HomeMy WebLinkAboutATQ planning studyAtqasuk Transmission Line
Feasibility and Planning Study
FINAL REPORT
September 15, 2011
Project Sponsors:
ALASKA
ENERGY AUTHORITY
r North Slope Borough
Prepared by:
Leland A Johnson & Associates
0
Report of Findings
Table of Contents
Table of Contents
List of Figures
List of Tables
1. Executive Summary
Page
i
vi
vii
A. Summary .....................................................................................................1
2. Introduction
A. Background....................................................................................................................
3
B. Project Sponsors and Organization................................................................................
3
C. Project Objectives..........................................................................................4
D. Project Description ....... :.......... .....................................................................5
3. Engineering Design Basis & Performance Criterion
A. Project Design Engineering Scope Description.............................................................
7
B. Route Description...........................................................................................................
7
B.1 Atqasuk Power Transmission ROW WRA and ER-2
C. Recommended Structures.............................................................................................
7
D. Electrical Loading.................................................................................--.....................
8
E. Transmission Line Components — Basis & Performance Criterion ................................ 8
E.1 Structure Types...........................................................................................8
E.2 Weather Data Parameters..........................................................................................
8
E.3 Conductors...................................................................................................................• 9
EAAeolian Vibration..........................................................................................................
9
E.5 Sag & Tension............................................................................................................
10
E.6 Loading & Overload Factor........................................................................................
10
E.7 Ground Clearance......................................................................................................
10
E.8 Load Flow Report at 34.5 kV AC..........................................................................
. ..... 10
E.9 Load Flow Report at 69 kV AC ........... ................... ................ ........... .......................... 10
E.10 Load Flow Report at 30 kV DC..................................................................................
11
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E.11 Load Flow Report at 50 kV DC.................................................................................. 11
E.12 One -Line Description for AC Operation..................................................................... 11
E.13 One -Line Description for DC Operation...........................................................12
E.14 HVDC Evaluation........................................................................................13
4. Geotechnical Engineering — Review & Commentary
A. Purpose & Objectives................................................................................................... 16
B. Prior work .................. ....................... ..... __..... ........................................................ ..... 16
C. Geologic & Geotechnical Findings/Considerations...................................................... 16
C.1 Surface & Shallow Subsurface Geology.................................................................... 16
C.2 Routing: Geologic Considerations.............................................................................. 17
C.3 Geo-hazards.............................................................................................................. 17
D. Geotechnical Considerations for Timber, Steel, & Fiber Reinforced Polymer (FRP) Poles
.........................................................................................................1.19
E. Geotechnical Considerations & Recommendations..................................................... 20
E.1 Alignment Routing............ ................... ....................................................................... 20
E.2 Fiber Reinforced Polymer (FRP) Structures............................................................... 21
5. Constructability Analysis, Technical Feasibility, & Cost Estimates
A. Purpose, Objective, & Scope of Work.......................................................................... 22
B. Physical Description..................................................................................................... 22
C.
Basis of Estimate......................................................................................................... 22
D.
Eastern Route 2 (ER2) — Physical Description & Basis of Estimate ............................
23
D.1
Barrow Substation — ER2...........................................................................................
23
D.2
Barrow to South Pad Line Segment ER2 — Length: 5.8 Miles ...................................
23
D.3
South Pad to Atqasuk ER2 — Overhead (OH) Line Segment — Length: 62.6 Miles...
24
DA
Tie-in for Walapka Gas Field to ER2 Segment — Length: 6.2 Miles ...........................
24
D.5
Atqasuk Substation ER2............................................................................................
5
E. Western Route 2 (WR1) — Physical Description & Basis of Estimate ..........................
25
E.1
Barrow Substation Western Route 1(WR1)...............................................................
25
E.2
South Pad Line Segment WR1 — Length: 5.8 Miles ...................................................
25
E.3
South Pad to Walapka Segment on VSM's, WR1 — Length: 18.8 Miles ....................
26
EA
Tie-in for Walapka Gas Field Segment, WR1 — Length: 0.2 Miles .............................
26
E.5
Walapka to Atqasuk, Overhead (OH) Line Segment, WR1 — Length: 48.8 Miles ......
27
E.6
Atqasuk Substation Western Route 1 (WR1).............................................................
27
F. Residence & Facility Heating Conversion in Atqasuk — From Diesel to Electric ..........
27
H. Review of Items Covered in Initial Matrix — Cost Per Mile..................................................29
J. Recommendations — Routing & Construction Methods ................................................
29
J.1
Best Route Recommendation —Eastern Route 1, AC Power Supply ..........................
30
J.2
Western Route is Not Recommended as the Best - Reasons ....................................
30
J.3
Other Report Data Utilized (AC Power Supply) — Polar Consult Report ...................
30
JA
Maintenance Requirements — AC Power Supply........................................................
31
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K. Estimate Basis Issues that Need Clear Understanding........ ........................................ 32
6. Environmental Considerations
A. Introduction................................................................................................................... 33
B. Methods........................................................................................................................34
B.1 Avian Resources........................................................................................................ 34
B.2 Mapping Spectacled Eider Breeding Habitats............................................................ 35
C. Results & Discussion................................................................................................... 36
C.1 Avian Resources........................................................................................................ 36
C.2 Spectacled Eider........................................................................................................ 37
C.3 Steller's Eider............................................................................................................. 38
CAYellow -billed Loons.................................................................................................... 39
C.5 Other Species of Concern.......................................................................................... 39
D. Spectacled Eider Habitats in the Project Area............................................................. 40
E. Potential Affects of Power Lines on Birds at the North Slope ...................................... 41
E.1 Collisions............................................................................................................41
E.2 Electrocutions............................................................................................................. 42
E.3 Habitat Loss............................................................................................................... 42
EA Increased Predation Due to Habitat Enhancement.................................................... 42
F. Wildlife and Habitat Related Regulations Affecting the Proposed Power Line ............. 42
G. Recommendations for Power Line Alignment: Re: Birds & Wetland Habitats ............ 43
L. List of Exhibits or Figures............................................................................................. 44
7. Permitting Considerations
A. Introduction................................................................................................................... 49
B. Federal Permits & Authorizations................................................................................. 49
C. State Permits & Authorizations.................................................................................... 51
D. North Slope Borough Permits & Authorizations........................................................... 55
E. Permitting Support — Engineering...................................................................57
8. Economic Analysis
A. Objective...................................................................................................................... 59
B. Methodology & Assumptions........................................................................................ 61
C. "Without Project" Case: Diesel -Based Power Generation & Heating System .............. 63
C.1 Annual Operations & Maintenance (O&M) Costs ....................................................... 65
C.2 Replacement & Overhaul Costs for Diesel Generation Units ..................................... 66
C.3 Summary of Cost Flows Associated with Existing Diesel -Based Power & Heating ... 66
D. Proposed Intertie Project Alternatives: "With Project Case" .................................. 68
D.1 Costs Associated with the Proposed Intertie Project ................................................. 68
D.2 Costs of Purchasing Electricity from Barrow.............................................................. 69
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D.3 Electric Power Only Scenario..................................................................................... 69
DA Electric Power & Heat Scenario................................................................................. 69
D.5 Annual O&M Costs of Atqasuk Facilities.................................................................... 69
D.6 Capital Costs of Electric Heating Conversion............................................................ 70
D.7 Cost Flows for Project Alternatives............................................................................ 71
E. Financing Costs............................................................................................................ 80
E.1 Results for NPV of Cost Savings After Financing Costs ............................................ 81
E.2 Sensitivity Analysis..................................................................................................... 82
F. Economic Summary ...................................................................................................... 83
9. Conclusions & Recommendations
A. Conclusions................................................................................................................84
B. Recommendations.........................................................................................86
10. References.............................................................................................87
Appendix A Design Engineering
EXHIBIT 1 - Structure Types
EXHIBIT 2 - Weather Data Parameters
EXHIBIT 3 - Recommended RUS Conductor Tension
EXHIBIT 4 - Aeolian Vibration
EXHIBIT 5 - Conductor Sag and Tension
EXHIBIT 6 - Conductor Loading and Overload Factors
EXHIBIT 7 - Conductor Ground Clearances
EXHIBIT 8 - Load Flow Report at 34.5 kV AC
EXHIBIT 9 - Load Flow Report at 69 kV AC
EXHIBIT 10 - Load Flow Report at 30 kV DC
EXHIBIT 11 - Load Flow Report at 50 kV DC
EXHIBIT 12 - One -Line Description for AC Operation
EXHIBIT 13 - One -Line Description for DC Operation
EXHIBIT 14 - High Voltage Direct Current (HVDC) Evaluation
Appendix B Geotechnical Engineering
EXHIBIT 1 — RS Group FRP Utility Pole Product Literature
Appendix C Constructability Analysis & Cost Estimates
EXHIBIT 1 - Eastern Route 2, ER2 Cost Estimate - AC Power Transmission, All Overhead
EXHIBIT 2 - Western Route 1, WR1 Cost Estimate - AC Power Transmission, All Overhead
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Table of Contents
Appendix D Environmental Considerations
Figure 1 - Western Spectacled Eider Observations: 1992 to 2005
Figure 2 - Spectacled Eider Observations: 1999 to 2010
Figure 3 - High -value Breeding Habitats — Spectacled Eiders
Figure 4 - Steller's Eider Observations: 1999 to 2010
Figure 5 - Yellow -Billed Loon Observations: 1950 to 2010
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Table of Contents
List of Figures
Figure 1 Atgasuk Transmission Line Routes....................................................7
Figure 2 Schematic for DC Operation .............................................. ........12
Figure 3 Net Present Value of Cost Savings by Project Alternatives....................60
Figure 4 Variable Costs per kWH, Current Situation vs Project Alternatives ........61
Figure 5 NPV of Cost Savings with Financing Costs........................................81
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Is
Table of Contents
List of Tables
Table 1
Threatened and Candidate Bird Species Listed Under the ESA.......................................45
Table 2
Identification of High - value Nesting Habitat..................................................................47
Table 3
Classification Crosswalk Table Between NWI Wetland Types and
WildlifeHabitat Types........................................................................................
8
Table 4 Net Present Value of Cost Savings..........................................................................59
Table 5
Benefit - Cost Ratio of the Proposed Intertie Project Alternatives.................................60
Table 6
Barrow Gas Field Gas Reserves..........................................................................63
Table 7
Diesel Fuel Consumption Atqasuk Fiscal Year 2010................................................65
Table 8
Annual O&M Costs of NSB Power and Fuel Facilities, Fiscal Year 2010.......................65
Table 9
Annual Cost Incurred in Selected Future Years Under the "Without Project" Case .......... 67
Table 10
Estimated Capital Costs of the Intertie...................................................................68
Table 11
Annual O&M Costs of the Intertie..........................................................................68
Table 12
Annual Electricity Requirements and Cost of Purchased Electricity from Barrow ............
69
Table 13
Estimated Annual Fuel Costs for Power and for Heating Under Various Scenarios .........
70
Table 14
Estimated Annual Non -Fuel Costs for Utility O&M Facilities under various Scenarios ......
70
Table 15
Cost Flows With Project - Eastern Route with AC for Power and Heat ..........................72
Table 16
Cost Flows With Project - Eastern Route with AC for Power Only................................73
Table 17
Cost Flows With Project - Eastern Route with DC for Power and Heat ..........................74
Table 18
Cost Flows With Project - Eastern Route with DC for Power Only................................75
Table 19
Cost Flows With Project - Western Route with DC for Power and Heat .........................
76
Table 20
Cost Flows With Project - Western Route with DC for Power Only...............................77
Table 21
Cost Flows With Project - Western Route with AC for Power and Heat.........................78
Table 22
Cost Flows With Project - Western Route with AC for Power Only ...............................
79
Table 23
Annual Financing Costs for Project Alternatives.......................................................
