA cV f-- a-v r .-t Kw'S O rss tYs •.ss au ■ aG• t M +S_. M C77 CV M aGs r°•a t RrR� # -f LS �"-' : [Y'Y '- .as ..� # UnF„ t� ^ C7 � ts• M M M M --4 CV cV cv ,-{ Gs 1 1-4 - - ■ M ass M C. a--t as afa t7r. i--tt x c -� t/a o/} cla } t-- c' s clj cv .er ca acar--- y�y,......L"... _ cJ] } t7{. cv cal taa cv ca. cts tas M C'1) CV .� JG' t i '•-�. � cr.•17 [^ iIf% M KA} t.? 1 U t ?{ •�ri •Yi �"." RYi t Ca -iM M CV / .C. �-r cV .vl Ca ta:a tO w-i a.0 i?3 a'v a3. <•+'} oss Vt.a #.+.� +i i } F i i'-- +�<]� tss - -cx•-r1• M M av F-t RCF OS MR �- __ } } } ■ o'. a-v C'V rV CV cV cV [Y CV Cam. 1 di ' i } } ! .d.> a.Ca� tO ar,J K+G aCt 'C ICI1P C{.■ •t.-t-� f �J .'la ECF C e • ,-L C. +G'• +C. �a C". O �C. G. -" �-? [� a:9 .-/ •V ?v ,.._.� ;� it "j-•,j RC1 ate, •"�. L i-- cV rV cV t ",f• a,G. aR;! aC:t c'4 ap C".l C'V atft aC:t aCi tep tit Y �f 1. • t! +-4 .C+ .C. L-Z l:.a +Ga �a a'a R-'f qJ Va } ;,� +c. -t-t 'ca ErL +ta +o C,.•.t f-. } i } acr .� � C� +C. c. �c. ate• �-t Cam. s~t ays _ - C C: Azz c" { ca CS t'3. �3 l W a w" all. !ti1 R1n 4" y„i" 1.). C? r t •-'lC C. K.-. f-- � � �.•-' aEa .[a .Yp RSS�fs Qi 43 tl] } [s3 cv tti ■ / G. M �. t71 .-i .-C s-i t.a G •. f tFl a_o EC LT t cry a E R. L< a< F p M 1CS •I�'11 L..T i-t #�' •�•i E E -, : C M c1C1 1 Rf'} r..• �^/Q�� 1 tea` ? �-i CIA C"':t „v ul'i at+ f-- G3 -C" c.,� tf7 "� : t�*+e 7-15 Preliminary Engineering - Final Report n_• •: : June 30, 2014 Atqasuk Transmission Line Project With the conductor temperature at 60 F, at a 1200 foot span, the resultant sag is expected to be 43.83 feet, and expected NESC Load Case tension equaling 7,448 lbs. Loading and Overload Factor The power line will be designed per NESC Heavy Loading District, applying REA Grade B Overload Capacity Factors, for Poles, Guy Assemblies, and Insulators as shown in Appendix H, "Conductor Loading and Overload Factors ", RUS Tables 11- 6 and 11-7. Ground Clearances The line will be designed for 69 kV Power Transmission capacity so the expected conductor ground clearances, when the conductor temperature is 60 degrees F, at full load, will be per the Table 7-5. It is recommended that 23.1 feet of vertical clearance from conductor to ground, is maintained, for most locations. To satisfy the USFWS recommendation that the power line should be designed within 40 to 50 feet ground clearance, Option 2 utilizes the three pole structure and has a minimum ground clearance of 40 feet at a temperature of 60 degrees F with a ruling span of 670 feet. 7.3.5 One Line Description for AC Operation It was determined in a meeting with BUECI at their Power Plant facilities that a new dedicated feeder cubicle will be added to the new bay of switchgear planned for installation later this year. The Atqasuk cubicle will consist of a dedicated 4160V Breaker. From this breaker an underground feed will connect to a 2 WA transformer to step up voltage from 4.16 to 69 kV near the BUECI Power Plant. The 69 kV Power line will be routed to the Barrow Gas Field South Pad and then to the UIC Gravel Pit on single poles with an old/new distribution under build. At the new sub - station near 7-16 Preliminary Engineering — Final Report • •. :• . June 30, 2014 Atgasuk Transmission Line Project Table 7-4 Conductor Ground Clearance Line conditions under which the NESC states vertical clearances shall be met (Calculations are based on Maximum Operating Voltage): 32°F, no wind, with radial thickness of ice, if any, specified in Rule 250B of the NESC for the loading district concerned. - Maximum conductor temperature for which the line is designed to operate, with no horizontal displacement Nominal Voltage, Phase to Phase (kVLL) 34.6 69 116 138 161 230 & 46 Max. Operating Voltage, Phase to Phase (kVu,) --- 72.5 120.8 144.9 169.1 241.5 Max. Operating Voltage, Phase to Ground kVLe ---- 41.8 69.7 83.7 97.6 139.4 NESC Basic Clear.(Note F) Clearances in feet 1.0 Track rails 26.5 29.2 29.7 30.6 31.1 31.5 32.9 2.0 Roads, streets, etc., subject to truck traffic 18.5 21.2 21.7 22.6 23.1 23.5 24.9 3.0 Driveways, parking lots, 18.5 21.2 21.7 22.6 23.1 23.5 24.9 and alleys 4.0 Other lands cultivated etc., traversed 18.5 21.2 21.7 22.6 23.1 23.5 24.9 by vehicles (Note B) 5.0 Spaces and ways accessible to 14.5 17.2 17.7 18.6 19.1 19.5 20.9 pedestrians only (Note O) 6.0 Water areas - no sail boating 17.0 19.7 20.2 21.1 21.6 22.0 23.4 7.0 Water areas - sail boating suitable (Notes D & E) Less than 20 acres 20.5 23.2 23.7 24.6 25.1 25.5 26.9 20 to 200 acres 28.5 31.2 31.7 32.6 33.1 33.5 34.9 200 to 2000 acres 34.5 37.2 37.7 38.6 39.1 39.5 40.9 Over 2000 acres 40.5 43.2 43.7 44.6 45.1 45.5 46.9 8.0 Public or private land and water areas posted for rigging or launching sailboats (Note E) Less than 20 acres 25.5 28.2 28.7 29.6 30.1 30.5 31.9 20 to 200 acres 33.5 36.2 36.7 37.6 38.1 38.5 39.9 200 to 2000 acres 39.5 42.2 42.7 43.6 44.1 44.5 45.9 Over 2000 acres 45.5 48.2 48.7 49.6 50.1 50.5 51.9 ALTITUDE CORRECTION TO BE ADDED TO VALUES ABOVE Additional feet of clearance per 1000 feet of .00 .02 .05 .07 .08 .12 altitude above 3300 feet Source: Rural Utility System Design Manual for High Voltage Transmission Line, Table 4-1, Bulletin 1724E-200, page 4-6 the BUECI Power Plant will be located one (1) 69 kV SF6 breaker. Another breaker will be installed at the end of the power line at Atqasuk. A one -line electrical diagram of the transmission line appears below in Figure 7-5. 7-17 Preliminary Engineering - Final Report • •' ' June 30, 2014 Atqasuk Transmission Line Project Figure 7-5 Electrical One -Line Diagram B., — BUEGI V.- 4.2 kV 43 W GRID Vd:0 % PF: 99.9 % 5 MVA-1 497.1 A 3676.4 kW 109.5 kVnr Vs: BB k V 72 kV Vd:-% PF: 10000 % 7 H Alq — 99 kV Vs: B9 kV 60.9 kV Vd /.3% PF�5.9 % 5 MVA-2 } _ 314A 3517 6 kW 1450.3 kVer L1 /k y b 9 & a 69 kV Reath, Vs: 69 kV 09.9 kV Vtl: -1 .3 % V.: 2kV 4k 4.18 kV . 1 kV 4.kV Vd: 1 % PF. 84 2 % Source: Sakata Engineering Services Note: Atqasuk average load at 1,507 kW for power and heat Next to the Atqasuk Power Plant will be installed a 2 MVA step down Transformer on a pad configured in a similar manner to the existing 1 MVA Transformer. Another pad will be required for a 4 WAR 69 kV Reactor. Also near the power plant will be installed a new 4160 V Recloser. The 69 kV incoming feeder will use a SF6 Low Profile Circuit Breaker. The 4160V Step-down voltage will be routed through a recloser that should connect to the Atqasuk Power System. 7-18 Preliminary Engineering — Final Report _ db= June 30, 2014 Atqasuk Transmission Line Project 7.4 Estimated Costs of Construction 7.4.1 Physical Description The Construction Cost Estimate is based upon procuring and constructing a new power transmission line capable of supplying power from Barrow to Atqasuk, Alaska; located approximately 65 miles SSW of Barrow. These Communities possess minimal existing infrastructure, and only winter trails currently exist between their locations. Some of these winter trails are near the proposed power line alignment. The estimate is based upon the Community of Atqasuk requiring a maximum electrical power load of 601 Kilowatts (KW) and a maximum electrical space heating load of 1758 kW, with a combined electrical peak demand of 2,359 kW. This electrical demand is supplied by the BUECI power plant in Barrow. It should be noted that review of the anticipated heating loads indicate that the stated 2 MW requirement presented in the Feasibility Study 2011, may be low, but the change in cost is not significant, as a function of initial project cost. Major cost increases from the 2011 Study include: foundation rill material, increase in labor and material cost, added 2.25 miles of newly constructed Power Line along the service road to South Barrow Gas field and environmental recommendations presented by USF&W. To address these costs increases, while addressing potential line loss, the design promotes conductor and structure material strengths that maximize span lengths. This serves to reduce costs, while applying allowed NESC and IEEE design parameters, which would allow a much larger power load increase without significant cost increases. In addition, the requirement for a 100 Kilowatt (kW) Tie-in at the Walakpa Gas field power plant is also included in the estimate and its load has been taken into account. 7-19 Preliminary Engineering — Final Report a = • June 30, 2014 Atqasuk Transmission Line Project 7.4.2 Basis of Estimate • Estimate is based upon historical data and recent material vendor quotes. Accuracy should be within a 10% to +25% of cost certainty. • Assumed labor costs are based upon Davis/Bacon or Union Scale pay rates, per the Fall 2013 Rate Schedules. They show 9% increase over 2011. • Several industrial commodities' costs, especially copper, have escalated substantially since the quotes were received, and should be indexed, during the next estimate effort. • No allowance is provided beyond installing switching and controls, for an electronic interface between the existing powerhouses. The NSB power loads and equipment costs, for any additional connections, should be minimal but the BUECI power and control interface may be a bigger issue since it is not just required to find a working solution, but one that BUECI concurs with. For example their equipment may require upgrades and a solution to enable matching signal inputs to older existing technology. BUECI has been working on a capital improvements program. • No allowance for Right of Way (ROW) or land acquisition is incorporated and is assumed to be provided by others, if required. • Labor Productivity Rates are based on trained, craft personnel and other Direct Costs are based upon the assumption that construction effort will be one year in duration. • The Construction Schedule is heavily dependent upon a onetime, on time, comprehensive, material delivery via Bowhead Barge Service, which occurs annually. There are other options available, but there would be significant cost impact if utilized. • The estimate is based upon constructing a power transmission line with 2 Megawatt (MW) operating load at 69 kilovolts (kV), designed with 115 kV spacing/insulation on overhead (OH) segments that comply with the National Electric Safety Code (NESC). • It is planned to tie into the existing control system with a Power Line Carrier (PLC) through a Supervisory Control and Data Acquisition (SCADA) system. • Facilities in Barrow and Atqasuk are expected to be utilized for housing and meals. For areas away from Barrow and Atqasuk along the line route, A Cat 7-20 Preliminary Engineering — Final Report •:�o ' June 30, 2014 Atgasuk Transmission Line Project Train Camp will provide support services including housing and meals for the crew.Camp costs including lodging, fuel and food are included in the labor estimates. • Equipment required for construction is planned to be leased like bucket truck, pullers and tensioners, diggers and mixers. These leased costs could be turned into equipment for purchase at not much additional cost. These costs are included in the labor estimates. 7.4.3 Construction Costs Construction costs are broken down into line and substation segments. A text description of each segment is presented below with a summation of costs presented at the end of this subsection. Barrow Substation • The construction estimate is predicated on the power transmission line tying from the BUECI Power Plant with a 4.16.kV breaker and connecting via an underground cable to a new 2 MVA step up transformer connecting to the new 69 kV volt power line. • An issue requiring resolution is the basis for the power and control interface between the BUECI and the NSB facilities. While an important and vital part of the system, the differences are not expected to cause significant cost impact. • It is assumed that there is adequate space available near BUECI power plant area, to allow for the required transformer, breakers, switches, control module, or other required appurtenances. • This work is assumed to be in the summer season although it should be noted that the substation equipment has the longest material order lead time. • Existing support facilities in Barrow are expected to be utilized for housing and meals. Barrow to South Pad Line Segment and UIC Gravel Pit Length: 9.0 Miles • This section of line will be on single poles with a 4.16.kV under build. 7-21 Preliminary Engineering — Final Report PA-M•' : June 30, 2014 Atgasuk Transmission Line Project • This work is assumed to be performed during the summer season, and is predicated upon utilizing the existing ROW/roadway, for an existing power line. During the construction effort personnel will install new 65' tall RLS Single Composite Pole Structures, with embedment of approximately 12' feet in depth, along the existing ROW. • This work, especially in Barrow area, will be performed with the system energized. • The existing 4160 volt circuit conductors will be relocated to new poles. An allowance is provided for all new dead end and angle structures. Approximately 50% of the tangent structures to be provided are required per National Electric Safety Code (NESC) clearances. Some transformers and cutouts will also be relocated to new structures. Short outages for transfer of the services will be required on this segment, but timely warning to the affected consumers should not be an issue. • Additional ROW footprint may be required, for guy anchor installation, due to the taller poles requiring longer guy leads. • Existing support facilities in Barrow are expected to be utilized for housing and meals. The cost estimate for the Barrow substation and transmission line to the UIC Gravel Pit, 9 miles, is $ 2.6 million. This applies to both Options. This estimate includes single pole 64.5' RLS Composite (F0205) TP-69 structures, 477 MCM ACSR Conductor, I I5kV Insulators. UIC Gravel Pit to Atqasuk — Overhead (OH) Line Segment — Length: 62.9 Miles • This work for Option 1 and Option 2 is assumed to occur during the winter season and is predicated on utilizing low ground pressure equipment for that construction, installing typical 62.4' or 64.5' RLS Single Composite Pole Structures, embedment at approximately 12' feet in depth. • This work for Option 2 will be utilizing three (3) 62.4' poles per structure for a section of 9.7 miles of the up to the Walakpa Junction from the UIC Gravel Pit • Sand slurry will be utilized to backfill the drilled excavation and will also be placed inside the bottom section to address the issue of the pole hollow core 7-22 Preliminary Engineering — Final Report :: June 30, 2014 Atqasuk Transmission Line Project • Strength, per Golder's recommendations. • Additional pole sections will be carried by crew to modify pole length if required due to terrain or ice lenses encountered during excavation. • ROW alignment was chosen to avoid long water crossings and selected native allotments. • ROW alignment was chosen to minimize Eider impact as shown on ABR's Eider Density map. • ROW alignment was chosen to minimize transmission line length. • A Cat Train Camp will provide support services including housing and meals for the crew. For Option 1 the cost estimate of the line from the UIC Gravel Pit to Atqasuk, approximately 62.9 miles is $ 12.0 million. This estimate includes single pole 65.6' RLS Composite (170205) structures, 477 MCM ACSR Conductor, 115kV Insulators For Option 2 the cost estimate of the line from the UIC Gravel Pit to Atqasuk, is $ 13.3 million. This estimate from the Gravel Pit to The Walakpa Junction, 9.7 miles, utilizes three (3) pole 62.4' RLS Composite (170104) structures, 477 MCM ACSR Conductor, 115kV Insulators. The estimate from the Walakpa Junction to Atqasuk, 53.2 miles utilizes single pole 64.5' RLS Composite (F0205) structures, 477 MCM ACSR Conductor, I I5kV Insulators Tie-in for Walakpa Gas Field to Walakpa Junction — Length: 6.1 Miles • This work is assumed to occur during the winter season and is predicated on utilizing low ground pressure equipment for that construction, installing typical 64.5' RLS Single Composite Pole Structures, with embedment at approximately 12' feet in depth for the 6.1 miles from the Walakpa Junction to the Walakpa Gas Field. • This work for Option 2 will be utilizing three (3) 62.4' poles per structure for the 6.1 miles from the Walakpa Junction to the Walakpa Gas Field. • The cost estimate includes a 69 kV Fuse Cutout at Walakpa Junction and an overhead line to the Barrow Gas Field with poles and step-down transformer 7-23 Preliminary Engineering — Final Report • •. ::� .�. June 30, 2014 Atgasuk Transmission Line Project bank at the gas line terminus. • Route length may vary slightly, depending upon further study of existing gas field infrastructure and terrain. It was problematic locating a route that avoids the significant surface water and lakes. • Fused taps are utilized to provide protection and isolation for loads. • Further work and discovery may determine that circuit switches, with SCADA control, might be required with a cost impact of approximately $90K additional cost. • A Cat Train Camp will provide support services including housing and meals for the crew. For Option 1 the cost estimate of the spur line from the Walakpa Junction to the Walakpa Gas Field, approximately 6.1 miles is $ 1.2 million. This estimate includes single pole 64.5' RLS Composite (170205) structures, 477 MCM ACSR Conductor, I I5kV Insulators For Option 2 the cost estimate of the spur line is $ 2.0 million. This estimate utilizes three (3) pole 62.4' RLS Composite (F0104) structures, 477 MCM AC SR Conductor, 115kV Insulators Note: Late in the study Sakata Engineering Service was tasked to look at alternatives to lower the cost of providing power to the Walakpa gas field from the proposed Barrow to Atqasuk transmission line. The most attractive alternative was the single phase alternative. It consists of: a Step down transformer from 69 kV to a single phase 12.47 kV at Walakpa Jct.; a single phase 15 kV aerial cable mounted on 35/3 class poles; a Step-down transformer from 12.47 kV to single phase 480 V; and a 250 kW Rectifier- Inverter to 480 V AC. This alternative is estimated at $890,500. Approximately $390,000 less than the spur line presented in Option 1 and $ 1.2 million less than option 2. This alternative is also 7-24 Preliminary Engineering — Final Report gft= June 30, 2014 Atqasuk Transmission Line Project attractive environmentally since the structure will have a lower profile compared to the methods used in both options. Since this alternative was not reviewed by the agencies it was left out of the overall estimate. For more details of this alternative and others see Appendix I, " Walakpa Distribution Report". Atqasuk Substation ER • The cost estimate is predicated on the power transmission line feeding the existing Atqasuk 4160 Volt Power Line from a tie-in to a new 2 MVA step down transformer located near the power house. • An issue requiring resolution is the basis for the power and control interface between NSB facilities. It is assumed the existing power plant will be retained as emergency backup power, and it will be advantageous to provide remote control of that plant at Barrow. • It is assumed that there is adequate space available at the Atqasuk Power Plant area, to allow for the installation of the transformer, breakers, switches, control module, or other required appurtenances. • This work is assumed to occur during the summer season although it should be noted that the substation equipment has the longest material lead time. Placing the order in time to utilize winter roads for the delivery of heavy electrical equipment, is the assumed basis. • Existing support facilities in Atqasuk are expected to be utilized for housing and meals. The cost estimate for the Atqasuk Substation is $ 1.1 million for both Options. Atqasuk Transformer Replacement • This estimate covers the replacement and upgrade of 24 existing transformers in Atqasuk when heating equipment in the Community is converted from oil to electric heat. • Twelve (12) transformers will be upgraded to 37.5 kVA and twelve more to 50 kVA. 7-25 Preliminary Engineering — Final Report 171r, ..- :..1 June 30, 2014 Atqasuk Transmission Line Project • This work is assumed to occur during the summer season The cost estimate for the transformer upgrades is $ 144,960 for both Options A summary of cost appears in Table 7-5. A more detail cost estimate is presented in Appendix J, " Cost Estimate " Table 7-5 Cost Estimate Summary for Options 1&2 SegmentsOption Option Barrow Substation and Line from BUECI to UIC 2,631,617.77 2,631,617.77 Gravel Pit, (9.0 miles) UIC Gravel Pit to Walakpa Junction, single pole 1,851,959.56 0.00 TP-69 structure, (9.7 miles) UIC Gravel Pit to Walakpa Junction, three (3) pole 0.00 3,182,066.14 structure, (9.7 miles) Walakpa Junction to Atqasuk, single pole TP-69 10,157,139.02 10,157,139.02 structure, (53.2 miles) Barrow and Atqasuk Connection 2,288,513.43 2,288,513.43 SCADA Remote Monitoring and Control and 330,627.50 330,627.50 Power Line Communications ABB Atqasuk Transformer Replacement. (heat option 144,960.00 144,960.00 only). Subtotal: 17, 404, 817.28 18, 734, 923.86 Walakpa Junction to Walakpa Gas Field single 1,279,367.25 0.00 pole TP-69 structure, (6.1 miles) and Connection Walakpa Junction to Walakpa Gas Field three (3) 0.00 2,115,826.03 pole structure, (6.1 miles) and Connection TOTALS:.:- ;. 7-26 Preliminary Engineering — Final Report t� ••�• June 30, 2014 Atqasuk Transmission Line Project 7.5 Transmission Line Operations and Maintenance 7.5.1 Remote Monitoring and Multiple Boiler Control System In order to manage the integration of both the Atqasuk and BUECI power systems a Supervisory Control and Data Acquisition, (SCADA), system will be installed. The SCADA system hardware will be installed at the Atqasuk Power Plant and will monitor measurements of diesel generators operating parameters, system power levels and weather data. Data can be viewed locally and remotely at BUECI and the NSB via a web based data historian. Parallel operations will be possible at both power plant locations. In addition to monitoring the diesel plant operating parameters the SCADA syatem will be used to remotely control, (on -off), twelve (12) three (3) phase boilers on twelve (12) NSB Buildings in Atqasuk. The ability to transfer the heat load form electric to oil fired equipment in twelve large buildings in Atqasuk will provide BUECI with the ability to "peak shave" the electrical demand from Atqasuk if BUECI is approaching the " double firm capacity" limit criteria. The electrical metering system can be expanded in the future to provide remote automatic meter reading monitoring of individual metering of electricity for power, space heating, heat trace on NSB water and sewer facilities and water for billing purposes. The system has additional functionality, such as, outage and leak assessments, remote connect/disconnect, load profiling, prepayment, and distribution automation. 7.5.2 Maintenance Program It has been determined the NSB will be responsible for the maintenance of the Atqasuk transmission line. Maintenance of the line will require two surveys annually. Based on the results of the surveys, If repairs are to be made, it is recommended to 7-27 Preliminary Engineering - Final Report '° ..- :• • • June 30, 2014 Atqasuk Transmission Line Project contract this work out. Not much is anticipated to go wrong with the line because transmission lines are not bothered with connections into secondary structures and are designed more robust to operate for long distances across barren lands. Below is a list of equipment needs and a maintenance program required to maintain the line. Maintenance Equipment: The type of equipment required for maintenance will also be used in the construction of the line. It is assumed that some of the equipment required for construction could be transferred to the NSB Light & Power line maintenance crew or contractor for use. These items are as follows: • low ground pressure man haul. It is possible the Gas Field operation may have such a vehicle available and could be shared with the NSB Light & Power. • a drill mounted on a flex track piece of equipment • a 20 ton boom crane on tracks similar to a Grove CN20. • two (2) Nodwells w/ buckets, one kept in Atqasuk and the other in Barrow The overall maintenance plan is to have a Nodwell, all necessary maintenance equipment, spare poles and hardware material available in both Barrow and Atqasuk. Maintenance Program: Thermogrraphic Survey: A thermographic survey of the line should be performed via over -flights or from a snow machine, where detecting hot spots with an infrared spotter, should reveal any problem areas well in advance of a failure caused by tracking. An initial Baseline Assessment of the line using an infrared spotter should be performed as part of the project start up performance evaluation. This would be a Capital Projects expenditure and would cost about $70,000 with the use of a Thermal Imaging firm experienced in this type of work and a local helicopter. 728 Preliminary Engineering — Final Report qW ds• June 30, 2014 Atqasuk Transmission Line Project Tracking surveillance should occur the first year after construction and once every . year for three years. Increase to twice a year if necessary. Subsequent surveys would fall under the operating budget and would cost about $50,000 with the continued use of the contractor and helicopter. Significant savings can be achieved if the Borough chooses to purchase the imaging equipment and train their staff on its use. Then the surveys can be performed by in-house staff during the annual site survey conducted by snowmachine. In-house Annual Site Survey: An annual site survey should be conducted once a year. This can be performed by snowmachine or other all -terrain vehicle. The frequency of the surveys may change depending on the requirements determined by governmental agencies whom may decide more frequent avian surveys need to occur. The annual in-house survey should include; a.) Dampener or bird diverters, if installed, should be visually inspected, as well as checked for vandalism. Damage to conductors or insulators, from firearms, is one of the most common causes of damage. b.) Changes in river or stream flow should be reviewed to confirm that no structural foundations are being adversely impacted by the waterway channel change. c.) Spot checking the tension on bolts, perhaps every 20th structure, on a regular, basis per a structured maintenance program is advised, even though it is uncommon for lock washers and pal nuts to allow the structural hardware to loosen. Repairs: From the annual surveys if there is a need to repair the line it is recommended to contract a four- man line crew. The cost to hire a crew for two weeks is about $40,000 to $55,000. There are several firms in Alaska capable of repairing a high voltage line. 7.5.3 Maintenance Costs Maintenance cost are based on one Thermographic Survey a year, one in-house site survey a year and a two week repair effort by a contracted firm. This equals about $1,600 per mile or an annual budget of $ 125,920. dm..0 • 7-29 Preliminary Engineering — Final Report J June 30, 2014 Atqasuk Transmission Line Project Section 8.0 - Power and Energy Supply Evaluation 8.1 Overview The energy source and electric power supplies and requirements of all the load centers involved with the transmission line are important to the feasibility of the project. It is important to evaluate both the capability of the Barrow Gas Fields to deliver sufficient natural gas and the BUECI power plant to deliver adequate electrical power throughout the life of the project. The purpose of this section is to describe the existing physical conditions and anticipated impacts from the Atqasuk Transmission Line Project on the Barrow Gas Field, Community of Atqasuk power and heating systems and BUECI power plant. In order to compare the various energy sources and their pricing, the price of each source is converted on a cost per million BTUs basis. A cost comparison of energy sources involved in this report is presented in Table 8-1. Table 8-1 Energy Source Comparison As an example from Table 8-1, natural gas is wholesaled to BUECI at $1.00 / MCF. This converts to $1.00 a million BTUs. Comparing Atqasuk electricity at $0.80 / kWh, this converts to $234 a million BTU's. Therefore, Atqasuk electricity priced at $ 0.80 / kWh costs 234 times more per million BTUs than a million BTUs of natural gas at $1.00 1 MCF. _ 8-1 Preliminary Engineering — Final Report •• June 30, 2014 Atgasuk Transmission Line Project 8.2 Power and Heating Systems in Atqasuk 8.2.1 Power Plant Description Atqasuk's power requirements are provided by Atqasuk Power & Light (ATQP&L), an enterprise formed under the NSB. Currently, 100 percent of the power is generated by diesel fuel. The power plant consists of two structures that are connected and house five diesel generators with a total capacity of 3,370 KW. The older building houses two 3508 Caterpillar diesel gensets rated at 450 KW each, and one 3512 Caterpillar diesel genset rated at 650 KW (See Figure 8-1). The newer building contains two 3512 Caterpillar gensets rated at 910 KW each. Figure 8-1 Atqasuk Power Plant The existing distribution system is a three phase overhead system configured with two feeders from the power plant. Power is generated at 480 volts and stepped up to 4,160/2,400 volts with two 1,000 KVA station transformers connecting one to each overhead feeder. 8-2 Preliminary Engineering — Final Report �� June 30, 2014 Atqasuk Transmission Line Project The power plant generated 3,473,398 kWh of electricity and had sales of 3,205,945 kWh in FY 13. The cost to generate power in Atqasuk in FY 2013 was about $2.7 million. Therefore the actual price per kWH was about $ .80. The revenue collected by NSB Power & Light in FY 2013 was $961,132.15 or about 35% of the total costs. 8.2.2 Atqasuk Fuel Oil Facilities The Atqasuk fuel facilities provide fuel for both the power plant and space heating requirements in the community. The NSB Public Works Department operates them. The current system consists of five 17,000-gallon tanks (total storage capacity of 85,000 gallons) at the power plant and two 250,000-gallon tanks (total storage capacity of 500,000) at the Atqasuk tank farm dispensing station. The price of diesel fuel delivered to Atqasuk in FY 2010 was $5.16 per gallon. In FY 2013 it increased to $6.70. The City of Atqasuk is challenged in that the community is isolated without waterways or roads leading to the village. Other negative factors surrounding imported fuel oil are potential interruptions in fuel delivery and significant fluctuations in fuel prices.This makes the cost of importing fuel into the community relatively high. The journey to get fuel into Atqasuk starts with the delivery of a one year supply of fuel to Barrow's tank farm in late summer. Unlike other NSB communities, fuel is transported from Barrow to Atqasuk throughout the year by airplane owned by Everts Air Fuel or driven overland by CATCO All Terrain vehicles. Photographs of the transport vehicles are presented in Figure 8-2. The quantity of diesel fuel consumed for power generation in Atqasuk during FY 2013 was 267,000 gallons. Fuel oil consumed for space heating equaled 233,000 gallons. 8-3 Preliminary Engineering - Final Report -' Mi/ June 30, 2014 Atqasuk Transmission Line Project Figure 8-2 Fuel Delivery Methods from Barrow to Atqasuk 8.2.3 Project Impact With the transmission line installed, it is anticipated Atqasuk's peak power load could reach 2,359 kW, combined heat and power, with 63.89% load factor, 1,507 kW yearly average load, and a 13,201,132 kWh annual load. The community of Atqasuk will retain their existing power plant and building oil- fired heating systems for backup. Since the peak load of the project is estimated at 2359 KW and the existing power plant has a generating capacity of 3370 KW, the power plant is large enough to provide 100% backup if necessary Since the NSB is maintaining the line, the borough would pay BUECI an agreed upon rate for electricity metered at the BUECI power plant. The rate would not include the cost for maintaining the line. Currently this is the case with power delivered to the NSB South and East Barrow Gas Fields. The NSB Gas Fields are charged under rate schedule E-10 that charges $ 0.0846 / kWh plus and an annual charge of $4,164. The maintenance costs of the line to the gas fields are covered by a Time and Materials (T&M) agreement between the NSB and BUECL The actual rate used for the 8-4 Preliminary Engineering — Final Report June 30,2014 Atgasuk Transmission Line Project proposed line would be negotiated at a later stage in the project. However, for this report we are using the E-10 rate as a conservative rate for analysis. In addition to the BUECI rate, there are additional costs to the NSB to operate and maintain the transmission line and the electrical facilities in Atqasuk. These costs have been estimated at $372,600. Both BUECI and NSB charges and projected revenue are presented in Table 8-2. Table 8-2 Cost per kWh with Project BUECI 14,654,493 0.0846 1,239,770 NSB 14,654,493 0.0254 372,600 Total: N/A 0.1100 1,612,370 Besides the economic benefits, the transmission line will provide a steady source of reliable, higher quality power at a stable price, a significant reduction in noise, and a reduction in expensive oil and glycol spills (see Figure 8-3). In addition, the borough could decommission one of the 250,000-gallon fuel storage tanks in the Atqasuk Tank Farm. This would reduce regulatory oversight of the Atqasuk Tank Farms. Air pollution - The federal government's main environmental goal is to curb emissions that cause climate change. In addition to climate change, air pollution from diesel power generation poses health risks in several areas. The EPA data indicates that diesel exhaust contributes more than 70% of the cancer risk from air pollution in the United States. Diesel exhaust is also a major source of harmful particulate pollution and zone -forming nitrogen oxides. Particulate pollution is linked to asthma, { -5 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project Figure 8-3 Oil Spill Response Drill cardiovascular and respiratory problems, strokes, heart attacks and premature death. High ozone levels are also linked to respiratory problems. The Atqasuk project will eliminate particulate pollution locally and Table 8-3 shows the anticipated reduction in the carbon "footprint" and other greenhouse gases formed by the annual combustion of 250,000 gallons of oil for power generation and 220,000 gallons of oil for space heating. Further, the Atqasuk conversion will reduce significantly the impact of any future regulatory changes associated with using fuel oil. Table 8-3 Atqasuk Annual Air Pollutants Calculation fr 8-6 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project On the negative side, Atqasuk would lose the state's power cost equalization benefit and would lose the heat generated by the power plant's waste heat recovery equipment. Another concern would be loss of jobs. Although transmission lines are generally very reliable, Atqasuk will need to retain sufficient local personnel for billing and collection as well as the ability to maintain and operate existing energy facilities to supply both power and heating needs if the transmission line experiences an unplanned interruption or planned maintenance function. This effort would take two power plant operators and a utility clerk. 