80
Table 24
Sensitivity Analysis of NPV for Eastern Route Alternatives.........................................83
Table 25
Sensitivity Analysis of NPV for Western Route Alternatives........................................83
Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
00
1. - Executive Summary
The North Slope Borough is seeking to reduce its dependency on the use of high priced and unstable
cost of imported diesel fuel to meet its energy needs in its Villages. Atqasuk is one of the most expensive
Borough villages to supply with imported fuel oil. This study investigates 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 fuel oil used in Atqasuk to meet both power and space heating
requirements in the village. The results of the study found that the project:
• Provides significant cost savings over the continued use of diesel fuel in Atqasuk
• Provides stable energy costs for the village of Atqasuk
• Is technically feasible
• Is feasible to construct
• Has a predictable outcome
• Minimizes the impact to the North Slope environment
• Will provide broadband capabilities to Atqasuk
Economic Analysis
Eight project alternatives were evaluated and all are economically feasible compared to the current
diesel -based system for power generation and heating. The economics of the alternatives are
summarized in the following table.
Net Present Value of Cost Savings of the Intertie Project Alternatives
Eastern Route Western Route
AC current DC current AC current DC current
Power Only $35,324,295 $27,156,697 $17,246,575 $15,621,944
Power and Heat $50,675,352 $42,507,754 $32,597,631 $30,973,001
The above analysis assumes a 35 year life.
Project Concept
The recommended Power Line, as a result of this study is Eastern Route 2 (ER2), at approximately 68
miles in length and at an estimated cost of $16.7MM. This route utilizes existing infrastructure, avoids
lakes and significant surface water, avoids existing Native Allotments, is the shortest and most economic
route, minimizes river crossings and to the best extent possible avoids dense avian nesting areas and
populations.
AC versus DC Evaluation
Alternating Current AC has emerged as the recommended power type selection. This option has lower
initial capital costs, has greater reliability, better equipment availability, and has a proven track record for
this type of commercial application. DC conversion technology in the size required is not mature enough
to be considered for this project.
Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
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Structures
The recommended structure for this application is a 69 kV Transmission Line Structure, the TP-69. The
A Typical pole selected, for most of the line, is a 65 foot long Fiber Reinforced Polymer (FRP) pole. This
structure proved to be the most economic alternative compared to other structures. The light weight,
strength and sectional single pole structure allows for ease of installation and spans of 700 feet.
Project Delivery Schedule
Construction should occur during the winter season, to prevent damage to the tundra flora, enable ad -
freeze pile installation, enable tundra access for logistical support, and minimize impact to migratory avian
populations.
Based on the demand impact on the BUECI power plant system, the Transmission line should be
installed in stages. The first phase would begin in 2013 and would involve connecting the transmission
line to the Village power system only. The second phase would begin in 2015 and would involve the
conversion of residential homes to electrical space heat. Non-residential space heating load is significant
enough however to require the conversion of non-residential space heating loads to be brought on as the
BUECI power facility improves its power capacity.
G1
The increase in gas consumption in Barrow by the addition of the electrical load or both the electrical and
heating load from Atqasuk would have a minimal impact on the overall Barrow Gas Field production rate
and reserves.
Recommendations
• Conduct a field reconnaissance trip to evaluate and "field adjust' the selected ROW alignment.
• Perform land surveys, soil sampling, river crossing site evaluations, etc.
• Along the proposed routes, determine ice jam issues, snowdrift zones, probe guy and anchor
locations and do geotech explorations at long spa areas as the preliminary engineering effort
develops.
• Study and determine power line height vis-a-vis eider collision hazard in Alaska.
• Perform tests on FRP poles to confirm their suitability for use in the permafrost soils that will be
encountered on this project.
• 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.
• Update the economic analysis.
• Investigate financial incentives including grants, low -interest loans, tax credits, depreciation
deductions and other types of federal, state or private financial assistance that may be available.
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Report of Findings
2. - Introduction
A. Background
The North Slope Borough (NSB) is aggressively exploring ways to provide heat and power to the NSB
villages but reduce its dependence on costly and unstable price of diesel fuel which is currently barged or
flown to NSB villages. A previous feasibility study evaluated a wide range of energy resources and
technologies for the purpose of reducing energy costs in Atkasuk. Atkasuk is one of the most expensive
villages to energize because of its inland location and the associated extra cost of overland fuel delivery.
The previous study concluded that electricity produced in Barrow using natural gas and transmitted via
overhead power lines to Atkasuk was the most economically attractive alternative. This is potentially the
first phase of a planned expansion of electrical support to other villages on the North Slope of Alaska. A
power line to Wainwright is the logical next step. The added electrical load for such an extension was
considered in the design of certain power transmission components in this study.
This project would also reduce the carbon "footprint' for these communities, which ultimately will be
beneficial to the health of the residents and for wildlife populations. There are some potential negative
benefits to endangered avian species and waterfowl habitats in the project area. An assessment of these
potential costs and mitigation means are also an important focus of this report.
B. Project Sponsors and Organization
The NSB acquired an Alaska Energy Authority (AEA) Renewable Energy Grant to study the possibility of
providing a more economic power supply to the village of Atqasuk. The village is located approximately
65 miles southwest of Barrow, on the Arctic Coastal Plain. Power would be provided via a new power
transmission line that would link existing gas fired power generation capacity at Barrow with the power
needs at Atqasuk.
North Slope Borough (NSB) stakeholders, and their assigned representatives, have commissioned this
A effort.
Io
so A Steering Committee was convened to ensure that community and borough objectives are being
adequately addressed and the project remains under control. These responsibilities were carried out by
so performing the following functions:
Control project Scope by ensuring that scope of work aligns with the requirements of project
sponsors, AEA and key stakeholder groups, City of Atqasuk and NSB.
Keep community informed of project activities and findings.
• Provide input on Project scenarios and evaluation criteria.
Providing assistance to the project when required.
Attend/participate in Steering Committee and Project monthly meetings, including conference
calls, workshops, and other meetings as needed.
Acceptance of project deliverables
The Steering Committee established appropriate screening criteria for the power transmission system.
Technical support and local control. A measure of the degree to which the start up and
3 Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
operation of an energy concept would require outside technical support; a high level of local
control is ideal.
• Technology maturity or readiness. A measure of the degree to which an energy concept has
been proven to work in its final form and under expected conditions.
• System reliability. A measure of the absence of service interruption to a customer or group of
customers and of the degree to which a power supply is free of significant frequency deviations,
voltage flicker, and sags and surges.
• Environmental considerations. How secure are the poles going to be in differing permafrost
conditions along the route.
The NSB Steering Committee was staffed with the following key personnel.
• Doug Whiteman, Atqasuk Vice Mayor
• Fred Kanayurak, Atqasuk Lead Power Plant Operator
• Max Ahgeak, Division Manager, Power & Light
• Kent Grinage, Division Manager, Fuel & Natural Gas
The NSB Atqasuk Power Line Transmission Study, was lead by Kent Grinage, as the NSB Project
Administrator, and was managed by Lee Johnson, PE of Leland A. Johnson & Associates (LAJA).
Specialty services were provided by the following Team:
• Sakata Engineering - Electrical Engineering, Albert Sakata EE PE
• NORCON - Construction Feasibility, Method, and Cost Estimate, Eric Worthington, EE EA
• DEB Services & CE - Route Location, Right of Way and Report Compilation, David Bristow, CE
PMP
• 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
The NSB, the Project Administrator and the NSB Steering Committee were instrumental in supporting this
effort by providing information and insight into the existing power generation and transmission facilities
located at Barrow and Atqasuk. The LAJA Team would like to express it's appreciation for the
cooperation and assistance provided by all participating entities.
C. Project Objectives
The objective of the Atqasuk Power Line Transmission Study is to determine the most feasible system for
transmitting power from Barrow to Atqasuk.
Alternative power line routes (corridors) were identified considering the following criteria.
• Maximizes use of existing infrastructure
• Minimizes power line corridor length
• Avoids geotechnical hazards
• Avoids native allotments
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Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
Is compatible with the most economically viable construction methods
• Provides least environmental impact to migratory waterfowl nesting areas
• Minimizes environmental impact to tundra and inland watersheds,
r Transmission system design alternatives were produced considering the following parameters.
• Power -only and power -plus -heat village demand senarios
• AC versus DC line voltage
• Composite poles versus wood and steel
• Construction methods
M • Construction and operating costs
Environmental Issues
• Geotechnical engineering constraints
• Permitting requirements
• Life cycle cost analysis (economics)
D. Project Description
The project entails a design engineering, permitting, and construction effort that will provide a new power
transmission line from Atqasuk to Barrow. Several routes have been studied in preparation for the
selection of the most environmentally friendly, economically viable, and technically feasible route that
does not impact native allotments. The following routes were selected after exhaustive alternative
analysis of other conceptualized routes.
They are as follows:
Western Route 1 (WR1) — length of route, approximately 74 miles.
Eastern Route 2 (ER2) — length of route, approximately 68 miles.
Western Route 1
Both WR1 and ER2, from Barrow to the Barrow Gas Field South Pad, utilize existing road infrastructure
(to Cake Eater Rd.) to facilitate construction, and uses/modifies the existing power line support structures
along this road. WR1 then proceeds south and utilizes the existing 6" gas line Vertical Support Members
(VSM) to support the power line from the Barrow Gas Field South Pad to the existing Gas Line terminus.
The final leg of WR1 travels along a new cross-country route, on 65' tall, overhead power poles. Drill and
slurry ad -freeze embedment is the construction method that will be used to install the power poles, during
winter season. WR1 will require two river crossings (Meade & Inaru Rivers) and will be directionally
drilled below the riverbed to minimize impact. This route was conceptualized in a similar manner to the
existing ROW's established during oil development on the North Slope. This method was employed due
to the successful record of the ROW's and their minimal impact to the environment. WR1 route ends at
the Atqasuk Power Substation.
5 Atqasuk Power Line Transmission Study
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September 15, 2011
Report of Findings
Eastern Route 2
Both WR1 and ER2, from Barrow to the Barrow Gas Field South Pad, utilize existing infrastructure. ER2,
at the Barrow Gas Field South Pad travels further to the east, along a new cross-country route, on 65' tall,
overhead power poles. Drill and slurry ad -freeze embedment is the construction that will be used to
install the power poles, during winter season. ER2 will also require two river crossings (Meade & Inaru
Rivers) and will be directionally drilled below the riverbed to minimize impact. This route was also
conceptualized in a similar manner to the existing ROW's established during oil development on the North
Slope. This method has been successfully employed for many years on the North Slope. The ER1 route
ends at the Atqasuk Power Substation.
Both routes are designed to minimize infringement upon known, densely populated, avian nesting areas.
Both avoid established native allotments. Both routes avoid installing VSM's at lakes, surface ponds, and
river drainages (as possible). WR1 and ER2 also provide power to the remote Walapka Gas Field,
although ER2 is connected via an intertie shown as Route 2A.
6 Atgasuk Power Line Transmission Study
September 15, 2011
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-A
F4 Report of Findings
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3. — Engineering Design Basis & Performance Criterion
11110
I* A. Project Design Engineering Scope Description:
Evaluate and select from the power transmission options currently being studied. They are
High Voltage Direct Current (HVDC) vs. 3-Phase Alternating Current (AC), and are analyzed
via comparative technical and economic viability and system reliability.
• Provide design engineering to select the line parameters that can provide the least
environmental impact to avian populations and also determine the most economic
20
transmission line from Barrow to Atqasuk.
30
• Minimize footprint of new facilities and utilize as much existing infrastructure as possible to
avoid impact to sensitive flora.
74
0 Determine design parameters for wind and ice loads in arctic conditions.
0
• Develop the design of a power transmission system that will serve Atqasuk and also facilitate
a future expansion to Wainwright.
• Produce transmission line concept designs to the Preliminary Engineering phase or sixty
percent (60%) of overall design completion.
• Assess both power -only and power and heat demand scenarios.