8.3 Barrow Electric Power Facilities 8.3.1 BUECI Plant Description BUECI is a member -owned, not -for -profit cooperative. It is governed by a nine member board of directors. The utility cooperative was established in 1964 to provide electricity, natural gas, water and sewer services to this community of Barrow. Currently with a population of approximately 4,500 people. The Barrow power plant houses seven (7) generators with a total capacity of 20,500 KW. This includes the following units: • Solar Centaur 40 output rated at 2.5 MW installed in 1976 • Solar Centaur 40 output rated at 2.5 MW installed in 1979 • Solar Centaur 40 output rated at 2.5 MW installed in 1982 • Solar Taurus 60 output rated at 5.0 MW installed in 1986 • Solar Taurus 60 output rated at 5.0 MW installed in 1999 • Two (2) Caterpillar 3615 reciprocating engines rated at 1.5 MW each. W70-rth Slope Borough 8-7 Preliminary Engineering - Final Report June 30, 2014 Atqasuk Transmission Line Project The turbines are in top condition according to the local Solar Turbines office. They undergo a complete overhaul every 30,000 hours. (a photograph of the BUECI Taurus Turbine is presented in Figure 8-4). Figure 8-4 BUECI Solar Taurus 5,000 KW Gas Turbine Unit Source: Photo taken by Sakata Engineering Services on February 21, 2014. Standing is BUECI Plant Manager Jim Murphy BUECI purchases natural gas from the NSB Gas Fields at the wholesale price of $1.00 a MCF. In FY 2013 BUECI generated 53,368,640 kWH. The average daily demand was 6,092 kWH with a peak load of 8,400 kW. BUECI annual system energy information is presented in Table 8-4 8.3.2 Project Impact The Atqasuk Transmission Line project is expected to add both the power loads and space heating loads of the Community of Atqasuk to the power demand at the 8-8 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project Table 8-4 BUECI Historical Energy Data 2010 49,243,000 5,610 27.42% 2011 50,211,000 5,732 27.96% 2012 .52,638,120 6,009 8,625 29.31 % 2013 53,368,640 6,092 8,400 29.72% BUECI power plant. The annual anticipated consumption in Atqasuk will equal 13,202,246 kWh, with a peak demand of 2,359 kW. Line losses from the transmission line will increase the annual kWh demand by 228,399 kWh. This will bring the total annual Atqasuk load at the BUECI Power Plant to 13,430,645 kWh, with a peak demand of 2,400 kW. This increase in demand will increase the annual power generated at the BUECI Plant by 25% or 66,799,285 kWh. Peak demand would increase by 29% to 10,800 kW. Historically, the highest peak demand recorded at BUECI was around 10,000 kW in 2006. The transmission line project will improve the economics of the BUECI power plant operation. It is anticipated the additional power and heating electric loads added to the current power load in Barrow will create a larger electric load base in Barrow and reduce the cost of power on a kWH basis. For instance, the Atqasuk load should increase the Barrow load by 25%, generating an increase in revenue of over a million dollars with only an incremental increase in expenses such as the cost for additional natural gas estimated at $146,000. The larger base load to the BUECI plant, with no appreciable increase in expenditures, should leave room to negotiate a lower Atqasuk electric rate or a decrease in the Barrow rate or both. 8-9 Preliminary Engineering — Final Report June 30, 2014 Atgasuk Transmission Line Project Although the peak power requirements of this project can be met by the BUECI plant, at 10,800 kW peak demand crosses, slightly, the "Double Firm Power" generation capacity limit established by BUECI. This limit means if the two largest generator units go down, the BUECI power plant would still have enough capacity on hand to meet peak demand. Therefore, if the two Taurus units go down the remaining generation capacity available would be 10,250M. If the need arises for BUECI to incrementally reduce the peak demand (peak shaving) because the demand is approaching the 10,250 kW "Double Firm Power" limit, they can do so through the Supervisory Control and Data Acquisition (SCADA) system installed on the transmission line. This system can be installed to include remote monitoring and control of several electric heating systems in NSB buildings in Atqasuk. BUECI will be able to switch the heating systems of those facilities from electric to oil fired heat, thus reducing the electrical load at the BUECI Power Plant. 8.4 Barrow Gas Fields 8.4.1 Gas Fields Description The Barrow Gas Fields consist of three fields. The South Barrow Gas Field, developed in 1949, is located four miles south of Barrow. The East Barrow Gas Field, discovered in 1974, is located seven miles east of South Barrow Gas Field and the Walakpa Gas Field, discovered in 1980, is located 15 miles south of Barrow. In 1984 ownership of the Barrow Gas Fields was transferred from the federal government to the NSB with the passage of the Barrow Gas Field Transfer Act of 1984. (See Appendix K, "Public Law 98-366 the Barrow Gas Field Transfer Act of 1984 ") This Act also gave the borough the permission to extend the natural gas to the surrounding North Slope villages of Atqasuk and Wainwright via gas pipeline or electric transmission. Further, both ASRC and UIC signed agreements to the Act that 8-10 Preliminary Engineering — Final Report June 30, 2014 Atgasuk Transmission Line Project provides the NSB with Right -of -Way access across their lands to extend their energy source to the outlying villages. 8.4.2 Project Impact The transmission line project will increase the kWh generated at the BUECI power plant by 13,430,645 kWh. The gas turbines at the plant have a heat rate of 10,830 BTU/kWh. This equates to 145,454,000,000 BTUs. There are 1,000,000 BTUs in an MCF of gas. Therefore the power plant will need an additional 145,454 MCF a year. Based on the last reserve analysis report performed by Petrotechnical Resources of Alaska (PRA) in 2006, the reserves of the Barrow Gas Fields equal between 163 to 259 billion cubic feet of natural gas. The City of Barrow consumes about 1.5 billion cubic feet a year. At this consumption rate, the life of the gas fields should be between 108 and 172 years. The addition of the Atqasuk project would add about 145 million cubic feet of gas annually, bringing the annual total gas usage rate in Barrow to 1.645 billion cubic feet a year, an increase of 10%. This reduces the life of the gas field to 99 to 157 years. A hundred years supply of gas is significant. Future drilling programs may extend the reserves, as they have done in the past, as more detailed knowledge is gained on the fields. Further, the demand for gas in Barrow could be reduced by improving the efficiency of the existing power plant and implementing conservation efforts. Of concern from the Feasibility Study 2011 was not the gas reserve but the gas fields' ability to deliver enough gas to meet peak demand conditions. The issue was the number of producing wells and each well's capacity. Since 2011 the NSB completed a drilling program in both the East Barrow and Walakpa Gas Fields. A comparison of each field's delivery capacity is presented in Table 8-5. 8-11 Preliminary Engineering — Final Report �� r� June 30, 2014 Atqasuk Transmission Line Project Table 8-5 Barrow Gas Fields Deliverability Note: * Flow rate will increase to 2,300 MCF with Savik #2 addition in the future. Source: NSB Gas Field Division From the Table 8-5, the Barrow Gas Fields have increased their deliverability of gas by 40%. The peak demand from the project will add an additional 680 MCF a day. The highest peak demand on the gas fields has been around 7,000 MCF. There appears to be no negative impact of this project on the Barrow Gas Field involving the fields reserves or its ability to meet peak conditions. 8.5 Conclusions The energy source and electric power supplies of the Barrow Gas Fields and BUECI power plant have the capacity to meet the requirements of Atqasuk's all electric power and heating demand for the long term. Although the BUECI plant, at 10,800 M, can meet the peak power requirements of this project, it slightly crosses the "Double Firm Power" generation capacity criteria established by BUECI. If this occurs BUECI can utilize the installed SCADA system to accomplish "peak shaving" by remotely switching the heating systems of the monitored facilities from electric to oil fired, thus reducing the electrical load at the BUECI power plant. 8-12 Preliminary Engineering — Final Report June 30, 2014 Atclasuk Transmission Line Project Section 9.0 Update Economic Analysis 9.1 Overview This section presents the economic analysis of the proposed electric power transmission line between Barrow and Atqasuk. The economics of the proposed project is evaluated by estimating the net present value (NPV) of the cost savings associated with the proposed intertie project. The cost savings are measured by comparing the costs associated with the existing power generation and heating systems in Atqasuk ("without project" case) against the costs associated with the proposed project. The NPV of cost savings (present value of the net benefits of the project) provides an estimate of the economic feasibility and informs the choice between alternative project options; the best economic option is the one with the highest NPV. This approach follows the same analytical framework used by the Alaska Energy Authority in evaluating the economics of Renewable Energy Fund Grant applications. Estimating the monetary value of reducing outages or other potential (social and environmental) benefits is outside the scope of this study. The proposed intertie would supply electricity generated from the Barrow electric power facility using relatively inexpensive natural gas, displacing electricity generated at the Atqasuk power plant using relatively expensive diesel fuel for power and possibly also displacing diesel fuel used for heating in the community. The intertie is also anticipated to improve the reliability and quality of electricity in Atqasuk. This section evaluates six project alternatives as shown below. Options 1 and 2 are engineering choices based on environmental recommendations by federal agencies (more detailed description of these options is provided in section 7.2.1 Agency Impact of this report): 1. Option 1 Power Line Engineering Concept with Electricity Generation for Power Only {=-J Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project 2. Option 1 Power Line Engineering Concept with Electricity Generation for Power plus Residential Heat 3. Option 1 Power Line Engineering Concept with Electricity Generation for Power plus Residential and Commercial Heat 4. Option 2 Power Line Engineering Concept with Electricity Generation for Power Only 5. Option 2 Power Line Engineering Concept with Electricity Generation for Power plus Residential Heat 6. Option 2 Power Line Engineering Concept with Electricity Generation for Power plus Residential and Commercial Heat Table 9-1 and Figure 9-1 show the net present value of the cost savings for each project alternative. The results of the economic analysis indicate that Engineering Concept Option 1 with electric power and heat for residential and commercial structures has the highest net benefit with an NPV of cost savings of $62 million over the 35 year life of the project. In general, a higher NPV is achieved with Engineering Concept Option 1, with the use of electricity for power and heat rather than for power only. Hence, the option with the least estimated capital costs and the highest possible fuel displacement (power and heat) make the most economic sense based on measuring the net present value of the cost savings. Table 9-1 Net Present Value of Cost Savings of the Proposed Project Alternatives Electricity Generation Alternatives Option 1 Option 2 Electric Power only 38,822,669 36,568,720 Electric Power and Heat (Residential and Commercial Structures) 62,148,917 59,894,967 Electric Power and Heat (Residential Structures Only) 44,830,160 42,576,210 Source: Northern Economics, Inc. 9-2 Preliminary Engineering — Final Report lone 30, 2014 Atgasuk Transmission Line Project $70 $60 $50 $40 c $30 $20 $10 $0 Figure 9-1 Net Present Value of Cost Savings by Project Alternative Electric Power only Electric Power and Heat Electric Power and Heat (Residential and Commercial) (Residential Only) a Option 1 a Option 2 Source: Northern Economics, Inc. Table 9-2 on the other hand, shows the calculated benefit -cost (B/C) ratios of the different project alternatives. As shown in the table, all of the project alternatives provide positive B/C ratios and therefore are all economically better compared to the "without project" case (that is, the existing power generation and heating system in Atqasuk, given the base case assumptions used in the analysis). Table 9-2 Benefit -Cost Ratios of the Proposed Project Alternatives Electricity Generation Alternatives Option 1 Option 2 Power only 3.14 2.81 Power and Heat (Residential + Commercial) 3.76 3.43 Power and Heat (Residential Only) 3.16 2.87 Source: Northern Economics, Inc. 9-3 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission line Project Figure 9-2 shows the results from a cost-effectiveness perspective, measured in terms of variable cost per kWh given current price and cost levels. The total variable cost of diesel generated power under the current situation is slightly below 80 cents per kWh. As shown in, the variable cost per kWh under any of the project alternatives would be considerably lower at less than 25 cents per kWh for all the other alternatives. Figure 9-2 Variable Costs Der kWh, Current Situation versus Proiect Alternatives $0.80 -- - $0.70 $0.60 $0.50 $0.40 i $0.30 $0.20 $0.10 Electric Power Only Electric Power and Electric Power and Heat (Res + Corn) Heat (Res) Source: Northern Economics, Inc. Diesel Generated Power While the NSB currently incurs the cost of slightly under 80 cents to generate a kilowatt- hour of electricity in Atqasuk, the electric rate per kWh paid by customers of electricity is much lower. The electric rate in Atqasuk has not changed since 1984: residential customers only pay $0.15 per kWh for the first 600 kWh (and $0.35 per kWh for every kWh over 600), the aged and handicapped are not charged for the first 600 kWh of consumption (and $0.35 per kWh for every kWh over 600), and commercial customers c7 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project pay $0.20 per kWh for the first 1,000 kWh, $0.30 per kWh for consumption up to 10,000 kWh, and $0.35 for every kWh of consumption over 10,000. The NSB would potentially realize a significant benefit from reducing the cost of electric power generation through the proposed intertie project. Figure 9-2 above calculates the cost per kWh of the different scenarios given current price and cost levels. Finally, in terms of payback period,the Table 9-3 below shows the results for each of the project alternatives. Table 9-3 Estimated Payback Periods of the Proposed Project Alternatives Electricity Generation Alternatives Option 1 Option 2 Electric Power only 10 years 11 years Electric Power and Heat (Residential and Commercial Structures) 8 years 9 years Electric Power and Heat (Residential Structures Only) 10 years 11 years Source: Northern Economics, Inc. estimates 9.2 Methodology and Assumptions On one hand, an intertie would provide benefits (cost savings) achieved through the offset of diesel generation costs at the Atqasuk facilities. On the other hand, the construction and the operation and maintenance of an intertie would involve costs. The net benefit of each alternative compares the costs of the existing power generation and heating system (without project situation) with the costs associated with the proposed project alternatives (with project scenarios). This economic analysis determines if the benefits to be realized with the intertie are greater than its costs. The benefits of the project are savings in fuel and non -fuel O&M costs at the Atqasuk facilities ("without project" situation). The costs of the project are the costs related to the development and construction of the intertie, annual costs for O&M of the intertie, costs for electric generation and transmission of electricity from Barrow to Atqasuk, and costs for conversion to electric heating systems at facilities and residences in Atqasuk. 5 Preliminary Engineering — Final Report �. ..- :.. June 30, 2014 Atqasuk Transmission Line Project The following are the main assumptions used in the economic analysis: • The economic analysis covers the period between the years 2014 and 2052. • All the costs are reported in real terms and expressed in constant 2013 dollars. • All cost flows (future stream of costs) are discounted to their present values using a 3 percent annual discount rate (same discount rate used in the evaluation of AEA Renewable Energy Fund Grant applications). • The analysis assumes that the additional natural gas usage and generation capacity at BUECI required to meet the Atqasuk demand —even during peak load- is sufficient to avoid imposing additional costs in the system at Barrow. • The analysis does not include cost of land, right of way costs, or salvage value at the end of the study period. • Only direct quantifiable monetary economic costs are considered The rest of this section is organized in the following order: • An analysis of the existing diesel -based system for power generation and heating in Atqasuk, i.e. the "without project" situation; • An analysis of the six proposed projects alternatives, i.e. the "with project" situations; • Estimates of potential financing costs associated with the project alternatives; and • Conclusions. 9.3 "Without Project" Case: Diesel -Based Power Generation and Heating System 9.3.1 Existing Atqasuk Energy Profile Atqasuk is an inland community in the NSB located 60 miles south of Barrow along the banks of the Meade River. Atqasuk's 2010 estimated population was 247. The community's power requirements are provided by the Atqasuk Power & Light (ATQP&L), an enterprise formed under the NSB. Currently, 100 percent of the power is generated by diesel fuel. The community's heating system is also primarily based on diesel fuel. For more detail of the energy systems see Section 8.2, "Power and Heating Systems in Atqasuk ". 9-6 Preliminary Engineering — Final Report .f-. June 30, 2014 Atqasuk Transmission Line Project The price of diesel fuel delivered to Atqasuk in FY 2013 was $6.70 per gallon. The quantity of diesel fuel consumed for power generation and heating in Atqasuk during FY 2013 is shown in Table 9-4. The power plant consumed 267,000 gallons of diesel fuel for power generation and a variety of users consumed about 233,000 gallons for space/water heating. Table 9-4 Diesel Fuel Consumption in Atqasuk, FY 2013 Diesel Fuel Use for Energy (Gallons) Power Generation Power Plant 267,000 Total for Power. 267,000 Heating Commercial 160,666 Residential 72,334 Total for Heating 233,000 Total Power + Heating 500,000 Source: North Slope Borough Fuel Division 9.3.2 Annual O&M Costs In FY 2013, the total costs of operating and maintaining the NSB power and fuel facilities amounted to approximately $4.47 million, with $3.35 million for fuel costs and $1.12 million for non -fuel costs (see Table 9-5). Fuel costs accounted for 76 percent of the cost of providing power generation and heating to the community. About $1.8 million was spent on fuel for the power plant and $1.6 million for heating fuel (see Table 9-5). Non -fuel costs in FY 2013 consisted of $0.94 million for power and $0.18 million for heating (see Table 9-5). Non -fuel costs include staff, inspections, equipment maintenance, and other miscellaneous costs. 9-7 Preliminary Engineering — Final Report . ..- '.. June 30 2014 Atgasuk Transmission Line Project Table 9-5 Annual O&M Costs of NSB Power and Fuel Facilities, FY 2013 O&M Cost Component FY 2013 ($) Power Fuel Costs $1,788,900 Non -Fuel Costs $938,384 Sub -total. $2, 727,284 Heating Fuel Costs 1,561,100 Non -Fuel Costs $179 488 Sub -total: $ 1, 740, 588 Total: 4,467,872 Source: North Slope Borough, Fuel Division Future O&M costs were estimated for the existing system assuming that the intertie is not built ("without project" situation). Future fuel costs are determined given the current fuel consumption for power and heat and projected diesel fuel prices. The quantity of fuel consumed in future years is assumed to stay at the current consumption levels. This assumption is based on the forecast of zero percent growth of Atqasuk's population (Alaska Department of Public Health, Bureau of Vital Statistics). The prices of diesel fuel in future years are projected as follows. The price of fuel delivered to Atqasuk consists of the price of landed fuel in Barrow plus the delivery cost from Barrow to Atqasuk. Half of the delivery cost is assumed to be a fixed cost and is projected to remain constant in real terms. The other half of the delivery cost as well as the landed fuel price in Barrow are both assumed to follow the trend in crude oil fuel prices under the Energy Information Administration's mid -case projections (Annual Energy Outlook). These projections are available until 2040; fuel prices for the years beyond 2040 were extrapolated by assuming the same trend as the previous 10 years (2021-2030). Based on these assumptions, the price of diesel fuel landed in 9-8 Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project Atqasuk is projected to increase at an average annual rate of 1.7 percent. Future non - fuel O&M costs are assumed to stay constant in real terms, which would be equivalent to assuming that they increase in nominal terms at the inflation rate. 9.3.3 Replacement and Overhaul Costs for Diesel Generator Units The ATQP&L power house has five diesel generator units with the following capacity: two 450 kilowatt generators, one 580 kilowatt generator, and two 910 kilowatt generators. The total generation capacity of the power plant is 3,300 kilowatts, more than sufficient to meet the average and peak loads of the community during the study period. The study assumes a one time replacement (over the period of analysis) of the five existing generator units at an estimated cost of $7 million, including the cost of shipping and installation in Atqasuk. For the three largest generators, the study also assumes major overhaul costs of $330,000 every 5 years and top end overhaul costs of $180,000 every 2 years. These costs are based on information provided by NC Machinery, the local distributor for Caterpillar diesel generators, and cost information from similar projects experienced in other North Slope communities. Note that the costs for minor overhauls are already included in the above mentioned annual O&M costs. 9.3.4 Summary of Cost Flows Associated with the Existing Diesel -Based Power and Heating Systems ("Without Project" Case) Table 9-6 shows the future annual costs for Atqasuk power generation and heating (for selected years) if the proposed intertie project is not built (the "Without Project" Case). Projected annual costs for the years 2013 (baseline year), 2018, 2023, 2028, 2033, 2038, and 2052 (end year of the analysis) are shown in the table. The estimated present value of all the annual future costs from 2014 through 2052 is approximately $138.8 million. x Preliminary Engineering — Final Report June 30, 2014 Atqasuk Transmission Line Project Table 9-6 Annual Costs Incurred in Selected Future Years under the "Without Project" Case (2013 $ millions) Cost Item: 2013 2018 2023 2028 2033 2038 2052 O&M Costs 4.478 4.687 5.018 5.378 5.779 6.225 7.392 Fuel Costs 3.360 3.569 &900 4.260 4.661 5.107 6.274 Fuel Cost for Power 1.794 1.906 2.083 2.275 2.489 2.727 3.350 Price ($/gallon) 6.72 7.14 7.80 8.52 9.32 10.21 12.55 Gallons 0.267 0.267 0.267 0.267 0.267 0.267 0.267 Fuel Cost for Heat 1.566 1.663 1.817 1.985 2.172 2.380 2.924 Price ($/gallon) 6.72 7.14 7.80 8.52 9.32 10.21 12.55 Gallons 0.233 0.233 0.233 0.233 0.233 0.233 0.233 Non Fuel Costs 1.118 1.118 1.118 1.118 1.118 1.118 1.118 Power 0.938 0.938 0.938 0.938 0.938 0.938 0.938 Heat 0.179 0.179 0.179 0.179 0.179 0.179 0.179 Scheduled Repair & Replacement Costs - 0.510 0.330 7.510 0.330 0.510 - Replacement of diesel generators (once in 2028) - - - 7.000 - - - Top End Overhaul (every 2 yrs starting in 2016) - 0.180 - 0.180 - 0.180 - Major Overhaul (every 5 yrs starting in 2018) - 0.330 0.330 0.330 0.330 0.330 - Total Costs 4.48 5.20 5.35 12.89 6.11 6.74 7.39 NPV of Costs (2014-2052) 138.78 Source: Northern Economics, Inc. estimates 9.4 Proposed Intertie Project Alternatives: "With Project" Case The proposed project description is described in Section 1.5, " project Description". As noted earlier there are 6 project alternatives considered in this analysis. The following sub -sections presents the cost components of the various proposed project alternatives. 9-10 Preliminary Engineering - Final Report � ii lone 30, 2014 ..- :.. . Atclasuk Transmission Line Project 9.4.1 Estimated Costs of the Proposed Project Alternatives 9.4.1.1 Project Capital Costs For all project alternatives, the environmental studies are assumed to take place during 2014 and 2015 at an estimated cost of 170,000 for pennitting and $500,000 for an Environmental Assessment (EA). At this point, it has not been determined that an Environmental Impact Statement (EIS) is required. If the Bureau of Land Management (BLM) decides that an EIS is required, the EIS is estimated to cost approximately $1.5 million and will replace the EA requirement. Construction of the intertie is assumed to take place over a 2-year with capital costs varying by alternative as shown in Table 9-7. The corresponding supporting engineering and construction management activities also occur over the same period and is estimated to be about 12 percent of the construction cost. Under the scenario of electric power and heat, the existing diesel oil fired boilers and furnaces in buildings would be replaced by electric heat. The cost of converting to electric heating systems for residential structures is estimated to amount to $2.8 million, and $1.87 million for coverting the the Borough facilities. Combined, the conversion costs amount to $4.68 million. 9.4.1.2 Annual Maintenance Costs for the Powerline The operation of the proposed intertie begins in 2018 and lasts 35 years. The annual maintenance costs for the intertie is estimated to be $125,920; or $1,600 per mile for both Option 1 and Option 2. For detail see Section 7.5.2, " Maintenance Program" 9-11 Preliminary Engineering — Final Report J; dm� lone 30, 2014 Atclasuk Transmission Line Project Table 9-7. Estimated Capital Costs of the Proposed Project Alternatives (2013 $) Powerline Powerline Heating Alternatives Environmental Construction Engineering/ Conversion Total Costs Studies Cost Construction Costs Management Option 1 Electric Power Only $670,000 $18,539,225 $2,224,707 $0 $21,433,931 Electric Power and Heat (Residential & Commercial) $670,000 $18,684,185 $2,242,102 $4,676,120 $26,272,407 Electric Power and Heat (Residential only) $670,000 $18,684,185 $2,242,102 $2,800,676 $24,396,963 Option 2 Electric Power Only $670,000 $20,705,790 $2,484,695 $0 $23,860,485 Electric Power and Heat (Residential and Commercial) $670,000 $20,850,750 $2,502,090 $4,676,120 $28,698,960 Electric Power and Heat (Residential only) $670,000 $20,850,750 $2,502,090 $2,800,676 $26,823,516 Source: Estimates are based on information provided by consulting engineers for this project. Note: The construction costs shown in the table includes a transformer replacement in Atqasuk amounting to $145,000; this cost is included only for the heat options. For the Power only options, this cost was deducted from the total construction cost. 9.4.2 Cost of Purchasing Electricity from Barrow The annual cost of purchasing electricity from BUECI depends on the price of electricity in Barrow and the quantity of electricity required to meet Atqasuk's needs. The future costs of electricity purchased from BUECI are projected assuming that the quantity is the same for all future years and that the price remains constant in real terms. For the price of electricity, this analysis assumes BUECI's E-10 rate for electricity of $0.0846 per kWh plus the annual fixed charge of $4,164 (or a monthly fixed charge of $347). The quantity of electricity varies depending on the electricity generation scenario considered (see Table 9-8). 9-12 Preliminary Engineering — Final Report f. �:- 11 a June 30, 2014 Atgasuk Transmission Line Project Table 9-8. Annual Electricity Requirements and Cost of Purchased Electricity from Barrow Item Scenario Electric Power Only Electric Power and Heat Quantity of Electricity Required (kWh) For Power 3,533,488 3,533,488 For Heating (Residential & Commercial) 9,897,157 For Heating (Residential only) 2,643,789 Cost of Electricity {$) For power $303,097 $303,097 For Heating (Residential & Commercial) $837,299 For Heating (Residential only) $233,665 Source: Estimates based on information provided by other project consultants 9.4.3 Annual O&M Costs of Atqasuk Facilities With the intertie and without the need to operate their diesel generators except in emergency situations, the Atqasuk power utility should be able to realize significant cost savings in both fuel and non -fuel O&M costs. Initially, during the first full year of operations, the utility will purchase one month's worth of fuel supply (equivalent to 22,250 gallons for power, 19,417 gallons for heating residential and commercial structures, and 6,028 gallons for heating just the residential structures) to be kept in storage as backup. In subsequent years, it is anticipated that the annual consumption of fuel to maintain the power plant in a ready condition would be about 2,500 gallons a year. A minimal amount of fuel back-up supply was assumed for heating (an additional 500 gallons per year). This would be replaced every year to maintain the months supply of emergency fuel. Table 9-9 shows the estimated annual fuel costs for power and heating for each of the proposed project alternativs. Since the fuel cost per year will vary depending on the projected price of fuel, the table below shows the estimated annual fuel costs given the projected fuel price in 2018 (year 1 of operations) and the projected fuel price in 2019 (year 2 of operations). 9-13 Preliminary Engineering — Final Report `.i June 30, 2014 .. : • . Atclasuk Transmission Line Project Table 9-10 shows the estimated annual non -fuel costs for power (Atgasuk power plant) and for heating (primarily related to the tank farm/dispensing station operations) associated with each of the alternatives, including the baseline case or the current non - fuel costs. In addition to offsetting fuel and non -fuel O&M costs, ATQP&L would benefit from the extension in operating life of its existing generators if the intertie is constructed. For the purpose of this analysis, it is assumed that with the intertie, ATQP&L would be able to avoid replacement and major overhaul costs during the study period. Table 9-9. Estimated Annual Fuel Costs for Power and for Heating under Various Scenarios Electric Generation Alternatives Year 1 of Operations Power Heat Year 2 of Operations Power Heat Electric Power Only $158,821 $1,663,160 $18,183 $1,694,643 Electric Power and Heat (Residential & Commerical) $158,821 $138,597 $18,183 $3,637 Electric Power and Heat (Residential only) $158,821 $179,488 $18,183 $1,168,547 Source: Northern Economics, Inc. estimates based on project data Table 9-10. Estimated Annual Non -Fuel Costs for Utility Operations and Maintenance Facilities in Atqasuk under Various Scenarios Power Fuel Operations Current and With Project Alternatives Combined Non -Fuel Costs Non -Fuel Costs Current: Without Project $938,384 $179,488 $1,117,872 Power only $372,600 $179,488 $552,088 Power & Heat (Residential & Commercial) $372,600 $89,744 $462,344 Power & Heat (Residential only) $372,600 $179,488 $552,088 Source: Northern Economics estimates based on historical information from the North Sope Borough and addition project data. 9.5 Financing Costs The NPV results from the previous section are equivalent to a baseline scenario where the project is financed with 100 percent equity and no debt. In this section we consider four alternative financing schemes with varying debt -equity ratios (see Table 9-11). 9-14 Preliminary Engineering — Final Report 17*All" Ae�- 'i �� June 30, 2014 Atqasuk Transmission Line Project For all project alternatives, the annual financing costs are calculated assuming that the intertie capital costs will be financed through bonds. The study assumes a 5 percent interest rate on the annual bond coupon payments plus annual deposits to a reserve fund (earning 3 percent interest) to cover the debt at the end of the 20-year term. As shown in Table 9-11, the financing costs for the power transmission line vary depending on the project alternative and depending on the debt to equity ratio. Project alternatives with higher capital costs and larger percentage of debt imply higher financing costs. Table 9-11, Annual Financing Costs by Project Alternative (2013 $) Alternatives Option 1 Option 2 Power only 50 percent debt 808,456 902,935 70 percent debt 1,131,838 1,264,109 20 percent debt 323,382 361,174 100 percent debt 1,616,912 1,805,870 Power and Heat (Residential and Commercial) 50 percent debt 1,012,371 1,106,851 70 percent debt 1,417,320 1,549,591 20 percent debt 404,949 442,740 100 percent debt 2,024,743 2,213,701 Power and Heat (Residential Only) 50 percent debt 936,909 1,031,388 70 percent debt 1,311,672 1,443,943 20 percent debt 374,763 412,555 100 percent debt 1,873,817 2,062,776 Source: Northern Economics estimates. 9.5.1 Results for NPV of Cost Savings after Financing Costs The previous subsection described the cost saving flows of the project before financing, which are the flows used in most benefit -cost analysis. These flows reflect the expected outcomes of the project itself and contain no information about the way the project might be financed. Any given project can, in theory at least, be financed in many different ways, involving different possible combinations of debt and equity 91-.15 Preliminary Engineering — Final Report 17 A ..