No B. Route Description
go There are two proposed Right -of- Ways (ROW) that were studied for this effort. They are shown on Figure
no 1, Atqasuk Transmission Line Routes. They are Western Route 1 (WR1) and Eastern Route 2 (ER2).
so Both line routes traverse south of Barrow over terrain that is mostly flat with not much change in
elevation. Adjacent to, and along the proposed line routes, are many shallow lakes surrounded by typical
so tundra, low-lying vegetation. The route has no roads but there are some existing snowmobile trails. The
so total lengths of each proposed route are as follows:
06 • WR1 -Approximately 74 Miles
do 0 ER2 - Approximately 68 Miles
C. Recommended Structures
10 As part of this design effort support structures for the transmission line have been identified and selected
The recommended structure for this application is a 69 kV Transmission Line Structure, the TP-69 as
shown in the attached drawing, see Appendix A, Design Engineering, Exhibit 1 — Structure Types. The
Typical pole selected, for most of the line, is a 65 foot long Fiber Reinforced Polymer (FRP) pole, with
required sub -grade embedment determined to be 11.3 feet in depth. This structure consists of two offset
high strength fiberglass insulators mounted on either side of the pole and a single vertical high strength
insulator mounted at the top of the 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
IA structure proved to be the most economic alternative compared to other structures since it is easier to
construct and is less costly than H-frame arrangements.
The line could operate at 34.5 kV initially and later would operate at 69 kV. Insulators for this line are to
■1 be 115 kV type to avoid flashover from salt contamination.
Ok
IN
Ok
IIA 7 Atqasuk Power Line Transmission Study
September 15, 2011
Pk
PROJECT
LOCATION
LEGEND
Western Route 1
Eastern Route 2
Walakpa Power Line Spur Route 2A
Existing Gas Lines
I� Native Allottment
REFERENCES
1.) AERIAL IMAGERY DOO DATED AUGUST
2005 WAS PROVIDE BY USGS AND
DISTRIBUTED BY ALASKA GEOGRAPHIC
INFORMATION CENTER (GINA)
EXISTING
OAS LINE'
Rpule 2a
Walakpa
Power Line
Spur
Westem Route 1
RT.1
' '1 s►►• Base Case
-L .4 .� _ '-�-
� a • �t•Y, s � _.
TI Eastern Route 2
r . (RT.2)
v ... ,ts
ky
8 0
ATQASUK
n SCALE
BARROW
Tm.E
AS SHOWN ATQASUK TRANSMISSION
`�1� DADD APG LINE ROUTES
r yv DATE 8/15/11
Anchorage. Alaska CHECK DEC
FILE No Algssuk-dvvg VAT` WWI Leland A. Johnson & Associates FIGURE
PROJECT 103-95558 REV. 0 .w+..._ , �A4&Mii 1
Report of Findings
D. Electrical Loading & Line Loss
As determined from previous load study information, and updates provided by stakeholders, Atqasuk has
a current peak load demand of 603 kW; with average daily demand of 384 kW. The peak electrical load
for Atqasuk is estimated to increase to 1.0 to 2.0 MW when considering adding the heat load to the power
load caused by the conversion of residences and facilities from diesel heating to electric heating. If power
is extended to Wainwright, for power load only (no heating load), the peak load would be increased by 1.0
MW extended in the future.
The proposed line, sized for 69 kV, can carry a total of 10 MW of power, and will have less than 3.8 %
power loss, which is an adequate/acceptable voltage drop for this scenario.
E. Transmission Line Components — Basis & Performance Criterion
1 — Structure Types
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 will
utilize a single pole structure, Type TP-69, and occasionally, the H-Frame Type TH-1. These two types of
structures will be installed for use by the AC Power Line Transmission scenario. Type TP-69 structure,
with only two top insulators, will be installed for use in the DC Power Line Transmission scenario.
Also, the structures will have sub -grade embedment with a design allowance of +10% in additional length
plus 5 feet, to achieve greater pole stability. Compacted backfill, when ad -freeze slurry cannot be
employed, will be used to aid in providing lateral and uplift resistance of the poles.
There is considerable information available regarding jacking and creep that occurred on the GVEA
Lattice Intertie from Healy. 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.
The following material selections were considered and evaluated, as a cost basis, for the overhead
transmission line portion of the design:
• Wooden Poles, Full Length Pressure Treated, Douglas Fir. Pressure treated per REA 1728F-
700.
• Steel Poles, with similar strength properties as wooden poles; with a provision for ground fault
protection.
• Fiber Reinforced Polymer (FRP) Poles.
• Insulators - the 69 kV Structures will utilize 115 kV Insulators to avoid potential flashover caused
by in -situ or coastal salt contamination.
2 - Weather Data Parameters
Based on research of the available historical weather data, see Appendix A, Design Engineering, Exhibit
2, Weather Data Parameters, the following design criterion (cases) are applied for the conductor loading
and anchoring design:
8 Atqasuk Power Line Transmission Study
September 15, 2011
0 Report of Findings
Is
to 0 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 Ibs/sf with no ice on the exposed conductor.
• Wind Load on Insulator Swings = 49 mph or 6 Ibs/sf with no ice on the exposed conductor, for
use as basis in horizontal clearance calculations.
3 - 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. A large group of candidates were reviewed for selection
as the design and cost basis for this project. The following conductors were considered during the
process:
• ACSR
• ACSR/AW
• ACSS/AW
• 1350 Aluminum Conductor
• AAC 6201
to • ACAR
• AWAC
• ACSR/SD
• T2
The factors considered when determining the conductor selection are as follows:
it
corrosion considerations — resistance or allowance
• material strength
• voltage drop properties - resistance
• thermal capability
economics of use
As determined during the selection process the recommended conductor is the Hawk/Aw 477.0 MCM
ACSS/AW which has the adequate resistance properties, has adequate strength, and exhibits good
corrosion resistance. The T2 type conductor will also be used at selected locations, as needed. 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. The
twisting provides light reflections allowing birds to see the conductor eliminating conductor -bird collisions.
The recommended, applied tension to the conductor, are per the RUS Table 9-2 found in Appendix A,
Design Engineering, Exhibit 3, Recommended RUS Conductor Tension.
4 - 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.
Mom 9 Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
CA
CA
To address Galloping Vibration, which is expected, the longest spans will be designed to be no longer
than 700 feet in length, installed at Single Poles, and no longer than 1200 feet in length, installed at the
H-Frame Structures. The conductors will be subjected to Double -Loop Galloping Vibration where the
required clearance is maintained. See Appendix A, Design Engineering, Exhibit 4, Aeolian Vibration,
Required Clearance.
5 -Sag and Tension
Conductor Sag and Tension Data, per NESC Load Cases:
• Span Basis - 700 feet and 1200 feet respectively.
• Conductor Basis - 477 MCM ACSS/AW.
See Appendix A, Design Engineering, Exhibit 5, Conductor Sag & Tension
Resultant Calculation
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.
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. If conductor temperature is -50 F, the
resultant sag is 36.40 feet and the tension is 28% of ultimate strength. The 60 F criteria therefore
controls.
E.6 -Loading and Overload Factor
The power line will be designed per NESC Heavy Loading District, applying REA Grade B Overload
Capacity Factors, for Poles, Cross -arms, Guy Assemblies, and Insulators as shown on Table 11-3. See
Appendix A, Design Engineering, Exhibit 6, Conductor Loading and Overload Factors.
E.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 90F, at full load, will be per the RUS Table 4-1. See
Appendix A, Design Engineering, Exhibit 7, Conductor Ground Clearances.
It is recommended that 21.6 feet of vertical clearance from conductor to ground, is maintained, for most
locations, when the line conductor temperature is 60 F.
8 - Load Flow Report at 34.5 kV AC
Case
At 75 miles in length, under a 2 Mw load, and using a 477 MCM conductor, the expected loss is 2.8%
with a 4.66% voltage drop.
Case information as provided in the referenced EDSA Report. See Appendix A, Design Engineering,
Exhibit 8, Load Flow Report at 34.5 kV AC.
9 - Load Flow Report at 69 kV AC
Case
10
Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
At 75 miles in length (to Atqasuk), under a 2 Mw load, and at 67 miles in length (to Wainwright) under a 3
Mw load, using a 477 MCM conductor, the expected overall loss is 2.02%; with a 0.15% voltage drop for
Atqasuk and 0.95% voltage drop for Wainwright.
Case
At 67 miles in length (from Junction), under a 2 Mw load at Atqasuk, and under a 6 Mw load at
Wainwright, using a 477 MCM conductor, the expected overall loss is 3.28%; with a 1.0% voltage drop for
RIP Atqasuk and 1.96% voltage drop for Wainwright.
Case information as provided in the referenced EDSA Report. See Appendix A, Design Engineering,
Exhibit 9, Load Flow Report at 69 kV AC.
10 -Load Flow Report at 30 kV DC
ca Case
At 75 miles in length (to Atqasuk), under a 2 Mw load, using a 477 MCM conductor, the expected loss is
9.12%; with an 8.36% voltage drop.
C* Case information as provided in the referenced EDSA Report. See Appendix A, Design Engineering,
CA Exhibit 10, Load Flow Report at 30 kV DC.
CA
Ifs 11 -Load Flow Report at 50 kV DC
Case
At 75 miles in length (to Atqasuk), under a 2 Mw load, using a 477 MCM conductor, the expected loss is
8.98%; with an 8.24% voltage drop.
CA Case information as provided in the referenced EDSA Report. See Appendix A, Design Engineering,
Exhibit 11, Load Flow Report at 50 kV DC.
co
co 12 - One -Line Description for AC Operation
C
CA% The BUECI feeder circuit from the power plant will be configured to provide power and power plus heat
t and will include a dedicated 4160V Breaker. From the breaker it will be routed to the Barrow Gas Field
South Pad. A 2 MVA Transformer will be located there with a 34.5 kV Re -closer, installed at the Barrow
CIA and Atqasuk ends of the power line. When using the 69 kV option, 69 kV SF6, Low Profile Type Breakers
will be considered for installation. Atqasuk will be configured with a 2 MVA Transformer, a 4160V Re -
closer, as well as a 34.5 kV Re -closer. See the referenced One -Line Diagram for clarity. See Appendix
r� A, Design Engineering, Exhibit 12, One -Line Description for AC Operation.
CA At the Atqasuk Power Plant a new 21VIVA Transformer will be installed on a pad configured in a similar
CA manner to the existing 1 MVA Transformer located there.
ro
rv� Both the 34.5 kV feeder circuit and the 69 kV feeder circuit option will use a re -closer for protection, and
an SF6 Low Profile Circuit Breaker. The 4160V Stepped -down voltage will be routed through a re -closer
l^ that should connect to TIP2 or B1 UP as is needed or convenient. See Figure 2 for clarity.
lA
MW
11
Atqasuk Power Line Transmission Study
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Report of Findings
POWER HOUSE (NOTE 7)
1500 AT
1000 KVA-PAD-MTD
45OKW --
1600 AFC
425KW d--�
65OKW —�
480V,
2500A
91OKW -�
91OKW —
n
1500 AT
1600 AF
TAP2 �"---------
NC X B1L3P1
3-140A TIP1
B1L2P3
480-4160Y/2400V �_ 3KV
NOTE 6 B1 LM
480-4160YI2400V
3-140A TIP7 TIP3 T643P1
NO
1000KVA-PAD-MTD 13KV
NOTE 6
3x15 TIPS 1x
Figure 2 schematic For AC Operation - Step Down Transformer & Protection
13 - One -Line Description for DC Operation
The BUECI feeder circuit from the power plant will be configured to include a dedicated 4160V Breaker.
From the breaker it will be routed to the Barrow Gas Field South Pad. A 2 MVA or 5 MVA Transformer
will be located at the South Pad and will step down voltage to 480V, and, with a separate breaker will
provide power to the inverter modules. These modules will convert 480V AC to 1500 V DC. This DC
output will be connected in series to achieve the desired 30 kV or 50 kV DC result. Line Protection will be
by provided by installing one 30 KV or 50 KV DC Breaker at Barrow and another at Atqasuk. The DC
converters, located at Atqasuk and Barrow, will require installation in weather-proof enclosures for
protection. At Atqasuk the 480V AC output from the DC Converters can be tied -in to the power plant
main bus through a 2500A 480V Breaker. Another feasible option explored is to step-up the 480V AC
output from the DC Converters with a 2 MVA Step- up Transformer, and tie-in to the power plant system
through a re -closer; that should connect to TIP3 or 131 1_2132 as is needed or convenient.
It should be noted that the proposed line configuration is the bipolar type, utilizing similar structures as the
AC line except that of the three conductors provided, only two are used.
See Appendix A, Design Engineering, Exhibit 13, One -Line Description for DC Operation, the referenced
One -Line Diagram, for more detailed information regarding the DC Power Line.
12
Atqasuk Power Line Transmission Study
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Report of Findings
14 - High Voltage Direct Current (HVDC) Evaluation
DC Converter Technology
• As a part of this study, significant effort was expended researching the possibility of utilizing a High
Voltage Direct Current (HVDC) "light" line feed for power transmission.
As a result, two principal suppliers of HVDC equipment, were identified. They are Siemens and
ABB. Unfortunately both companies do not offer equipment sized for the load capacities
discussed in this study. They do offer equipment rated at 10 MW at 140 kV capacities, however if
this equipment were utilized as estimate basis, it would increase the project cost by approximately
$10.01VM; not including the cost impact associated with a Walapka Power Line Tie-in. Company
representatives did not seem too enthusiastic and indicated they believed this was "not a good fit
for their equipment".
• Although the cost of the HVDC transmission line was found to be less than the AC transmission
line, the converter technology made the overall HVDC system less cost effective. No current or
past project effort could be found that has utilized HVDC systems with power loads of similar size,
as compared to this project's requirements.
• Tier Electronics, a manufacturer of smaller HVDC systems, did provide an attractive initial price
offering for 2 MW units, but after further review of the company, and no response to additional
requests for project history of the units they manufacture, it was determined that this equipment
source will require further verification. The initial quotation was used in this budgetary estimate,
and a request for a written quotation was promised at a later date.
• Tier Electronics did indicate that they can provide training and technical support, but did not
include the cost in their original proposal.
• It should be noted that Tier Electronics technical personnel advised that the increased load
resulting from electric heating, would require utilizing their 4 MW capacity units. They also
indicated that their equipment is more "load sensitive" than a transformer, and some increased
capacity is required to address this.
• Tier Electronics HVDC equipment is manufactured and rated to withstand -40 Deg. C
temperatures, but additional heating capacity will be required for temperatures below -40 Deg. C.
• The Denali Commission recently completed a review of HVDC technology for an Alaskan
application and they endorsed the suggestion to provide a third power conductor. It was also
suggested that power transformers should be pre -positioned to provide a "backup transition" to an
alternating current (AC) system.
DC Converter Costs
The DC Converter cost quotations are provided by Tier Electronics, an electronics manufacturer located
near Milwaukee, Wisconsin. This is the only vendor that provided converter costs.
The two DC Converter options offered are as follows:
• Two each, 480 VAC to 30 kV DC converters, with one located at Barrow and another located at
Atqasuk. This equipment will provide 2 MW of capacity. Cost: $ 1.9 MM US, for two converters.
• Two each, 480 VAC to 50 kV DC converters, with one located at Barrow and another located at
Atqasuk. This equipment will provide 5 MW of capacity. Cost: $ 3.985 MM US, for two
converters.
13 Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
it
It should be noted that ABB was approached to provide a proposal, since they have a previous track
record of completing many projects in Europe, but in their response the only offering was for equipment
capable of providing 80 kV DC of conversion capacity with a power rating of 40 MW. The two converters
were quoted at $30MM to $35MM US which included the associated DC/AC Switchyards.
For more detailed cost information, see Appendix A, Design Engineering, Exhibit 14, DC Converter Costs.
DC Converter Reliability
The life span of this electronic equipment is measured in "mean time between failures" (MTBF). This
MTBF is normally high for a single converter and the equipment could be expected to experience some
potential component failure. Due to the Converter MTFB, it should be considered that the Converter
Components Plan, a scenario that would require having 20 to 40 converters installed in series, would only
allow for a minimum of one or two acceptable failures. If more failures occurred, the whole system would
fail, and not provide the adequate, reliable DC voltage output.
Maintenance expertise is not readily available and there are not adequate training opportunities provided
or available, in the remote communities where this equipment is being considered for use. With these
issues the actual reliability that the proposed converters will provide should be questioned.
The proposed converter equipment will be factory tested at the Northrop facility near Milwaukee, but this
equipment has never been utilized for a similar commercial application. There is no proven track record
of performance for this application since it would be a "first" for TIER Electronics.
In consideration of the foregoing facts, we must conclude that a DC system is not viable for our situation.
HVDC Conclusions
For the advantages of HVDC vs AC power see Appendix A, Design Engineering, Exhibit 15,
Advantages of HVDC vs AC Power.
• It is not the least cost option. The cost estimate was based on the written quote received for a 4
MW HVDC system. The quote indicated that a third conductor for a ground would be required.
A The requirement for a third conductor was not utilized for this estimate as it is not a HVDC design
requirement.
• HVDC Equipment sources are not readily available. Tier Electronics, is only known source of
HVDC equipment with the capacity required by the project found. Tier's equipment does meet
the project performance criterion of 2 MW - 4 MW of power at 40 kV to 70 kV. A "10 MW
minimum and 110kV minimum" equipment was proposal provided by ABB and Siemens. They
provide the bulk of the equipment, for the HVDC transmission market, and although HVDC is
suggested for this project, it was indicated that their gear is not a good fit for this project; $10MM
for the equipment without any provision to tie to Walapka Gas Field.
• Polar Consult Alaska, Inc, a group funded by the Denali Commission, is developing HVDC
technology, and was studied for potential use in this project. It was found that the technology
they are developing is still in the prototype stage and is sized well below the design requirements
for this project. It was also indicated they realize the need for 50kV 100 kW to 5 MW capacity
HVDC units but there are no current plans for further development.
• The use of a Single Wire Earth Return (SWER) is advocated by the Denali Commission report
A findings, but as the authors indicate, "the SWER is rarely used because it induces modest ground
currents and voltages that can rapidly corrode some buried metals". Conventional HVDC is
14 Atgasuk Power Line Transmission Study
September 15, 2011
r
Report of Findings
defined as using two wires to prevent a ground return and is required to protect the NSB gas field
infrastructure per the current electrical codes.
• HVDC utilizes technology not common in the region, nor can manufacturers with similar design
requirements be located. HVDC system theory appears to be well founded. However, the lack of
information for similar systems does not allow a viable review of durability and economics
associated with HVDC systems, and, at this time would not be the proper choice for this project's
use. In short, HVDC technology maturity is too low to be considered for this project.
15 Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
i
i 4. — Geotechnical Engineering — Review & Commentary
A. Purpose and Objectives
'
The purpose of this work was to review existing geotechnical and near surface geologic data along two
transmission line alignment corridors developed in conjunction with other members of the design team.
The purpose of the data review was to determine if significant geotechnical hazards could be anticipated
i along the proposed alignments. The work relied on existing publically accessible geotechnical literature
and imagery augmented with our general geotechnical knowledge and experience in the area. A site
reconnaissance or subsurface exploration program was not included under this scope of services.
i The project objectives are to provide a narrative of reasonably expected geotechnical issues along the
i proposed alignments and provide conceptual level geotechnical design considerations for the
transmission structures. A discussion of potential geotechnical issues for fiber -reinforced polymer (FRP)
transmission poles in cold climatelpermafrost areas is also included. Identification and discussion of
potentially significant geotechnical hazards and design considerations that may severely impact project
costs is also provided. Design -level geotechnical engineering recommendations were not included under
this scope of services.
B. Prior Work
Environmental and engineering analysis for a power line between Barrow and Atqasuk was completed in
the early 1980's by Jack West Associates and others. This report included power lines between Barrow,
Atgasuk, and Wainwright with the Barrow to Atqasuk alignment approximately 70 miles long. The West
report provided limited geotechnical field data along the proposed routes. Subsequent to the West report,
the !North Slope Borough (NSB) has considered several alternate alignments between Barrow and
i Atqasuk.
C. Geologic and Geotechnical Findings/Considerations
A variety of options were considered for the conductors and support structures. Details of the proposed
alignment and utility pole geometry are provided by other members of the team. At this time the preferred
option for the vertical supports are monopole structures with structure adjustments for longer spans over
1 lakes and drainages.
i Golder was tasked with three geotechnical items for conceptual -level engineering:
Summary discussion of reasonably expected shallow subsurface geology and thermal
states along the proposed alignments.
0 Summary discussion of potential geo-hazards related to the transmission line
construction and operation and maintenance (O&M).
• Geotechnical considerations related to use of Fiber Reinforced Polymer (FRP) utility
poles in lieu of conventional timber or steel transmission pole structures.
CA - Surface and Shallow Subsurface Geology
The, proposed Barrow to Atqasuk power line will lie entirely within the Teshekpuk Lake section of the
Arctic Coastal Plain, See Figure 1. This is an area with little topographic relief. Occasional pingos and
tundra -covered sand dunes provide the only break in an otherwise flat horizon. The Meade River, near
Atqasuk, and scattered tributary streams, incised a few feet into the plain, provide the only drainage for
much of the area. Poorly developed drainage ways flow toward the coast at the northern end of the
project area.
16 Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
1114
1110 The entire coastal plain is underlain by permafrost with a seasonal thaw depth of up to a few feet in
111111110 undisturbed, windswept areas. Permafrost will extend deep in the project area, in excess of 1,000 feet,
which is not uncommon. Deeper seasonal thaw may be encountered along drainages, under areas with
deeper snow cover, and where the tundra mat has been disturbed. As a result the region is poorly
drained and very marshy in the summer. A network of ice -wedge polygons covers the coastal plain and
elongated thaw lakes are common. The lakes are generally shallow and range in length from a few feet
to several miles in length. These lakes have been reported to expand by as much as three (3) feet per
111111110 year and several generations of drained lakes have been identified.
14
Beneath the tundra cover, a sequence of Quaternary Age marine sediments are present over nearly flat,
coal bearing, Cretaceous sedimentary rocks. Wahrhaftig reported in USGS Professional Paper 482
(1962) that the overlying unconsolidated sediments range from 10 to 150 feet in thickness. The coal
bearing rocks are exposed in the banks of the Meade River which is in the vicinity of Atqasuk, but are
much deeper to the north. These rocks are composed of silty sandstone and limey siltstone with shale -
like inter -beds. The more durable sandstone units observed near Atqasuk were generally about 2 to 4
inches in thickness.
C.2 - Routing: Geologic Considerations
There are few geologic conditions that will significantly impact the route for the power line. The following
conditions, however, should be considered as the route is finalized. Additional discussion is presented
under following Geo-hazards section.
• Avoid locating structures immediately adjacent to the migrating lakes, with special attention given
to the ends of the larger lakes
• Avoid locating structures in or immediately adjacent to small streams especially at stream
junctions where seasonal aufeis (overflow ice) may occur
• Shallow rock may be encountered at the southern end of the line. Drilling in the rock may be
difficult with conventional disc -type auger commonly used for foundation installation in the area,
but the banded nature of the material suggests that it may be possible to penetrate.
Based on our review of the proposed alignments identified on the attached imagery, several key areas of
geologic concern are identified. Key areas of concern include:
• River Crossings - Two (2) Ea. along Right of Way and rock strata encountered.
- Inaru River
- Meade River
• Ice Rich Permafrost - can be mitigated with field adjusted embedment length of VSM; commonly
practiced and known as "pupping".
C.3 - Goo -hazards
As discussed above, ice -rich permafrost under the tundra surface is expected along the transmission line
corridors. Both alignments will traverse areas with large numbers of surface water bodies. Thus, the
alignments are expected to require numerous guy anchorages. The active layer, or depth of seasonal
thaw, is expected to be 1 to 3 feet where the surface vegetation is intact. Deeper seasonal thaw and
potentially degrading permafrost can be expected in areas with damaged surface vegetation, along a
larger surface drainages, near a larger surface water bodies, and in areas with significant snow drifting.