- :.t. June 30, 2014 Atqasuk Transmission Line Project finance, and, different debt arrangements. Different arrangements in rates of interest and/or maturities will generate different financing costs for the project's owners. The NPV of cost saving after debt financing costs determines whether the investor will be willing to participate in the project on the conditions offered to him. The NPV after financing should not determine which project alternative to choose; this decision should be driven by the NPV of cost savings from the project itself calculated in the previous subsection. Otherwise, a "bad" project could look good simply by virtue of its sponsors having access to concessional funding on terms more favorable than what the financial markets offer. Conversely, a "good" project may look "bad" only because its sponsor is unable to secure more favorable loan conditions available elsewhere in the market. For this reason it was important to first consider the project's economic feasibility before financing cost. Figure 9-3 shows the NPV of cost savings after debt financing costs for the six project alternatives, considering different percentage of debt. 9.6 Conclusions In conclusion, the best alternative is Engineering Concept Option 1 with electric power and heat (for both residential and commercial structures), both from an economic feasibility point of view and from the project's owner point of view. All the six project alternatives are economically feasible as they have a positive NPV of cost savings compared to the current diesel -based system for power generation and heating. The various proposed project alternatives appear to be cost effective as the cost per kWh seems reasonable in magnitude and is significantly lower than the equivalent cost per kWh of the existing system. The proposed project would stabilize the cost of energy in the community of Atqasuk and the North Slope Borough would benefit from potential significant cost savings resulting from the proposed project. 9-16 Preliminary Engineering -- Final Report June 30 2014 Atqasuk Transmission Line Project Figure 9-3 NPV of Cost Savings with Financing Costs $70 $60 $50 U) o $40 $30 $20 — - $10 Option 1: Option 1: Option 1: Option 2: Option 2: Option 2: Power & Heat Power Only Power & Heat Power & Heat Power Only Power & Heat (Res+ Com) (Res) (Res+ Com) (Res) 20 percent debt a 50 percent debt w 70 percent debt a 100 percent debt Source: Northern Economics, Inc. 9-17 Preliminary Engineering -- Final Report June 30, 2014 Atqasuk Transmission Line Project 10.0 Conclusions and Recommendations 10.1 Conclusions 10.1.1 Overview The results of the Atqasuk Transmission Line Project, Phases I & II, find, when compared to the continued use of fuel oil, that implementation of the project would lower and stabilize the cost of energy in the community of Atqasuk and both, the community and the NSB, would benefit from potential significant cost savings. It should be noted all six project alternatives evaluated were found to be economically feasible as they have a positive NPV of cost savings compared to the current diesel -based system for power generation and heating. The best alternatives include Options 1 & 2 with both power and heat. • Option 1, power & heat NPV of cost savings of $62.1 million over 35 years • Option 2, power & heat NPV of cost savings of $59.9 million over 35 years. The economics of the project demonstrates two economic dynamics: 1) One is the "economy of scale" whereby an increase in production of Barrow's electric load base by 25%, results in a reduction in the cost per unit of electricity, ($/ kWh). The savings could be felt by utility customers in both Atqasuk and Barrow; 2) The NSB has the natural resources to develop its own independent energy market, such as utilizing Barrow's natural gas source. By converting to this source Atqasuk would eliminate its dependency on purchasing fuel oil from the unpredictable global energy market and would realize a lower cost, stable priced and long term energy supply. This is made possible by the construction of the transmission line. 10-1 Preliminary Engineering —Final Report June 30, 2014 Atqasuk Transmission Line Project The NSB is fortunate to have several local energy sources in large quantities on their lands. The problem being they are not close to existing communities and/or the technology market doesn't support small scale utilities. The use of a transmission line to interconnect electric systems on the North Slope could potentially encourage the development of other local energy resources such as wind, coal or natural gas on a regional basis. Then the Borough would be on its way to establishing a local energy market independent of the unpredictable global market. Other notable benefits of the power line are: the project will eliminate particulate pollution and significantly reduce the carbon "footprint" and greenhouse gases formed by the combustion of oil for power generation and space heating in Atqasuk; the use of BUECI's larger turbines will improve the quality of power delivered to the Community; the project will eliminate the noise pollution associated with the Atqasuk power plant; and the project would reduce the potential of oil and glycol spills. Although the project has several significant benefits, alternatively, it could have negative effects on wildlife resources as well as negative aesthetic (e.g., visual) impacts. Technical Findings The preliminary engineering phase has addressed the issues identified in the Feasibility Study 2011. There does not appear to be any technical "fatal flaws" to this project. Two critical issues resolved in this report are: route selection and suitability of Fiber Reinforced Polymer (FRP) pole to function in the arctic environment. �..- •.. . 10-2 Preliminary Engineering —Final Report June 30, 2014 Atqasuk Transmission Line Project Route — Important to the project was the selection of a route for the line from Barrow to Atqasuk. This study selected the Eastern Route from the 2011 Feasibility Study. The route is about 71.9 miles in length and avoids dense avian nesting areas and populations, utilizes existing infrastructure, avoids lakes and significant surface water, avoids existing Native Allotments, ties into the Walakpa gas field power plant, and is the shortest and most economic route. Structures — The selected structure for this application is a 69 kV Transmission Line Structure, the TP-69. The typical pole selected, for most of the line is a 65 foot long Fiber Reinforced Polymer (FRP) pole. Key to the project were the Compressive freeze/thaw stress and adfreeze bond strength tests conducted on this project on the modular FRP utility pole systems and other materials. Based on the test findings, the FRP pole material was found to be suitable for operation in an Arctic permafrost environment. This structure proved to be the most economical alternative compared to other structures since it is easier to transport and install. 10.1.2 Major Issue Facing the Project The major issue facing the project is what level of natural, social and economic environmental information will be required under the National Environmental Policy Act (NEPA) process. The proposed Powerline route crosses several important avian habitats, including habitats for threatened Stellar and Spectacled Eiders listed under the Endangered Species Act and the yellow -billed loon, a species of conservation concern in northern Alaska. Since the project crosses BLM land, the project would have to comply with the NEPA. Under NEPA the BLM will determine if the project will require environmental disclosure documents or an EA or EIS. These documents take different levels of 10-3 Preliminary Engineering —Final Report '' db= June 30, 2014 Atqasuk Transmission Line Project time and funding and are generally prepared by the federal agency with input from the project proponent, in this case the NSB. At this point the BLM feels that an EIS will need to be done because they can't justify a "Finding of No Significant Impact". Further, the BLM will not commit to any specific NEPA requirements until they have a final design of the transmission line in hand. It is estimated the EIS would cost $500,000 to $1.5 million and take 1.5 to 3 years to complete. 10.1.3 Avian Protective Measures Throughout the Feasibility and Preliminary Engineering Phases the project team has sought to reduce the collision risk to threatened and migratory birds such as the eiders and loons. For example: the line route was selected to minimize infringement upon known, densely populated, avian nesting areas; the transmission line alignment was sited next to existing powerline infrastructure were possible; the use of FRP poles allowed for wider spans between poles to reduce the number of poles; using T2 a specialized conductor cable that provides light reflections allowing birds to see the conductor thus reducing conductor bird collisions. It is proposed to install T2 conductor on the two outer wirelines on the pole structure for the length of the transmission line. In addition to the effort of the Project Team the project held two meetings with BLM and USF&WS during Phase II. This resulted in additional avian protection measures that were recommended by USF&WS and incorporated into the Option 2 line design concept. They were: design the power line structures to be within 40-50 ft minimum ground clearance to avoid the common flight altitudes of bird species; reduce the proximity of the line to bird take -off and landing areas (micro -alignments of poles ); and keep the vertical arrangement of wires to a 10-4 Preliminary Engineering —Final Report ••- '• .tune 30, 2014 Atqasuk Transmission Line Project minimum. This led to the design of the line near Barrow to have all three conductor phases in the same elevation by using three pole structures without the use of crossarms. The agencies feared crossarms would provide nesting opportunities for Ravens whom prey on birds. As the project progresses through the permitting and NEPA process additional avian safety measures may be brought to the attention of the project team for evaluation and implementation. 10.2 Recommendations Although the economics are very good and there are no technical "fatal flaws" to the project the project is a complex process that will take up to 5 years to complete. Presently the project is at a "go -no go" decision point. The preliminary engineering effort has adequately defined the project concept. The next step is for the NSB and Community of Atqasuk, to make a decision to advance the project or not and if so to what level, alternative 1, power only, alternative 2, power plus residential heat load or 3, power plus residential and commercial heat loads. The project team feels the project is ready to enter into the final design and construction phase. Alternative #3 provides the greatest long term savings and benefits to the Borough and Atqasuk. If the Borough chooses to go forward with the project, funding will be an issue. A financial plan will need to be developed based on yearly funding requirements, including an investigation of available grants, bonding or low -interest loans, tax credits, depreciation deductions and other types of federal, state or private financial assistance that may be available. 10--5 Preliminary Engineering —Final Report s June 30, 2014 Atqasuk Transmission Line Project 10.2.1 Project Development Schedule Assuming funding is available and alternative #3 is selected, it is estimated that a five year development and construction schedule would be needed to complete the project. The pre -construction activities include geotechnical surveys, environmental studies and permitting and engineering surveys and final design. Several of the activities include field work that needs to be done mid spring to early fall. Also, the actual time it takes to perform an EA or EIS is hard to determine, especially if the agencies do the studies in-house. A development schedule is presented based on an assumption BLM will require an EIS and will take two years to complete. A Gantt chart presenting the project schedule of activities is provided in Appendix L, "Project Development Schedule " The following are steps in a Project Development Schedule: Pre-Design_Agency Meeting From the Agency meetings the project team held with USFWS and BLM we were given several criteria recommended by USFWS that would help get the project permitted. The BLM, on the other hand, was less committed and wanted to see a final design before making a commitment. The BLM stated they are open to helping with the environmental process and continuing the discussion established in this report. They have suggested a pre -design meeting with the NSB. We recommend the Borough take advantage of such a meeting. Items that could be discussed: 1. The possibility of the NEPA studies beginning as an EA and if results show a need for an EIS then that would be the direction the project would take. 2. Normally the environmental studies under NEPA are performed in-house by the agency. The NSB would not have to pay for this work. However if the Borough wants to expedite the process it can propose to do the work through one of their own contractors. The BLM would take the document created by the Borough's contractor and modify it to meet their requirements, and then make it their own. In this case the Borough would pay for the work. The drawback of having the BLM do the work is that the North Slope Borough 10-6 Preliminary Engineering —Final Report June 30, 2014 Atqasuk Transmission Line Project BLM would have to fit it in with all the other work they are doing and it would take longer to complete the required studies. 3. Review project concepts Options 1 and 2. Discuss avian safety measures as it pertain to this project. Environmental Permits and Studies For all project alternatives, the environmental studies are assumed to take place during year 1 and year 2 at an estimated cost of $170,000 for permitting and $500,000 for an EA. At this point, it has not been determined that an EIS is required. If BLM decides that an EIS is required, the EIS is estimated could cost up to $1.5 million and take 1.5 to 3 years to complete. Geotechnical and engineering field work would need to be done initially to support the many permits required, (see Section 7, "Permitting Considerations" from the Feasibility Study Phase I, 2011) and to support the NEPA process. Geotechnical and Engineering Field Activities Geotechnical and engineering will need to establish a definitive route and conceptual design. Activities include: • Conduct aerial and ground topographic surveys and "field adjust" the selected ROW alignment. • Along the proposed alignment routes, the following geotechnical elements should be performed: a. Ice jam issues along drainages should be monitored during breakup. b. Late spring flyover to identify snow drift zones c. Hand thaw probing in late fall should be conducted at potential areas of deeper thaw at proposed pole and guy anchor structures • Perform an Engineering Survey - once the specific alignment is identified in the field and tied down with specific coordinates the engineer will perform an engineering survey that includes a land survey with aerial photography. The engineering survey will locate physical features in plan and determine elevations along the route. �MrrNorth Slope Borough 10-7 Preliminary Engineering —Final Report June 30, 2014 Atqasuk Transmission Line Project Final Desian Based on the engineering survey, plan and profile drawings will be developed and a Basis of Design Document prepared that documents the design requirements: • codes and standards • clearance requirements • sag and tension • physical loading requirements • ROW constraints • guying requirements From the final layout, sizing of major facility components and material, labor and equipment pricing will be brought up to date to form a Cost Estimate. Construction Transmission Line - Construction of the intertie is assumed to take place over a 2- year period (year 4 and year 5). The corresponding supporting engineering and construction management activities also occur over the same period and is estimated to be about 12 percent of the construction cost. Conversion to Electric Heat - Determine the equipment and installation requirements to convert the heating systems in residences and other buildings in Atqasuk from fuel oil to electric. Because each conversion would be unique in some way, site visits would be required to every heated structure. The cost of converting to electric heating systems for residential structures is estimated to amount to $2.8 million, and $1.87 million for converting the Borough facilities. Combined, the conversion costs amount to $4.68 million. The analysis assumes that the heating equipment conversion would be designed in year 4 and constructed in year 5. 10-8 Preliminary Engineering —Final Report qldm� June 30, 2014 Atqasuk Transmission Line Project Section 11.0 References Section 2.0 Agency Review References ABR, Inc. —Environmental Research and Services (ABR). 2013. A graphical summary of bird flight altitudes recorded in northern and western Alaska. Draft Report prepared for Leland A. Johnson and Associates. 6 November 2013. Avian Power Line Interaction Committee (APLIC). 2012. Reducing avian collisions with power lines: the state of the art in 2012. Edison Electric Institute and APLIC. Washington, D.C. Bevanger, K. 1994. Bird interactions with utility structures: collision and electrocutions, causes and mitigating measures. This 136: 412-425. Birdlife International. 2007. Position statement on birds and power lines: on the risks to birds from electricity transmission facilities and how to minimize any such adverse effects. Brussels, Belgium Janss, G.F.E. 2000. Avian mortality from power lines: a morphological approach of a. speciesspecific mortality. Biological Conservation 95: 353-359. Rioux, S., J-P.L. Savard, and A.A. Gerick. 2013. Avian mortalities due to transmission line collisions: a review of current estimates and field methods with an emphasis on applications to the Canadian electric network. Avian Conservation and Ecology 8(2): 7. Section 3.0 Geotechnical Evaluation References Williams, J.R., 1983, Engineering - geologic maps of northern Alaska, Wainwright Quadrangle: U. S. Geological Survey Open -File Report 83-457, 28 p., 1 sheet, scale 1:250,000 Williams, J.R. and Carter, L.D., 1984, Engineering - geologic maps of northern Alaska, Barrow Quadrangle: U.S. Geological Survey Open -File Report 84-124, 39 p., 2 sheets. Reger, R.D., Stevens, D.S.P., Bowman, N.D., Campbell, K.M., and Smith, R.L., 2003, Survey of geology, geologic materials, and geologic hazards in proposed access corridors in the Meade River Quadrangle, Alaska: Alaska Division of Geological & Geophysical Surveys Miscellaneous Publication 89, 5 sheets, scale 1:250,000, Beck, R. A.; Rettig, A. J.; Ivenso, C.; Eisner, W. R.; Hinkel, K. M.; Jones, B. M.; Arp, C. D.; Grosse, G.; Whiteman, D., 2010, Sikuligiruq: Ice dynamics of the 11-1 Preliminary Engineering — Final Report 47- d •• :•�• � June 30, 2014 Atqasuk Transmission Line Project Meade river - Arctic Alaska, from freezeup to breakup from time -series ground imagery, Polar Geography, 33: 115-137. Johnson, P.L. and Kistner, F.B., 1967. Breakup of Ice, Meade River, Alaska., U.S. Army Materiel Command, Cold Regions Research & Engineering Laboratory, Special Report 118. 18p, US Army Corps of Engineers Engineer Research and Development Center, Cold Regions Research and Engineering Laboratory Ice Jam Information Clearinghouse, 2006-2012, http://iceiams.crrel.usace.army.mil/ Section 5.0 Power Pole Heights References Alerstam, T., and G. A. Gudmundsson. 1999. Migration patterns of tundra birds: tracking radar observations along the Northeast Passage. Arctic 52: 346-371. Anderson, B. A., and S. M. Murphy. 1988. Lisburne Terrestrial Monitoring Program, 1986 and 1987: the effects of the Lisburne powerline on birds. Report for ARCO Alaska, Inc., Anchorage, AK, by Alaska Biological Research, Inc., Fairbanks, AK. 60 pp. APLIC (Avian Power Line Interaction Committee). 2012. Reducing avian collisions with power lines: the state of the art in 2012. Edison Electric Institute and APLIC, Washington, DC. 159 pp. Bailey, A. M. 1948. Birds of Arctic Alaska. Colorado Museum of Natural History, Denver, CO. Popular Series, No. 8. 317 pp. Boisvert, J. H. and R. H. Day. 2006. Collision potential of spring migrant Sandhill Cranes and other birds, USAF Tin City Long Range Radar Site, May 2005. Report for United States Air Force, Elmendorf Air Force Base, AK, by ABR, Inc. —Environmental Research & Services, Anchorage, AK, and Fairbanks, AK. 42 pp. Boisvert, J. H., C. T. Schick, and R. H. Day. 2004. Collision potential of fall migrant Sandhill Cranes and other birds, USAF Tin City Long Range Radar Site, September 2003. Unpublished report prepared for U.S. Air Force, Elmendorf Air Force Base, AK, by ABR, Inc. —Environmental Research & Services, Anchorage, AK, and Fairbanks, AK. 34 pp. Cooper, B. A., and R. H. Day. 1998. Summer behavior and mortality of Dark-rumped Petrels and Newell's Shearwaters at power lines on Kauai, Hawaii. Colonial Waterbirds 21: 11-19. Day, R. H., and B. A. Cooper. 1995. Patterns of movement of Dark-rumped Petrels and Newell's Shearwaters on Kauai. Condor 97: 1011-1027. 11-2 Preliminary Engineering — Final Report MIA-1db= June 30, 2014 Atqasuk Transmission Line Project Day, R. H., J. R. Rose, B. A. Cooper, and R. J. Blaha. 2001. Migration rates and flight behavior of migrating eiders near towers at Barrow, Alaska. Report for U. S. Fish and Wildlife Service, Fairbanks, AK, and North Slope Borough, Barrow, AK, by ABR, Inc., Fairbanks, AK. 40 pp. Day, R. H., J. R. Rose, A. K. Prichard, R. J. Blaha, and B. A. Cooper. 2004. Environmental effects on the fall migration of eiders at Barrow, Alaska. Marine Ornithology 32: 13-24. Day, R. H., R. M. Burgess, and P. E. Seiser. 2005a. Movements of eiders and other birds near a proposed windfarm at Hooper Bay, western Alaska, spring 2004. Report for Alaska Village Electric Cooperative, Anchorage, AK, by ABR, Inc. — Environmental Research & Services, Fairbanks, AK. 55 pp. Day, R. H., R. M. Burgess, and P. E. Seiser. 2005b. Movements of eiders and other birds near a proposed windfarm at Mekoryuk, Nunivak Island, Alaska, fall 2004. Report for Alaska Village Electric Cooperative, Anchorage, AK, by ABR, Inc. — Environmental Research & Services, Fairbanks, AK. 58 pp. Day, R. H., J. R. Rose, R. J. Ritchie, J. E. Shook, and B. A. Cooper. 2003. Collision potential of eiders and other birds near a proposed windfarm at St. Lawrence Island, Alaska, October —November 2002. Report for Alaska Industrial and Development Authority —Alaska Energy Authority, Anchorage, AK, by ABR, Inc.Environmental Research & Services, Fairbanks, AK, and Forest Grove, OR. 31 pp. Drewitt, A. L., and R. Langston. 2008. Collision effects of wind power generators and other obstacles on birds. Annals of the New York Academy of Sciences 1134: 233-266. Faanes, C.A. 1987. Bird behavior and mortality in relation to power lines in prairie habitats. USFWS Technical Report No. 7. 24 pp. Gall, A. E., and R. H. Day. 2007. Movements of birds near a proposed powerline corridor and windfarm sites at St. Michael, Alaska, summer and fall 2006. Report prepared for Alaska Village Electric Cooperative, Inc., Anchorage, AK, by ABR, Inc. —Environmental Research & Services, Fairbanks, AK. 36 pp. Gollop, M. A., and R. A. Davis. 1974. Autumn bird migration along the Yukon Arctic coast, July, August, September 1972. Chapter 3 in W. W. Gunn and J. A. Livingston (eds.). Bird migrations on the North Slope and in the Mackenzie Valley regions, 1972. Arctic Gas Biological Report Series, Vol. 13: 83-162. Kessel, B., and T. J. Cade. 1958. Birds of the Colville River, northern Alaska. Biological Papers of the University of Alaska, No. 2. 83 pp. Lehnhausen, W. A., and S. E. Quinlan. 1981. Bird migration and habitat use at Icy Cape, Alaska, 1981. U.S. Fish and Wildlife Service, Anchorage, AK. 297 pp. 11 Preliminary Engineering — Final Report _:+ • • - c• : June 30, 2014 Atqasuk Transmission Line Project Myres, M. T. 1958. Preliminary studies of the behavior, migration, and distributional ecology of eider ducks in northern Alaska, 1958. Interim Progress Report to Arctic Institute of North America, Calgary, AB, Canada. 14 pp. NSB (North Slope Borough). 2011a. Atqasuk power line transmission study. Report of Findings, 15 September 2011. 93 pp. NSB (North Slope Borough). 201 lb. Restoration and enhancement of habitat adjacent to Barrow II (REHAB II). Final report for U.S. Fish and Wildlife Service, Fairbanks, AK, by Department of Wildlife Management, North Slope Borough, Barrow, AK. 10 pp. Oppel, S., A. N. Powell, and D. L. Dickson. 2008. Timing and distance of King Eider migration and winter movements. Condor 110: 296-305. Petersen, M. R., J. B. Grand,_ and C. P. Dau. 2000. Spectacled Eider, Somateria fischeri. in A. Poole and F. Gill (eds.). The Birds of North America. The Birds of North America, Inc. Philadelphia, PA. No. 547 Podolsky, R., D. G. Ainley, G. Spencer, L. DeForest, and N. Nur. 1998. Mortality of Newell's Shearwaters caused by collisions with urban structures on Kauai. Colonial Waterbirds 21: 20-34. Quakenbush, L. T., and R. S. Suydam. 2004. King and Common Eider migrations past Point Barrow. University of Alaska Coastal Marine Institute, Annual Report No. 10: 60-69. Richardson, W. J., and S. R. Johnson. 1981. Waterbird migration near the Yukon and Alaskan coast of the Beaufort Sea. I. Timing, routes, and numbers in spring. Arctic 34: 108-121. Suydam, R., L. Quakenbush, M. Johnson, J. C. George, and J. Young. 1997. Migration of King and Common eiders past Point Barrow. Pp. 21-28 in D. L. Dickson (ed.). King and Common eiders of the western Canadian Arctic. Canadian Wildlife Service, Occasional Papers, No. 94. Suydam, R. S., L. T. Quakenbush, D. L. Dickson, and T. Obritschkewitsch. 2000. Migration of King, Somateria spectabilis, and Common, S. mollissima v-nigra, eiders past Point Barrow, Alaska, during spring and summer/fall 1996. Canadian Field -Naturalist 114: 444-452. TERA (Troy Ecological Research Associates), 2003. Spectacled Eider movements in the Beaufort Sea: distribution and timing of use. Report for BP Exploration (Alaska) Inc., Anchorage, AK, and Bureau of Land Management, Fairbanks, AK; by Troy Ecological Research Associates, Anchorage, AK. 18 pp. TERA (Troy Ecological Research Associates). 2003. Molt migration of Spectacled Eiders in Beaufort Sea region. Report for BP Exploration (Alaska) Inc., Anchorage, AK, by Troy Ecological Research Associates, Anchorage, AK. 17 pp. Woodby, D. A., and G. J. Divoky. 1982. Spring migration of eiders and other waterbirds at Point Barrow, Alaska. Arctic 35: 403-410. .s._F;. Preliminary Engineering - Final Report June 30, 2014 Appendix A. - Minutes of Oct 28 & Nov. 7 Agency Review Meetings Meeting Notes Date: October 28, 2013 Time: 9:00 am Location: USFWS Fairbanks, Refuges Conference Room Meeting Subject: Atqasuk-Barrow Intertie Agency Meeting Meeting Attendees: Max Ahgeak, NSB: Jewel Bennett, FWS; Megan Boldenow, FWS; Sarah Conn, FWS; Bob Day, ABR; Stacey Fritz, BLM; Adrian Gall, ABR; Kent Grinage, Leland; Lon Kelly, BLM; Stacie McIntosh, BLM; Debbie Nigro, BLM; Kaiti Ott, FWS; Robin Reich, Solstice AK; Bob Ritchie, ABR (by phone); Tim Rowe, NSB; Albert Sakata, Leland; Richard San Jose, NSB; Louise Smith, FWS; Ted Swem, FWS Notes: Adrian Gall (ABR) opened the meeting with introductions and meeting goals. Max Ahgeak (North Slope Borough, NSB) gave an overview of Atqasuk and discussed the high cost of power in Atqasuk. He said that Atgasuk's city council supported the intertie from Barrow through a resolution. Richard San Jose (Rico, NSB) discussed the need for the intertie including cost of power and fuel delivery via rollagon. He said a wind study showed poor wind resources in the area. Kent Grinage (Leland A. Johnson & Associates) gave a presentation on the transmission line design and layout. His presentation included: • A summary of studies that have been completed on the project • A summary of grants that have been acquired for the project • An overview of annual costs of power in Atqasuk • A summary of the eastern and western route options • Structures considered and their design details • How avian issues (potential electrocutions and collisions) have shaped the route and structure selection Questions/comment received following Kent's presentation Question: Would a new power line be needed between Barrow and the gas field? Response: There is a good existing line; however it is old and it needs safety improvements. It would make sense to install the new line to the gas field when the Atqasuk line is constructed. Question: Would river crossings be overhead? 4 Atqasuk-Barrow Avian Study Response: Overhead lines, spanning 1,200 feet and supported by H-framed structures on each side of the river, are proposed. Question: What kind of system redundancy would be incorporated into the project to insure that power is reliable? Response: The Atqasuk power plant would remain in place and could be started in the remote case of line failure. Question: How much of the line would use T2 cable? Response: T2 cable could be installed wherever there are bird sensitivities. Comment: The project might want to consider using T2 line instead of bird diverters, since devices often fail. Question: Does the Borough have plans to construct a road to Atqasuk? Response: Recent studies have found that the road, at about $2 M/mile, would be very expensive to build and not feasible. There has not been much talk about the road lately. Adrian gave a presentation on avian considerations for the Barrow-Atgasuk Line. Her presentation included: • An overview of the habitat in the project area • A summary of species of concern • The avian issues that were considered during route planning • Best practices and mitigation options that were considered for reducing avian/power line collisions Questions/comment received following Adrian's presentation Question: Are there Yellow -billed Loon migration tracks in the project area? Response: There have been no locations to indicate birds flying through the project area. Comment: Matt Sexson's data on bird movement through the project area should be considered. His points are closer in time and have a finer level of detail. Robin Reich (Solstice Alaska Consulting) discussed the need for other environmental approvals including a Bureau of Land Management National Environmental Policy Act (NEPA) approval for crossing federal land, an Army Corps of Engineers' (wetlands) permit, and compliance with other Federal laws triggered by NEPA. In addition, right-of-way may need to be secured across State-owned lands. Additional questions/comment received Comment: If the project uses micropiles (which involves placing fill), a wetland permit would be needed; however, if the project is only pounding piles into the ground, a wetland permit may not be needed. Question: What is the timeline for the project? Response: Once the project is permitted, it would take 1.5 years to design and 2 years to construct. 5 Atqasuk--Barrow Avian Study Comment: BLM would likely require an Environmental Impact Statement (EIS) level NEPA analysis. BLM would work with a third party contractor to prepare the EIS. It usually takes about 2 years to complete an EIS. The work is done through a cost recovery agreement where the applicant (in this case, the NSB) would pay for the cost of preparing the EIS. It is estimated it could cost $1.5 M; however this is only an approximation. Comment: The best height for a power line varies with the bird taxa and with what the birds are doing in the area. Migrant birds are likely moving east to west in the area; therefore, a line running north to south is the worst alignment. It is likely that USFWS could give power line recommendations based on waterfowl behavior predictions; however, Red Phalarope and Pectoral Sandpiper may be more at risk. There are lots of movements of these species in the project area. Comment: The power line's lowest point (due to "drooping down") could be an issue. More power poles could help to keep the line higher and reduce the collision risk. While costs could be increased by adding poles, the savings from the project could make additional poles feasible. Question: It would be better to have a single plane of lines to reduce collision risk. Would a horizontal crossbar with spikes on the poles instead of lines running in 3 planes be feasible? Response: The engineers looked into this. It would likely cost 30-40% more to have H-frame structures. Comment: Birds see lines differently than we do. We don't know how/why collisions occur, but it's probably because of issues differentiating the lines from the horizon or backdrop. The higher the lines are the better. Comment: The design of the poles should consider minimizing nesting habitat for Ravens. Response: A single pole design (instead of an H-frame structure) would help with this. Question: Would there be a ground wire? Response: There is no ground wire needed because the line is not in a lightning prone area. USFWS Response: This is better because ground wires are smaller and harder for birds to see. Comment: The environmental document would need to consider connected and cumulative actions. Would there be a line to Wainwright if this line is constructed? Response: Wainwright is moving forward with a wind project which could reduce the need for the line from Atqasuk; however, the line is currently designed to accommodate Wainwright power needs. Comment: Agencies will likely want to see an analysis of different line and pole designs. Comment: BLM would want an archeological survey anywhere ground disturbance activities would occur. Question: What is the funding scenario for the project? Response: Currently the plan is for 90% of the funding to come from the State and 10% of the funding to come from the Borough. Construction costs will be paid primarily by NSB through bonds. Comment: Agencies may be able to get comments back by Thanksgiving (November 28). 