17
Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
re
In general, the shallow soils 15 to 20 feet below the tundra mat will be ice rich organic silt with the
potential for thick sequences of massive ice_ Geotechnical work form the early 1980s conducted
approximately 10 to 15 miles westerly of the proposed alignments encountered a live tundra mat with an
underlying peat and organic silk layer to 4 to 6 feet below the ground surface. In general, icy mineral silt
was encountered below the organic silt with occasional layers of silty clay to approximately 20 feet below
grade, the limit of the explorations.
Soil moisture, as a percentage of dry weight, ranged from 200 to 500 percent within the uppermost 5 to 7
feet decreasing to 50 to 70 percent to 12 feet below grade further decreasing to approximately 25 to 35
percent of dry weight below 12 feet. Within the upper 10 to 12 feet below grade, soil moistures in excess
of the dry soil weight should be expected.
As discussed in the Geology section, the soils near Atqasuk are re -worked wind deposits, generally
considered dune deposits. The shallow subsurface soils near Atqasuk are generally fine sands to coarse
silt by particle size and will typically have lower soil moisture contents, roughly slightly above thawed state
saturation concentrations. In Atqasuk the near surface sandier soils generally have fewer massive ice
layers; however, massive ice can be expected in areas with more silty and organic soil deposits.
Pore water salinity is prevalent in the permafrost throughout the Barrow area and should be expected
along most of the proposed alignments, with a reduction in pore water salinity near Atqasuk. Pore water
salinity will depress the freezing point of the permafrost. Near Barrow, pore water salinities have been
encountered at concentrations resulting in un-bonded permafrost at ground temperatures near 25° F
within foundation pile embedment depths, 15 to 30 feet below grade.
In general, }yore water salinities up to 8 to 18 parts per thousand (ppt) should be anticipated along the
alignment at depths commonly expected for utility pole embedment. However, larger pore water salinity
concentrations up to and exceeding 35 ppt have been encountered near Barrow and should be expected
along the proposed alignments.
Shallow ground temperatures have been measured in Barrow and Atqasuk over the past 30 years on
numerous construction projects. In general, ground temperatures near 20° to 25° F at 15 to 20 feet below
grade can be expected near Barrow. At the base of the active layer, the ground temperatures will
increase to 32°F and ground surface temperatures will vary in response to annual air temperature
variations. Permafrost temperatures will vary depending on local conditions, including albedo, snow drift,
slope orientation, vegetation and other factors.
Engineering climate indices including average thaw and freezing indices (ATI and AFI, respectively)
indicate a warming trend from the 1950-1978 period to the 1978-2004 period. The Barrow area average
climatic indices are summarized below.
1950-1980 1980-2004
Average Air Temperature: 7.5 °F 11.2 °F
Average Thawing Index: 400 'F-days 670 'F-days
A Average Freezing Index: 8,700 'F-days 8,240 *F-days
As noted, the Barrow area has experienced a general warming trend with potential impacts to longer
design life facilities. This general warming trend should be expected along the transmission line corridors
and throughout the design life for the structures.
• • 18 Atqasuk Power Line Transmission Study
September 15, 2011
■
Report of Findings
Along the proposed alignments, several geo-hazards should be anticipated:
1 Ice -rich Permafrost - Ice rich permafrost may experience additional creep under sustained load,
particularly for lateral load conditions such as guy anchors. Also, deeper thaw into the underlying
permafrost may occur if the tundra surface is damaged. Deeper thaw may result in a deeper point of
fixity for lateral load analysis.
Elevated Pore Water Salinity - Pore -water salinity will depress the freezing point in the permafrost.
In addition, conventional drill and slurry ad -freeze foundation systems may experience accelerated
creep under moderate to light loads in higher salinity permafrost, particularly for steel piles.
Snow Drift - In areas subject to deeper snow drifting, the ground surface will be insulated from winter
cooling air temperatures with a potential for warming or degrading permafrost. As permafrost warms,
a reduced ad -freeze bond capacity and reduced lateral resistance should be expected.
Seasonal Lake Ice - The larger water bodies may have water sufficiently deep to not freeze to the
mud line. If so, permafrost degradation may be occurring. In general, the lateral extent of the
permafrost degradation will be limited, particularly if the shoreline is wind swept during the winter.
However areas along the shorelines adjacent to deeper water should be checked for potentially
r deeper thaw or warming permafrost.
Larger Surface Drainages - Several geo-hazards should be considered along larger surface
drainages. First, seasonal ice jams have occurred along larger drainages with the potential for
A damage to pole structures. Second, the larger drainages may have deeper thaw channels and
r oxbows or channel meanders may have unfrozen soil states, depending on localized hydraulics,
vegetation, and river geometry. Third, the larger drainages may have significant snow drift conditions
that may alter the thermal regime along the banks. Fourth, channel migration and erosion are active
geomorphic processes that may impact structures adjacent to active drainage channels.
Lake Shoreline Erosion - The larger lakes along the proposed alignments have a noted NW -SE
elongation orientation. This orientation is related to the prevailing winds and some thermal
degradation and erosion may occur along the northern and southern margins of these lakes. Vertical
* members planned along larger lakes should consider the potential for shoreline migration over the
project design life.
D. Geotechnical Considerations for Timber, Steel and Fiber Reinforced
Polymer (FRP) Poles
It is understood that the vertical support members will be direct -buried using conventional drill and slurry
construction practices. In Barrow, it is understood that BUECI traditionally re -uses the auger cuttings as
slurry aggregate with potable water. Pole embedment depths by BUECI are generally 10 feet. BUECI
reports few problems related to utility pole performance in Barrow, however isolated utility poles have
experienced problems in Barrow near'surface drainages or along roadway shoulders where permafrost
degradation may have occurred.
Axial and lateral design loads for the transmission system have not been developed at this conceptual
level, but it is reasonable to assume that if larger spans are utilized, this will result in installing taller poles
along the transmission alignment, and significantly greater lateral loads should be expected. Lateral
loads will be developed normal to the conductor alignments due to wind an ice loadings and along
tangents where conductor directions change. At these tangent points, it is understood that guy anchors
will be required and a free-standing monopole structure is not feasible for the expected design loads.
19
Atqasuk Power Line Transmission Study
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i
i Report of Findings
i
i Timber drill and slurry ad -freeze foundations have a successful performance record, in the Barrow area,
i installed in higher pore -water saline permafrost. Nearly all conventional timber ad -freeze piles in
i permafrost areas are specified as untreated, rough cut material. Utility poles are generally treated, but
limited axial or lateral loading problems are apparent due to the preservative treatment along the
i embedded pole sections.
i Steel piles have experienced accelerated axial creep in higher salinity permafrost in Barrow, even under
relatively low sustained axial loads (wrt to buildings and structures). Lateral creep has also been reported
along guy anchors for communication towers in the Barrow area, resulting in loss of tension and repeated
operations and maintenance cost for guy cable re -tensioning.
Very little performance data are available in the literature or through field performance for FRP pole
structures in icy permafrost conditions. The ad -freeze capacity should be determined for FRP materials
and potential creep related variables. Field and/or laboratory bench testing can be conducted to
r estimated ad -freeze capacity.
i
Likewise, the robustness of FRP poles to transport and handling should be considered. If the FRP
products are sensitive to handling and transport relative to timber or steel products, the impacts due to
handling and transport should be determined.
All FRP manufacturers contacted make full length FRP utility poles. Golder personnel were able to locate
only one manufacturer for nested or sectional FRP utility poles, RS Group in Calgary, Alberta. Based on
preliminary discussions with RS Group, they have installed their FRP products in areas with seasonal
frost but not in permafrost conditions. Based their literature, the cold regions FRP installations have
performed as designed. For more information see Appendix B, Geotechnical Engineering, Exhibit 1, RS
FRP Pole Structure Examples.
E. Geotechnical Considerations and Recommendations
Based on review of existing geologic and geotechnical literature along the proposed transmission line
alignments (WR1/ER2) and our current understanding of the project, we offer the follow geotechnical
considerations and recommendations at the conceptual planning and development level:
EA - Alignment Routing
Along the proposed alignment routes, the following elements should be considered as the conceptual
level effort develops:
• Terrain unit mapping based on existing data sources should be conducted along the
preferred route(s) for possible field assessment of shallow subsurface conditions.
• Coupled with local resident knowledge and experience, ice jam issues along drainages
should be monitored during breakup to assist with route selection.
• Late spring flyover should also map relict snow drift zones for future thaw probing
• At the end of the fall season, hand thaw probing should be conducted at potential areas
of deeper thaw at proposed pole and guy anchor structures
r 20 Atgasuk Power Line Transmission Study
September 15, 2011
Report of Findings
• Geotechnical explorations should be considered at the longer span areas if larger tension
loads are expected
Potential slurry aggregate sources along the alignment(s) should be identified to reduce aggregate
transportation costs. Likewise potential slurry water sources should be identified to reduce water
handling and transportation costs.
E.2 - FRP Structures
Since limited performance data are available for FRP structures in permafrost using drill and slurry ad -
freeze design, we recommend considering laboratory and field-testing with the planned FRP products to
determine basic geotechnical design parameters. This effort should include determining sustained ad -
freeze bond capacities, pore water salinity influence on ad -freeze bond strength, lateral load and
deformation behavior, and basic handling and constructability considerations.
The University of Manitoba has published and unpublished structural performance data on FRP
structures. Coordination with Dr. Dimos Polyzios, at the University of Manitoba, Department of Civil
Engineering should be considered. Golder established preliminary discussions with Dr. Polyzios for this
submittal and additional effort is recommended to follow up with his research and findings.
21 Atqasuk Power Line Transmission Study
September 15, 2011
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Report of Findings
5. — Constructability Analysis, Technical Feasibility, & Cost Estimates
A. Purpose, Objective, & Scope of Work
The project scope of work included developing a construction method, material selection, and
representative cost estimate for a new power transmission line from Barrow to Atqasuk; that addresses
the environmental considerations for executing a power line construction project in an area where
endangered avian populations are present. The construction method and material selection for
i installation, were crucial choices, bearing in mind the potential environmental consequences, so "minimal
impact" was a significant part of this effort's mission goal. The construction basis and feasibility, technical
feasibility of chosen construction method/materials, and budgetary costs developed for a feed to the
electrical distribution grid at Atqasuk were the primary deliverables. Also included in the scope of work
was a tie-in to the Walapka Gas Fields so it can be provided with power from low-cost power generation
in Barrow; on a least cost basis. This is possible due to the development of Eastern Route 2, whose
alignment would make the Walapka Gas Field tie-in possible. See Figure 1, Atqasuk Transmission Line
Routes: Western Route 1, WR1 and Eastern Route 2, ER2.
B. Physical Description
The Construction Cost Estimate is based upon on 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 villages possess minimal existing infrastructure, and only winter trails currently exist
between their locations. Some of these winter trails are near the proposed power line alignments. The
proposed right-of-ways or alignments, WR'I and ER2, are located near critical nesting areas for the
Steller's Eider, Spectacled Eider, and Brant Goose, of which the Steller's Eider has been classified as an
endangered species.
The estimate is based upon on an assumed maximum load of 608 Kilowatts (KW) power load 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 may be low, but the change in cost is not significant, as a function of
initial project cost. However, related upgrades to the Atqasuk distribution system, including transformers,
electric drop services, metering, and installation of electric powered heating equipment may ultimately
produce a required power load approaching 2.5 MW. To address this increase in load, 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. The changes to the
"step-up" and "step-down" power transformers would typically be the only item required for the increased
loads. It should be noted that the load increase is caused partially by low ambient temperature which
allows an increased load on the transformer. A requirement for a 100 Kilowatt (kW) Tie-in at the
Walapka Gas field, is also included in the estimate, and that load has been taken into account.
A
C. Basis of Estimate
1111 0 Estimate is based upon historical data and recent material vendor quotes.
A • Assumed labor costs are based upon Davis/Bacon or Union Scale pay rates, per the Fall 2010 Rate
A Schedules. Accuracy should be within a -10% to +25% of cost certainty. It should be noted that
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
y = 22 Atqasuk Power Line Transmission Study
September 15, 2011
I�
7
Report of Findings
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.
• No allowance for Right of Way (ROW) or land acquisition is incorporated and is assumed to be
provided by others.
• 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.
ime
eria
• The Construction Schedule i Serrvice, which occurs a nually.vily dependent un a -tThere arte other options available,, comprehensive, tbut I
delivery via Bowhead Barge
there would be significant cost impact if utilized.
• The estimate is based
pdesigned withga power 110 kV spacing/insulation ission ine on with
overhe d (OH)(segments that
operatingload at 69 kilo -volts (kV),
comply with the National Electric Safety Code (NESC).
• It is planned to tie into the existing control system with a Fiber Optic Cable (FOC) circuit through a
Supervisory Control And dai ab eui between Barrow system. A and Atq su side -benefit to installing this link is
broad band access will be a
• Provision for utilization of reflective conductors to prevent bird strikes is included in the estimate, as a
protective measure, but permitting issues may require additional items with undefined procurement
and construction costs.
D. Eastern Route 2 (ER2) — Physical Description i& Basis of Estimate
DA Barrow Substation — ER2
• The construction estimate is predicated on the power transmission line tying into the existing 4160
volt power line, with a drop to the substation at that same voltage, and the power feed output at 34.5
1 kV; achieved by routing through a 2 MVA transformer.
An issue requiring resolution is the basis for the power and control interface between the BUSCI and
the NSB facilities. While an important and vital part of the system, the differences between the as -bid
and the as -found condition are not expected to cause significant cost impact.
i No underground (UG) cable is not utilized in this power line cost estimate. No reactors are required
to offset the capacitive reactance.
It is assumed that there is adequate space available at BUECI, 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.
0 D.2 Barrow to South Pad Line Segment ER2 - Length: 5.8 Miles
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
23 Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
install new 78' tall RLS Single Composite Pole Structures, with embedment of approximately 13' 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 cut-outs
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.
D.3
South Pad to Atqasuk ER2 — Overhead (OH) Line Segment — Length: 62.6 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 63' RLS Single Composite Pole Structures,
embedment at approximately 12' feet in depth.
•
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 strength, if required.
•
Additional pole sections will be carried by crew to modify pole length if required due to terrain or ice
lenses encountered during excavation.
•
A Cat Train Camp will provide support services including housing and meals for the crew.
•
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.
13.4
Tie-in for Walapka Gas Field to ER2 Segment — Length: 6.2 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 63' RLS Single Composite Pole Structures,
with embedment at approximately 12' feet in depth.
• The cost estimate includes OH Power Feed to the Barrow Gas Field with distribution poles and step-
down transformer bank at the gas line terminus.
Route length may vary slightly, depending upon further study of existing gas field infra -structure and
A 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.
• Similar Structure can be provided for small cost impact for the future Western Tie-in.
M0 Further work and discovery may determine that circuit switches, with SCADA control, might be
A required with a cost impact of approximately $82K additional cost.
�a 24 Atqasuk Power Line Transmission Study
" September 15, 2011
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It
v Report of Findings
10
10 D.5 Atqasuk Substation ER2
If • The cost estimate is predicated on the power transmission line feeding the existing 4160 Volt Power
to Line from a tie-in to a 2 MVA transformer located at the power house.
11110 • An issue requiring resolution is the basis for the power and control interface between NSB facilities. It
10 is assumed the existing power plant will be retained as emergency back-up power, but it may 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, 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 ice 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.
10
!1% E. Western Route 1 (WR1) — Physical Description & Basis of Estimate
E.1 Barrow Substation Western Route 1 (WR1)
• The construction estimate is predicated on the power transmission line tying into the existing 4160
volt power line, with a drop to the substation at that same voltage, and the power feed output at 34.5
kV; achieved by routing through a 2 MVA transformer.
• An issue requiring resolution is the basis for the power and control interface between the BUSCI and
the NSB facilities. While an important and vital part of the system, the differences between the as -bid
and the as -found condition are not expected to cause significant cost impact.
• Underground (UG) cable is used for a significant part of the line, so approximately 4 MVAR's of
Reactors, to offset the capacitive reactance, will be required and result in about $453K of cost impact
to correct the issue.
• An issue requiring clearer definition is the location of the substation that feeds the Power
Transmission Line at the BUECI site; and/or to provide an allowance for a connection to this site from
the power line feed location. It is assumed that there is adequate space available at BUSCI, to allow
for the required reactors, transformer, breakers, switches, control module, or other required
appurtenances. Additional footprint is required at the substation due to the required reactors and
their breakers.
• This work is assumed to be performed during the summer season and it should be noted that the
substation equipment has the longest material lead time.
• Existing support facilities in Barrow are expected to be utilized for housing and meals.
E.2 Barrow to South Pad Line Segment, WR1 — Length: 6.8 Miles. Common to Both
Routes
• This work is assumed to be done during the summer season, and is predicated upon utilizing the
existing ROW/roadway for an existing power line. This construction effort will install new 78' tall RLS
Single Composite Pole Structures, with embedment of approximately 13' feet in depth.
�G=a� 25 Atqasuk Power Line Transmission Study
September 15, 2011
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Report of Findings
• This segment is assumed to be installed during the summer season; and is predicated upon utilizing
the existing ROW/roadway for an existing power line. This construction effort will install new 78' tall
RLS Single Composite pole Structures, with embedment of approximately 13' feet in depth.
• 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. 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 cut-outs will
also be relocated to new structures. Short outages for transfer of the services will be required on this
segment, but timely warning to 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.
E.3 South Pad to Walapka Segment on VSM's, WR1 — Length: 18.8 Miles
1 •
10
1
s
s
E.4
This work is assumed to be done during the winter season and is predicated on utilizing low ground
pressure equipment for the installation of a steel messenger cable on the existing VSM's.
A bolted support assembly, to attach the messenger cable to the VSM is the basis of the estimate,
and it is planned to install the 3-phase, jacketed, medium voltage cable, (Okonite CLX) and the FOC
in a 1 % inch HDPE duct; carried in CAD clamps which is typical construction method at the Prudhoe
Bay oil fields,
Additional anchors will be required to resist the imposed strains.
A Cat Train Man Camp will provide support services including housing and meals for the crew.
The ROW Alignment is the existing 6" Gas Line VSM routing.
Cable Insulation will be limited to the 35 kV Conductor, due to cost and constructability constraints.
There will be a step-down transformer bank located at the Barrow Gas Field terminus to enable the
tie-in to the existing grid. Further work and discovery may determine that circuit switches, with
SCADA control, might be required with a cost impact of approximately $82K additional cost.
The cost estimate includes an OH Power Feed to the Barrow Gas Field with distribution poles and
step-down transformer bank at the gas line terminus.
Tie-in for Walapka Gas Field Segment, WR1 — Length: 0 .2 Miles
This work is assumed to be done during the winter season and is predicated on utilizing low ground
pressure equipment for that construction, utilizing the current maintenance facility as a connection
point.
There will be a step-down bank at that gas field terminus to tie into the existing grid
Further work and discovery may determine that circuit switches, with SCADA control, might be
required with a cost impact of approximately $82K additional cost.
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Atqasuk Power Line Transmission Study
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Report of Findings
E.5 Walapka to Atqasuk Western Route, Overhead (OH) Line Segment, WR1 — Length:
48.8 Miles
• This work is assumed to be performed in the same manner as the Eastern Route with installation
occurring during the winter season and utilizing low ground pressure equipment for that construction.
Typically 63' RLS single composite pole vertical support structures will be embedded to twelve (12)
feet in depth.
• Route will start at the southern terminus of the Walapka gas field VSM's and follows the Eider friendly
route originally identified.
• Slurry will be utilized to backfill the drilled excavation and will also be placed inside the bottom section
with a "fly bucket" to deal with issue of hollow core strength if required.
• Additional pole sections will be provided, for construction personnel to modify pole length if required,
due to terrain or ice lenses encountered during drilled excavation.
• A Cat Train Man Camp will provide support services including housing and meals for the crew.
Should it be determined that circuit switches with SCADA control are needed, that potential cost
impact has been identified and would result in approximately $82K of additional cost.
E.6 Atqasuk Substation Western Route 1 (WR1)
• The construction estimate is predicated on the power transmission line tying into the existing 4160
volt power line, with a drop to the substation at that same voltage, and the power feed output
achieved by routing through a 2 MVA transformer
• 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 back-up power, but it may 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, to allow for the
installation of the transformer, breakers, switches, control module, or other required appurtenances;
with no additional cost impact.
• 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 ice 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.
F. Residence & Facility Heating Conversion in Atqasuk — From Diesel to Electric
• It has been clearly identified that the conversion of residential and NSB facility heating systems, from.
oil -fired to less expensive electric heat, is the most likely source of significant power load escalation,
but it is a more economic solution to the villages' heating needs. The current heating source is
heating oil or diesel fuel, which is flown in and is extremely costly. Utilizing electricity would decrease
current heating costs by approximately 30%, as well as decrease the carbon footprint of the
community.
• To provide a more accurate cost estimate, it would require site visits to every heated structure and an
analysis of the waste heat system.
27
Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
o If there is adequate space for the installation, a separate electric boiler would probably be the
least cost option. A control box, to retain the existing boiler capacity for back-up, could be
installed for approximately $2500 per residence. It is estimated the service requirements are
to provide a 9 kW 31,000 BTU heating source, per residence.
o Electric baseboard or radiant heat is another option that may be preferred. The cost is
% dependent upon the routing for the power supply feed, as well as the equipment locations.
Costs would be similar to the boiler as indicated in the heating unit described above.
o At the other end of the spectrum, as a worst case scenario, some residences may require
changing their existing distribution transformer, upgrading their electrical service, increasing
n existing load center capacity from 100 amps (typ.) to 200 amps; as well installing a larger
electric boiler or other electric heating equipment. There exists potential to overload the
current service configurations with this load. For example a 68,000 BTU boiler, as reviewed,
requires a 240 volt, 80 amp breaker with a #2 copper power feed from a source located at the
opposite side of the building. This conversion could cost on the order of $12K to $25K,
depending on circuit routing and structural/architectural restoration costs.
o The conceptual cost estimate (+/- 50% cost certainty) for residential heat conversion is
approximately $1.072MM, and does not allow for remodeling costs or items required, beyond
the basic conversion. The estimate is based upon a performance requirement that the
conversion matches the current heating equipment BTU rating. The estimate does not allow
M for upsizing transformers, services, load centers, or installing electric boilers, and strip
heaters. This work could be performed by local maintenance personnel to potentially reduce
costs. NSB maintenance personnel have indicated they are available to perform that scope
of work, but there is no agreed -to budget established within the estimate that reflects NSB
feedback on productivity or labor rates. This should be accomplished during the next
estimate effort.
o A concern that arose during this study is that if the existing, back-up oil -fired equipment,
required in the event of a power line outage, does not receive regularly scheduled
maintenance, doubts would arise as to the reliability of the back-up equipment, during an
outage, and the fear is that many of the "original oil -fired heaters" will not be operational when
needed.
o The conceptual cost estimate (+/- 50% cost certainty) for NSB Facilities heat conversion,
including utilizing the available waste heat, is approximately $.88MM. Oil -fired boilers are in
place as emergency back-up, but it should be noted that the existing heat exchangers should
be replaced with commercial grade electric boilers. Review and discussion of this issue
should be accomplished during the next estimate effort.
o NSB maintenance personnel who have indicated they are available to perform that scope of
work, have presented a reasonable way forward, and further NSB input is required to
establish it as a project basis. Another opportunity to explore this will occur if the power
transmission line is built.