6 Atqasuk-Barrow Avian Study Meeting Notes Date: 7 November 2013 Time: 13:00 Location: BLM Conference Room, Fairbanks, AK Meeting subject: Atqasuk-Barrow Intertie Agency meeting, Part II Attendees: Jewel Bennett, FWS; Megan Boldenow, FWS; Sarah Conn, FWS; Adrian Gall, ABR; Debbie Nigro, BLM; Kaiti Ott, FWS; Bob Ritchie, ABR; Louise Smith, FWS; Ted Swem, FWS Goal of the meeting: Bring the 2 regulatory agencies (FWS and BLM) to agreement about the primary permitting concerns and possible mitigation options. Neither agency is interested in preventing the project from being permitted. There are, however, concerns about bird strikes that must be addressed to the best of the engineers' abilities. Notes: Bob Ritchie provided history about the mitigation considered to date. In 2010, the NSB asked ABR for assistance in developing routes that would minimize interactions with birds. ABR provided information from Alaska Coastal Plain and ABR surveys and encouraged consideration of VSMs. These suggestions were incorporated into the current route alignment proposal. In the past 2 months, ABR has assembled information about powerline heights, configuration, and bird flight behavior to assist in the design of the powerlines. Comment: BLM and FWS are not interested in preventing community development. Because of the strong community support for the project and the small footprint of the transmission line, they do not anticipate major subsistence or archeological issues (although an archeological survey will be required). Bird strikes will be the primary issue with the permit request and will require an EIS. It is not clear if the stipulation for the NPRA that prevents overhead lines in all but the most rare of cases applies to projects other than oil and gas development. A solicitor is looking into that. Regardless, this project would set a precedent for overhead lines in the NPRA. The clients are advised to review other permits issued by BLM in the NPRA for examples of stipulations that may be included in a permit for this project (e.g., habitat surveys to inform micro -alignment of the powerline route; pre -construction bird surveys; post -construction collision monitoring). Question: Will either route or the engineering specs of the line be adequate to extend to Wainwright in the future? Comment: Ideally, the layout of lines across the North Slope will be done with long-range planning in mind rather than piece -meal. Regulatory agencies would like to see that future development is considered in the current plan, even if the details of future development are not fully fleshed out. Comment: Horizontal line configuration would be preferable to reduce the probability of interaction with powerlines. If that configuration requires H-poles, however, there will be a trade-off between reducing the vertical profile and providing perching and nesting options for ravens and raptors. 7 Atqasuk-Barrow Avian Study Comment: T2 along the entire line would be preferable to hanging diverters of any kind that would require maintenance. Another possible advantage of the horizontal configuration is that T2 might not be needed on all lines if they are all strung at the same height (i.e., only have T2 on the 2 outer lines and not on inner lines). Comment: It would be preferable to raise the minimal line height (i.e., the height at the bottom of the sag) as high as feasible. The agencies recognize that adding poles and possibly switching to a horizontal configuration will increase the initial cost of the project. They are interested in an analysis that evaluates the relationship between increasing line height (more and/or different poles) and cost. The immense savings in fuel costs will offset the investment in bird mitigation measures. 8 Atgasuk-Barrow Avian Study Appendix B. - U.S. Fish and Wildlife Service Written Recommendations OVERHEAD POWERLINES: RECOMMENDATIONS FOR REDUCING RISK TO MIGRATORY BIRDS ON ALASKA'S NORTH SLOPE U.S. Fish and Wildlife Service Fairbanks Fish and Wildlife Field Office 101 12th Ave, Room 110 Fairbanks, AK 99701 December 2013 The U. S. Fish and Wildlife Service (Service) has concerns about the risks overhead powerlines pose to migratory birds. Documented risks to birds include injuries and fatalities caused by collisions, resulting from the interplay between biological, environmental, and engineering variables (Bevanger 1994, Janss 2000, Rioux et al. 2013). Overhead powerlines on Alaska's North Slope may pose particular collision risks to migratory birds, due to frequent low light conditions and poor weather that leads to many low visibility days. At risk are a wide variety of migratory bird species, such as shorebirds and waterfowl, including Alaska -breeding Steller's (Polysticta stelleri) and spectacled eiders (Somateria frscheri), both of which are listed as threatened under the Endangered Species Act, and the yellow -billed loon (Gavia adamsii), a species of conservation concern. Overhead lines pose different risks to regional migrants as compared to individuals that nest locally, juveniles using the area, or molting adults. Regional migrants passing through the area generally fly at altitudes that make them less likely to encounter lines, except during inclement weather, while individuals using the local habitat may encounter lines repeatedly during lower - altitude, regular flights between nesting, feeding, and roosting areas. Therefore our recommendations here are largely aimed at reducing impacts to birds that make use of local habitats. 9 Atgasuk-Barrow Avian Study The Service recognizes the necessity for overhead powerlines in certain cases on the North Slope (e.g., providing affordable energy to communities), and in those situations the Service would like to provide input on powerline design and placement to minimize potential impacts to migratory birds. The Avian Power Line Interaction committee has developed guidelines for electric utilities (APLIC 2012) that describe a variety of opportunities to modify project design and mitigate collision risk to migratory birds. Using these guidelines, as well as our experience in Alaska, we suggest the following recommendations be considered when designing overhead powerlines on the North Slope. Powerline Route Current research on effects of overhead powerlines suggests location is the most important factor for determining avian collision risk. Powerline routes should be chosen to avoid areas where large numbers of birds regularly fly at low altitude, such as along coastlines and topographical bottlenecks, wetlands, and breeding colonies (BirdLife International 2007). Overall route and routing refinements that offer a possible reduction in risk to birds should continue to be a topic of discussion between the Service and Project Proponent throughout the project design phase. When choosing and refining a proposed route, a critical consideration is how often and in what numbers birds would fly across a given section of powerline during their daily, local movements (APLIC 2012). The Project Proponents should expect that studies to answer these critical questions may be required prior to permitting and construction of powerlines. In choosing and refining the route, the Project Proponent together with the Service should look at whether the proposed orientation bisects a habitat (e.g. a single wetland complex) or follows the margin between two habitats (e.g. dividing a wetland complex from upland habitat), and which route would pose more risk to the local bird community. Evidence exists for increased risk posed by either scenario, and which represents greater risk will depend on local conditions and the species present in the area (APLIC 2012). Site -specific information about the local conditions and bird community will be necessary to inform this analysis. It is critical to apply information gathered locally because collision risk from any particular powerline depends in part upon the way each species uses the surrounding habitat (APLIC 2012). Variables that may influence flight behavior and contribute to collision risk include species, age, sex, reproductive status (i.e. 10 Atgasuk-Barrow Avian Study breeding or non -breeding), and reasons for local movements (e.g. courtship or territorial displays, flocking, hunting, or undertaking feeding flights to and from the nest). Birds are likely at greater risk of collision during low-level flight, including take -off and landing. Therefore it follows that placement of a powerline in or near an attractive habitat (e.g. a feeding area) should be avoided (APLIC 2012). In general, APLIC guidance recommends a buffer around waterbodies, although the guidance does not identify a specific buffer distance. That distance will depend upon the species use of the area. Powerline Configuration Placing all wires in one horizontal plane (i.e. reducing the vertical spread of the wires) will reduce the area of the collision zone and is desirable. The Service would like to see an analysis of design options that could achieve a single vertical plane for multiple wires. In particular, we are interested in designs that avoid the use of H poles to prevent creation of raven nesting platforms. Support structures for overhead powerlines may provide artificial nesting platforms for ravens, an uncommon but efficient predator of ground -nesting birds. Ravens currently have a limited distribution north of the Brooks Range and nest in this area almost exclusively on anthropogenic nesting sites. Increasing raven nests may ultimately result in a greater negative impact to locally -nesting birds than collisions resulting from stacked wires. A single -pole design that reduces the vertical span of wires should be a design priority. Powerline Height Data provided by ABR, Inc. (ABR 2013) suggests that powerlines that are a minimum of 40 to 50 feet above ground level would avoid the common flight altitudes documented for many bird species flying overland in coastal northern and western Alaska. Therefore, powerline design that maximizes the amount of line with wires above this height is very desirable because it would reduce collision risk for the very large number of birds that migrate through the area. Wire Type Use of wires that are designed to be highly visible is also desirable. Wire types such as T2, a twisted electrical wire, may reduce collision risk by increasing the visibility of the wires. It is possible that in multi -wire powerlines, lines could be configured in such a way as to use this 11 Atgasuk-Barrow Avian Study more expensive wire type on a subset of the wires (e.g. consider whether avian detection and avoidance objectives would be met if T2 was used for just the outer wires, with all wires strung at the same height). Diverters Although diverters have been successfully used on powerlines to reduce collision risk in some locations, prior experience and local knowledge indicate some types do not survive the rigors of arctic weather. Some of the diverters that have been used on the North Slope readily break and would require constant maintenance to remain functional. If bird diverters are considered as an option for enhancing visibility in particularly sensitive locations, the Service encourages use of more durable types with demonstrated utility in extremely cold and windy environments. 12 Atgasuk-Barrow Avian Study STANDARD FORM 299 (1/2006) Prescribed by DOUCTSDAMOT P.L. 96487 and Federal Register Notice 5-22-95 APPLICATION FOR TRANSPORTATION AND UTILITY SYSTEMS AND FACILITIES ON FEDERAL LANDS NOTE: Before completing and filing the application, the applicant should completely review this package and schedule a preapplication meeting with representatives of the agency responsible for processing the application. Each agency may have specific and unique requirements to be met in preparing and processing the application. Many times, with the help of the agency representative, the application can be completed at the preapplication meeting. 1. Name and address of applicant (include zip code) 2. Name, title, and address of authorized agent from Item 1 (include zip code) 4. As applicant are you? (check one) a. ❑ Individual b. ❑ Corporation* C. ❑ Partnership/Association* it ❑ State Government/StateAgency C. ❑ Local Government f. ❑ Federal Agency * if checked, complete supplemental page what application is for (check one) a. ❑ New authorization b. ❑ Renewing existing authorization No. c. ❑ Amend existing authorization No. it. ❑ Assign existing authorization No. e. ❑ Existing use for which no authorization has been received* f. ❑ Other* *Ifchecked provide details underltem 7 6. If an individual, or partnership are you a citizen(s) of the United States? ❑ Yes ❑ No FORM APPROVED OMB NO. 1004-0189 Expires: November 30, 2008 FOR AGENCY USE ONLY 3. TELEPHONE (area code) 7. Project description [describe in detail): (a) Type of system or facility, (e.g., cana!, pipeline, road); (b) related structures and facilities; (c) physical specifications (length, width, grading, etc.); (d) tern of years needed; (e) time of year of use or operation; (f) Volume or amount of product to be transported; (g) duration and timing of construction; and (h) temporary work areas needed for construction (Attach additional sheets, if additional space is needed,) 8. Attach a map covering area and show location of project proposal 9. State or local government approval: ❑Attached []Applied for ❑ Not required 10. Nonreturnable application fee. ❑Attached ❑Not required 11. Does project cross international boundary or affect international waterways? ❑ Yes ❑No (If 'yes, " indicate on map) 12. Give statement of your technical and financial capability to construct, operate, maintain, and terminate system for which authorization is being requested. (Continued on page 2 ) This form is authorized for local reproduction. 13a. Describe otherreasonable alternative routes and modes considered. b. Why were these alternatives not selected'? c. Give explanation as to why it is necessary to cross Federal Lands 14. List authorizations and pending applications filed for similar projects which may provide information to the authorizing agency. (Spec, number date, code, or name) 15. Provide statement of need for project, including the economic feasibility and items such as: (a) cost of proposal (construction, operation, and maintenance); (b) estimated cost of next best alternative; and (c) expected public benefits. 16. Describe probable effects on the population in the area, including the social and economic aspects, and the rural lifestyles. Describe likely environmental effects that the proposed project will have on: (a) air quality; (b) visual impact; (c) surface and ground water quality and quantity; (d) the control or structural change on any stream or other body of water, (e) existing noise levels; and (f) the surface of the land, including vegetation, permafrost, soill, and soil stability. 18. Describe the probable effects that the proposed project will have on (a) populations of fish, plantlife, wildlife, and marine life, including threatened and endangered species; and (b) marine mammals, including hunting, capturing, collecting, or killing these animals. 19. State whether any hazardous material, as defined in this paragraph, will be used, produced, transported or stored on or within the right-of-way or any ofthe right-of-way facilities, or used in the construction, operation, maintenance or termination of the right-of-way or any of its facilities. "Hazardous material" means any substance, pollutant or contaminant that is listed as hazardous under the Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended, 42 U.S.C. 9601 et seq., and its regulations. The definition of hazardous substances under CERCLA includes any "hazardous waste" as defined in the Resource Conservation and Recovery, Act of 1976 (RCRA), as amended, 42 U.S.C. 9601 et seq., and its regulations. The term hazardous materials also includes any nuclear or byproduct material as defined by the Atomic Energy Act of 1954, as amended, 42 U.S.C. 2011 et seq. The term does not include petroleum, including crude oil or any fraction thereof that is not otherwise specifically listed or designated as a hazardous substance under CERCLA Section 101(14), 42 U.S.C. 9601(14), nor does the term include natural gas. 20. Name all the Department(s)/Agency(ies) where this application is being filed. I HEREBY CERTIFY, That I am of legal age and authorized to do business in the State and that I have personally examined the information contained in the application and believe that the information submitted is correct to the best of my knowledge. Title 18, U.S.C. Section 1001 and Title 43 U.S.C. Section 1212, make it a crime for any person knowingly and willfully to make to any department or agency of' the United States any false, fictitious, orfraudulent statements or representations as to any matter within its jurisdiction. (Continued on page 3 ) (SF -299, page 2) APPLICATION FOR TRANSPORTATION AND UTILITY SYSTEMS AND FACILITIESON FEDERAL LANDS GENERAL INFORMATION ALASKA NATIONAL INTEREST LANDS This application will be used when applying for a right-of-way, permit, license, lease, or certificate for the use of Federal lands which lie within conservation system units and National Recreation or Conservation Areas as defined in the Alaska National Interest Lands Conservation Act. Conservation system units include the National Park System, National Wildlife Refuge System, National Wild and Scenic Rivers System, National Trails System, National Wilderness Preservation System, and National Forest Monuments. Transportation and utility systems and facility uses for which the application may be used are: 1. Canals, ditches, flumes, laterals, pipes, pipelines, tunnels, and other systems for the transportation of water. 2, Pipelines and other systems for the transportation of liquids other than water, including oil, natural gas, synthetic liquid and gaseous fuels, and any refined product produced therefrom. 3. Pipelines, slurry and emulsion systems, and conveyor belts for transportation of solid materials. 4. Systems for the transmission and distribution of electric energy. 5. Systems for transmission or reception of radio, television, telephone, telegraph, and other electronic signals, and other means of communications. 6. Improved rights -of -way for snow machines, air cushion vehicles, and all -terrain vehicles. 7. Roads, highways, railroads, tunnels, tramways, airports, landing strips, docks, and other systems of general transportation. This application must be filed simultaneously with each Federal department or agency requiring authorization to establish and operate your proposal. In Alaska, the following agencies will help the applicant file an application and identify the other agencies the applicant should contact and possibly file with: Department of Agriculture Regional Forester, Forest Service (USFS) Federal Office Building, P.O. Box 21628 Juneau, Alaska 99802-1628 Telephone: (907) 586-7847 (ora local Forest Service Office) Department of the Interior Bureau of Indian Affairs (BIA) Juneau Area Office 9109 Mendenhall Mall Road, Suite 5, Federal Building Annex Juneau, Alaska 99802 Telephone: (907) 586-7177 Bureau of Land Management (BLM) 222 West 7th Ave., Box 13 Anchorage, Alaska 99513-7599 Telephone: (907) 271-5477 (ora local BL.L1 Office) National Park Service (NPS) Alaska Regional Office, 2525 Gambell St., Rm.107 Anchorage, Alaska 99503-2892 Telephone: (907) 257-2585 U.S. Fish&Wildlife Service (FWS) Office of the Regional Director 1011 East Tudor Road Anchorage, Alaska 99503 Telephone: (907) 786-3440 Note -Filings with any Interior agency may be filed with any office noted above or with the: Office of the Secretary of the Interior, Regional Environmental Officer, Box 120, 1675 C Street, Anchorage, Alaska 99513. see page Department of Transportation Federal Aviation Administration Alaska Region AAL-4,222 West 7th Ave., Box 14 Anchorage, Alaska 99513-7587 Telephone: (907) 271-5285 NOTE- The Department of Transportation has established the above central filing point for agencies within that Department. Affected agencies are: Federal A`riation Administration ('AA), Coast Guard (USCG), Federal Highway Administration (FHWA), Federal Railroad Administration (FRA). OTHER THAN ALASKA NATIONAL INTEREST LANDS Use cf this form is not limited to National Interest Conservation Lands of Alaska. Individual departments/agencies may authorize the use of this form by applicants for transportation and utility systems and facilities on other Federal lands outside those areas described above. For proposals located outside of Alaska, applications will be filed at the local agency office or at a location specified by the responsible Federal agency. SPECIFIC INSTRUCTIONS (Items not listed are self-explanatory) Item 7 Attach preliminary site and facility construction plans. The responsible agency will provide instructions whenever specific plans are required. 8 Generally, the map must show the section(s), township(s), and ranges within which the project is to be located. Show the proposed location of the project on the map as accurately as possible. Some agencies require detailed survey maps. The responsible agency will provide additional instructions. 9, 10, and 12 - The responsible agency will provide additional instructions. 13 Providing information on alternate routes and modes in as much detail as possible, discussing why certain routes or modes were rejected and why it is necessary to cross Federal lands will assist the agency(ies) in processing your application and reaching a final decision. Include only reasonable alternate routes and modes as related to current technology and economics. 14 The responsible agency will provide instructions. 15 Generally, a simple statement of the purpose of the proposal will be sufficient. However, major proposals located in critical or sensitive areas may require a full analysis with additional specific information. The responsible agency will provide additional instructions. 16 through 19 - Providing this information in as much detail as possible will assist the Federal agency(ies) in processing the application and reaching a decision. When completing these items, you should use a sound judgment in furnishing relevant information. For example, if the project is not near a stream or other body of water, do not address this subject. The responsible agency will provide additional instructions. Application must be signed by the applicant or applicant's authorized representative. If additional space is needed to complete any item, please put the information on a separate sheet of paper and identify it as "Continuation of Item'. (SF-299, page 3) SUPPLEMENTAL NOTE: The responsible agency(ies) will provide additional instructions CHECK APPROPRIATE BLOCK I - PRIVATE CORPORATIONS ATTACHED PILED* a. Articles of Incorporation b. Corporation Bylaws c. A certification from the State shoaling the corporation is in good standing and is entitled to operate within the State. d. Copy of resolution authorizing filing e. The name and address of each shareholder owning 3 percent or more of the shares, together with the number and percentage of any class of voting shares of the entity which such shareholder is authorized to vote and the name and address of each affiliate of the entity together with, in the case of an affiliate controlled by the entity, the number of shares and the percentage of any class of voting stock of that affiliate owned, directly or indirectly, by that entity, and in the case of an affiliate which controls that entity, the number of shares and the percentage of any class of voting stock of that entity owned, directly or indirectly, by the affiliate. f If application is for an oil or gas pipeline, describe any related right-of-way or temporary use permit applications, and identiAT previous applications ❑ ❑ g. If application is for an oil and gas pipeline, identify all Federal lands by agency impacted by proposal II -PUBLIC CORPORATIONS a. Copy of law forming corporation b. Proof of organization C. Copy of Bylaws d. Copy of resolution authorizing filing e. If application is for an oil or gas pipeline, provide information required by Item "I-P and "I-g" above. III - PARTNERSHIP OR OTHER UNINCORPORATED ENTITY a. Articles of association, if any b. If one partner is authorized to sign, resolution authorizing action is c. Name and address of each participant, partner, association, or other d. If application is for an oil or gas pipeline, provide information required by Item "I-f' and "I-g" above. ❑ * If the required information is already filed with the agency processing this application and is current, check block entitled "Filed." Provide the file identification information (e.g., number, date, code, name). If not on file or current, attach the requested information. (Continued on page 5) (SF-299 e 4 NOTICES NOTE: This applies to the Department of the Interior/Bureau of Land Management (BLM) The Privacy Act of 1974 provides that you be furnished with the following information in connection with the information provided by this application for an authorization. AUTHORITY: 16 U. S. C. 310 and 5 U. S.C. 301. PRINCIPAL PURPOSE: The primary uses of the records are to facilitate the (1) processing of claims or applications; (2) recordation of adjudicative actions; and (3) indexing of documentation in case files supporting administrative actions. ROUTINE USES: BLM and the Department of the Interior (DOI) may disclose your information on this form: (1) to appropriate Federal agencies when concurrence or supporting information is required prior to granting or acquiring a right or interest in lands or resources; (2) to members or the public who have a need for the information that is maintained by BLM for public record; (3) to the U.S. Department of Justice, court, or other adjudicative body when DOI determines the information is necessary and relevant to litigation; (4) to appropriate Federal, State, local, or foreign agencies responsible for investigating, prosecuting violation, enforcing, or implementing this statute, regulation, or order; and (5) to a congressional office when you request the assistance of the Member of Congress in writing. EFFECT OF NOT PROVIDING THE INFORMATION: Disclosing this information is necessary to receive or maintain a benefit. Not disclosing it may result in rejecting the application. The Paperwork Reduction Act of 1995 requires us to inform you that: The Federal agencies collect this information from applicants requesting right-of-way, permit, license, lease, or certifications for the use of Federal Lands. Federal agencies use this information to evaluate your proposal. No Federal agency may request or sponsor and you are not required to respond to a request for information which does not contain a currently valid OMB Control Number. BURDEN HOURS STATEMENT: The public burden for this form is estimated at 25 hours per response including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to: U.S. Department of the Interior, Bureau of Land Management (1004-0189), Bureau Information Collection Clearance Officer (WO-630) 1849 C Street, N.W., Mail Stop 401 LS, Washington, D.C. 20240. A reproducible copy of this form may be obtained from the Bureau of Land Management, Land and Realty Group, 1620 L Street, N.W., Rm. 1000 LS, Washington, D.C. 20036. (SF — 299, page 5) This article was downloaded by: [Beck, Richard] On: 23 December 2oio Access details: Access Details: [subscription number 9315468111 Publisher Taylor & Francis Informa Ltd Registered in England and Wales Registered Number: 1072954 Registered office: Mortimer House, 37- 41 Mortimer Street, London W1T 3JH, UK Polar Geography Publication details, including instructions for authors and subscription information: hftp://vr,k-w.informaworld.com/smpp/title-content=t781223423 Sikuliqiruq: ice dynamics of the Meade River - Arctic Alaska, from freezeup to breakup from time -series ground imagery Richard A. Beek'; Andrew J. Rettig'; Chantal Ivenso'; Wendy R. Eisner'; Kenneth M. Hinkel'; Benjamin M. Jones'- Christopher D. Arpd; Guido Grosse`; Douglas Whiteman' Department of Geography, University of Cincinnati, Cincinnati, OH, USA' Alaska Science Center, U.S. Geological Survey, Anchorage, AK, USA ° Geophysical Institute, University of Alaska Fairbanks, Fairbanks, AK, USA 'Water and Environmental Research Center, University of Alaska Fairbanks, Fairbanks, AK, USA' Atmospheric Radiation Measurement Program, Atgasuk, AK, USA Online publication date: 23 December 2010 To dte this Article Beck, Richard A., Rettig, Andrew J. , Ivenso, Chantal , Eisner, Wendy R. , Hinkel, Kenneth M., Jones, Benjamin M., Arp, Christopher D. , Grosse, Guido and Whiteman, Douglas(2010) 'Sikuligiruq: ice dynamics of the Meade River - Arctic Alaska, from freezeup to breakup from time -series ground imagery', Polar Geography, 33: 3, 115 — 137 To link to this Arlide: DOI: 10.1080/1088937X.2010.545753 URD http://dx.doi.org 10.1080/1088937X.2010.545753 PLEASE SCROLL DOWN FOR ARTICLE Full terms and conditions of use: http://www.informaworld.com/terms-and-conditions-of-access.pdf This article may be used for research, teaching and private study purposes. Any substantial or systematic reproduction, re -distribution, re -selling, loan or sub -licensing, systematic supply or distribution in any form to anyone is expressly forbidden. The publisher does not give any warranty express or implied or make any representation that the contents will be complete or accurate or up to date. The accuracy of any instructions, formulae and drug doses should be independently verified with primary sources. The publisher shall not be liable for any loss, actions, claims, proceedings, demand or costs or damages whatsoever or howsoever caused arising directly or indirectly in connection with or arising out of the use of this material. Polar Geography Vol. 33 Nos. 3-4 September —December 2010 115-137 ;�,o Taylor & Francis , , , Taybr&FrancisGroup Sikuliqiruq: ice dynamics of the Meade River — Arctic Alaska, from freezeup to breakup from time -series ground imagery RICHARD A. BECK a*, ANDREW J. RETTIG', CHANTAL IVENSOa, WENDY R. EISNERa, KENNETH M. HINKELa, BENJAMIN M. JONESb'', CHRISTOPHER D. ARP', GUIDO GROSSE° and DOUGLAS WHITEMAN' aDepartment of Geography, University of Cincinnati, Cincinnati, OH, USA; bAaaska Science Center, U.S. Geological Survey, Anchorage, AK, USA; 'Geophysical Institute, University of'Alaska Fairbanks, Fairbanks, AK, USA; dWater and Environmental Research Center, University of Alaska Fairbanks, Fairbanks, AK, USA; 'Atmospheric Radiation Measurement Program, Atgasuk, AK, USA 0 N Ice formation and breakup on Arctic rivers strongly influence river flow, sedimentation, river ecology, winter travel, and subsistence fishing and hunting Q by Alaskan Natives. We use time -series ground imagery of the Meade River to M " examine the process at high temporal and spatial resolution. Freezeup from " complete liquid cover to complete ice cover of the Meade River at Atqasuk, M Alaska in the fall of 2008 occurred in less than three days between 28 September and 2 October 2008. Breakup in 2009 occurred in less than two hours between 23:47 UTC on 23 May 2009 and 01:27 UTC on 24 May 2009. All times in UTC. Breakup in 2009 and 2010 was of the thermal style in contrast to the mechanical style observed in 1966 and is consistent with a warming Arctic. x U Introduction bSikuliqiruq is an Inupiaq word meaning `the process of breakup' of ice during the Arctic spring thaw (Webster et al. 1970). The most striking feature of sikuliqiruq on land is supiruq (`the rush of a river at breakup') (Webster et al. 1970). Supiruq 3 occurs during sikuibivik (`ice breakup time') or suvlubvik (`rivers flow time') (Webster et al. 1970). Both words are synonyms for the month of May. The rich Inupiaq vocabulary related to the timing and process of river breakup during the Arctic spring thaw highlights its importance to the Inupiat people. Indeed, breakup (thawing of surface ice) on Arctic rivers each spring impacts the hydrology, erosion and sedimentation, vegetation, and ecology of the fluvial Arctic landscape (Ashton 1985; Beltaos 1983, 1993, 1997, 2003, 2007; de Rham et al. 2008; Johnson and Kistner 1967; Mackay and MacKay 1965; Prowse and Culp 2003; Rodhe 1942; Smith 2000; Wendler et al. 1974; Williams 1955). The timing and process of river ice breakup influences human activities ranging from subsistence hunting (Callaway et al. 1999) to bridge design (Beltaos 2007). Beltaos (2003) divides the process of river breakup into four phases: pre -breakup, onset, drive, and wash. Pre -breakup consists of thermally induced thinning and *Corresponding author. Email: richard.beck@uc.edu Polar Geography ISSN 1088-937X print/ISSN 1939-0513 online (0 2010 Taylor & Francis littp://www.tandf.co.uk/jouriials DOT: 10.1080/ 1088937X.2010.545753 116 R.A. Beek et al. eta„ oW 1 41 Wain -Am aht 1 } 19060203 N j1 �1°'w7�Lti S E Meters (((((( 0 14,000e,000 56,000 84,000 112000 1:1'%0X0 S Figure 1. (a) Location of Meade River drainage basin (in black) in northern Alaska, USA, (b) Map of Meade River drainage (USGS Cataloging Unit (HUC) 19060203), North Slope of Alaska. The Meade River at Atqasuk drains an area of 4618 km2. The entire Meade River watershed covers an area of 10,655 km2. The thick black polygon outlines the Meade River watershed. Red circles =cities. Black square =stream gauge. The background is a MODIS true color image collected by the NASA Aqua satellite on 22 May 2009 at 00:15 UTC. The Meade River has broken up with the exception of a few places along its length and at its mouth on the Arctic Ocean (see arrows in Figure 16). weakening of the ice cover. Onset includes the initial fracturing of the ice cover. Drive is the transport of ice blocks and slabs by the current (Beltaos 2003). Wash involves the refloating and transporting of ice blocks that may have been emplaced in shallow parts of the river during previous drive phases associated with the failure of ice dams upstream. Ice blocks transported during the drive and wash phases often jam and form ice dams that slow or block the river flow, resulting in flooding upstream of the jumbled blocks of ice. These ice dams may fail and reform Ice Dynamics of the Meade River 117 1000 0.1 � ti i r• � i � � r� � r r i i Oct Nov Doc Jan Fab Mar Apr May Jun Jut Aug Sep Oct 2008 2009 Month Figure 2. Mean discharge (ems) of the Meade River from the stage gauge at Atqasuk for the period of October 2008 through September 2009. Note lack of flow in gauge pool during most of the winter months when the Meade River is completely covered by ice. repeatedly as upstream reaches are progressively cleared of ice by the river during thaw. Breakup of surface river ice usually falls between two end members, mechanical and thermal (Beltaos 2003). Mechanical breakup consists of fracturing of the winter ice cover of the river and the transport of ice blocks downstream either continuously or intermittently via the formation and destruction of a series of ice dams. Mechanical breakup is usually relatively sudden and may be due to thaw and/or runoff in the headwaters of the river that increases the river's stage. The rising waters float and fracture downstream regions of ice cover. Abundant ice blocks associated with mechanical breakup often form ice dams that flood the adjacent river banks until the dam fails and the effects cascade further down- stream (Ashton 1985). Mechanical breakup has been common on north -flowing _8 -14 1 - I I -16 1920 1030 1940 1950 1960 1970 1980 1990 2000 Year Figure 3a. Temperature (C) record for Barrow, Alaska, 1920-2008. Barrow is 100 km NNE of Atqasuk. (Alaska Climate Research Center, Geophysical Institute, University of Alaska at Fairbanks). 