• From a preliminary review of the economics of residential and NSB Facility heat conversion, utilizing
the estimated budgets required for completing the work, it would appear there is a comparatively
short payback period required, as a result of doing this work. A potential increase in cost to the base
proposal may occur as a result of increasing the size of the "step-up" and "step-down" transformers at
existing units with new ones rated for 3 or 4 MVA. That additional cost is approximately $50K. Given
the number of variables, at this point in the project development effort, it is difficult to foresee if this
will be required. Since the heating loads are highest when the ambient temperatures are lowest, the
transformers may not require upgrade due to fact that the transformer core is cooled by those lower
ambient temperatures.
28 Atgasuk Power Line Transmission Study
■� September 15, 2011
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M Report of Findings
H. Review of Items Covered in Initial Matrix
To review, the estimate is based on using the following:
Structures - RUS standard pole -line, single pole, and H-Structure type construction, using the least
cost option for pole height that complies with NESC design requirements, i.e. ground clearance and
phase clearance criterion.
Costs are shown for each type of structure identified during this study, and are expressed below as
the supply and installation cost per mile for the support type used, as follows:
o Treated Douglas Fir Poles, H-Structure — $318,212 per mile.
o Treated Douglas Fir Poles, Single Pole Structure — $223,876 per mile.
o Direct Embedded Steel H-Structures, supplied by Valmont — $232,102 per mile.
o Direct Embedded Steel Single Pole Structures, supplied by Valmont — $192,446 per mile.
o Composite Poles, H-Structures, supplied by RLS—$236,735 per mile
o Composite Single Pole Structures, supplied by RLS—$172,788 per mile
• Use of the existing 6" VSM's (gas line VSM's), with 25 foot spacing, to support the cable with a
messenger cable, typical to the methodology used on oil field projects with 35 kV cable—$660,140
per mile
r Use of the existing 6" VSM's (gas line VSM's), with 25 foot spacing, to support the cable with a
messenger cable, typical to the methodology used on oil field projects with 15 kV cable—$388,989
per mile
Installing new 6" VSM's with 45 foot spacing to support the cable with a messenger typical to the
methodology used on oil field projects with 35 kV cable—$995,946 per mile
1 Installing new 6" VSM's with 45 foot spacing to support the cable with a messenger typical to the
methodology used on oil field projects with 15 kV cable—$742,180 per mile,
• Trenching through ice road on tundra and installing 35 kV CLX cable—$1,576,912 per mile
• Trenching in road from Barrow to South Pad and installing 35 kV CLX cable—$1,407,185 per mile
Using, as cost basis, Standard Alternating Current AC Power Transmission at 24.9 kV, 34.5 kV, 69
kV and 110 kV.
Using, as cost basis, High Voltage Direct Current Transmission at 30kV and 50kV.
Review of connection requirements to provide cost basis for power feeds required for the planned
loads.
J. Recommendations — Routing & Construction Methods
A significant portion of the costs for this project are driven by the logistics required to perform
construction on the North Slope. No road system exists and access is assumed to be permitted only
on a winter trail, with low ground pressure equipment. Our estimates do not include an ice road. An
ice road would be required to support winter trenching activity to prevent damage to the tundra; that
would take many years to re -vegetate.
29 Atgasuk Power Line Transmission Study
September 15, 2011
Report of Findings
� The primary
focus of the power line routing involved avoidance of the high -density, nesting areas
i utilized by endangered N. Slope bird species: Steller's Eider, Spectacled Eider and Brant Geese.
J.1 - Best Route Recommendation
i AC Power Supply, due to the following:
Eastern Route 2 (ER2), pp Y� g:
• Has the lowest total installed cost: $16,577,142.
• Is the route with the least potential impact to the endangered bird species.
F
• Is the shortest, most viable route given the information provided, avoiding lakes and river crossings to
the greatest degree possible.
F
• Construction methodology has a proven track record in the arctic environment.
I
• Materials or alternates are available from multiple sources
I • Poles chosen for use are reported to get stronger in a colder environment and have a 40 year
warranty; which is two times the warranty duration period provided by steel manufacturers. Their
lighter weight allows for the use of small helicopters to install the assembled structure and allows air
I transport of much taller poles. Less field assembly is required.
} Uniform manufacture allows defining the exact requirements for connection hardware installation.
This is not offered or possible with typical wood structures.
I
• See Appendix C, Constructability Analysis and Cost Estimates, Exhibit 1 —Eastern Route —ER2 Cost
Estimate
J.2 - Western Route 1 (WR1) is not recommended as the best route due to the following:
i
• Route crosses some of the more dense nesting areas encountered during the study.
• Route has considerably more cost: $31,787,570, or almost two times the installed cost of ER2, due to
the 35 kV cable cost impact, a rapidly escalating cost element, due to correction caused by HV cable
construction capacitive reactance mitigation.
1 Route would be more difficult to maintain or repair.
• The capacitive reactance created by the cable is about 4 MVARs which would need to be offset,
which is technically complex and difficult to do.
• Material Pricing for this estimate was completed during the Fall of 2010. It should be noted that
certain commodities prices, including copper, have escalated since completion of the estimate.
Material costs should either be indexed for the cost escalations over time, or re -priced.
• Retrofit of an existing VSM takes more time and varied resources to complete the work. This
segment of the of the route would take a comparatively longer period of time to construct as opposed
to typical overhead line structure installation.
• See Appendix C, Constructability Analysis and Cost Estimates, Exhibit 2 — Western Route — WR1
Cost Estimate
J.3 - Other Report Data Utilized (AC Power Supply) — Polar Consult Report, August 2009,
Denali Commission
The Polarconsult report defines AC line cost as $296,000 per mile with a range of $140,000 to
$400,000 per mile. The $296,000 per mile cost is in agreement with the Napakiak value used
,`- 30 Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
r
earlier in their report and seems reasonable as we understand the project actual cost was a little
higher. The reason for this is that H-piles were used for pole foundations in an area that is very
susceptible to frost jacking. This constituted a significant part of that project's cost. These values
also serve to validate our cost estimate.
• The report proposed long span, tall pole, installations with SWER HVDC system construction. We
concur but maximizing span lengths has always been considered one of the economic design
solutions for both AC and 2-Wire, and conventional HVDC lines. NESC clearance issues, caused by
Aeolian vibration and Galloping vibration are the primary reason that a SWER HVDC could achieve
longer span lengths.
• The report proposed alternative utilizes hollow fiberglass poles, similar to the composite poles used in
this project's estimate basis. They are proposed for similar reasons except that the composites
required (and those are currently in production) are stronger and have a longer installation history.
JA - Maintenance Requirements — AC Power Supply
• Tracking Review 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. Tracking surveillance should occur the first year after construction and about once
every three years thereafter. One reason a coastal route was avoided is that it would add salt
. spray to the power line, causing a tracking problem.
4 Dampener or bird diverters, if installed, should be visually inspected yearly, as well as checked
. for vandalism. Damage to conductors or insulators, from firearms, is one of the most common
. causes of damage.
• Changes in river or stream flow should be reviewed to confirm that no structural foundations
. are being adversely impacted by the waterway channel change.
•0 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.
. • Anchor creep or structural jacking mitigation will be required, especially if the Western Route
1 with it's many VSM's, is chosen. The forces imposed by a pipeline and by a messenger strand
. supported cable are not usual, so an inspection of the support members and anchors should
. occur yearly.
• Equipment required for maintenance should be defined and it is assumed that some of the
equipment required for construction should be transferred to the line maintenance crew or
contractor for use. These items are as follows:
o low ground pressure man -haul
o a man -lift mounted on a flex track piece of equipment
o a drill mounted on a flex track piece of equipment
o a 20 ton boom crane on tracks similar to a Grove CN20.
Those costs are in the Maintenance budget assuming that at least half the cost goes to the construction
budget and the value for demobilization of that equipment is transferred to the maintenance budget.
31 Atgasuk Power Line Transmission Study
September 15, 2011
Repot of Findings
• Estimated maintenance costs include a basic O&M cost of $1,315 per mile for all alternatives, an
annual cost of $5 000 for VSM inspection for the Western Route alternatives, and $50,000 for
converter inspections for the ❑C alternatives-
K. Estimate Basis - Issues That Need Clear Understanding
it should be noted that "economies of scale" can be achieved as a result of employing standard types of
design and from permitting requirements; if the majority of the design is standardized and repeatable, and
the volume of repeatable work resulting from permitting requirements is larger enough. Although costs
will be affected by the final route location, and some costs could change significantly, the estimate cost
certainty should be maintained at the -1 fl%/+25% range. The estimated project cost is based on un-
escalated costs for materials, labor, equipment, quoted or assumed construction costs, and the proposed
construction methodology appears to meet the project requirements. The construction schedule is heavily
dependent upon material deliveries via a barge that completes one delivery per year to Barrow, and is
this cost is included in the estimate. Market demand may escalate material costs included in the current
cost estimate.
32
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Report of Findings
6. — Environmental Considerations
A. introduction
The goal of this project is to lessen North Slope community dependence on economically and
environmentally costly diesel fuel which currently is barged to the communities annually. The project
would also represent a reduction in the carbon "footprint" for these communities, which ultimately will be
beneficial for wildlife populations, but the implementation of the projects comes with some potential costs
for wildlife, especially bird populations. The evaluation of the avian resources and waterfowl habitats in
the project area, as a precursor to an assessment of the potential costs for birds from implementation of
the proposed power line from Barrow to Atqasuk, is the focus of this report section.
The proposed power line would rain from the gas processing plant in Barrow south approximately 129 km
(80 miles) to the village of Atqasuk on the Meade River. Currently the NSB is proposing two alternative
routes for the power line (a Western Route [Base Case] and an Eastern Route [Preferred Alternative]; see
Appendix D, Figures 1 to 5). During initial planning for the sighting of these two alternative routes,
environmental concerns (e.g., avian occurrence and avian habitat information) were included in
discussions to try to reduce the potential for impacts on threatened bird species and bird species of
conservation concern. A route previously envisioned (during the early 1980s) for a power line from
Barrow to Atqasuk was rejected at an early stage in planning because it ran close to the coast and likely
would have necessitated more maintenance due to corrosion from salt spray. A power line along this
coastal route also may have represented more of a collision hazard for migratory birds because of the
prevalence of coastal fog and its effects on visibility of the power line. Of the two alternative routes
selected, the northernmost section of the Western Route would follow existing power lines and gas
i pipelines associated with the Barrow gas fields south to Walapka; where possible, the power line would
be laid alongside gas pipelines and would be connected to existing vertical support members (VSMs).
The majority of the Western Route for the proposed power line, however, would be OH from Walapka
south to Atqasuk. The OH portion of the line would involve single -pole construction and support poles
would be spaced from 700 to 1200 feet apart. The power line would be elevated approximately 60 feet off
the ground. The proposed Eastern Route power line would be all OH and the pole spacing and line
elevation would be as noted for the Western Route. Because formal design plans and routing of the
proposed power line also depend on engineering and economic concerns, environmental analyses
represented only one set of concerns discussed during the planning phase. Factors such as cost (buried
. versus OH), location of private lands, location of existing infrastructure, and human health and safety
were evaluated. Finally, environmental mitigation measures deemed feasible at this stage of design,
including the possibility of using reflective wire (T2) to increase visibility for birds and placing some
portions of the power line along existing gas pipelines, as proposed for the Western Route, were
considered.
Overhead power transmission lines can result in direct effects on birds through injury or mortality due to
collision or electrocution (e.g., Manville 2005). Although no comprehensive estimate of annual mortality of
birds in North America is available, mortality rates can be substantial (Day et al. 2007). The few
comprehensive studies in Alaska suggest that although most birds do avoid collision with power lines,
many collisions and consequently fatalities do occur (Anderson and Murphy 1988, Shook et al. 2009).
r Many factors such as weather, migratory patterns, season, and behavior patterns unique to individual bird
species can affect mortality rates. Birds also can be affected indirectly by the construction of power lines
(e.g., creating perches for avian predators and the displacement birds from important habitats).