118 R.A. Beck et al. 30 28 26 24 22 E 20 �= 18 16 OL 14 '5 12 i • 8 B 4 2 0 1920 1930 1940 1950 1960 1970 1980 1990 2000 Year Figure 3b. Precipitation (cm) record for Barrow, Alaska, 1920-2008. Barrow is 100 km NNE of Atqasuk. (Alaska Climate Research Center, Geophysical Institute, University of Alaska at Fairbanks). rivers in the Arctic because their headwaters often experience thaw and runoff or rainfall while their more northerly downstream reaches are still ice covered. The most destructive mechanical breakups occur when rain storms in the headwaters of the river system create a flood that results in the pre -mature mechanical breakup of downstream reaches of thick and ice dam prone river ice cover (Beltaos 2003). In contrast, thermal breakup consists of gradual melting and thinning of the river ice cover due to warmer air temperatures above and/or warmer water temperatures below, dislodgement of the relatively thinner ice cover, fewer and weaker ice dams, less catastrophic ice dam failure and a generally less destructive hydrologic regime. A general warming trend throughout the Arctic for the last several decades has been cited as a reason for earlier breakup of river ice in Figure 4. Time -series ground imagery system installed on the old hotel located on the west bank of the Meade River at Atqasuk, Alaska. The system records frames at a 10 minute interval to a laptop PC. Camera location is shown in Figure 5. x U W P W N 0 0 3 A N W+E S Ice Dynamics of the Meade River 119 kt><1 Figure 5a. Detail image map of location of time -series ground camera and USGS stream gauge on the Meade River at Atqasuk, Alaska. The USGS stream gauge (white triangle) is located at Lat 70 deg., 29 min., 20 sec., long 157 deg., 24 min. 40 sec. referenced to North American Datum of 1927, in SW 1/4 SE t/4 SW 1/4 sec.7, T.13 N., R.21 W., North Slope Borough, AK, Hydrologic Unit 19060203, (Meade River B-3 quadrangle), on left bank, 1.6 km downstream of Atqasuk, 4 km upstream from mouth of Usuktuk Creek, and 96 km SSW of Barrow. Black dots in the river near the gauge show location of depth profile shown in Figure 5b. Siberia (Smith 2000) and northern Canada (de Rham et al. 2008). Smith (2000) found suggestions of a trend from mechanical to thermal breakup in Siberian rivers between 1917 and 1994. Although long-term records of river ice phenology and short-term process -based studies have been conducted for large regions in the Arctic, no such data currently exist for northern Alaska. Thus we have established a river observation station on the Meade River (Kuulugruaq) at Atqasuk, Alaska. Given the importance of sikuliqiruq to the Arctic landscape, its ecology and its people within the context of a warming Arctic, we have begun to 120 R.A. Beck et al. -0.s -os -1 -12 4.4 4.6 m -2 O 22 -2.4 -2.s -2.8 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 Fln Figure 5b. Depth profile (in meters) across the Meade River adjacent to the USGS stream gauge at location shown in Figure 5a. The horizontal axis is sonar sample site number. The left side of the graph is NW and the right side is SE. The length of the profile is 122 m. monitor sikuligiruq on the Meade River at the caribou hunting village of Atqasuk approximately 100 km from one of the longest meteorological records in the western Arctic at Barrow, Alaska. Study area and methods The Meade River begins in the outer foothills of the Brooks Range of northern Alaska and flows approximately 300 km northward to the Arctic Ocean (Figure 1). The Meade River drains approximately 10,655 square kilometers of the North Air Temperature (C), Atqasuk, Alaska 24 Sept to 05 Oct, 2008 •2.1 3R -4.9 1 -5.5 5.4 -7.2 Figure 6. Daily air temperature C at Atqasuk during late September to early October 2008 freezup (K.M. Hinkel, Atqasuk Circum-arctic Active Layer Monitoring Project). s A 4 ci 3 2 1 MI Ice Dynamics of the Meade River 121 01-Sep•08 08Sep-08 15-Sep•08 22-Sep-08 29Sep-08 Date Figure 7. Daily water temperature C of the Meade River at Atqasuk during late September to early October 2008 freezup. Water temperature actually reached 0°C on 28 September 2008 as shown by time -series ground imagery. Slope of Alaska (Johnson and Kistner 1967). The North Slope of Alaska lies entirely north of and within the Arctic Circle and is underlain by perma- frost (permanently frozen ground) several hundred meters deep. During the summers approximately 1 in or less of the surface thaws and then refreezes during the following winter. The exceptions are lakes and rivers deeper than maximum winter ice cover 1.6 m) such that a talik or thaw -bulb persists year-round. At Atqasuk, the Meade River averages 150 m in width with an average depth of —3 in except during flood events (Walker 1994). Once fully ice covered, the Meade River typically has no discernable flow (USGS 2010) (Figure 2). Global average temperature has increased by approximately 0.5°C since Johnson and Kistner studied the process of breakup at what is now the village of Atqasuk on the Meade River in June of 1966 (IPCC 2007) (Figure 1). Average spring temperatures have increased at Barrow, Alaska, 100 km to the north of Atqasuk Figure 8. Meade River at Atqasuk, 28 September 2008, 17:58:29 UTC — Ice Free. 122 R.A. Beek et al. Figure 9. Meade River at Atqasuk, 28 September 2008, 19:48:29 UTC — Ice begins to form. A by more than 2.5°C over the last 50 years (Figure 3). There are no continuous N temperature records at Atqasuk before 1999. M Johnson and Kistner (1967) studied the breakup of ice on the Meade River in the spring of 1966. They described a process more similar to what Beltaos (2003) refers to as `mechanical' breakup than `thermal' breakup between 18:20 local time on b 7 June and 11 June 1966 (07:20 UTC on 8 June and 12 June 1966). During that interval they described the repeated ice darn formation and failure at Atqasuk and a by inference based upon pulses of ice blocks up to 1.5 m thick from upriver, similar ice dam formation and failure upstream of Atqasuk. Reconnaissance by light aircraft indicated that the river was completely clear of ice near Atqasuk by 13 June 1966_ Details of their 1966 findings can he found in Johnson anti Kintner (1967)_ Figure 10. Meade River at Atqasuk, 29 September 2008, 04:06:07 UTC — Approximately 50% ice cover. Ice Dynamics of the Meade River 123 Figure 11. Meade River at Atqasuk, 29 September 2008, 04:26:06 UTC — Approximately 70% ice cover. We performed a similar study during the fall of 2008 and the spring of 2009 as described below. As part of a study of the permafrost landscape near Barrow, Alaska (Hinkel et al. 2001, 2003, 2007) we installed automated cameras to collect time -series imagery of freezeup and breakup of the Meade River at Atqasuk from late summer 2008 through the spring thaw of 2009. The cameras were mounted on the roof of an old hotel on the west bank of the river at Atqasuk (Figures 4 and 5). The time series ground imagery was compared with hydrographic data from the US Geological Survey stream gauge station (US Geological Survey, station number 15803000) located just down river, and within the field of view of the camera from the village of Atqasuk. The Meade River is incised into Cretaceous sedimentary rocks and surrounded by aeolian sediments of Quaternary Figure 12. Meade River at Atqasuk, 2 October 2008, 16:50:06 UTC — 100% ice and snow cover. 124 R.A. Beck et al. 2.5 V C a 0.0 01SepA" 15-se"s 29Sep48 134)d-08 27-Oct-08 Date Figure 13. Daily mean discharge of the Meade River (cubic meters per second) at Atqasuk during freezup. age (Beikman and Lathram 1976). A depth profile showing incision into bedrock of at least 3 m is shown in Figure 5b. This means that the Meade River does not freeze to the entire river bottom during winter. Results Freezeup b Freezeup of the Meade River at Atqasuk in the fall of 2008 was preceded by a rapid decrease in air (Figure 6) and water temperature (Figure 7). By late September 2008 a the water temperature reached 0°C. Once this threshold was reached and sustained, freezup occurred rapidly. Freezeup from complete liquid cover to complete ice cover of the Meade River at Atqasuk, Alaska in the fall of 2008 occurred in less than three days between a 28 September and 2 October 2008. At 17:58:29 UTC on 28 September 2008, the c Meade River at Atqasuk was ice free (Figure 8). Ice began to form along the west 3 O Q 600 V +QC? W .5W N 4. 400 w E 300 t3 U 200 04-May-09 11-May-09 18-May-09 2"ay-09 Date Figure 14. Estimated daily mean discharge of the Meade River in cubic meters per second at Atqasuk during breakup in 2009. Source: US Geological Survey. Ice Dynamics of the Meade River 125 Figure 15. Meade River at Atqasuk, 17 May 2009, 05:57:42 UTC — 100% ice and snow cover. bank of the river by 19:48:29 (Figure 9). By 04:06:07 on 29 September 2008, the N river was approximately 50% ice covered (Figure 10). Twenty minutes later it was M approximately 70% ice covered (Figure 11). The next frame recorded by the M system was at 16:50:06 on 2 October with the river 100% ice covered as demonstrated by the thin and continuous snow cover (Figure 12). Discharge records for the Meade River at Atqasuk indicate that this ice cover remained intact (Figure 13). x Despite missing frames between 70 and 100% ice cover, it is clear that freezeup on the Meade River in 2008 was a very rapid process. More than 70% of the river was covered with ice in less than nine hours. The river was 100% ice covered in less than bthree days. By that time the ice was thick and continuous enough to support a thin Itsnow cover (Figure 12). O 3 O q Breakup Breakup on the Meade River at Atqasuk occurred during the last two weeks of May 2009 as seen in the hydrograph for the adjacent stream gauge (Figure 14). Ice cover was still complete on the Meade River in the Atqasuk area until 17 May 2009 (Figure 15). Reaches of the Meade River to the north (downstream) and south (upstream) of Atqasuk broke up by 23 May 2009 as shown by moderate resolution satellite imagery (Figure 15). An AVNIR-2 satellite image acquired early that day showed that breakup had occurred along most of the Meade River with the exception of two remaining reaches in the river bend adjacent to Atqasuk and one just downstream of Atqasuk (2009) (Figure 16). Breakup at this location was facilitated by melting due to increasing air and river water temperatures (Figure 17) and enhanced melting along the river margins presumably due to remobilized very fine sand from a Pleistocene Arctic erg (Black 1951; Carter 1981; Eisner et al. 2005; Everett 1979; Lea and Waythomas 1990) that forms the banks of the Meade River at Atqasuk (Figure 18). 126 R.A. Beek et al. Figure 16. Meade River at Atqasuk, 23 May 2009, 00:06:52 UTC as viewed from the AVNIR-2 electro-optical imager on the ALOS satellite. The black triangle is a nominal location of a USGS stream gauge approximately 1.6 km NNE of Atgasuk Village. Arrows show a few reaches still covered with ice. Copyright JAXA (2009). Early melting along the banks accommodated fracture propagation near the center of the river. This fracturing process corresponds to the onset stage recognized by Beltaos (2003) (Figure 19). Extension along the propagating crack was accompanied by compression along the western river margin with ice block emplaced along the river margin between 23:57 on 23 May 2009 and 00:37 on 24 May 2009 (Figure 20). a X 0 0 3 O Q 25 20 U 15 9 i' 10 Ice Dynamics of the Meade River 127 -�- Water Temperature --1F- Air Temperature 23-May U&JUn 20-Jun 04-Jul 18-Jul 01-Aug ©ate Figure 17. Air and river water temperature in degrees C for the Meade River during breakup, 2009. Source: U.S. Geological Survey unpublished data, 2010. The central fracture in the river continued to widen and river ice continued to be displaced onto the river banks until 01:07 on 24 May 2009 (Figure 21). Transport of upstream ice blocks beneath and past the ice dam assisted fracture propagation as shown by blocks of ice that surface beyond the very last remnants of continuous ice cover at 01:17 (Figure 22). Failure of the ice cover on the Meade River at Atqasuk occurred between 0 1: 17 (Figure 22) and 01:27 on 24 May 2009 (Figure 23). This failure process corresponds to the drive stage recognized by Beltaos (2003). The drive stage lasted approximately 10 minutes and was largely complete by 01:37 on 24 May 2009 (Figure 24). Some large blocks of grounded ice persisted in midstream near the USGS gauging station until 03:37 on 24 May 2009 (Figure 25) during a two-hour wash phase (Beltaos 2003). Another reach of ice cover or another ice dam failed upstream of the study site and a second pulse of floating ice rafted past Atqasuk between 04:27 and 04:57 (Figures 26-29) on 24 May 2009. The only obvious candidate source was an area of ice approximately 1 km upstream of the study site as seen in Figure 16. The failure Figure 18. Meade River at Atqasuk, 23 May 2009, 20:57:34 UTC — Melting occurred first along the banks of the river. 128 R.A. Beek et al. Figure 19. Meade River at Atgasuk, 23 May 2009, 23:57:34 UTC — A fracture begins to propagate downstream (from right to left) along the center of the river. of this or a similar area of ice resulted in multiple drive and wash phases as observed in other Arctic rivers (Ashton 1985; Beltaos 2003; Johnson and Kistner 1967). Smaller drive and wash cycles occurred between 05:37 and 07:27 UTC on 24 May 2009. Only rare blocks of ice were observed floating in the river after that time. The river was mostly clear of ice at this location by 12:47 UTC on 26 May 2009 although blocks of ice emplaced during the onset phase at this location remained on the river banks until at least this time. As a whole, the drive phase of breakup is a rapid threshold processes (Ashton 1985; Beltaos 2003) that may occur at a single point on the Meade River in less than two hours due to simultaneous fracture propagation, ice shove onto the river margin and subaqueous ice block removal. Multiple ice cover and ice dam failures (Beltaos Figure 20. Meade River at Atqasuk, 24 May 2009, 00:37:34 UTC — The fracture has propagated downstream (from right to left) along the center of the river, and widened, displacing ice cover into previously ice free areas along the banks. Ice Dynamics of the Meade River 129 Figure 21. Meade River at Atqasuk, 24 May 2009, 01:07:34 UTC —The fracture continued to widen and blocks of river ice were displaced onto the banks. Q 2003) occurred during breakup resulting in multiple pulses of floating ice past the M Atqasuk observation point in 1966 (Johnson and Kistner 1967) and in 2009. N ti Discussion Breakup on the Meade River in 2009 was nearly complete before it occurred at Atqasuk (Figure 15), 14 days earlier than in 1966 (Johnson and Kistner 1967). Breakup in 2009 appears to have been characterized by blocks of ice that were thinner and less numerous, and associated with flood stages that were considerably less in 2009 than in 1966. These differences may be due to the relative timing of melting and breakup along the Meade River. Johnson and Kistner (1967) were not able to observe the length of the Meade River between 20 May 1966 and 13 June 1966. Figure 22. Meade River at Atqasuk, 24 May 2009, 01:17:34 UTC — The fracture has almost propagated completely through the ice cover of the river at Atqasuk. Pq v 0 0 0 0 A 130 R.A. Beck et al. Figure 23. Meade River at Atqasuk, 24 May 2009, 01:27:34 UTC — The fracture has propagated completely through the ice cover of the river at Atqasuk and the river is in full `drive' phase. Nonetheless, the style of breakup observed at Atqasuk on the Meade River in 2009 appears to be much closer to the thermal style of breakup (Beltaos 2003) than it was in 1966 (Johnson and Kistner 1967). Once the continuous ice cover at Atqasuk was broken in 2009, no significant jams that lasted more than 10 minutes (the interval of our cameras) were formed. In contrast, Johnson and Kistner (1967) noted major ice jams that occurred at Atqasuk after the continuous ice cover of the Meade River had been breached. These major ice jams were associated with major increases in the stage of the river upstream of the jam. Further, several studies in northern Canada have shown a decreasing trend in ice jamming events and associated flooding over the last half -century (Beltaos et al. 2006; Goulding et al. 2009). Figure 24. Meade River at Atqasuk, 24 May 2009, 01:37:34 UTC — The drive phase is nearly complete. Ice Dynamics of the Meade River 131 Figure 25. Meade River at Atqasuk, 24 May 2009, 03:37:34 UTC — The wash phase associated with the drive at this location was nearly complete. Beltaos and Prowse (2009), Bieniek et al. (2010), Hinzman et al. (2005), and Magnuson et al. (2000) among others have discussed the changes in the style and date of river ice breakup to be expected with a warming Arctic. Bieniek et al. (2010) found a general trend of 1.3 days per decade toward earlier river ice breakup in Interior Alaska that is in general agreement with the findings of White et al. (2007) who found a 5.5 day/century trend toward earlier breakup for the Tanana River at Nenana, in interior Alaska. With only two data points (1967 and 2009) one cannot make any conclusions regarding trends in the style of breakup on the Meade River at Atqasuk. Breakup on the Meade River at Atqasuk occurred on 8 June 2010 (Whiteman, personal Figure 26. Meade River at Atqasuk, 24 May 2009, 04:27:34 UTC — A second drive phase begins due to the failure of ice cover or an ice dam upstream. 132 R.A. Beek et al. Figure 27. Meade River at Atqasuk, 24 May 2009, 04:37:34 UTC — A second drive phase near its peak. observations), one day later than in 1966 and 15 days later than in 2009. However, as in 2009, breakup in 2010 was preceded by melting that began along the margins in response to decreased albedo due to river bank dust and/or ponding of tundra snow -melt water (Figure 30). As in 2009, breakup at Atqasuk in 2010 was also preceded by extensive melting of the river ice cover before final failure on 8 June 2010 (Figure 31). In 2010, as in 2009, final drive was associated with the closure of moats along the river banks, emplacement of blocks of river ice onto the banks and the propagation of fractures down the center of the river (.Figure 32). Despite the later date for breakup at Atqasuk in 2010, the style of breakup is again more similar to the thermal style of Beltaos (2003) than the mechanical style observed by Johnson and Kistner in 1966. Reliable determination of trends in the style of breakup of the Meade River at Atqasuk will require continued monitoring in the future complimented by the collection of oral histories from the Figure 28. Meade River at Atqasuk, 24 May 2009, 04:47:34 UTC — A second drive phase begins to wane. Ice Dynamics of the Meade River 133 Figure 29. Meade River at Atqasuk, 24 May 2009, 04:57:34 UTC — A second drive phase is nearly complete. Alaskan Natives of Atqasuk (e.g. Eisner et al. 2005, 2009). If real, this apparent shift in style of river ice breakup would be consistent with the predictions of Beltaos (2003), Beltaos and Burrell (2003), and Beltaos and Prowse (2009) for a shift from mechanical to thermal river ice breakup in a warming Arctic and would impact river flow, sedimentation, river ecology, and subsistence fishing and hunting by Alaskan Natives. Conclusion v Freezeup (from complete liquid cover to complete ice cover) on the Meade River at Atqasuk can occur in less than three days and perhaps in as little as one day. The drive phase of breakup (the transition from continuous ice cover to almost no ice cover across the river) is a rapid threshold process that can occur in less 0 0 A Figure 30. Meade River at Atqasuk, 2 June 2010, approximately 18:00 UTC. Source: Image captured by D. Whiteman. 134 R.A. Beck et al. Figure 31. Meade River at Atqasuk, 8 June 2010. Source: Image captured by D. Whiteman. than two hours due to simultaneous fracture propagation, ice shove onto the river margin and subaqueous ice block removal. Multiple ice dam failures occur during breakup resulting in multiple pulses of floating ice past the observation point. The style of breakup observed at Atqasuk on the Meade River in 2009 and 2010 appears to be much closer to the thermal style of breakup (Beltaos 2003) than it was in 1966 (Johnson and Kistner 1967). This apparent shift may be symptomatic of a warming Arctic. If real and sustained, such a shift will obviously change the hydrology of the Meade River and therefore its pattern of erosion and sedimenta- tion. Johnson and Kistner (1967) noted that the (mechanical) breakup style they observed strongly influences river ecology via scouring of riparian vegetation, especially willows. Later freezing and earlier thermal breakup will require a shift from winter to summer modes of transportation. Winter travel in this area is usually faster, less ti .L %JUN 9�",, • i Figure 32. Meade River at Atqasuk, 9 June 2010. Source: Image captured by D. Whiteman. Ice Dynamics of the Meade River 135 expensive, and less constrained especially in east —west directions than summer travel with the possible exception of north -south travel on the river itself. Therefore, it is likely that subsistence activities by Alaskan Natives will become more focused along river corridors for a greater part of the year. Thermal breakup may also decrease spring ice thicknesses and increase danger to snow machine travel before final failure of river ice cover. Continued monitoring of the Meade River at Atqasuk is necessary before any trends in the style of breakup and its possible consequences at this location can be established. Acknowledgements This work was supported by grants from the National Science Foundation under grants ARC-0640371 to RAB, OPP-9911122 and 0240174 to WRE, and OPP-9732051 and 0094769 and ARC-0713813 to KMH. Any opinions, findings, conclusions, or recommendations expressed in this material are those of the authors and do not necessarily represent the views of the National Science Foundation. We are grateful for the logistical support of the Atqasuk Village Corporation, Barrow Arctic Science Consortium (BASC), the Ukpeagvik Inupiat Corporation (UIC), and anonymous reviewers whose comments improved this manuscript significantly. References " ASHTON, G.D., 1985, River ice. Annual Reviews of Fluid Mechanics, 10, pp. 369-392. M BEIKMAN, H.M. and LATHRAM, E.H., comps., 1976, "Preliminary geologic snap of northern c Alaska" U.S. Geological Survey Miscellaneous Field Studies, p. 789, 2 sheets, scale b 1:1,000,000. BELTAOS, S., 1983, River ice jams: theory, case studies and applications. 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HINKEL, K.M., EISNER, W.R., BOCKHEIM, J.G., NELSON, F.E., PETERSON, K.M. and 0 XIAOYAN, DAi, 2003, Spatial extent, age, and carbon stocks in drained thaw lake basins on the Barrow Peninsula, Alaska. Arctic, Antarctic, and Alpine Research, 35(3), pp. 291-300. HINKEL, K.M., JONES, B.M., EISNER, W.R., Cuomo, C.J., BECK, R.A. and FROHN, R., a 2007, Methods to assess natural and anthropogenic thaw lake drainage on the western Arctic Coastal Plain of northern Alaska. Journal of Geophysical Research -Earth Surface, 112, F02S 16, doi:10.1029/2006JF000584 HINKEL, K.M., PAETZOLD, R.F., NELSON, F.E. and BOCKHEIM, J.G., 2001, Patterns of soil temperature and moisture in the active layer and upper permafrost at Barrow, Alaska: b 1993-1999. Global and Planetary Change, 29, pp. 293-309. HINZMAN, L.D., BETTEZ, N.D., BOLTON, W.R., CHAPIN, F.S., DYURGEROV, M.B., FASTIE, a C.L., GRIFFITH, B., HOLLISTER, R.D., HOPE, A., HUNTINGTON, H.P., JENSEN, A.M., JIA, G.J., JORGENSON, T., KANE, D.L., KLEIN, D.R., KOFINAS, G., LYNCH, A.H., w w LLOYD, A.H., MCGUIRE, A.D., NELSON, F.E., DECHEL, W.C., OSTERKAMP, T.E., w RACINE, C.H., ROMANOVSKY, V.E., STONE, R.S., STOW, D.A., STURM, M., VOURLiTiS, G.L., WALKER, M.D., WALKER, D.A., WEBBER, P.J., WELKER, J.M., o WINKER, K.S. and YOSHIKAWA, K., 2005, Evidence and implications of recent climate 3 change in northern Alaska and other Arctic regions. Climate Change, 72, pp. 251-298. $ IPCC, 2007, Contribution of Working Group I to the Fourth Assessment Report of the Intergovernmental Panel on Climate Change, 2007: The Physical Science Basis. S. Solomon, D. Qin, M. Manning, Z. Chen, M. Marquis, K.B. Averyt, M. Tignor and H.L. Miller (Eds.). Available online at: http://iwww.ipec.ch (accessed 21 November 2010). JOHNSON, P.L. and KiSTNER, F.B., 1967, Breakup of ice, Meade River, Alaska. United States Army. Cold Regions Research and Engineering Laboratory Special Report, 118, pp. 1-12. LEA, P.D. and WAYTHOMAS, C.F., 1990, Late-pleistocene eolian sand sheets in Alaska. Quaternary Research, 34(3), pp. 269-281. MACKAY, D.K. and MACKAY, J.R., 1965, Historical records of freezeup and breakup on the Churchill and Hayes Rivers. Geographical Bulletin, 7, pp. 7-16. MAGNUSON, J., ROBERTSON, D., BENSON, B., WYNNE, R., LIYINGSTONE, D., ARAI, T., ASSEL, R., BARRY, R., CARD, V., KUUSISTO, E., GRANIN, N.. PROWSE, T., STEWARD, K., and VUGLINSKI, V., 2000, Historical trends in lake and river ice cover in the northern hemisphere. Science, 289, pp. 1743-1746. PROWSE, T.D. and CULP, J.M., 2003, Ice breakup: a neglected factor in river ecology. Canadian Journal of Civil Engineering, 30, pp. 145-155. Ice Dynamics of the Meade River 137 RODHE, B., 1942, On the relations between air temperature and ice formation in the Baltic. Geografiska Annaler, 34, pp. 175-202. SMITH, L.C., 2000, Trends in Russian Arctic River -ice formation and breakup, 1917 to 1994. Physical Geography, 21(1), pp. 45-56. U.S. GEOLOGICAL SURVEY, 2010. National Water Information System (NWIS). Available online at: http://Iwaterdata.usgs.gov/nwis/ (accessed 21 November 2010). WALKER, H.J., 1994, Environmental impact of river dredging in Arctic Alaska (1981-1989). Arctic, 47(2), pp. 176-183. WEBSTER, D.H., ZIBELL, W., and WEBSTER, T., 1970, Inupiat Eskimo Dictionary (Fairbanks, AK: Summer Institute of Linguistics). WENDLER, G., CARLSON, R.F., and KANE, D.L., 1974, Break-up characteristics of the Chena River watershed, central Alaska. In Advanced Concepts and Techniques in the Study of Snow and Ice Resources, H. Santeford and J. Smith (Eds.), pp. 523-531 (Monterey, CA: National Academy of Sciences). WHITE, K.D., TUTHILL, A.M., VUYOVICH, C.M., and WEYRICK, P., 2007, Observed climate variability impacts and river ice in the United States. In Proceedings of the CGU HS Committee on River Ice Processes and the Environment, 14th Workshop on the Hydraulics of Ice Covered Rivers, K. Dow, F. Hicks and P. Steffler (Eds.), Quebec N City, Quebec, Canada, June 20-22. WILLIAMS, J.R., 1955, Observations of freezeup and breakup of the Yukon River at Beaver, Alaska. Journal of Glaciology, 2, pp. 488-495. a M N M M rl m i Special Report m by Philip L. Johnson and Frank B. K stoer O CTOBER 1967 UAL AWAY MATUM, COWMN ► COLD REGION$ RESEARCH & ENGINEERING LABORATORY HANOVD, lief 14AIM OSHM This document has been approved for public release and safe, its distribution is unlimited, ReportSpecial BREAKUP r#x x D RIVER, • x x x by Philip L. Johnson and Frank S. Kistner OCTOBER 19+6T U.S. ARMY MATWIL COW" COLD REGIONS RESEARCH & ENGINEERING LABORATORY NAN0V e, N1W HAMP$HW DA Task IV025001AT3002 This document has been approved for public release and sale; its distribution is unlimited. ii PREFACE This report was prepared by Dr. 11, L. Johnson, ecologist, and F. B. Kistner, geologist, Photographic Interpretation Research Division, under the general supervision of R.E. Frost, Chief, as part of Project Z4.4, Arctic and Subarctic Vegetation Studies. An arctic camp, light plane flights, and substantial logistical support were provided by the Arctic Re- search Laboratory, Barrow, Alaska (Max Brewer, Director). Grateful appreciation is expressed for this support and to the office of Naval Re- search. USA CRREL is an Army Materiel Command laboratory. iii CONTENTS Page Preface----------------------------- ..,.__.._-_ _-_ ______-_ ii Introduction-_M.,..,,..,,.----___....-,--------. _--------. -- 1 Conditions of breakup period ----------------------------- Z Chronologyof breakup --W__,...__..-----_----__----_- ------------------------------------ 4 fl Literature cited ------ .----,...----�»,.-.,....--- ..,.. ----- - lZ ILLUSTR.A.TIONS Figure 1. Location of the Meade River ----------------------- 1 2-21. progression of ice breakup on Meade R.ivc. r, 1 - 14 June -1 -9 Zz. Meade River Camp, V June 1966. with residual ice blocks in the willow zone of the river bar -------- 1 43. Aerial photographs of the Meade River on 6 July 1945 and June 1948 showing ic.- blocks stranded on river TABLES Table I. Climatic parameters during river breakup ----------- 3 11. Evaporation rates for midday hours ----------------- 3 BREAKUP OF ICE, MEADE RIVER, ALASKA by Philip L. Johnson and Frank B. Kistner INTRODUCTION Observations of spring breakup and fall freeze -over of river and lake ice in Alaska and Canada are important to the hydrology, ecology, and economy of the local area. Historical records of ice thickness and dates of ice forma- tion and disintegration are indicators of climatic variation (MacKay and Mac- Kay, 1965). The relationships between air temperatures and freeze -over and breakup were developed by Rodhe (194Z), Bilello (1964) and MacKay and Mac- Kay (1965). The latter authors suggest that mean semi-monthly temperatures for 16-31 October and 16-31 May can be established from historical ice ob- servations for periods prior to climatic observations. A unique opportunity to observe and photograph the process of ice breakup on the Meade River occurred in June 1966. A semi -permanent camp was established on a bluff 10 meters above mean river level for ecological re- search throughout the summer and climatological instruments were maintained from the beginning of snow melt in late May until early September. The Meade River originates in the northern foothills of the Arctic Coastal Plain north of Lookout Ridge. Seven miles north of camp the river bends sharply eastward and continues to the Beaufort Sea via lease Inlet (Fig. 1). #A*~ 0 C CAN I r moov� 00 1_00 Lr 7, WARSO Figure 1. Location of the Meade River on the Arctic Slope in northern Alaska. The large arrow indicates the camera orientation for the breakup sequence. 2 BREAKUP OF ICE, MEADE RIVER. ALASKA The Meade River Basin is approximately 300 km in length; the channel is 30m wide at camp and maximum depth is about 5 m. The river drains about 10. 000 square kilometers. As a result, spring melt waters initiate breakup at the more southerly head of the basin while the lower reaches of the river are still frozen. This report describes and documents observations and some environmental conditions during the breakup period. The ecological effects of ice floes and floods on strearnside vegetation were shown for temperate latitudes by Hack and Goodlett (1960), Lindsey El aI. (1961) and Sigafoos (1964) among others. Bliss and Canaan (1957) describe plant succession along arctic slope rivers, but do not discuss breakup. An excellent description of ice formation and degradation was provided by Wit- liams (1955) for the Yukon River at Beaver, Alaska. Walker and Aalborg (1963) discuss the effect of river ice on riverbank erosion along the Colville River. CONDITIONS OF BREAKUP PERIOD Camp was established at Meade River Coal Mine (70* Z8' N. 156's Z31 W) on ZO May. A complete snow surface covered the tundra, river and take ice, and sunshine and wind had produced a hard sastrugi crust. Very little melting and comparatively little compaction were evident. The river ice was used as a landing strip by a ski plane from 20 May to I June, after which date the snow on the river ice had become too slushy for safe landings. A snow survey on 23 May indicated a 100% tundra snow cover with a mean depth of 30 cm along a sampling transect of 600 m (140 points). By Z2 May, numerous tundra high spots, less than a meter in diameter, began to appear. The prevailing clear skies and high radiation resulted in a noticeable softening of the snowpack. The climatic conditions during the period of breakup are summarized in Table 1. Incoming shortwave radiation was recorded on two solarimeters from May throughout the summer; only net radiation values from a pair of C. S.I. R. 0. pyrheliorne te rs are included in Table I. It is evident that air temperature and thaw depth values increase as the growing season is initiated during the first week of June. During the winter and spring deep snowdrifts had accumulated on both sides of the Meade River as a result of prevailing easterly winds and westerly storm winds that dominate the coastal plain climate (Conover, 19601. A repre- sentative vertical profile through these snowbanks was charted for density and stratigraphy on both sides of the river by Dr. Carl S. Benson, Geophysical Institute, University of Alaska, on 30 May and I June. The drift on the west bank exceeded 460 cm vertical depth and the drift on the east bank, 4. 5 km upstream, exceeded 700 cm vertical depth. Rapid snow melting and runoff were evident after 25 May. Strong winds alternated with periods of calm, but skies were generally clear until 6 June, the first day of liquid precipitation. Snow flurries were observed on Z8 May. By Z9 May, the river bluff was 1016 snow -free and by I June upland tundra was 60% exposed. Snow on the river showed ponding of malt water at the snow/ ice interface by I June. This condition progressed with increasing amounts of saturated snow on the river ice (Fig. Z-7) until breakup occurred on 7 June. No increase in river height or bulging of center ice was observed before break- up. On 13 June only 10% of the tundra contained snow, primarily in snow - filled depressions and accumulation areas along the river cut banks (Fig. Z3). Net radiation was high in early June prior to breakup and air temperatures in- creased, especially after the tundra was largely snow -free and the river was clear of ice. BREAKUP OF ICE, MEADE RIVER, ALASKA 3 Table 1. Climatic parameters during river breakup. M e an Degree Net Snow Thaw Date air temp firs radiation Precip Wind depth depth (0 C) I L> OC) Q Ida - (mrn) - - - -(m2h) (cm) - (c m) Z 3 May 30 0 z 5 -4.8 0 ? 6 _5.2 0 6.8 27 -5. U 0 0 4.9 za -0.8 0 T 6.3 29 -1.5 2 0 4.5 30 -0.9 )z 0 3.0 31 -0, 1 Z3 0 3, Z I June -1.4 0 0 4.5 2.1 85 0 5.7 3 Z 4 4 484.5 0 Z. 5 4 1.5 67 538.4 0 3.6 Z4 6 5 Z. 3 63 581.5 it 1.4 6 0.9 70 Z76. 1 0.3 1.8 7 0.4 17 Z88.8 0 9.5 8 -1.2 26 430.5 Z's 10.5 9 1.0 58 445.3 0 6.7 10 1.4 100 348. 1 0 6. 1 11 3.4 11Z 308.6 5.1 3.3 17 7 la 4.5 119 446. Z 0 3.8 13 7.9 Z40 567.6 0 4.6 14 11.0 301 577.9 0 3.0 18 0 Considerable evaporation was observed from shallow melt water pools and tundra troughs during the period of rapid snow melt as well as throughout the growing period; this was substantiated by evaporation measurements. A shal- low pan ZI cm in diameter, tinned and highlypolished, was placed on the ground 3 m from the river bluff and filled with 500 cm3 of water. This evaporation pan was weighed to the nearest 0.1 gram periodically. A decrease in weight was equated with evaporation from a free water surface and expressed in mg cm-4 hr-1 and in mm (Table 11). Midday values obtained during the breakup period Table 11. Evaporation rates for midday hours, mg water cm-z hr-1 Date ME mm Date mg mm 5 June 20 Zo 11 June 23 Z3 6 June to .10 1 Z June 31 .31 7 June 9 . 09 13 June 44 .44 10 June 27 .27 14 June 47 .47 represent 3- to 4-hour periods during maximum radiation flux, The maximum evaporation value measured during the summer was 6Z mg cm-z hr-1 (6.Z mm) from 1?,45 to 194S on 16 June. 4 BREAKUP OF ICE, MEADE RIVER, ALASKA Figure 2. 1 June 2.100. Figure 4. 3 June 1030. Figure 3. ?. June 1700. V Figure 5. 4 June 1415. CHRONOLOGY OF BREAKUP The first indication of breakup was the sighting of an ice floe progressing down river at 1820 on 7 June. A flow of brownish river water about 40 cm in height was progressing over the top of the river ice, picking up snow as it went. This "slush wave" moved forward at the pace of a fast walk, perhaps 8 km/hr. In plan this wave front varied in shape. At the stream meander it advanced most rapidly along the side of the river channel overlying shallow bars where water was ponded on shore -fast ice (Fig. 4-7). However, the BREAKUP OF ICE, ME,ADE RIVER, .ALA KA Figure b. 4 June 1815. Figure 7. 5 .tune 1830. wave front assumed a „U" or horseshoe shape on straight reaches of the river with the medial or mid -channel portion 10-15 m in front of the lateral portion at a point directly in front of camp. A floe of jumbled ice blacks choked the channel behind the slush wage. This ice floe at times overflowed the unbroken. river ice or simply created ice blocks as it advanced. The advancing ice ;Flee with its slurry of water and ice blocks jammed quite suddenly when it reached a narrowing of the channel 0. 5 km below camp. The river, now completely choked with jumbled ice blacks, rase rapidly, about 2 m in 1.5 hours. (This rise can be followed in Figures 8-10.) It inundated the coal mine entrance which had been excavated downward through the snow- drift on the west bank to reach a, coal seam. On the east bark, the water level stabilized momentarily, just above the first willows occupying the levee. By 2030 hours on the 7th this ice jam was only 1 km long (Fig. 10). The river was clear of ice at least a short distance upstream with only occasional floating ice blocks joining the jam. Many of these ice blacks were larger than the original floe and they were rimmed with snow collected as they had dragged against the snow-covered river banks. As the drifting blocks of ice accumulated, time ice jam compacted, over- riding, elevating, and rafting other blocks. Some of these rafted ice blocks were up to 1. 5 m in thickness (Fig. 1 1- 14). An ice glaze farmed from freezing rain the night of the 7th. The river was apparently clear of ice for some distance on the 8th both above and below the dam. The river flowed through and around the ice jam and through the willows on the river bar. This condition continued through the 9th with only minor shifts in the ice pack. On the afternoon of the l tlth avery high river level, allowed the ice jam to slip downstream several hundred meters* large ice blacks were floated further into the willows on the east bank. Evidently a BREAKUP OF ICE, MEADE RIVER, ALASKA Figure 8. 7 June 1825. "44 Figure 9. 7 June 1830. 0 x Figure 10. 7 June 2030. BREAKUP OF ICE, MEADS RIVER, ALASKA Figure 11. 8 June 1605. NE-M-.3 Figure IZ, 8 June 1945. bi Figure 13. 8 June 2300. Figure 14. 9 June 1810. similar ice jam had broken upstream, and the rising water briefly freed and cleared the river in front of camp only to have it jam again (Fig. 15-17). This time considerable ice arrived from upstream and the river was choked with ice blocks for several kilometers upstream. The river continued to rise dur- ing the I Ith. Ponded water from snow runoff was extensive on the tundra augmented by light rain. On the night of the I I th the entire ice floe broke and continued down river. The jam was released when the rising river level alluwe-i lateral expansion of the floe onto the adjacent willow bar of the east bank of the river. 8 BREAKUP OF ICE, ME:ADE RIVER, ALA.SKA Figure 15. 10 June 1545. Figure 16. 10 June 1548.. Figure 17. 10 June 1745. After the darn released, the river bevel dropped briefly on iljcx I I th and again on. the 13th leaving both banks lined with vertical cliffs of ice blacks 3-4 m high (Fig. IS-zl). An overflight by light aircraft on 13 June confirmed that ,no ice persisted in the Meade, although there was extensive flooding near the mouth of the river. Flooding was also very extensive on the lower Colville River at this time (Walker, 1966), BREAKUP OF ICE, MEADE RIVER, ALASKA q Fissure 18. 11 June 1000. Figure 19. 12 June 180J. Figure ZO. 13 June 18) L Figure 21. 14 June 1800. The ice blocks that floated into the willow zone on the river bar persisted for several weeks (Fig. 22) and growth of Salix alaxensis and Salix richardsonii beneath them was delayed until late July. Even 1ar('rew1llow9.,' c -m--'Z—ia ter and 2 m tall, were sheared from the top and sides of the levee in the vicinity of the ice jam. These willows were estimated from ring counts to be 31 years old. Some of these shrubs had scarred stems indicating recovery from ice damage in 1948. It is evident that the retarded willows were at first covered by ice and that development of the soil thawed zone was greatly delayed. These 10 BREAKUP OF ICE, TMEADE RIVER, ALASKA Figure ZZ. Meade River Camp, Z7 June 1966, with residual ice blocks in the %,�illow zone of the' river bar. willows must have completed all the phenological processes more rapidly than the rest of the stand during the shortened growing season. It is estimated that the effective growing season was 50 days instead of an average of 75 days. The effective thaw season was approximately 86 days. Although river breakup was not discussed by Bliss and Cantlon (1957), it is apparent that these catas- trophic events tend to perpetuate the willow stage of plant succession on river bars in environmentally controlled allogenic stages as opposed to autogenic phases later in the sere. SUMMARY Following substantial solar radiation in late May and the first week in June, breakup of Meade River ice occurred suddenly and rapidly, forming an ice darn that persisted for 4 days. Observations of this ice jam and the at- tendant rapid changes in water level make it obvious that breakup occurred in a sequence; melt local . ice -rising _ dam flood and water � breakup _"'dam water release ice breakup that progresses repetitiously downstream. Airphotos taken after breakup in 1945, 1948, and 1966 suggest that these ice darns probably form frequently at the same channel constrictions, as evidenced by the ice blocks rafted and Boated into the willow zone (Fig. 23). Considerable sediment was deposited on and among the willows by ice rafting. The undisturbed appearance on the aerial photos of the polygonal tundra adjacent to the river strongly suggests that spring flooding has been confined to the immediate river meander sys- tem for a long time. Further, it is inferred that the willows growing on the levee and sand bar must be adapted to periodic flooding and to rapid growth after scouring and suppression by ice. The amount of channel or cutbank erosion i-a difficult to evaluate, although it would be greatest where the ice BREAKUP OF ICE, MEADE RIVER, ALASKA lI Figure Z3. Aerial photographs of the Meade River on b July 194 (,left and in late June 1948 (right) showing ice blocks stranded on both river banks. The camera station and direction for Figures 2-Zl is indicated by the open arrows. darns form. The river level fluctuates throughout the season as a function of storm frequency, although the seasonal trend is clearly to lower and lower flaws. Bank erosion is therefore most active during snow melt -off and batik slumping following thaw. This pattern of river breakup is similar to many described from the Arctic Basin in Canada (MacKay, 1966), although some streams apparently break up without observable ice jams. I Z BREAKUP OF ICE, MEADE RIVER, ALASKA LITERATURE CITED Bilello, M.A. (1964) Methods for_ELedicting river and lake ice formation, Journal of Applied Meteorology, vol. 3, p. 38-44. -_ Bliss, L.C. and Cantlon, S.E. (1957) Succession on river alluvium in northern ' Alaska, American Midland Naturalist, vol. 58, p. 45Z-469. Conover, J.M. (1960) Macro- and micronieteorology of the Arctic Slope of Alaska, Quartermaster Research and Engineering Center, Natick, tvlassa- chusetts, Technical Report E P- 139, 65 p. Hack, J. T. and Goodlett, J. C. (1960) Geornor2hology and forest ecoloEy of the mountain region of central Appalachians, U.S. Geological Survey, Pro- fessional Paper 347, 66 p. Lindsey, A. A.; Petty. R. 0.; Sterling, D. If. and VatiAsdall, W. (1961) Y2feta- tion and environment along the Wabash and Tippecanoe Rivers, Ecological Monographs, vol. 31. _p 1-0-57-TO-6— MacKay, D. K. (1966) MacKenzie River and delta ice survey, 1965, Geograph- ical Bulletin, vol. 8, p. Z70-178. and MacKay, J. R. (1965) Historical -records of f reeze-up and I;reak-up on the Churchill and Ilayt!s Rivers, Geograp�.ical Bulletin, vol. 7, p. 7-16. Rodhe, B, (1942) On the relation between air te_Merature and ice formation in the Baltic, Geografiska Annaler, vol. 34, p. 175-ZOZ. Sigafoos , R.S. (1964) Botanical evidence of floods and flood -plain deposition, U.S. Geological Survey, Professional Paper 485-A, 35 p. Walker, H. J. (1966) Riverbank erosion, An Arctic _.!��m le, Abstract, Geological Society of America Program. and Arnborg (1963) Permafrost and ice -wedge effect on river- bank' erasion, Proceedings International Permafrost Conference, PuU-l%7'ca- tion IZ87, National Academy of Sciences, p. 164-171. Williams, J. R. (1955) Observations of freeze-up and break-up of the Yukon River at Beaver, Alaska, Journal of Glaciology, vol. Z, p. 488-495. Unclassified i; M *; Q. �catr aro�eCrs 1.INK A LINK * LINK e w r River ice --Breakup River ice- -Formation- -Alaska River ice- -Format on -Meteorological effect Ice breakup _-Photographic analysis Unclassified Sr rite CiassmeaROO Unclassified 5ecu:i.ly ClAasificnlxan QfCiltAEN'T CONTROL, DATA , R & (Ucurity atas.sltkwian al fibs. body at abstrsrt rnd in4t#X1A$ MnA*14100 i XW#f bO 011WArd Wh*n tht awsr411 ri► t to 000a01ti4 ... _ i. ORI(atMATIMG ACTIVITY (Car,Tarttto •Itthar) go. REPORT SECURITY CLAXOt FICATIOtN U.S. Army Cold Regions Research and Unclassified ab. afta,P Engineering Laboratory, Hanover, N.H. S. Itilw4 IT T/TI.E BREAKUP OF ICE, MEADS RIVER, AL,,AISKA 4. **SCRIPTIVE NOTWS (TSrpo at ropWt and tnTotusiws dots#) _. . S ecial Re ort 1. AUTMORt51 (First tww". lnEdA7* Initist, tilt nasis) Philip L. Johnson and .Frank B. Kistner d. REPORT DATE Ts, TOTAL. NO. OF PACES T& tNO, OF news October 1967 la l2 AM. CO;Y ;ACT Oil GRANT 110. Mii. CRIGINATORS REPORT NUM"BE14I41 ,. PROJ/LCT ftot Special Report 1.18 -DA Task 1 V025001 A 13 0-OZ D#, hT. -R REPORT MOM (An,•r other numbers 9W mwy b* mratlnsd M WSTRIDUTtON STATEMENT This document has been approved for public release and sale„ its distribution is unlimited. it. 4wovLEwe"TX14tX NOTES - 01. SPONSORING MILITARY ACTIVITY U.S. .Army Cold Regions Research and Engineering Laboratory, Hanover, N.H. is. A4lTRACT- The climatic conditions and chronology of ice breakup on the Meade River, Alaska, in 1966 are reported and documented phototiraiphically. These observations and the interpretation of aerial phonography suggest that ace damming, flooding, andd dam release are the typical patterns of breakup that progress repetitiously downstream. The implications of ice breakup on plant succession on river bars and on channel erosion are discussed. UUIYlit'R ^z #F#.$0#y ii �►� VRr tARM i♦€7. • .t AR{ i*i, RMt6Rt I• t Nov4M l/ a��rtL.is .al» �►t�,tl,t I��I�. Unclassified cur ty 106601COTO—ft Search Results https://rsgisias. crrel. usace.army.mil/apex/f?p=273:12:1155532076732401:... Index Number: 20130708140033 Location: Atkasuk, AK River: Meade River Jam Date: 05/27/2012 Water year: 2012 Jam Type: Current Condition: Damages: CRREL Contact: M. Carr Local Contact: Visuals: Reports: Latitude: 700 29' 20" N Longitude: 1570 24' 40" W Gage Number: 15803000 Hydrologic Unit Code: 19060203 Publication: Print USGS Water Resources Data for Alaska WY 2012 reported an annual maximum peak stage of 30.88ft Description: on 27-MAY-2012 due to backwater from ice at USGS gaging station 15803000 Atkasuk, AK. The average daily discharge was estimated at 2,000cfs. Index Number: 20120808143925 Location: Atkasuk, AK River: Meade River Jam Date: 05/29/2011 Water year: 2011 Jam Type: Break-up Current Condition: released Damages: CRREL Contact: M. Carr Local Contact: Visuals: Reports: Latitude: 700 29' 20" N Longitude: 1570 24' 40" W Gage Number: 15803000 Hydrologic Unit Code: 19060203 Publication: USGS Water Resources Data for Alaska WY 2011 reported an annual maximum peak stage of 33.80ft Description: on 29-MAY-2011 due to backwater from ice at USGS gaging station 15803000 Atkasuk, AK. The gage height was not reported. Index Number: 20110725101611 Location: Atkasuk, AK River: Meade River 1 of 3 11 /19/2013 2:45 PM Search Results https://rsgisias. crrel.usace.army.mil/apex/f?p=273:12:1155532076732401: Jam Date: Water year: Jam Type: Current Condition: Damages: CRREL Contact: Local Contact: Visuals: Reports: Latitude: Longitude: Gage Number: Hydrologic Unit Code: Publication: Description: Index Number: Location: River: Jam Date: Water year: Jam Type: Current Condition: Damages: CRREL Contact: Local Contact: Visuals: Reports: Latitude: Longitude: Gage Number: Hydrologic Unit Code: Publication: Description: Index Number: Location: River: Jam Date: Water year: Jam Type: Current Condition: Damages: CRREL Contact: Local Contact: Visuals: Reports: 06/09/2010 2010 Unknown M. Carr 700 29' 20" N 1570 24' 40" W 15803000 19060203 USGS Water Resources Data for Alaska WY 2010 USGS Water Resources Data for Alaska WY 2010 reported an annual maximum peak stage of 31.20ft on 9-JUN-2010 due to backwater from ice at USGS gaging station 15803000 Atkasuk, AK. The average daily discharge was 20000cfs. 20110725101138 Atkasuk, AK Meade River 05/23/2009 2009 Unknown M. Carr 700 29' 20" N 1570 24' 40" W 15803000 19060203 USGS Water Resources Data for Alaska WY 2009 USGS Water Resources Data for Alaska WY 2009 reported an annual maximum peak stage of 30.91ft on 23-MAY-2009 due to backwater from ice at USGS gaging station 15803000 Atkasuk, AK. The average daily discharge was 13000cfs. 20090803124416 Atkasuk, AK Meade River 05/29/2008 2008 Unknown unknown K. White Latitude: 700 29' 20" N Longitude: 1570 24' 40" W 2 of 3 11/19/2013 2:45 PM Search Results https://rsgisias. crrel. usace.army. mil/apex/f?p=273:12:1155532076732401: Gage Number: 15803000 Hydrologic Unit Code: 19060203 Publication: USGS Water Resources Data for Alaska WY 2008 USGS Water Resources Data for Alaska WY 2008 reported an annual maximum peak stage of Description: 32.80cfs on 29-MAY-2008 due to backwater from ice at USGS gaging station 15803000 Meade River at Atkasuk, AK. The average daily discharge was 15,000cfs. Index Number: 20090625140119 Location: Atkasuk, AK River: Meade River Jam Date: 06/05/2007 Water year: 2007 Jam Type: Unknown Current Condition: unknown Damages: CRREL Contact: K. White Local Contact: Visuals: Reports: Latitude: 700 29' 20" N Longitude: 1570 24' 40" W Gage Number: 15803000 Hydrologic Unit Code: 19060203 Publication: USGS Water Resources Data for Alaska WY 2007 USGS Water Resources Data for Alaska WY 2007 reported an annual maximum peak stage of Description: 33.49cfs on 05-JUN-2007 due to backwater from ice at USGS gaging station 15803000 Meade River at Atkasuk, AK. The average daily discharge was 39,000cfs. Index Number: 20090520123024 Location: Atkasuk, AK River: Meade River Jam Date: 05/29/2006 Water year: 2006 Jam Type: Unknown Current Condition: unknown Damages: CRREL Contact: K. White Local Contact: Visuals: Reports: Latitude: 700 29' 20" N Longitude: 1570 24' 40" W Gage Number: 15803000 Hydrologic Unit Code: 19060203 Publication: USGS Water Resources Data for Alaska WY 2006 USGS Water Resources Data for Alaska WY 2006 reported an annual maximum peak stage of Description: 32.87cfs on 29-MAY-2006 due to backwater from ice at USGS gaging station 15803000 Meade River at Atkasuk, AK. The average daily discharge was 7,000cfs. 3 of 3 11 /19/2013 2:45 PM a • k lab v t � f s High Pe forma TW nce t Modula' 4, Utilitv Polesr- Case Study: Innovative Materials & Design The RS pole was chosen for Southern California Edison's 'Circuit of the Future' - a project that utilized the most advanced, reliable utility products on the market. High performance RS modular comps utility poles provide a cost effective, reliable solution where environmental conditions, weight, physical access, lead time, aesthetic considerations, transportation, high strength, enhanc safety or long service life are requirec new lines or pole replacement. Significant portions of the utility grid were installed decades ago. Aging structures endure constant attack from rot, corrosion, woodpeckers and termites and are regularly challenged by ice storms, hurricanes, tornadoes, vandals and even vehicular impact. New line construction and pole replacement can be problematic with long lead times, challenging terrain, right of way issues, environmental assessments, disposal costs, power interruptions and costly equipment requirements. The RS Pole Solution RS Composite Utility Poles are constructed from combinations of up to eight standard -sized tubular modules to create poles with heights ranging from 30 ft. [9.1 m] to 155 ft. [47.2 m] that use standard industry hardware. RS poles deliver the following: a Lowest Loyristics Costs with industry best lead times, more efficient transportation, fast installations and cost effective inventory management. ® Lowest Liability with a limited 41 year warranty, high dielectric strength providing improved safety for workers and the public, better storm and high wind resilience, faster response times in emergencies and minimal environmental impact. ® Longest Life with an 80 year service life, integrated UV protection and immunity to rot, corrosion, woodpeckers and termites. T he highest performing Utility Pole on the Market RS poles have been used by over 29S utilities worldwide, including installations in North America, Scandinavia, Australia, Europe, South America, Asia and the Caribbean. 2 RSComposite Utility Poles COMPOSITE MATERIALS The RS utility pole is made from an advanced composite material with integrated UV protection that combines an ultra - strong polyurethane resin and E-glass fiber rovings. MODULAR DESIGN The RS pole's unique tapered design enables the modules to be nested in compact bundles allowing for maximized efficiencies in storage and transportation. The eight module system can be configured to build virtually any pole class up to 155 ft. [47.2 m], which lowers the lead time for deliveries, reduces inventory requirements and simplifies transportation, handling and installation. S ADVANTAGES aliftlill, Case Study: Storm Resilience RS poles can sustain a high load from hurricanes, tornados, snow and ice and return to their original position. dware Compatibility y pole, be it wood, steel, concrete or composite, will perform at its best when it is .hed with the correct hardware. Smooth surfaced hardware without sharp points ,ntact is used with RS poles and is commonly available. The RS pole's round cross on ensures easy hardware selection. erior Temperature Performance :omposite material performs well in both hot and cold onments. The established temperature range is -76°F to +167°F [-60'C to +75'C]. t Assembly ole slip joints assemble in approximately 10 minutes each or with the assembly entire poles can be completed in 15 minutes with a crew of four including a lanically fastened connection. Poles can be pre -drilled for specific framing rrns prior to shipping to reduce installation time. lularity :)m length and strength poles are created from standard sized modules for ultimate Ality. Below are different module combinations to build a 75 ft. [22.8 m] pole: 75 ft. CL 1 [22.8 ml 7 M2 M3 i 75 ft. H1 [22.8 ml M617 75ft. H4 [22.8 ml 75ft. H6 [22.8 ml MW INFRASTRUCTURE FOR LIFE° 3 Case Study: Inventory Advantage "Having the ability to build a variety of pole lengths and classes from just eight modules gives utilities faster deployment time for emergency outages." Utility Products, November 2006 LOWEST LOGISTICS COST The RS pole's modular design offers the fastest delivery and lowest logistics cost of any utility pole, from the time the order is placed to the time the pole is installed. Industry Best Lead Times RS maintains a large inventory of modules which enables even large custom pole orders to be shipped within weeks and on demand production capability ensures RS has the pole inventory you require. Minimal Inventory Because the interchangeable modular system can satisfy multiple pole strength and length requirements, nested module sets that take up a fraction of the space that single piece poles require are stocked instead of many custom single piece poles. A major contributor to an effective sparing strategy, RS's modular system keeps minimal inventory on hand, quickens turnover cycles and reduces safety stock inventory costs while effectively meeting day-to-day and emergency requirements. Downtime from grid damage is significantly reduced because the modules can be quickly configured to build almost any pole class up to 155 ft. [47.2 m]. One Set of n'/OdW25 can build 262 Different poles RS Modular Pole Combination Sampling I M1 M2 M3 M4 M5 M6/7 M8/9 M10/11 30 ft. 35 ft. - 40 ft. [9.1 m] [10.7m-13.7m] �1A yy� jpe�M3 NFN G :M M M tA 3 = ] 4 M N M M M M M 2 3 4 M 4 5 4 3 4 M r. 4 M 617 M 3 M M 6n in 1 Al M it n4. t M TM 4 4 H7 Ws -.M M M M 6n7 L3 - 161tt 6M M M M M 619 ;.: 16/11 1M/ 16J11 STRENGTH 4 RSComposite Utility Poles Dnln Cro%r" nrne Cef o%$ DC RAo%Av ml� INFRASTRUCTURE FOR LIFE® s Case Study: Transportation Advantage "Compared to other transmission poles we evaluated, the RS pole was the most cost effective. Transportation, assembly and installation was easier and less expensive than that of traditional poles." Shawn Woon, Manager, Midifte Poweriine Construction Efficient Transportation The IRS pole's nesting modules mean even the longest IRS poles only require standard length trailers and they eliminate the need for slow and expensive long load permits. See the Truckload Quantity Comparison chart below to review the significant shipping efficiencies that can be realized with IRS poles. Depending on pole size, IRS modules can also be shipped and stored in 20 ft. [6.1 m] or 40 ft. [12.2 m] intermodal containers for international deliveries and quick deployment after natural disaster damage to the grid. Lightweight IRS poles have been air freighted in bulk quantities in emergencies. r� aA illY IMI Yril� iflfN fill rr Ya Y�ill �t riyr i Truckload Quantity Comparison 60 ft. [18.3 m] Class 1 Poles 19 ft 19 % IS-S m] 15 ft [s.8 m] 4S ft [4.6 m] 19 ft - [13.7 m] IS-8 M3" .r60 tL 4F �- 60 it [18.3 m] ,i 1. IRS Steel Wood Concrete S3 Poles 27 Poles 1S Poles 6 Poles -v '� �rmt�iC.•••• - all,III!! Ajjjjjjjrjl1� KMMIII�� _ �4- 6 Composite Utility Poles Installation Flexibility Lightweight RS poles can be assembled in 15 minutes per pole with a four man crew. When setting the pole, in addition to using lighter duty machinery, modularity allows for installations sequencing options. The entire pole can be assembled on the ground and then installed. Alternatively, the base can be installed first and the remaining top modules added at a later time either one at a time or as a preassembled unit. On -the -fly line design changes to pole height and class are easily accomplished by simply adding or removing the desired module. Pole modularity also provides for simple circuit height adjustments, future system expansion and revenue generating joint use potential. Compared to traditional pole materials, smaller helicopters can be used to lift fully constructed H-frames for challenging location drops. RS poles are easily cut and/or drilled in the field. i4111111, Case Study; Installation Advantage Norwegian utility NTE has calculated that the installed cost of RS poles is about 10% less than wood when spanlengths are optimized and helicopters are used for installation. INFRASTRUCTURE FOR LIFE® 7 Case Study: Reliability "You can't beat the warranty. We like to use RS poles to harden our infrastructure in critical, high value locations." Steve Coltharp West Kentucky EC Case Study: Reliability Rio Grande EC had just finished installing a 34.5kV line when a tornado touched down. "We lost eight 40 ft. [12.2 m] Class 3 wooden poles. RGEC Operations reported that the RS composite poles that we Installed in this area `did not budge at all'." Dan Laws Rio Grande EC Case Study: Non - Conductivity RS poles were proven by test lab Kinectrics in Ontario, Canada to pass the test for a hot stick, making them one of the safest poles on the market. Case Study: Environmental Advantage "RS poles do not need to be coated with Penta, arsenic or creosote. As a result, these poles are the most environmentally friendly ones available in the market place." NWPPA Bulletin, January 2006 LOWEST LIABILITY High performance RS poles reduce the risks and costs associated with managing utility infrastructure and increase grid reliability. Reliable Storm Protection The ultra strong RS composite pole can absorb significant elastic strain energy in high -load situations like hurricanes, tornados, ice storms and seismic events. This capability delivers infrastructure reliability far beyond the expected performance of conventional utility pole materials. The exceptional load carrying capacity combined with the RS pole's light weight reduces the potential for cascade failures. Excellent fracture toughness protects against crack initiation and propagation. Additionally, RS poles are self -extinguishing and meet the published pole strength values from tests conducted after exposure to moderate to severe simulated wildfires. Increased Safety Manufactured with a non-conductive and hydrophobic material, RS poles reduce the risk of second point of contact injuries, eliminate electrical tracking and help prevent arcing due to lightning or switching. RS Composite Utility Poles pass the 100 µA test for a hotstick which makes live -line installations safer. The lightweight modules decrease the probability of worker injury and equipment fatigue. The tubular RS pole allows ground wires to be run internally. Environmentally Responsible RS poles are free of toxic preservatives common to wood poles and as a result they do not leach chemicals into the ground or water table. Soil remediation is never required. RS poles have been tested with the ASTM C1308-08 Leach Test and the water used in the test subsequently passed both Canadian and US drinking water safety standards. The RS manufacturing process releases no volatile organic compounds (VOC) or hazardous airborne pollutants (HAP). Public Satisfaction RS's controlled manufacturing process ensures a consistent lifetime aesthetic. RS poles are available in either grey or brown to match existing wood and steel poles or to blend in with the scenery. The surface of the RS pole is easily cleaned of graffiti and poster glue and is resistant to staples. Specific Strength Comparison Ili RS pales: 630 psi.ft3/lb [271 kPa.m3/kg] ■ Wood (Douglas Fir): 272 psi.ft3/lb [117 kPa.m3/kg] Steel: 119 psi.ft3/lb [51 kPa.m3/kg] r Concrete: 7 psi.ft3/lb [3 kPa.m3/kg] 700 psi 575 psi 350 psi 175 psi 0 psi Weight Comparison N RS poles: 1,181 Ibs [536 kg] Steel: 2,190 Ibs [993 kg] ■ Wood: 3,695 Ibs [1,676 kg] ■ Concrete: 8,500 Ibs [3,856 kg] 300 kPa 4,080 kgs 225 kPa 3,060 kgs 150 kPa Z040 kgs 75 kPa 1,020 kgs .Li73'?i O kg -= 75 ft. [22.8 m] Class 1 Pole 9,000 Ibs 6,750 bs 4,500 Ibs Z250 Ibs 0 Ib +� Composite Utility Poles LONGEST LIFE Manufactured with integrated UV protection and a durable composite material, RS poles have a longer service life than any other pole alternative. Excellent Weathering and UV Protection High performance RS poles are engineered for an 80 year service life. This extended life expectancy is achieved from a single step manufacturing process which creates a monolithic laminate with an imbedded layer of aliphatic UV protection that cannot be scratched or flaked off. RS poles are covered by a 41 year limited warranty- see the RS Limited Warranty for complete details, Corrosion, Rot and Pest Resistant RS poles will not rot or corrode because the pole wall is hydrophobic. This allows for excellent wet area and coastal performance as well as resistance to salt and chemicals. RS poles are impervious to woodpeckers, termites and other pests. These performance advantages dramatically extend the life of the grid. Maintenance Free Poles RS poles require no scheduled maintenance, like preservative treatments or repainting, resulting in significant operational savings. Inspections are faster and less invasive and typical pole replacement frequencies are cut in half. Even hardware re -tensioning is required less often because RS poles have a similar coefficient of expansion to that of steel hardware. Installed Cost and NPV Advantage The RS pole delivers the lowest total ownership cost based on Net Present Value (NPV) calculations. In installations with challenging terrain, long length poles, remote locations or helicopter lifts RS poles can provide the lowest installed cost. Move beyond the material cost comparison and find out how much wood poles truly cost. A tailored analysis for your grid will be completed by RS Technologies, IANTES-,r TKAI. 0�1'i�EItSIIIl' t:OS'1' Expected Service Life STEEL' -------------------------- CONCRETE WOOD' ................ .0 70 :0 90 100 Years *Grid infrastructure replaced at 2.5% annually (100/2.5 = 40 year typical service life for traditional pole materials) Case Study: Longevity Advantage A Pacific island utility plagued by termite damage on wood poles has Increased the life of their grid 6-fold by using RS poles. INFRASTRUCTURE FOR LIFE® 9 0.0 WORLD CLASS CUSTOMER SUPPORT RS is the leader in composite utility poles. Our dedicated and qualified team of experienced engineers work with you from preliminary planning to line completion. Design Support The RS technical department is involved throughout the entire process to ensure you chose the right RS pole for your application. Our design support includes structural analysis or PLS-POLE- and PLS-CADD- where your loading requirements are reviewed and a report is generated detailing the performance of the RS pole in your application. RS poles can also be analyzed independently using the FRP library files available from Power Line Systems (PLS). Technical Binder All RS technical information is compiled into a single package containing: ® RS Pole Data Sheets from 30 ft. [9.1 m] to 155 ft. [47.2 m] ® Structural Design Guide ® Hardware Guide ® Maintenance and Inspection Guide ® Technical Specification 0 Testing Overview ® Assembly and Installation Guide ® Frequently Asked Questions Application and Installation RS engineers can assist with project planning and assessment and are available to answer questions and provide support. Prior to commencing a project, we can complete a full hardware review and provide the necessary recommendations to ensure a long lasting, successful installation. LAB TESTED, FIELD PROVEN The RS controlled manufacturing environment produces consistent pole modules each and every time for measured, reliable performance in your grid. You can count on it. Quality Assurance RS is ISO 9001:2008 certified and maintains a stringent quality focus throughout the entire manufacturing process. From material inputs to formulation to final production, each step is carefully monitored to ensure you receive the best product on the market. Testing RS poles have been thoroughly full scale tested and verified to all relevant ASTM, ANSI and IEEE standards. Line Installations Current installations are subject to extreme temperatures, corrosive environments, pest attacks, heavy loading and severe weather. All poles continue to deliver superior, predictable performance. Composite Utility Poles __�RS t Case Study: Hardware Non -cleated, flat surfaced hardware is require for RS poles and hardware suppliers have compatible alternatives to wood pole hardware readily available. In most cases, existing hardware that is compatible with concrete and round steel poles can be used on RS poles. ry.. �t T R=S www.RSpoles.com Email info cr RSpoles.com Toll Free +1 877 219 8002 Phone +1 403 219 8000 r 4i Fax +1 403 219 8001 IRS Technologies Inc. 233 Mayland Place NE Calgary, AB T2E 7Z8 'ILS-`J.MV1.UU4.Ut'J LRSKAKT-ANL:(l U-LtS-1Jj.ULb (ANL: 0 0 0 0 0 0 D7 0o r m W CD C c) D m z (n 3 N N m 3 Z z a � r r m m U) 0 n r M>_ i 1- 11 LAtS UKAIN 514t rULLJ AL;arngus 1/22114 PERCENT FINER BY WEIGHT 0 0 0 0 0 m n 0 o 0 0 C n � Ln co m m 0 D m z co c i z � Z t� v cn -n ) 7' C m CD (n CCD j m (/) m C z C m W m CIO O o a 'G z o z o = � � n o m w co m m V) co n % Passing Sieve o (interpolated if not measured) o o 0Cnr- 0 W o (An c CA � A� hJ IJ N i W n S 3 V- no 4.3 v v v O 3 Oy1 � 3 EllO a. i O O� 7t 0t oo N A� -i N N W �� e �� 7 A 0 cm O O (aCL� O O� Rs CD CD C4f A O O O CD CD O CD O O O 1 y � n. O (D co O �D O (D O N C31 y y O p A "o zo (D, g 0 C. W , (n .F � O -' :A ppCA(p A rD C'4 o N O 2 L L Sr W O O P W W t7l -4 A to W S B n r a m m 0 0 0 0 Om_I 28 o � Ca � b rn Y VI Y y.i 0 0 � � n N ° �O••U� � � {••i Y iyy � �•y � .�y � 1 O •� U .. U o O +- is o o >~ m o Y w R •� O •.Y~•� �y(yyQy °: t/l 7�4 V % `$}may r3 ^� Y - irk i-i oo Q, 3 0 .0 3 x a • � c°� 3 Y o . 0 0 ° ° o Y Y 5 b r, 2 aL ' a. , 5 5 U U U N U N O U U78 s O � R 0 O h N I cq 0 M O 8 Sb rN M C G r O Ko b t4 79 x '~ o cl .5 3 cs 45 9 n Bulletin 1724E-200 Page 11-17 TABLE 11-6 RECOMMENDED LOAD FACTORS AND STRENGTH FACTORS TO BE APPLIED TO NESC DISTRICT LOADS (Grade B New Construction) (NESC Tables 253-1 and 261-1A) (Note 5) FACTORS NESC RUS LOAD FACTORS Vertical Loads 1.50 1.50 Transverse Loads Wind 2.50 2.50 Wire Tension 1.65 1.65 Longitudinal Loads At crossings General 1.10 1.33 Deadends 1.65 1.65 Elsewhere General 1.00 1.33 Deadends 1.65 1.65 STRENGTH FACTORS (Note 3) Steel and Prestressed Concrete Structures 1.00 1.00 Wood Poles (Note 4) 0.65 0.65 Wood Crossarms (Note 4) 0.65 0.50 Guy Wire Assemblies 0.90 0.65 (Note 1) Guy Anchors and Foundations 1.00 0.65 Guy Attachment Assemblies (includes guy 1.00 0.65 (Note 2) hardware) Conductor Support Hardware Note 6 1.00 1.00 Notes: 1. A value different than 0.65 may be used, but should not exceed 0.9. 2. This strength factor of 0.65 may be increased for steel and prestressed concrete poles. 3. It is recognized that structures will experience some level of deterioration after installation. These strength factors are for new construction. 4. For wood structures, when the deterioration reduces the structure strength to 2/3 of that required when installed, the wood structure should be replaced or rehabilitated. If the structure or structure component is replaced, the structure or structure component needs to meet the strength for the original grade of construction. The rehabilitated portions of the structures have to be greater that 2/3 of that required when installed for the life of the line. 5. When calculating the additional moment due to deflection, deflections should be calculated using loads prior to application of the load factor. 6. Conductor Support Hardware is any hardware not a part of the structure, guy assembly, or guy attachment. Conductor support hardware may be splices, extension links, insulator string yokes, y-clevis balls, ball hooks, deadend clamps, etc. Bulletin 1724E-200 Page 11-18 TABLE 11-7 RECOMMENDED LOAD FACTORS AND STRENGTH FACTORS TO BE APPLIED TO EXTREME WIND LOADS (Rule 250C of the NESC) AND TO EXTREME WIND/ICE LOADS (Rule 250D of the NESC) (Grade B New Construction) (NESC Tables 253-1 and 261-1A) (Note 5) FACTORS NESC RUS LOAD FACTORS Vertical Loads 1.00 1.10 Transverse Loads Wind 1.00 1.10 Wire Tension 1.00 1.00 Longitudinal Loads At crossings General 1.00 1.00 Deadends 1.00 1.10 Elsewhere General 1.00 1.00 Deadends 1.00 1.10 STRENGTH FACTORS (Note 3) Steel and Prestressed Concrete Structures 1.00 1.00 Wood Poles (Note 4) 0.75 0.75 Wood Crossarms (Note 4) 0.75 0.65 Guy Wire Assemblies 0.90 0.65 (Note 1) Guy Anchors and Foundations 1.00 0.65 Guy Attachment Assemblies (includes guy Not Specified 0.65 (Note 2) hardware, bracket and guy attachment assemblies) Conductor Support Hardware Note 6 0.80 0.80 Notes: 1. A value different than 0.65 may be used, but should not exceed 0.90. 2. This strength factor of 0.65 may be increased for steel and prestressed concrete poles. 3. It is recognized that structures will experience some level of deterioration after installation. These strength factors are for new construction. 4. For wood structures, when the deterioration reduces the structure strength to 2/3 of that required when installed, the wood structure should be replaced or rehabilitated. If the structure or structure component is replaced, the structure or structure component needs to meet the strength for the original grade of construction. The rehabilitated portions of the structures have to be greater that 2/3 of that required when installed for the life of the line. 5. When calculating the additional moment due to deflection, deflections should be calculated using loads prior to application of the load factor. 6. Conductor Support Hardware is any hardware not a part of the structure, guy assembly, or guy attachment. Conductor support hardware may be splices, extension links, insulator string yokes, y-clevis balls, ball hooks, deadend clamps, etc. WALAKPA DISTRIBUTION REPORT NORTH SLOPE BOROUGH SAKATA ENGINEERING SERVICES, LLC June 2014 Walakpa Distribution Report Scope of Work Sakata Engineering Service was tasked to look at options to lower the cost of providing power to the Walakpa gas field from the proposed Barrow to Atqasuk transmission line. Options There were two new options considered, Option 3 and 4 are previously presented.: • The three phase option. This Option 1 consists of : 1. Step down transformer from 69 kV to a three phase 12.47 kV at Walakpa Jct. and 2. using a three phase 15 kV aerial cable 3. mounted on 35/3 class poles 4. Step-down transformer from 12.47 kV to 480 V • The single phase option This Option 2 consists of : 1. Step down transformer from 69 kV to a single phase 12.47 kV at Walakpa Jct. and 2. using a single phase 15 kV aerial cable 3. mounted on 35/3 class poles 4. Step-down transformer from 12.47 kV to single phase 480 V S. 250 kW Rectifier- Inverter to 480 V AC • Option 3 consists of extending the 69 kV line on a single pole configuration with a fuse cutout at the Jct. and a step-down transformer at Walakpa. • Option 4 consists of extending the 69 kV line on a three pole configuration with a fuse cutout at the Jct. and a step-down transformer at Walakpa Executive Summary. 1 have attached the drawings for the sub at Walakpa Jct. and the map for the area and the cost estimates. The summaries of costs are: Option 1 total costs are at: $1,143,930.17 Option 2 total costs are at: $ 890,453.38 Option 3 total costs are at: $1,472,911.72 Option 4 total costs are at: $2,426,471.61 Option 1 and 2 are attractive since they have a low profile, the one thing that will help greatly in the environmental permitting The recommended option is Option 1 since it will take fewer components, only two transformers and the 15 kV cable while the Option 2 requires a convertor from single phase to three phase. Although both Options are good Options. Costs Details Sakata Engineering Services, LLC 6/5/2014 Option 1 Walakpa Junction 15 Kv (Three phase Option) Item Description Units Material Units Cost Labor Unit CostCost Total Cost 69 kV Fuse Cutout 3 $750.00 $250.00 $3,000.00 1.5 MVA Transformer 69/12.47 kV 1 $62,000.00 $7,500.00 $69,500.00 15 kV Fuse Cutout 3 $250.00 $175.00 $1,275.00 Sub Miscelaneous (Fence, Grading) 1 $5,000.00 $7,500.00 $12,500.00 35/3 Pole RLS 160 $1,661.22 $1,200.00 $457,795,20 Shipping poles (Ibs) 56691 $0.76 $0.03 $44,785.93 Pole Hardware (Tangent and angle) 160 $150.00 $100.00 $40,000.00 Guying and anchoring 30 $125.00 $225.00 $10,500.00 15KvTriplexcable with messenger (1,OOOft) 36.717 $11,506.00 $0.05 $422,467.64 Shipping cable (Ibs) 92160 $0.76 $0.03 $72,806.40 225 Wa Transformer 12470/480V 1 $7,800.00 $1,500.00 $9,300.00 otal Costs $1,143,930.17 Option 2 Walakpa Junction 15 Kv (Single phase Option) Item Description Units Material Units Cost Labor Unit CostCost Total Cost 69 kV Fuse Cutout 2 $750.00 $250.00 $2,000.00 500 KVA Transformer 69/7.2 kV 1 $45,000.00 $7,500.00 $52,500.00 15 kV Fuse Cutout 1 $250.00 $175.00 $425.00 Sub Miscelaneous (Fence, Grading) 1 $5,000.00 $7,500.00 $12,500.00 35/3 Pole RLS 122 $1,661.22 $1,200.00 $349,068.84 Shipping poles (Ibs) 47243 $0.76 $0.03 $37,321.61 Pole Hardware (Tangent and angle) 160 $150.00 $100.00 $40,000.00 Guying and anchoring 30 $125.00 $225.00 $10,500.00 15KvTriplex cable with messenger (1,OOOft) 36,717 $5,753.00 $0.05 $211,234.74 Shipping cable (Ibs) 46080 $0.76 $0.03 $36,403.20 225 Wa Transformer 7200/480V 1 $14,500.00 $1,500.00 $16,000.00 Rectifier and Inverter equipment 480V 3phase 1 $110,000.00 $12,500.00 $122,500.00 Total Costs $890,453.38 Option 3 Walakpa Jct Cost Estimate on Single 64.6' (F-0205) pole RLS Composite 115 Kv Structures (TP-69) Total Labor Total Labor Components Description Unit # Units Cost Total Cost Unit Labor Hours Hours Cost Unit Cost Total Cost 477 MCM cable ACSR (ft.) 50miles 815,800 $1.50 $1,223,700.00 0.028 22,842.40 $2,427,576.06 $4.48 $3,651,276.06 Shipping above cable (lbs.) 509,059 $0.76 $386,884.99 0.002 1,018.12 $108,200.53 $0.97 $495,08552 64.6 RS Poles (700' Ruling span) 377 $3,989.70 $1,504,686.86 13.500 5,091.43 $541,091.57 $5,424.41 $2,045,778.43 Shipping above Poles (lbs.) 397,509 $0.76 $302,106.51 0.002 795.02 $84,490.45 $0.97 $386,596.96 Tangent Assembly 358 $954.07 $341,557.06 8.200 2,935.60 $311,980.89 $1,825.53 $653,537.95 Angle Assembly 19 $1,741.32 $33,333.84 9.800 187.60 $19,937.19 $2,782.82 $53,271.03 Dead-end Assembly 25 $4,401.22 $110,030.50 14.400 360.00 $38,259.00 $5,931.58 $148,289.50 Anchors 265 $145.00 $38,404.29 8.800 2,330.74 $247,699.70 $1,080.22 $286,103.98 Foundation fill materials 377 22.000 8,297A4 $881,778.86 $2,338.05 $881,778.86 Shipping Misc, above to ped 258,818 $0.76 $196,701.57 0.002 517.64 $55,011.74 $0.97 $251,713.31 Dampers 1,131 $28.84 $32,630.40 0.500 565.71 $60,121.29 $81.98 $92,751.69 Mob & Demob Lot $600,000,00 Cost for 60 miles $4,170,036.02 44,941.40 $4,776,147.27 $9,546,183.29 Cost / mile 60 Miles $190,923.67 Walakpa Jet Cost 7 Miles $1,327,678.83 Walakpa Jct Cost w Sub costs $1,472,911.72 Option 4 Walakpa Jct Cost Estimate on three (3) 62.4' (F-0104) pole RLS Composite 115 W Structures Total Labor Total Labor Components Description Unit # Units Cost Total Cost Unit Labor Hours Hours Cost Unit Cost Total Cost 477 MCM cable ACSR with T2 (ft.) 50miles 815,800 $1.50 $1,223,700.00 0,028 22,842.40 $2,427,576.06 $4.48 $3,651,276.06 Shipping above cable (Ibs.) 509,059 $0.76 $386,884.99 0.002 1,018.12 $108,200.53 $0.97 $495,08552 62.4' RS Poles (674' Ruling Span down from NESC min tc 1,175 $3,169.44 $3,724,327.12 13.500 15,863.50 $1,685,893.62 $4,604.15 $5,410,220,74 Shipping above Poles (lbs.) 995,288 $0.76 $756,418.75 0.002 1,990.58 $211,548.43 $0.97 $967,967.18 Tangent Assembly 1,116 $320.00 $357,120.00 8.200 9,151.20 $972,543.78 $1,191.46 $1,329,663.78 Angle Assembly 20 $1,741.32 $34,289.02 9.800 192.98 $20,508.49 $2,78232 $54,797.51 Dead-end Assembly 25 $4,401.22 $110,030.50 14.400 360.00 $38,259.00 $5,931.58 $148,289.50 Anchors 268 $145.00 $38,88151 8.800 2,359.71 $250,777.72 $1,080.22 $289,659.23 Foundation fill materials 1,175 22.000 25,851.63 $2,747,382.20 $2,338.05 $2,747,382.20 Shipping Misc. above to ped 601,138 $0.76 $456,865.15 0.002 1,202.28 $127,771.96 $0.97 $584,637.11 Power Line Sentry Bird Flight Diverters 15,086 $15.00 $226,285,71 0.250 3,771.43 $400,808.57 $41.57 $627,094.29 Dampers 1,175 $2834 $33,889.14 0.500 587.54 $62,440.50 $81.98 $96,329.64 Cost for 50 miles 1 $7,348,691.90 85,191.35 $9,053,710.86 $16,402,402.76 Cost / mile 50 Miles $328,048.06 Walakpa Jct Cost 7 Miles $2,281,238.72 Walakpa Jot Cost w Sub costs $2,426,471.61 Walakpa Cost Estimate For Connection Total Labor Total Labor Components Description Unit # Units Cost Total Cost Unit Labor Hours Hours Cost Unit Cost Total Cost 300 kVA Transformer 69 IN to 480V 1 $22,500 $22,500.00 26.000 26.00 $2,763.15 $25,263.15 $25,263.15 69 kV Fuses 1 $7,800 $7,800.00 18.500 18.50 $1,966.09 $9,766.09 $9,766.09 Platforms 1 $5,760 $5,760.00 36.000 36.00 $3,825.90 $9,585.90 $9,585.90 SCADA/Metering link 1 $28,800 $28,800.00 60.000 60.00 $6,376.50 $35,176.50 $35,176.50 Shipping Misc. above to ped 25,000 $0.76 $19,000.00 0.006 150.00 $15,941.25 $1.40 $34,941.25 225 kVa Transformer 7200/490V 1 $14,500.00 $14,500.00 $16,000.00 $30,500.00 $83,860.001 29050 $30,872.89 $145,232.89 Cost / each 1 Each $145,232.89 Q� alakpa Bay, Alaska, -,USA POLE 250'SPAN 11 Vol si�*OUWMI O � a OLLF-suIFVvF SERIAL CAR[ . . . . . . . . . . ........ Setting the Standard Introduction Okonite's factory assembled aerial cables have been successfully used for over 75 years on distribution systems from 600V to 46kV. Okonite's aerial cables are a product of closely coordinated efforts in research, engineering and manufacturing to bring Jacket to the market the lowest cost and most reliable Self -Supporting Aerial Cables EPR that can be made today. Insulation Screen Okonite's aerial cable designs combine EPR over 40 years of reliable service, using Strand Screen an all EPR Okoguard insulation system, together with engineered installation technology. The following two constructions are typical of EPR Self -Supporting Aerial Cable designs. EPR Materials Self -Supporting 15kV Unjacketed Aerial Cable with Bare Copper Binder Strap. Self -Supporting 15kV Jacketed Aerial Cable with Thermoplastic Coated Binder Strap. Shield Okogua Insulatii Conduc • Okoguard Cables are manufactured on a continuous vulcanization machine (CV) with three tandem extruders * A closed system that applies all three EPR components in one process • Damage of critical interfaces and contamination are eliminated • Employs laser micrometers to measure and control dimensions Triple Tandem is superior to the common head process which is limited to the measurement of the combined insulation and insulation shields Curing Tube Lacer Lacer ten extruder applies the 2nd extruder immediately 3rd extruder apptfes ilia conductor shield, a black applies red Okoguard EPP insulation shield. a black semiconducting, EPP insulation semiconducting. EPR thermosetnnq compound thennnselting compounn Okoguard Demonstrates Deformation Resistance and Good Physical Stability Through Operating, Overload and Short Circuit Temperature Ranges 100% Hot Modulus Advantages During Thermal Loading 1. Prevents the conductor from deforming the insulation at cable bends, 2. Reduces the affect of the metallic shield deforming the insulation during current overload- 3. Minimizes insulation flattening due to mechanical compression. 0 20 75 90 130 :1 1, Temperature C 1 /0 Solid Conductor 280 MIL insulation Wall After 6 Load Cycles — 4 Hrs. 90°C, 4 Hrs. at Room Temperature Shrink Back 300 270 210 200 lyy _N g t00 70 Advantages: • Maintains integrity of molded mminations • Prevents voids at the insulation -connector interface splices Okaguard XLPE.t XLPE 2 XLPE 3 XLPE-4 Insulations Okoguard Demonstrates long Term Stability in Water Seven year 900C Water Test, - #2 AWG Conductor with 220 mil Okoguard Wall -Voltage Tested at 40 and 80V/mil n 1.0 Dissipation Factor ID.F.I Okoguard 0 12 24 36 48 60 72 84 Months 4.0 3.0 110 175 mil Wall Okoguard Samples After Cyclic Aging All Samples Exceeded AEIC Requirement ♦ Passed Number of Impulses to Failure 1 2 to Ll 3 E M 4 5 AEIC R,!,I,; wr.t Ambient Temperature ♦ ♦ ♦ ♦ ♦ 2 ♦ ♦ ♦ ♦ ♦ ♦ 2 ♦ ♦ ♦ ♦ ♦ ♦ 1 High Impulso 1130 Cl ♦ ♦ ♦ ♦-- --.,._`3 ♦ ♦ ♦ ♦ ♦ 1 f i I I 1 i I 0 110 1t9 140 170 200 230 260 2g0 3• i 3 i 13 1 31 (3) 13.1 13-1 13-1 Applied Voltage Steps kV Prior to shipment, Okoguard cables are tested at 4 times specified operating voltage to ground The Corona test results are recorded and comply with. or exceed, ICEA standards 5 Each Sample 1/0 Aluminum 09X) 345 MIL insulation Wall Beading at Room Temperature Bending at 0` Centigrade Okoguard - natural sag 0 to. Okoguard - natural sag 0 lb. XLPE - 4 lb. pull required to equal Okoguard XLPE - 9 lb. - requires more then double room temperature pull to equal Okoguard Aw • ii* o • Okoguard flexibility at 0°C remained the same .� �i 6 i n� as at room temperature • XLPE lost one half of its flexibility from room temperature to 0°C Okoguard permits ease of handling during ntilal:aunn spirting and term.naung The formulation and manufacture of Okoguard and the all EPR insulation system yields a free stripping i 0 insulation shield. ®KOGUARDO SERVICE RECORD 14N an 1 W49 11 13 75 77 79 at a3 85 87 89 91 93 95 97 99 01 03 05 072006 YEAR Design Features of Okonite's Preassembled Aerial Cable • Messenger design provides a safety factor of 4 times the allowable messenger stress to allow ample safety margin for wind and ice loading. • Messengers are copper clad steel, galvanized steel or stainless steel to prevent corrosion damage. • Binder straps have rounded edges and are protected with a thermoplastic covering to prevent damage of the jacket. • Engineered factory packaging helps to prevent installation problems. • The use of an all EPR insulation system provides flexibility for easier installation. • Jackets are designed to withstand cold flexure damage and are UV light resistant. • Okoguard 105°C Medium Voltage and 90°C Low Voltage insulations are moisture resistant EPR compounds, designed and tested for long-term stability • Messengers, when properly grounded, provide protection against lightning and surge currents. Aerial Cable Construction 600 volt — Three 1 /C Class B stranded copper or aluminum conductors, tandem extruded Okoguard EPR insulation, and Okolon jacket. Three single conductors are cabled together and laid parallel to a cop- per clad steel, galvanized steel or stainless steel messenger. The messenger and tri- plexed assembly are bound together with a PE coated copper or stainless steel strap. 2.4 kV or 5 kV non -shielded — Three 1 /C Class B stranded copper or aluminum con- ductors, triple tandem extruded, EPR strand screen Okoguard EPR insulation and Okolon jacket. Three single conductors are cabled together and laid parallel to a cop- per clad steel, galvanized steel or stainless steel messenger. The messenger and tri- plexed assembly are bound together with a PE coated copper or stainless steel strap. Medium voltage 5-46kV shielded — Three 1 /C Class B stranded copper or aluminum conductors, triple tandem extruded, semi- conducting EPR strand screen— Okoguard EPR insulation — extruded semiconducting EPR insulation screen, shielding tape and an overall jacket. This construction is also available in unjacketed form and with alter- nate type shielding tapes. Three single con- ductors are cabled together and laid parallel to a copper clad steel, galvanized steel or stainless steel messenger. The messenger and triplexed assembly are bound together with a PE coated copper or stainless steel strap. *Alternate aerial cable constructions are available upon request. g 8 Typical Self -Supporting Aerial Cable Designs h' (7X) COPPERWELD MESSENGER • • 0.375' X 0.030" COPPER BINDER TAPE 0.020' OKOLENE (PE) 3.585° 350 KCMIL COMPACT ROUND COPPER CONDUCTOR EXTRUDED SEMICONDUCTING EPR CONDUCTOR SCREEN 0.220' NOMINAL OKOGUARD EPR INSULATION, NORMINAL OD=1.104' 0.032" EXTRUDED SEMICONDUCTING EPR CONDUCTOR SCREEN NOMINAL OD=1,182' 0.005' BARE COPPER TAPE, HELICALLY APPLIED W125% NOMINAL OVERLAP 0.080' NOMINAL OKOSEAL (PVC) JACKET, NOMINAL OD=1.37(' CABLE WEIGHT = 6,106 LBSIFT. Jacketed Shielded Construction 5-46kV %:' (7X) COPPERWELD 40% HS MESSENGER 0.500" X 0.040' COPPER BINDER STRAP 9 KCMIL CLASS B CIRD .LED STRAND AL CONDUCTOR ONDUCTORSCREEN )GUARD EPR, NOM. O.D. 1.141" ON SCREEN 1,219' :KEL TAPE, 20% LAP NOMINAL OD=1.232' CABLE WEIGHT = 3.62 LBS/FT. Unjacketed Shielded Construction 5-46kV Design and assembly of Okonite aerial cables are a product of dedicated engineering efforts to provide cables which install without twisting or snagging and withstand the hostile environmental conditions of wind, rain and ice. Many assembly parameters must be considered and optimized in the manufacture of these cables. These include: • Balancing torsional characteristics of the components • Quality control and assurance • Proper spacing of the components • Precise messenger tension • Controlled binder tension • Cable length of lay • Preparation of cable ends • Packaging for shipment Aerial Cable Constructions Typical triplexed Self -Supporting Aerial Cable Designs (150 ft. spans) Copper Clad Insulation Jacket Steel Approx. Approx. Thickness Thickness Messenger O.D. NWM Ampacity Conductor Strands Mils Mils Size Inches Lbs. Amps 600 Volt Non -Shielded Copper Conductor #2 7X 45 30 .375 1.57 1208E58 4/0 19X 55 45 .375 2.18 2796 350 37X 65 65 .500 2.75 4557 500 37X 65 65 .563 3.13 6323 2.4 kV or 5 kV Volt Non -Shielded Copper Conductor #2 7X 125 80 .375 2.23 1767 158 4/0 19X 125 95 .375 2.79 3547 335 350 37X 140 110 .563 3.48 5786 464 500 37X 140 110 .563 3.76 7414 580 2.4 kV or 5 kV Non -Shielded Aluminum Conductor #2 7X 125 80 .375 2.28 1394 123 4/0 19X 125 95 .375 2.79 2203 262 350 37X 140 110 .375 3.28 3111 364 500 37X 140 110 .500 3.66 3973 458 15 kV 133% Level Copper Conductor, .005" Copper Shield Jacketed #2 7X 220 80 .500 2.91 2576 173 4/0 19X 220 80 .500 3.41 4406 349 350 37X 220 80 .563 3.90 6383 472 500 37X 220 80 .563 4.18 8067 583 15 kV 133% Level Aluminum Conductor, .005" Copper Shield Jacketed #2 7X 220 80 .375 2.81 1962 135 4/0 19X 220 80 .375 3.47 2871 273 350 37X 220 80 .500 3.79 3892 372 500 37X 220 80 .500 4.07 4617 462 15 kV 133% Level Copper Conductor, .005" Cu-Ni Shield Uniacketed #2 7X 220 - .375 2.27 2017 173 4/0 19X 220 - .500 2.87 3960 349 350 37X 220 - .500 3.30 5750 472 500 37X 220 - .563 3.80 7552 583 15 kV 133% Level Aluminum Conductor, .005" Cu-Ni Shield Un'acketed #2 7X 220 - .375 2.27 1628 135 4/0 19X 220 - .375 2.80 2467 273 350 37X 220 - .500 3.30 3440 372 500 37X 220 - .500 3.53 4060 462 10 The Economics of Self -Supporting Aerial Cable Installed Costs are Surprisingly Low Okonite Self -Supporting Aerial Cable is an economical solution, and may actually cost less than other overhead constructions, where annual tree trimming, taller poles, extra labor or additional hardware may be required. Here are the various types of construction available when primary power distribution lines are to be installed overhead. 1. Ordinary bare conductor strung through or above trimmed trees on insulators and crossarms on conventional length poles. 2. Tree wire with rubber insulation, strung through trees on insulators and crossarms on conventional length poles. 3. Ordinary weatherproof wires strung above trees on insulators and crossarms on extra length poles. 4. Aerial cable pre -assembles with a messenger (self-supporting) and strung through trees on conventional length poles. Reliability Improvements M 0 7. Aerial cables spun to the messenger in the field and strung on conventional length poles in open areas or below tree limbs. Aerial cable pulled into rings on a messenger on conventional length poles with comparatively little or no tree trimming necessary. Spacer cable. Three single conductors, partially insulated, suspended from a messenger and held by a spacer. Okoguard Insulated Self -Supporting Aerial Cables typically provide higher reliability, which translates into lower Total Owning Costs when evaluating against other overhead construction methods. System reliability has been the focus of Distribution System owners and continues to be the key component for capital investment and customer satisfaction. Reduced Need for Tree Trimming Since the SSAC system is completely insulated, the requirements for tree trimming are reduced not only saves operating costs, but alleviates problems with customers sensitive to aesthetics. Where to use Okonite Self -Supporting Aerial Cable In Utility and Industrial Distribution Applications • Where tree conditions prohibit the use of open wires or require constant trimming. • Where taller poles would be needed to clear trees. • Where greater reliability of service is required that can't be obtained from open wire circuits. • Where improved aesthetics are needed. • Where an existing pole line is incapable of carrying any additional open wire circuits but can accommodate one or more aerial cables below the open wire construction. • Where narrow clearances from structures and other lines prohibit the use of open bare wire. • Where overhead line approaches to power stations and substations are already congested and space for additional pole lines is limited. • Where the voltage to be used makes it impractical to have open wire circuits. • Where right-of-way for open bare wire is unobtainable. • Where cable circuits are urgently required and aerial cable can be installed much more quickly than underground cable. • Where joint construction in connection with other utilities is best provided for by the use of Self -Supporting Aerial Cable. Where to use Okonite Self -Supporting Aerial Cable • Where additional safety is needed for crossing private properties, freight yards, bridges, trestles, and in other public areas. • Where cable has to be continued across marshy ground that would otherwise necessitate costly pile foundations for underground conduit. • To carry power circuits along haulage ways and drifts within the mine. • Where power lines are carried overhead through trees to distant shafts and bore holes in outdoor locations. In Industrial Plants • Where power circuits can be carried overhead supported by beams or trusses rather than by hazardous open wire on insulators, or with cable in conduit. • Outdoors, on brackets attached to buildings or on poles in the open. Installation of Self -Supporting Aerial Cable The following instructions and sketches are in- tended to suggest methods for installing Self -Sup- porting Aerial Cables. In general, operating companies can use fittings and practices that are most convenient and in line with their normal usage and needs. Self -Supporting Aerial Cable can be supplied in long lengths, which result in minimizing the number of splices. The practical limit is usually the reel size, which can be handled by the power drive reel trailer or cable truck. The cable is normally transported to the installation site on a power drive reel trailer or cable truck and set up 50-75 feet from the terminal pole. Pulleys are mounted on each pole and a pulling line threaded using the pulleys, through any trees which the cable will pass. In some cases additional pulleys may be necessary to prevent the cable catching in limbs or at road crossings to prevent sagging which could block traffic. These additional pulleys are sometimes mounted from a temporary messenger or a bucket truck. All pulleys should be large enough to allow ample clearance around the cable so that there will be no danger of the binder tape catching against the frame of the pulley. A minimum diame- ter of ten inches for the inside of the pulley and a minimum clearance of 1 inch on both sides of the cable is recommended. Figure 1 shows a typical straight line pulley. The top is hinged and fastened with a loose pin so the cable can be readily removed and the messenger can be placed in the messenger clamp. When the cable must make a change in direc- tion, a multisheave radius roller assembly is neces- sary. Figure 2 shows a corner pulley. This is hung by a bracket pinned to the center top of the pulley frame. It can be mounted on the pole slightly above or connected to the mes- senger clamp. The side of the frame next to the pole is hinged so the cable may be pulled out and placed in the clamp. For large di- ameter or heavy cables a large radius (4 or 5 ft.) multisheave roller is rec- ommended. Figure 1 — Typical pulley for use on tangent poles HEAVY DUTY MESSENGER CLAMP Figure 2 - Typical pulley for use on offset or corner poles 14 Installation of Self -Supporting Aerial Cable The pulling line is fastened to the overlength of messenger with a swivel connection. A ball bearing or roller bearing swivel is recom- mended. The end of the cable should be tapered and tightly bound to the messenger to prevent _ slippage of the messen- ger and to facilitate passing through the pul- leys. The speed of the reel must be controlled so as to maintain a reason- able sag between the poles. This sag should be controlled to prevent dragging the cable on the ground between spans or rubbing on tree limbs and other cables. Using the greatest sag possible results in lower pulling tension and helps prevent twisting of the cable. The ten- sion on the cable leav- ing the reel should be kept to a minimum. A cable will sometimes rotate or twist as it goes through a pulley. This twist can usually be re- moved by temporarily halting the pull and hav- ing line -personnel un- twist the cable. Once the cable passes through the pulley there should be no further tendency for the cable in that span to twist. After the entire reel has been pulled, the end should be dead -ended at the pole leaving ample cable for making connections to fuse cutouts, splices, or other devices. Sometimes an addi- tional 100-150 feet of messenger is coiled on the reel drum, so that the trailing cable end can be pulled up to the desired location. This method eliminates the previous procedure of temporarily tying off the cable at the first pole, unreeling the last couple of cable coils still on the reel, and attaching a winch to the trailing end of the messenger. The cable should be pulled to a tension 25% higher than the final tension, and then loosened to facilitate the placement of holding clamps. A come -along is then applied to the cable at the last pole to maintain the tension. This tensioning is not intended to prestretch the messenger but rather to equalize the tension in the various spans. It is impossible to prestress unidirectional cable completely as the messenger will not slide for the entire distance. Some strain will always be taken by the conductors in the center of the section but this will gradually relax with time. Installation of Self -Supporting Aerial Cable Figure 3 shows a typical arrangement of a dy- namometer being used for tensioning and a come -along for holding tension. Temporary guys may be required. The binder strap is then removed for about a foot on each side of the pulley and clamped to the messenger. CHAIN COME -ALONG HOIST TEMPORARY GUY DYNAMOMETER ,4 TO WINCH—+ Figure 3 — Tensioning Self -Supporting Cable The pulleys are then removed, as the messen- ger is placed in position in permanent support- ing clamps at each pole. The messenger should be placed in corner clamps before final tensioning. A block and fall is usually required to pull the messenger over the clamp. The clamp is left loose and the messenger allowed to slide during tensioning. The cable is not re- moved from straight pulleys until after tensioning, as the cable can be readily removed and placed in the messenger clamps under final tension. The pulleys are then moved along to the next section and the pulling line threaded. Figure 4 shows a typical straight line support. Figure 5 shows a typical angle support. HEAVY DUTY MESSENGER CLAMP Figure 4 — Permanent tangent messenger hanger 16 Figure 6 shows a typical corner pole. Note that the mes- senger has been spliced to obtain ad- ditional length for passing through thimbles. In this messenger hanger case the cable must be tensioned at this inter- mediate pole. The entire length is pulled in but not tensioned. Then the section back from this corner pole is tensioned with a come -along and dead -ended. The messenger is spliced and the cable trained at the corner. The rest of the ca- ble is then tensioned as for a straight pull. ANCHOR GUY ASSEMBLY OEADENO Figure 6 — Corner pole THIMBLE CONNECTORS The next section is pulled similar to the first section, except that instead of dead -ending the last end off the reel it is spliced to the first sec- tion, leaving an overlap of insulated cable. This section is then pulled, tensioned and fastened at the last pole. The temporary fastening at the last pole of the first section is then removed. It is recommended that the cable be left at least a day before splicing so any uneven tension may equalize throughout the length. Lightning arresters should be provided at junc- tions to open wire lines, being sure the arrester grounds are interconnected with the messen- ger to minimize surges across the insulation. Frequent grounding of the messenger is desir- able for protection of the cable. Installation Practices - Procedures Sag and tension calculations for aerial cables The sag and tension are based on the formulas for a parabola which are approximately the same as for a true catenary for small deflections. This well- known formula is: t = sew 8d where t = horizontal tension in messenger (Ibs.)* s = span length (ft.) w = weight of complete cable including messenger (Ibs. per foot) d = sag (ft.) *Use 50% of messenger breaking strength for Heavy Loading and 25% of breaking strength for Normal Loading. The total tension in the messenger at the support is the horizontal tension plus the vertical compo- nent due to the dead load. The vertical component has been neglected. Some typical messenger breaking strengths are given below. For more information see ICEA Publication P-79-561 "Guide for Selecting Aerial Cable Mes- sengers and Lashing Wires". Also, see IEEE Std C2 (NESC) Section 250 for extreme wind loading on wind and ice loading for the installation load. Determination of ice and wind loading Ice and wind loading are determined by geograph- ical location. The United States is divided into three districts for which standard loading condi- tions are specified in the National Electric Safety Code. The loadings for the various districts are as follows: Loading District Radial Thickness of Ice (in.) Horizontal Wind Pressure (Ibs/sq.ft) Temperature (F) Constant-k (Ibs/ft.) Heavy Medium Light 1/2 1/4 0 4 4 9 0 15 30 0.31 0.22 0.05 The resultant weight of loaded cables is calculate( as follows: i = Weight of ice loading (Ibs/ft.) = 1.24 t (D + t) t = Thickness of ice (inches) D = Diameter of cable (inches) P = Force due to wind (Ibs./sq. ft.) h = Force due to wind (Ibs/ft.) = P(D + 2t) 12 w' = Weight of unloaded cable w" = Vertical weight of loaded cable w"=w'+i The loaded weight of the cable is the resultant of the vertical and horizontal weights plus the proper constant. w"' = Resultant weight of loaded cable w"' _ (w' + i)Z + hz + k Messenger Characteristics EHS Copperclad (30%) Aluminum -Clad Steel EHS Galvanized Steel HS Stainless Steel Type 316 Area Area Area Area Nominal Messenger Breaking x Breaking x Breaking x Breaking x Size Strength Modulus Strength Modulus Strength Modulus Strength Modulus lb/ft (Ibs) (ae) lb/ft (Ibs) (ae) lb/ft (Ibs) (ae) lb/ft (Ibs) (ae) 1/4"7x — — — .104 6301 825700 .121 6650 871000 .135 8500 1060000 5116'7x .204 9196 1313000 .165 10020 1313000 .205 11200 1502000 .212 13200 1665000 31' 7x .324 13890 2088000 .385 15930 2088000 .273 15400 1821000 .282 18000 2217000 7116"7x .409 16890 2633000 .433 19060 2633500 .399 20800 2770000 A16 26000 3234000 1/2"7x .515 20460 3319000 .486 22730 3319000 .517 26900 3442000 .535 33700 4190000 9/16"7x .650 24650 4186000 .546 27030 4186000 .671 35000 4469000 — — — 9/16"19x .700 1 30610 1 4494000 1 - I - I - 1 .637 1 33700 1 4383000 1 .670 1 36200 1 5240000 Coefficient of Linear Expansion .0000072, Except Stainless Steel = .0000092 per degree F. Installation Practices Typical example of sag and tension calculations* Cable: 3 conductor 2/0 Self -Supporting Cable rated at 5 kV. Messenger: 3/8" Extra High Strength (30% Conductivity) Copperweld Ruling Span: 125 ft. Normal Tension: 3470 lbs. (25% of ultimate strength) To find the sag at 60F and the sag and tensions under heavy load- ing conditions: Weight of complete cable w' = 2.712 lbs./ft. (2712 lbs./1000') Diameter of cable (circumscribed circle) D = 2.50" Normal Tension T = 3470 lbs. Area x Modulus, ae = 2,088,000 Calculate normal sag at 60°F. Span S = 125 ft. SW _ 125 x 2.712 = a0976 T 3470 From Table on page 19 note that sag factor corresponding to T = 0,0976 is 0.01221 Sag = 0.01221 x 125 = 1.530 ft. = 18.3 inches To find sag and tension under heavy loaded conditions: Heavy loading -1/2" radial ice and 4 Ib. sq. ft. horizontal wind force at 0 F. Constant k = 0.31 Weight of ice loading, i = 1.24 x t(D + t) = 1,24 x .5 (2.50 + .5) = 1.860 lbs. Horizontal force, h = P (D + 2t) 12 = 1.167 Vertical weight of loaded cable, NP = w' + i = 2.712 + 1.860 = 4.572 lbs Resultant force, w"' = W + (w' + i) + k 1.1672 + 4.5722 + .31 =4.72+.31 =5.03 The procedure for calculating the sag and tension under loaded conditions consists of finding the unstressed length of the cable, changing its length for the change in temperature and then stress- ing the cable for the new loaded conditions and determining the new sag and tension. In the above calculations of normal sag we calculated Sw' = 0.0976 T Calculate Elongation factor Sw' _ 125 x 2.712 _ 0.000162 ae 2,088,000 From the curves on pages 20 and 21 determine the unstressed length factor for the abscissa Sn+' = Q000162 as and the curve ST = 0.0976 This is found to be 0.99873 = unstressed length factor Correct this from 60F to 0 F. Temperature correction factor of linear expansion .0000072/F. Correction of length factor = -60 x (.0000072) =-.000432 Unstressed length at 0 F. = 0.99873-0.000432 = 0.99830 Calculate elongation factor for loaded weight w" = 5.03 lbs./ft. Sw"' _ 125 x 5.03 = .000300 ae 2,088,000 From the curves on pages 20 and 21 determineSW for the ordinance of 0.99830 and the abscissa of 0.000300. This is found to be 0.126. Calculate Tension T' under loaded conditions from Sw„ = 0.126 T' T, = 125 x 5.03 = 4990 lbs 0.126 This is seen to be 35.9% of the ultimate strength of the messenger. The sag factor is determined from Table on page 19 correspond- ing to ST = 0.126 and is found to be 0.01578 Sag = 0.01578 x 125 = 1.970 ft. = 23.6 inches. For stringing the cable it is usual practice to calculate the stringing tension (unloaded) for various temperatures and plot a curve for ready reference. The procedure is the same as in the above ex- ample using the unloaded cable weight. The work can be speeded by tabulating the calculations. Stringing Temp. F 0 30 60 90 Correction for length-.00043-.00022 0 +.00022 Unstressed length factor .99830 .99851 .99873 .99895 For these values and Sw = .000162 ae find Sw T = .082 .090 .098 .106 Solving for Stringing Tension T 4140 3760 3460 3200 The sags may also be calculated if desired, but the spans usually vary so it is more convenient to pull the entire length of cable up to the desired tension rather than measuring the sag. The above calculations are based on final stretch values. The messenger is usually over -stressed during installation so the final stretch values are more accurate than initial values. 'Additional information can be found in ANSI/ICEA P-79-561 "Guide for Selecting Aerial Cable Messengers and Lashing Wires'. 18 Sag Tables .050 .006 25 .100 .012 51 .150 .018 81 .200 .025 14 .250 .031 54 .038 00 .350 .044 56 .051 .008 37 .101 .012 64 .151 .018 93 .201 .025 27 .251 .031 66 .301 .038 13 .351 .044 69 .052 .006 50 .102 .012 76 .152 .019 06 .202 .025 40 .252 .031 79 .302 .038 26 .352 .044 82 .053 .006 62 .103 .012 89 .153 .019 19 .203 .025 52 .253 .031 92 303 .038 39 .353 V4 95 .054 .006 75 .104 .013 02 .154 .019 31 .204 .025 65 .254 .032 05 .304 .038 52 .354 045 08 .055 .006 87 .105 .013 14 .155 .019 44 .205 .025 78 .255 .032 18 .305 .038 65 .355 .045 22 .056 .007 00 .106 .013 27 .155 .019 56 .206 .025 91 .256 .032 31 .306 M8 78 ,356 .045 35 .057 .007 12 .107 .013 39 .157 .019 69 .207 .026 03 .257 .032 44 .307 .038 91 .357 .045 48 .058 .007 25 .108 .013 52 ,158 .019 82 .208 .026 16 .258 .032 56 .308 .039 04 .358 .045 61 .059 .007 37 .109 ,013 64 .159 .019 94 .209 .026 29 .259 .032 69 .309 .039 17 .359 .045 75 .060 .007 50 .110 .013 77 .160 .020 07 .210 .026 42 .260 .032 82 .310 D39 30 .360 .045 88 .061 .007 62 .111 .013 90 .161 .020 20 .211 .026 54 .261 .032 95 .311 039 43 .361 .046 01 .062 .007 75 .112 .014 02 .162 .020 32 .212 .026 67 .262 .033 08 .312 .039 56 .362 .046 14 .063 .007 87 .113 .014 15 .163 .020 45 .213 .026 80 .263 .033 21 .313 .039 70 .363 .046 28 .064 .008 00 .114 .014 27 .164 .020 58 .214 .026 93 .264 .033 34 .314 .039 83 N .046 41 065 .008 13 ,115 .014 40 .165 .020 70 .215 .027 05 .265 .033 47 .315 .039 96 .365 046 54 .066 .008 25 .116 .014 52 .166 .020 83 .216 .027 18 .266 .033 60 ,316 .040 09 .366 D46 67 .067 ,008 38 .117 .014 65 .167 .020 96 .217 .027 31 .267 .033 72 .317 .D40 22 .367 .046 81 .068 .008 50 ,118 .014 78 .168 .021 08 .218 .027 44 .268 ,033 85 .318 MO 35 .368 .046 94 .069 .008 63 .119 .014 90 .169 .021 21 .219 .027 56 .269 .033 98 .319 040 48 .369 .047 07 .070 .008 75 .120 .015 03 .170 .021 34 .220 .027 69 .270 .034 11 320 .040 61 .370 .047 21 .071 .008 88 .121 .015 15 .171 .021 46 221 .027 82 .271 .034 24 .321 .040 74 .371 .047 34 .072 .009 00 122 .015 28 .172 .021 59 .222 .027 95 .272 .034 37 .322 .040 87 .372 .047 47 .073 .009 13 .123 .015 40 .173 .021 72 .223 .028 08 .273 .034 50 .323 .041 00 .373 .047 61 .074 .009 25 .124 .015 53 .174 .021 84 .224 .028 20 .274 .034 63 .324 .041 13 .374 .047 74 .075 .009 38 .125 .015 66 .175 .021 97 .225 .028 33 .275 .034 76 .325 .041 27 .375 .047 87 .076 .009 50 126 .015 78 .176 D22 10 .226 .028 46 .276 .034 89 .326 .941 40 .376 ,948 01 .077 .009 63 .127 .015 91 .177 .022 22 .227 .028 59 .277 .035 02 .327 .041 53 .377 .048 14 .078 .009 75 .128 .016 03 .178 .022 35 .228 .028 71 .278 .035 15 .328 .041 66 .378 .048 27 .079 .909 88 .129 .016 16 .179 .022 48 .229 .028 84 .279 .035 28 .329 .041 79 .379 .048 41 .080 .010 00 .130 M6 29 .180 .022 60 .230 .028 97 .280 .035 40 .330 .041 92 .380 .048 54 .081 .010 13 .131 .016 41 .181 .022 73 .231 .029 10 .281 .035 53 .331 .042 05 .381 .048 67 .082 .010 26 .132 .016 54 .182 .022 86 .232 .029 23 .282 .m 66 .332 .042 18 .382 .048 81 A83 .010 38 .133 .016 66 .183 .022 98 .233 .029 35 .283 .035 79 .333 .042 32 .383 .048 94 ,084 .010 51 .134 .016 79 .184 .02311 .234 .029 48 .284 .035 92 .334 .042 45 .384 049 07 .085 .010 63 .135 .016 92 .185 .023 24 .235 .029 61 .285 .036 05 .335 .042 58 ,385 .049 21 .086 .010 76 .136 .017 04 .186 .023 36 .236 .029 74 .286 .036 18 .336 .042 71 .386 .049 34 .087 .010 88 .137 .017 17 .187 .023 49 .237 .029 87 .287 .036 31 .337 .042 84 387 D49 47 .088 .011 01 .138 .017 29 .168 .023 62 .238 .029 99 .288 .036 44 .338 .042 97 .388 .049 61 .089 .011 13 .139 .017 42 .189 .023 74 .239 .030 12 .289 .036 57 .339 .043 10 .389 D49 74 .090 .011 26 .140 .017 55 .190 .023 87 .240 .030 25 .290 .036 70 .340 .043 24 .390 .049 88 .091 .011 38 .141 .017 67 .191 .024 00 .241 .030 38 .291 .036 83 .341 .043 37 .391 .050 01 .092 .011 51 .142 .017 80 .192 .024 13 .242 .030 51 .292 .036 96 .342 .043 50 .392 .050 14 .093 .011 63 .143 .017 92 .193 .024 25 .243 .030 64 .293 .037 09 .343 .043 63 .393 .050 28 .094 .011 76 .144 .018 05 .194 .024 38 .244 .030 76 .294 .037 22 .344 .043 76 .394 .050 41 .095 .011 89 .145 .018 18 .195 .024 51 .245 .030 89 .295 .037 35 .345 ,043 90 .395 .050 55 .096 .012 01 .146 .018 3D .196 .024 63 .246 .031 02 .296 .037 48 .346 .044 03 .396 .050 68 .097 .012 14 .147 .018 43 .197 .024 76 .247 .031 15 .297 .037 61 .347 .044 18 .397 .050 82 .098 .012 26 .148 .018 55 .198 .024 89 .248 .031 28 .298 .037 74 .348 .044 29 .398 .050 95 .099 .012 39 .149 .018 68 .199 .025 02 .249 .031 41 .299 .D37 87 .349 .044 42 .399 .051 08 .100 .012 51 1 .150 .018 81 .200 .025 14 ,250 .031 54 1 .300 .038 00 .350 .044 56 1 .400 .051 22 21 Notes Okonite Cables Facilities Overview *Orangeburg, SC 'Pros"i, A6 *- s * #21 AIW `Orangeburg, SC - 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(703) 904-1610 E-Mail: washington@okonite.com International Sales (201) 825-0300 FAX: (201) 825-9026 Service Centers: Houston Kansas City Pittsburgh New Orleans Portland Los Angeles *Qualified to provide nuclear Products 102 Hilltop Road, Ramsey, NJ 07446 • 201.825.0300 Fax: 201.825.9026 • wwwokonite.com % j Printed on post consumer paper 05541 COMPACT STRAND CONSTRUCTION A Uncoated, Okopact (Compact Stranded) Copper Conductor Strand Screen -Extruded Semicon- ducting EPR Insulation-Okoguard EPR Insulation Screen - Extruded Semiconducting EPR Shield Copper Tape Jacket-Okolon TS-CPE Product Deft" Segtlon 2� Shebt,l 1. Okoguard®-Okolon® TS-CPE Type MV-105 15kV Shielded Power Cable One Okopace (Compact Stranded) Copper Conductor/105°C Rating 100% and 133% Insulation Level For Cable Tray Use -Sunlight Resistant UL �'. Okoguard is Okonite's registered trade name for its exclusive ethylene -propylene (EPR) based, thermosetting compound, whose opti- mum balance of electrical and physical properties is unequaled in other solid dieleo- trics. Okoguard insulation, with the distinctive red color and a totally integrated EPR sys- tem, provides the optimum balance of electrical and physical properties for long, problem free service. The triple tandem extrusion of the screens with the insulation provides optimum electri- cal characteristics. Jp The Okolon TS-CPE jacket on this cable is a vulcanized chloronated polyethylene base compound which is mechanically rugged, flame, radiation, and oil resistant. Okoguard shielded Okolon TS-CPE Type MV-105 power cables are recommended for use as feeder circuits in electric utility gener- ating stations, for distribution circuits, and for feeders or branch circuits in industrial and commercial installations. Type MV cables may be installed in wet or dry locations, in- doors or outdoors (exposed to sunlight), in any raceway or underground duct, directly buried if installed in a system with a ground- ing conductor in close proximity that conforms with NEC Section 250.4(A)(5), or messenger supported in industrial establish- ments and electric utilities. Sizes 1/0 AWG and larger may also be installed in cable tray. Conductor: Annealed uncoated copper compact stranded per ASTM B-496. Strand Screen: Extruded semiconducting EPR strand screen. Meets or exceeds elec- trical and physical requirements of ICEA S-93-639/NEMA WC74 & S-97-682, AEIC CS8, CSA C68.3 and UL 1072. Insulation: Meets or exceeds electrical and physical requirements of ICEA S-93-639/NEMA WC74 & S-97-682, AEIC CS8, CSA C68.3 and UL 1072. Insulation Screen: Extruded semiconduct- ing EPR insulation screen. Meets or exceeds electrical and physical requirements of ICEA S-93-639/NEMA WC74 & S-97-682, AEIC CS8, CSA C68.3 and UL 1072. Shield: 5 mil bare copper tape helically ap- plied, with 25% nominal overlap. Jacket: Meets or exceeds electrical and physical requirements of ICEA S-93-639/NEMA WC74 & S-97-682, CSA C68.3 and UL 1072 for chlonated polyethyl- ene jackets. UL listed as Type MV-105, sunlight resis- tant and for use in cable tray in accordance with UL 1072, CSA listed meeting the requirements of C68.3 and rated FT4 (1/0 AWG and larger) and -40°C. Triple tandem extruded, all EPR system. Okoguard cables meet or exceed all rec- ognized industry standards (UL, CSA, AEIC, NEMA/ICEA, IEEE). 105°C continuous operating temperature. 1400C emergency rating. 2500C short circuit rating. Passes UL and IEEE 383 and 1202 (1/0 AWG & larger) Vertical Tray Flame Tests. Excellent corona resistance. Screens are clean stripping. Exceptional resistance to "treeing." Moisture resistant. Resistant to most oils, acids, and alkalies. Sunlight resistant. For Cable Tray Use; 1/0 AWG and larger. CSA FT4 and -40°C. Improved Temperature Rating. Okoguard-Okolon TS-CPE Type MV-105 15kV Shielded Power Cable One Okopact (Compact Stranded) Sp Copper Conductor/ 105°C Rating �`J 100% and 133% Insulation Level For Cable Tray Use -Sunlight Resistant ew o� J x off' `r �� ti ♦t �1 �bl g� 4, 04. Goo Oyp� +44Q'00 0a,�' +� +� +ono + 00o `��` �� GZ`gk�.A L� O G°cp"G Gdc' PAQ -40 pQQo°�a�'C�`�o�.�'�Gk�G•`�pQ�`° PQ"to PQ $SP \�P4 to ,� PSG r P�Jcaoc prcP�`o Okoguard Insulation: 175 mils (4.45mm), 100% Insulation Level 115-23-2011 2 33.6 0.67 0.73 60 1.52 0.89 22.5 585 640 165 165 - 3 115-23-2013 1 42.4 0.70 0.76 80 2.03 0.96 24.4 700 765 190 185 - 3 115-23-2015 1/0 53.5 0.73 0.79 80 2.03 1.00 25.3 790 855 215 215 220 3 115-23-2017 2/0 67.4 0.77 0.83 80 2.03 1.04 26.4 905 965 255 245 250 3 115-23-2019 3/0 85.0 0.82 0.88 80 2.03 1.09 27.6 1040 1110 290 275 290 3 115-23-2021 ' 4/0 107.0 0.87 0.93 80 2.03 1.13 28.7 1200 1280 330 315 335 3)2 115-23-2023 250 127.0 0.93 0.99 80 2.03 1.19 30.3 1370 1450 365 345 370 3,, 115-23-2027 350 177.0 1.01 1.07 80 2.03 1.28 32.4 1725 1825 440 415 460 4 115-23-2031 500 253.0 1.13 1.19 80 2.03 1.39 35.4 2255 2370 535 500 575 4 115-23-2035 750 380.0 1.31 1.37 80 2.03 1.57 39.9 3140 3320 655 610 745 5 115-23-2038 1000 507.0 1.46 1.52 80 2.03 1.73 43.9 4020 4255 755 690 890 5 Okoguard Insulation: 220 mils (5.59mm), 133% Insulation Level 115-23-2111 2 33.6 0.75 0.81 80 2.03 1.01 25.8 710 775 165 165 - 3 115-23-2113 1 42.4 0.79 0.85 80 2.03 1.05 26.7 790 860 190 185 - 3 115-23-2115 1 /0 53.5 0.82 0.88 80 2.03 1.08 27.5 880 945 215 215 220 3 2 115-23-2117 2/0 67.4 0.86 0.92 80 2.03 1.12 28.5 995 1075 255 245 250 3� 115-23-2119 3/0 85.0 0.91 0.97 80 2.03 1.18 29.9 1145 1225 290 275 290 3y 115-23-2121 4/0 107.0 0.96 1.02 80 2.03 1.22 31.1 1310 1400 330 315 335 3.y 115-23-2123 250 127.0 1.01 1.07 80 2.03 1.28 32.4 1465 1565 365 345 370 4 115-23-2127 350 177.0 1.10 1.16 80 2.03 1.37 34.7 1840 1940 440 415 460 4 ♦ 115-23-2131 500 253.0 1.22 1.28 80 2.03 1.49 37.7 2385 2570 535 500 575 5 ♦ 115-23-2135 750 380.0 1.40 1.46 80 2.03 1.66 42.2 3285 3540 655 610 745 5 115-23-2138 1000 507.0 1.54 1.60 110 2.79 1.87 47.5 4275 4540 755 690 890 6 115-23-2144 1250 633.5 1.75 1.81 110 4.33 2.08 52.7 5255 5645 845 770 995 6 115-23-2145 1500 760.2 1.88 1.94 110 4.33 2.20 56.0 6140 6540 925 845 1090 8 Visit Okonite's web site, www. okonite.com for the most up to date dimensions. ♦ Authorized Stock Item. Available from our Customer Service Centers. Aluminum Conductors (1) Aluminum conductors are available on special order. Ampacities (2) Ampacities are in accordance with Table 310.60(C)(73) of the NEC for three single Type MV-105 conductors, or single conductors twisted together (tri- plexed) and installed in an isolated conduit in air at an ambient temperature of 40°C and a conductor temperature of 105°C. (3) Ampacities are in accordance with Table 310.60(C)(77) of the NEC for three single conductors or triplexed cable in one underground raceway, three feet deep with a conductor temperature of 105'C, 100% Load Factor, an ambient earth temperature of 20°C and thermal resistance (RHO) of 90. (4) Ampacities based on single Type MV-105 conductors, or single conductors twisted together (triplexed, quadruplexed, etc.), sizes/0 AWG and larger, in- stalled in uncovered cable tray in accordance with Section 392.80(B) of the NEC at an ambient temperature of 400C and a conductor temperature rating of 105'C. In accordance with NEC Section 392.80(B)(2)(a), the ampacities are 75% of the values given in NEC Table 310.60(C)(69) (copper conductors). Where the cable tray is covered for more than six feet with solid unventilated covers, the ampacities shall not exceed 93% of the values shown above. Refer to the NEC, IEEE/ICEA-S-135 Power Cable Ampacities, or the Okonite Engineering Data Bulletin for installation in duct banks, multiple point grounded shields, other ambient temperatures, circuit configurations or installation re- quirements. (5) Recommended size of rigid or nonmetallic conduit for three conductors based on 401% maximum fill. 'The jam ratio conduit I.D. to cable O.D. should be checked to avoid possible jamming. Ramsey, New Jersey 0744E January 2014 Prices F 7/22/2014 RS Pole Option w 477 MCM ACSR Barrow to UIC Gravel Pit Cost Estimate on Single 64,6' (F-0205)pole RLS Composite 115 Kv Structures (TP-69) (9 miles) w distribution underbuild Unit Labor Total Labor Total Labor Components Description for 69 kV Unit # Units Cost Total Cost Hours Hours Cost Unit Coat Total Cost 477 MCM cable ACSR (1t) 9 miles 146,844 $1.50 $220,266,00 0.028 4,111.63 $436,963.69 54.48 $857,229.69 Shipping above cable (Ibs.) 91,631 $0.76 $69,639.30 0.002 183.26 $19,476.10 50.97 $89,115.39 64.6 RS Poles (400' Ruling span) 119 53,989.70 5473,976.36 13.500 1,603A0 S170,443.85 $5,424.41 5644,420.21 Shipping above Poles(lbs.) 126,216 $0.76 $95,163.55 0.002 250.43 $26,614.49 50.97 $121,778.04 argentAssembly 113 $954.07 $107,809,91 8.200 926.60 $98,474.42 $1,826.53 $206,284.33 Angle Assembly 6 $1,741.32 $10,099.66 9,800 56.84 $6,040.67 $2,782.82 $16,140.33 Dea"nd Assembly 4 $4,401.22 $17,604.88 14.400 57.60 $6,121.44 $5,931.58 $23,726.32 Anchors 59 $145.00 $8,626.00 8.800 517.44 $54,990.94 $1,080.22 $63,516.94 Foundation fill materials 119 22.000 2,613.60 $277,760.34 $2,338.05 $277,760.34 Shipping Misc. above to pod 72,675 $0.76 $55,167.00 0.002 145.15 $15,425,82 $0.97 $70,582.82 Cost for 9 miles 1 $1,058,242.661 10,466.35 1 $1112,311.74 $2,170,554.4 Cost/mile 9Mlles $241,172.71 Unit Labor Total Labor Total Labor Components Description for 4.18 kV Unit # Units Cost Total Cost Hours Hours Cost Unit Cost Total Cost Reusing wire from BUECI to lest House on Cakeater Rd w only new wire from last House to S Barrow and reused wire from S. Barrow to UIC #2 cable ACSR (2.25 miles from last House to Barrow S. Gas Field) 48,947 50.65 $31,815.23 0.018 881.04 $93,632.21 $2.56 $125,44T43 Shipping above cable(Ibs.) 5,237 $0.76 $3,980.33 0,002 10.47 $1,113.18 $0.97 $5093.51 4.16 kV TangentAssembly 118 $554.19 $65,394.42 5.000 590.00 $62,702.25 $1,085.57 $128:096.67 4.16 kV Angle Assembly 16 $1,763.92 $28,062.72 8.000 128.00 $13,603.20 $2,604.12 $41,665.92 4A6 kV DeadenMAssembly 8 $1,753.92 $14,031.36 8.000 64.00 $6,801.60 $2,604A2 $20,832.96 4,16 kV Anchors 120 $105.00 $12,600.00 7.000 840.00 $89,271.00 $848.93 $101,871.00 Shipping M isc. above to ped 39,130 50.76 $29,738.80 0.002 78.26 $8,317.08 $0.97 $38,055.88 Cost for 9 miles 1 $185,622.851 2,591.77 $275,440.52 $461,063,38 Cost /mile 9 Mlles $51,229.26 Cost for 9 miles for HV and 6.6 miles distribution 1 $1,243,865,511 1 13,058.131 $1,387,752.261 1 $ 631,617.77 Barrow-Atqasuk Cost Estimate on Single 64.6' (F-0205) pole RLS Composite 115 Kv Structures (TP-69) Unit Labor Total Labor Total Labor Components Description Unit# Units Cost Total Cost Hours Hours Cost Unit Cost Total Cost 477 MCM cable ACSR (it) 50miles 815,800 $1,50 $1,223,700.00 0.028 22,842.40 $2,427,576,06 $4.48 $3,651,276.06 Shipping above cable (lbs.) 509,059 $0.76 5386,884.99 0.002 1,018.12 $108,200.53 $0.97 $495,085.52 64.V RS Poles (700' Ruling span) 377 $3,989.70 $1,504,686.86 13,500 5,091.43 $541,091.67 $5,424Al $2,045,778.43 Shipping above Poles(lbs.) 397,509 $0.76 $302,106.51 0.002 795.02 $84,490.45 $0.97 $386,596.96 TangentAssembly 35B $954D7 $341,557.D6 8.200 2,935.60 $311,980.89 $1,825.53 5653,537.95 Angle Assembly 19 $1,741.32 $33,333.84 9.800 187,60 $19,937.19 $2,782.82 $53271.03 Dead-end Assembly 25 $4,401.22 $110,030.50 14.400 360.00 $38,259.00 $5,931.58 $148:289.50 Anchors 265 $145.00 $38,404.29 8.800 2,330.74 $247,699.70 $1,080.22 $286,103.98 Foundation fill materials 377 22.000 8,297.14 $881,778.86 $2,338.05 $881,778.86 Shipping MI-. above to ped 258,818 $0.76 $196,701,57 0.002 517.64 $55,011.74 $0.97 $251,713.31 Dampers 1,131 $28.84 $32,630.40 0.500 565.71 $60,121.29 $81.98 $92,751.69 Mob & Demob Lot $600 000.00 Cast for 50 miles1 $4,170,036.02 44,941.40 $4,776,147.27 59,546,183.29 Cost/mile 50 Miles $190,923.67 Barrow-Atqasuk Cost Estimate on three (3) 62.4' (F-0104) pole RLS Composite 115 kV Structures Unit Labor Total Labor Total Labor Components Description Unit • Units Cost Total Cost Hours Hours Cost Unit Cost Total Cost 477 MCM cable ACSR with T2 (ft.) 50miles 815,800 $1.50 $1,223,700.00 0.028 22,842.40 $2,427,576.06 $4A8 $3,651,276.06 Shipping above cable(lbs.) 509,059 S0.76 $386,884.99 0.002 1,018.12 $108,200.53 $0.97 $495,085.52 62.4' RS Poles (674' Ruling Span down from NESC min to 40' from 1,024 ft) 1,175 $3,169.44 $3,724,327.12 13.500 15,863.50 $1,686,893.62 $4,604.16 $5,410,220.74 Shipping above Poles (Ibs.) 995,288 $0.76 $756,418.75 0,002 1.990.58 $211,548.43 $0.97 $967,967.18 Tangent Assembly 1,116 $320.00 $357,120.00 8.200 9,161.20 $972,543.78 $1,191.46 $1,329,663.78 Angle Assembly 20 $1,741.32 $34,289.02 9.800 192.98 $20,508A9 $2,782.82 $54,79T51 Deadend Assembly 25 $4,401.22 $110,030.50 14.400 360.00 $38,259.00 $5,931.58 $148.289.50 nchors 268 $145.00 $38,881,51 8.800 2,359.71 $250.777.72 $1,080.22 $289,6,%23 Foundation fill materials 1,175 22.000 25,851.63 $2,747,382.20 $2,338.05 $2,747,382.20 Shipping Misc. above to ped 601,138 S0.76 $466,865.15 0.002 1,202.28 $127,771.96 $0.97 $684,637.11 Power Lire Santry Bird Flight DNerters 15,086 $15.00 S226,285.71 0.250 3,771.43 $400,808.57 $41.57 $627,094.29 Dampers 1,175 $28.64 $33,989,14 0.500 587.54 $62,440.50 $81.98 $96,329.64 Cost for 50 miles 1 $7,348,691.90 85,191.35 $9,053,710.86 $16,402,402.76 Cost/mile 50 Mlles $828,048.08 Barrow Cost Estimate For 69 kV Connection w/ 4.16AV UG Feed in/out to NSB Sub Unit Labor Total Labor Total Labor Components Description Unit t Units Cost Total Cost Hours Hours Cost Unit Cost Total Cost 2 MVA Transformer 4.1 kV to 69 kV 1 $72,000 $72,000.00 36.000 36.00 $3,825.90 $75,825.90 $75,825.90 69 kV Breaker/Switchers 4 $55,200 $220,800.00 38,000 162.00 $16,153.80 $5%238.45 $236,953.80 4160 V breaker Bred at BUECI for Oe to ATQ Gdtl 1 $216,000 $216,000.00 300.000 300.00 $31,882.50 $247,882.50 $247,882.50 69 kV Takeoff structure 1 $35,000 $35,000.00 250.000 250.00 $26,568.75 $61,668.75 $61,568.75 4160 V cable to Transformer 750 $15 $11,260.00 3.000 2,250.00 $239,118.75 $333.83 S250,368.75 4160 V Fuse Disconnect at Transformer 1 $4,500 $4,500.00 30,000 30.00 $3,188.26 $7,698.25 $7,688.25 Substation fencing and grounding 1 $30,000 $30,000.00 150.000 150.00 $15,941.26 $46,941.25 $45,941.26 SCADA link 1 $81,600 $81.600.00 60.000 60.00 $6,376.50 $87,976.50 $87,976.60 Platforms 3 $5,760 $17,280.00 36,000 108.t10 $11,477.70 $9,585.90 $28,757,70 Shipping Misc. above to ped 60,000 S0.76 545,600.00 0.006 360.00 S38,259.00 $1.40 $83,869.00 Walakpa Cost Estimate For Connection Unit Labor Total Labor Total Labor Domponents Description Unit • Units Cost Total Cost Hours Hours Cost Unit Cost Total Cost 300 kVA Transformer 69 kV to 480V 1 $22,500 $22,500,00 26,000 26.00 $2,763.15 $26,263.16 $25,263.15 39 kV Fuses 1 $7,800 S7,800.00 18.500 18.50 $1,966.09 $9,766.09 S9,766.09 -latforms 1 $5,760 $5,760.00 36,000 36.00 $3,825.90 $9,585.90 $9,585.90 3CADAIMetedng link 1 $28,800 $28,800.00 60.000 60.00 $6,376.50 $35,176.50 $35,176.50 Shipping Misc. above to ped 25.000 $0.76 S19.000.00 0.006 150.00 S15.941.25 S1 40 S.0 941 25 Atqasuk Cost Estimate For Connection Unit Labor Total Labor Total Labor Components Description Unit t Units Cost Total Cost Hours Hours Cost Unit Cost Total Cost 2 MVA Transformer 4.16 kV to 69 Kv 1 $90,000 $90,000.00 36.000 36.00 $3,825.90 S93,826A0 $93,826.90 4 MVAR Reactor 69kV 4 $70,000 $280,000.00 36.000 144.00 $15,303.60 $73,825.90 $295,303.60 69 KV Breaker 1 $86,400 $86,400.00 60.000 60.00 $6,376.50 $92,776.50 $92,776.50 4160 V breaker erect for tle to Atqasuk Grid 1 $45,000 $45,000.00 300.000 W,00 $5,313.75 $50,313.75 $50,313.75 SCADA/Metering link 1 $81,600 $81,600.00 60.000 1.00 $106.28 $81,706.28 $81,70628 ABB 500 WA Statcom/PCS 1 $312,000 $312,000.00 60.000 60.00 $6,376.50 $318,377 S318,376.50 Plalforms 3 $5,760 $17,280.00 36.00D 108.D0 $11,477.71) $9,585.90 $28,757.70 Shipping Misc. above to pad 72,000 $0.76 $54,720.00 0.006 432.00 $45,910.80 $1.40 $100,630.80 Mob & Demob Lot $50,000.00 $967,000.00 91.00 94,691.03 S7,i H,691.03 CostlEach 1 Each $1,111,691.03 Assumptions: 1. 9 miles of single pole w underbuild from BUECI to UIC Gravel Pd and 9.7 milesfrom there to Walakpa Ct and 53.2 miles of line on single pole structures to Atqasuk 2. 1&8 miles line on three pole structures w 6A miles to Walakpa from Walak Jct antl 9.7 miles from UIC Gravel Pit to Walakpa Jet. 3. Power Line communication are included in Option 1 and Option 2 4. Materials are FOB Seattle COSTS SUMMARY A. Cost for 9 miles for HV and 5.6 miles distribution from Barrow to UIC Gravel Pit 1 $2,631,617.77 B. (Single pole) Line Costs UIC Gravel Pit to Walakpa Jct, (9.7 miles) Option 1 $1,851,959.66 Walakpa Jct. to Atqasuk Single pole Line Costs (53.2 miles) Option 1 $10,157,139.02 Walakpa Jet. to WalakpaSingle Pole 6.1 miles Option 1 $1,,64,634.36 Total Costs Single Pole Line Option 1 $13,173,73z.84 C. (3 poles) Line Costs UIC Gravel to Walakpa Jct. (9.7 miles) Option 2 $3,182,066.14 Walakpa Jet. to Atqasuk Single pole Line Costs (53.2 miles) Option 2 $10,157,139.02 WalakpaJct. to Walakpa3 poles)6.1 miles Option 2 $2,001,093.14 Total Line Costs for Option 2 $16,340,298.29 F. Supervisory Control and Data Acquisition SCADA $200,000.00 G. Atqasuk replacement transformers 1 $144,960.00 (Option #1) Total Line & Sub Costs are A+B+D+E+F+G $18,684,184.52 (Option #2) Total Line & Sub Costs are A+C+D+E+F+G $20,850,711.33 98 STAT. 468 PUBLIC LAW 98-366--JULY 17, 1984 Public Law 98-366 98th Congress An Act .iuf 1 574014 �1H_R. 574t1) Entitled, the "Darrow Gas Field Transfer Act of 1984"' Be it enacted by the Senate and House of Representatives of the Burrow Gas United States of America in Congress assembled, Field Transfer Act of 1994. SwnoN 1. The following may be cited as the "Barrow Gas Field Alaska. Transfer Act of 1984". Ssc. 2. (a) The Secretary of the Interior thereinafter "the Secre- tary") shall convey to the North Slope Borough the subsurface estate held by the United States to the Barrow gas fields and the Walakpa gas discovery site, related support facilities, other lands, interests, and funds in accordance with the terms and conditions of the agreement, including appendix numbered 1, between the Secre- tary of the Interior and the North Slope Borough dated September 22, 1983 thereinafter "the NSB Agreement"), on file with the Senate Energy and Natural Resources Committee and the House Interior and Insular Affairs Committee, which is hereby incorporated into this Act. Research and (b) Upon conveyance, the North Slope Borough is authorized, development. notwithstanding any other provision of law, to explore for, develop, and produce fluid hydrocarbons within the lands and interests granted: Provided, That section 301(a) of the NSB Agreement shall not reduce revenues which would otherwise be shared with the State 94 sta►t. 2957. of Alaska under the provisions of Public Law 96-514 by providing for the disposition of gas at less than the value referred to in section 301(d) of the NSB Agreement or as a result of the crediting provi- sions of section 301(aX3) of the NSB Agreement. (c) The Barrow gas fields and related support facilities shall 49 USC app. 1671 continue to be exempt from the Pipeline Safety Act, title 49 of the note. Code of Federal Regulations, and all other rules and regulations governing the design, construction, and operation of gas pipelines, wells, and related facilities, 42 USC; 4321 (d) The provisions of the National Environmental Policy Act shall note. apply to any land conveyance under section 203(b) of the NSB Fish and fishing. Wildlife, Agreement. During the NEPA process, the North Slope Borough shall consult with the United States Fish and Wildlife Service, the Cultural Aprogramslaska Department of Fish and Game, and the National Park Historic Service concerning the fish, wildlife, cultural, and historic values of preservation. the area to be selected. The Secretary is authorized to approve or deny the selection. If denied, the North Slope Borough shall be entitled to identify an alternative site, which shall be subject to the review process set forth in this section. (e) The North Slope Borough shall not make a selection under section 203(b) of the NSB Agreement in areas designated by the Congress or the Secretary under section 104(b) of the Naval Petro- 42 USC 6W4. leum Reserves Production Act of 1976 for the protection of surface values, as depicted on the map set forth on page 125 of the "Final Environmental Impact Statement on Oil and Gas Leasing in the National Petroleum Reserve in Alaska" dated February 1983, or PUBLIC LAW 98-3136—JULY 17, 1984 98 STAT. 469 within the boundaries of the Kasegaluk Lagoon Potential Natural Landmark as identified in study report numbered 2 prepared pursu- ant to section 105(c) of that Act, or within any area withdrawn or 42 USC". Wk designated for study pursuant to section 604 of the Alaska National Interest Lands Conservation Act. 1G use 1276. (f) Notwithstanding the time limit specified in the NSB Agree- ment, the North Slope Borough shall have ten years from: the date of this Act to make its selection under section 203(b) of the NSB Agreement. If, within ninety days of the expiration of the ten-year period, or after the expiration of such period, the Secretary denies any selection, the North Slope Borough shall select an alternative site within ninety days of such denial. If an alternative site is denied, the selection and review process in this subsection shall be repeated until a site is approved by the Secretary-.. (g) Notwithstanding any provision of the NSB Agreement, the Water - .North Slope Borough shall obtain the right to divert, use, appropri- ate, or possm water solely through compliance with applicable laws of the United States and the State of Alaska. (h) Notwithstanding any provision of the NSB Agreement, the right of the North Slope Borough to exploit gas and entrained liquid hydrocarbons from Federal test wells in the National Petroleum Reserve -Alaska shall not apply to test wells in areas designated by the Congress or the Secretary under section 104(b) of the Naval Petroleum Reserves Production Act of 1976 for the protection of 42 USC 6-5 }- surface values, as depicted on the map set forth on page 125 of the "Final Environmental Impact Statement on. Oil and Gas Lensing in the National Petroleum Reserve in Alaska" dated February 1983, or within the boundaries of the Kasegaluk Lagoon Potential Natural Landmark as identified in study report numbered 2 prepared pursu- ant to section 105(c) of that Act, or within any area withdrawn or V USC 6:05- designated for study pursuant to section 604 of the Alaska National Interest Lands Conservation Act. 16 USC 1276. 0) The Secretary shall process any application submitted by the North Slope Borough under section "a)of the NSB A meet for =war which crosses, in whole or in part, any lanceds within a r*htf andesignated bythe CongressortheSec104 of the Naval Petroleum Reserves Production Act of 1y76 for 42 use 65114. the protection of surface values, as depicted on the snap set forth on page 125 of the "Final Environmental Impact Statement on Oil and Gas Leasing in the National Petroleum Reserve in Alaska" dated February 1983, or within the boundaries of the Kasegaluk Lagoon Potential Natural Landmark as identified in study report numbered 2 prepared pursuant to section 105(c) of that Act, or within any area 42 USC 65015, withdrawn or designated for study pursuant to section 604 of the .Alaska National interest Lands Conservation Act, under the provi- 16 USG• 1.276. sions of title Ki of the Alaska National interest Lands Conservation Act. In processing any such application for a right-of-way which 16 USc Nisi. crosses, in whole or in part, any lands within any area designated by the Congress or the Secretary under section 104(b) of the Naval Petroleum Reserves Production Act of 1976, the protection of the 42 USC 6504. values and the continuation of the uses specified in section 104(b) of that Act shall be considered to be the purposes for which the area was established. 0) Nothing in this Act or in the NSB Agreeme nt ment shall be con- strued as amending the provisions of the Alaska National interest Lands Conservation Act or as amending or repealing any other 16 USC 2101 note. 98 STAT. 470 PUBLIC LAW 98-366—JULY 17, 1984 provision of law applicable to any conservation system unit, as that 16 USC 31ft term is defined in section 102(4) of that Act. Ukpeagvik Sec. 3. The Secretary of the Interior shall convey to Ukpeagvik. inupiat Corporation. Inupiat Corporation (hereinafter "UIC", subject to valid existing rights, all right, title, and interest held by the United States to sand and gravel underlying the surface estate owned by UIC in the Barrow gas fields and Walakpa gas discovery site, upon execution of an easement agreement with the North Slope Borough, satisfactory to the North Borough, in consideration for the conveyance to UIC of such sand and gravel, providing for easements, for all purposes associated with operation, maintenance, development, pro- duction, generation, or transportation of energy, including the transmission of electricity, from the Barrow gas fields, the Walakpa discoverysite, or from any other source of energy chosen by the North Sope Borough, to supply energy to Barrow, Wainwright, and Atkasook, and providing such easements when and where required as determined by the North Slope Borough during the life of such fields or other energy sources. SEc. 4. (a) Section 102 of the Naval Petroleum Reserves Production Act of 1976 (42 U.S.C. 6502) is amended by adding "and the North Slope Borough" immediately after "Alaska Natives", by deleting "and" immediately after "responsibilities under this Act,", and by replacing the period following "Alaska Native Claims Settlement Act" with ", and (4) grant such rights -of -way to the North Slope Borough, under the provisions of title V of the Federal Land Policy 43 USC 1761. and Management Act of 1976 or section 28 of the Mineral Leasing 30 USC 185, Act, as amended, as may be necessary to permit the North Slope Borough to provide energy supplies to villages on the North Slope." (b) Section 104(e) of the Naval Petroleum Reserves Production Act of 1976 (42 U.S.C. 6W4(e)) is repealed effective October 1, 1984. Arctic slope SEc. 5. (a) In consideration for the relinquishment of rights that Regional, Corporation. Arctic Slope Regional Corporation has under section 1431(o) of the Alaska National Interest Lands Conservation Act, Public Law 96- 94 Stat. 2533, 487, 94 Stat. 2371, 2541, to the subsurface resources in the Barrow gas fields and the Walakpa gas discovery site conveyed to the North Slope Borough and Ukpeagvik Inupiat Co ration pursuant to sections 2 and 3 of this Act, the Secretary of the Interior and Arctic Slope Regional Corporation are authorized to exchange lands and interests as set forth in the se rate agreement between the Secre- tary and Arctic Slope Itegionai Corporation dated �Ianuary 24, 1984 (hereinafter "the ASRC Agreement"), on file with the Senate Energy and Natural Resources Committee and the House Interior and Insular Affairs Committee. The specific terms, conditions, and covenants of the ASRC Agreement are hereby incorporated into this Act and ratified, as to the rights, duties, and obligations of the United States and Arctic Slope Regional Corporation and as to the rightsand nd interests of the North Slope Borough, as a matter of F (b) Notwithstanding the provisions of paragraph 4 of the ASRC Agreement, in lieu of the additional 69,120 acres of subsurface estate to be identified by ASRC pursuant to said Paragraph 4, ASRC shall identify for conveyance or relinquishment to the United States, as appropriate, the 101,272 acres of subsurface estate beneath the surface estate of the lands described in subparagraphs 2 (a), (b) and (d) of the August 9, 1983 agreement between Arctic Slope Regional Corporation and the United States of America. PUBLIC LAW 98-366--DULY 17,1 84 98 STAT. 471 (c) To the extent that any provision or interpretation of the NB Agreement is inconsistent with the provisions of this section or the ASRC Agreement, the provisions of this section and of the ASRC Agreement shall prevail. (d) All of the lands, or interest therein, conveyed to and received Arctic Slope by Arctic Slope Regional Corporation pursuant to this section or the Regional ASRC Agreement and pursuant to the August 9, 1983 agreement Corporation. between Arctic Slope Regional Corporation and the united States of America shall, in addition to other applicable authority, be deemed conveyed and received pursuant to exchanges under section 22(f) of the Alaska Native Claims Settlement Act, as amended (43 U.S.C. 1601,1621(f)). Approved July 17, 1984. LEGMIATME HIsWltY---H.R. 57417 HOUSE REPORT No. 9"43 (Comm. on Interior and Insular Affairst, CONGRESSIONAL RECORD, Vol. 130 t1984): June 18, considered and passed House; ,tune 28, considered and passed Senate. ! I ! I u n I � 8 E E I a 1 I A a 0 � W E E o E E t= �'96 r T Y .o c W m m° U0 0 c o °Q m S r ¢ C7 v W "m c w d Yo c d l N •. �' E c 75 c c c c 3 c u v E u iv uai f W o o o c W y g c c c r� `m t G o l7 ¢ w a+ m E c m c W N N N W N O C y W >> C a! Ol Z J J a 00 to �F .a i O I �p to N > C C AC W Y O U O O y L L L d d d b0 Z N ct N Y d I W 4e m m a w _€ c a �o c d c aci 8 E-2 Y 101.4 x x a n Y Y Y Y E m' r 2 uo W H a a a a u r a