Important environmental features of interest included two threatened eider species (Spectacled and
Steller's Eider) both protected by the Endangered Species Act (ESA), and other sensitive, closely related
resources (e.g., wetlands and avian habitats). To accomplish the evaluation of this environmental
information, ABR, Inc. —Environmental Research & Services (ASR) reviewed available literature and
unpublished data available on these threatened eider species, as well as other species of conservation
• 33 Atqasuk Power Line Transmission Study
September 15, 2011
bh�-A
111111110 Report of Findings
concern (e.g., Yellow -billed Loons, a candidate species under the ESA, and Brant, a species of
conservation concern), mapped important wetland habitats used by the most common threatened species
in the area (Spectacled Eider), and briefly summarized known and potential impacts of overhead power
lines on birds in northern Alaska. This report provides a summary of those resources and potential
impacts related to the proposed power line. Because engineering plans for this project are preliminary, we
limited our presentation to the power line itself and did not discuss any associated facilities that may be
required.
B. METHODS
B.1 Avian Resources
We first identified all endangered, threatened, or candidate bird species listed under the ESA that occur in
the Barrow—Atqasuk region, as listed by the U.S. Fish and Wildlife Service (USFWS 2010a), and all bird
species of conservation concern likely to occur regularly in tundra habitats the Barrow—Atqasuk region
(Table 1). To identify bird species of conservation concern, we used the conservation concern lists from
organizations that have specialized experience with various bird species groups in Alaska, including
Water bird Conservation for the America's North American Water bird Conservation Plan (Kushlan et al.
2002 and 2006), Alaska Shorebird Group's Conservation Plan for Alaska Shorebirds (ASG 2008), and
Boreal Partners in Flight Working Group's Landbird Conservation Plan for Alaska Biogeographic Regions
(BPIFWG 1999). In addition, we use the conservation concern lists from management agencies in Alaska
that are likely to be involved in the permitting process for this project, including USFWS's Birds of
Conservation Concern (USFWS 2008), Alaska Department of Fish and Game's Species of Special
Concern (ADFG 1998) and Comprehensive Wildlife Conservation Strategy (ADFG 2006), and the Bureau
of Land Management's Special Status Species List for Alaska (BLM 2005).
We then focused on collecting information on the occurrence of four water bird species (Spectacled Eider,
Steller's Eider, Yellow -billed Loon, and Brant) for which detailed observational data are available from
aerial survey work; this information was displayed in map form to help in developing the two proposed
alternative alignments. Primary sources of information on these water birds species included unpublished
databases on bird observations in northern Alaska developed from broad -scale aerial survey programs
managed by the U.S. Fish and Wildlife Service (USFWS) (e.g., the North Slope Eider Survey and Arctic
Coastal Plain breeding pair survey), as well as information from more localized aerial surveys during the
. breeding season by ABR, USFWS, and the North Slope Borough Department of Wildlife Management in
the Barrow region. We also mapped more site -specific information on water birds (e.g., Yellow -billed Loon
nests and Brant nesting colony locations) using USFWS and ABR generated databases. In addition to the
information on water birds, we acquired and presented GIS data on the location of native allotments,
which were important to avoid in designing the alignment for the proposed power line.
Although a jurisdictional wetland determination will eventually be required during the Section 404 wetland
. permitting process for the project, we only mapped those wetland habitats in the region that were known
to be of high value for breeding Spectacled Eiders (see below). The wetland habitats preferred by
Spectacled Eiders also are used by other waterfowl species on the North Slope, so this mapping provides
some information on the occurrence of breeding habitats for a larger set of waterfowl species.
From the scientific literature, we summarized natural history information on habitat use, timing of use, and
history of collisions with power lines for each threatened or candidate species, especially in northern
Alaska, to help assess the potential for these species to collide with OH power transmission lines on the
North Slope.
34 Atqasuk Power Line Transmission Study
. September 15, 2011
Report of Findings
Finally, in June 2010, we conducted an aerial survey along the original (coastal) power line route that was
envisioned in the 1980s to assess waterfowl habitats and record the presence of Steller's and Spectacled
Eiders in that area. The observations from that survey are displayed in Appendix D, Figures 1, 2, and 4.
B.2 Mapping Spectacled Eider Breeding Habitats
High -value Spectacled Eider breeding habitat was mapped for the project area between Barrow and
Atqasuk using existing, publicly available National Wetland Inventory (NWI) wetland mapping available
digitally from the U.S. Fish and Wildlife Service (USFWS 2010b). The NWI mapping available for the
project area was prepared using aerial photography obtained in 1979 and 1985. The mapping of breeding
habitats was used to help identify potential power transmission line routes that would cross fewer areas of
high -value breeding habitats for eiders and other waterfowl species. Breeding habitats for Spectacled
Eiders are roughly representative of breeding habitats used by other waterfowl species on the coastal
plain, and especially the water body/wetland complexes used during brood -rearing by species such as
Long-tailed Duck and Northern Pintail.
The approach used to map high -value Spectacled Eider breeding habitat (a combination of nesting and
brood -rearing habitats) was based on first identifying preferred nesting and brood -rearing habitats and
then equating or "cross -walking" those habitats to the available NWI wetland types in the project area.
The polygon boundaries for Spectacled Eider breeding habitats are based on the NWI wetland map
boundaries and because the NWI mapping is coarse scale, the final map of breeding habitats for
Spectacled Eiders also is coarse scale. The identification of preferred nesting habitats for Spectacled
Eiders was based on information collected during field surveys in the Colville River Delta (Johnson et al,
2004), the Kuparuk oilfield (Anderson et al. 2009; Stickney et al. 2010), and the Prudhoe Bay oilfield
(Warnock and Troy 1992) (see Table 2). The technique to map preferred nesting habitat involves
identifying suitable nesting habitats that fall within 100 meters of aquatic marshes and open water bodies
because Spectacled Eiders most often nest in proximity (usually <100 meters) to water bodies and
especially wetland/ water body complexes (Anderson et al. 2009; Stickney et al. 2010; see Schick et al.
2004 for more information on the identification and mapping of high -value Spectacled Eider nesting
habitat). In the area mapped for this study, five broad habitat types were considered high -value for
nesting and/or brood -rearing (Tables 2 and 3).
The NWI wetland types mapped in the region of the proposed power line were cross -walked and
classified into eight wildlife habitat types (Table 3). Five habitats were treated as high -value nesting
and/or brood -rearing habitats, two represented large open water bodies, and one represented lacustrine
barrens (Table 3). High -value nesting habitats for Spectacled Eiders were delineated using a GIS by
i buffering out 100 meters from the edges of high -value brood -rearing and all open -water habitats and then
selecting all high -value nesting habitats that occurred within those buffer areas. High -value breeding
habitats for Spectacled Eiders then were assembled by combining the high -value nesting habitat
polygons (within the 100-meter buffer areas above) with the polygons representing high -value brood -
rearing habitats. Large open water lakes (> 20 acres in area) were not considered high -value brood -
rearing habitats, but preferred nesting habitats within 100 meters of the shorelines of large lakes were
considered high value for nesting. Habitat selection and geo-processing were done using Arc GIS 10.0.
The assessment of the habitats present in the region of the proposed power line and the cross -walking
! with the NWI types previously mapped were conducted using color infrared (CIR) imagery for the project
area acquired during summer 2002 (2.5-meter pixel resolution; supplied by Golder Associates Inc.).
35 Atgasuk Power Line Transmission Study
September 15, 2011
4
Report of Findings
C. RESULTS AND DISCUSSION
C.1 -Avian Resources
Approximately 70 species of birds commonly occur in the Barrow area (Pitelka 1974). Additional species
will occur in the project area because of the additional inland habitats found near Atqasuk (e.g., riparian
scrub and foothill scrub habitats), which are not found on the Arctic Coastal Plain near Barrow. The
project area's avian communities are dominated by water bird species including loons, waterfowl,
shorebirds, gulls, and jaegers. The diversity of passerine and raptor species (including owls) is far lower
than water birds in the area. Roughly half of the birds recorded regularly breed in the area, while others
are rare breeders or migrants (Pitelka 1974). Nearly all birds using the study area are present during the
spring, summer, and fall (May to early October). Based on the set of eight bird conservation concern lists
noted above in Methods, 21 of the 70-plus species that occur in the project area currently are considered
species of conservation concern and three are listed as threatened or candidate species under the ESA
(Table 1).
Most breeding birds on the North Slope arrive on their tundra nesting habitats in late May and early June
and begin to nest as soon as suitable tundra nesting habitats are snow -free. After nesting, departure is
highly variable among species, but most shorebirds and passerines have left the area by late August or
early September, while the larger migratory waterfowl and loon species, which have longer
developmental periods, linger into October and November. Ptarmigan, Gyrfalcons, Snowy Owls, and
Common Ravens may occur in the project area during the winter months.
Three features of the bird community are most important in discussing the development of OH power
lines in the region. First, 24 species of conservation concern breed in, or migrate through the region
(Table 1). Two of those 24 species (Spectacled and Steller's Eider) are classified as threatened under the
ESA, while a third species (Yellow -billed Loon) has been identified as a candidate for listing under the
ESA. The presence of the two threatened species in the project area will necessitate Section 7
consultation under the ESA to evaluate the expected impacts on those threatened species from
construction and operation of the proposed power line. Candidate species also are sometimes considered
in Section 7 consultations.
Second, raptors also are often associated with power lines and are known to use power line poles as
perches, although most raptor species nest in the foothills of the Brooks Range rather than on the coastal
plain. Juveniles of some species, however, including Golden Eagles, do use coastal plain habitats in the
study area (Ritchie et al. 2003), and migrant adult and immature birds of other species such as Peregrine
Falcons also occasionally occur on the coastal plain. Golden Eagles receive special protection under the
Bald and Golden Eagle Protection Act.
Third, Point Barrow is one of the most prominent locations in the migration pathways of water birds in
spring and fall in North America. During spring migration (May), hundreds of thousands of water birds
pass Point Barrow following early season, near shore leads in the ice (Woodby and Divoky 1982). Many
species also may fly inland of Point Barrow as indicated by telemetry studies and visual observations
(e.g., Troy 2003, J. Schmutz, USGS, pers. comm.). Fall migration past Point Barrow occurs in early July
through October or November (Suydam et al. 2000). Additionally, near shore marine waters, including
Elson Lagoon, east of Point Barrow and Ledyard Bay west of Barrow, are important for staging and
molting water birds in the region (Fischer and Larned 2004, Lysne et al. 2004).
36
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Report of Findings
r
C.2 Spectacled Eider
Spectacled Eiders occur in disjoint coastal breeding populations in arctic Russia, western Alaska, and
northern Alaska (Petersen et al. 2000). The subpopulation in western Alaska has undergone severe
declines in abundance (Kertell 1991, Stehn et al. 1993) and this precipitated listing the species as
threatened by the USFWS in 1993. Historical records of Spectacled Eider abundance in northern Alaska
are less certain, but some data suggests recent declines in numbers (Warnock and Troy 1992, TERA
1993, Peterson et al, 2000), The USFWS suggests that the Arctic Coastal Plain in northern Alaska now
1 supports the main breeding population of Spectacled Eiders in Alaska (USFWS 1996, Larned et al. 2009),
with a relatively stable population between 5,000-7,000 breeding pairs (Larned et al. 2009).
Spectacled Eiders arrive on the tundra in the study area in late May or early June (Johnson and Herter,
1989, USFWS 1996). Nesting begins by mid -June and eggs start hatching in mid -July (Warnock and Troy
1992, Anderson and Cooper 1994). Although specific nesting studies have not occurred near Barrow,
studies in the oilfields of northern Alaska show Spectacled Eiders use a variety of habitats for nesting,
including salt -killed tundra, aquatic sedge with deep polygons, and non -patterned wet meadow within
drained lake complexes (Warnock and Troy 1992, Johnson et al. 2000, Bart and Ernst 2005, Anderson et
al. 2009). Nests are often on small islands, peninsulas, and pond shorelines usually within a meter of
water (Anderson et al. 1999, Bart and Ernst 2005). These habitat types occur between Barrow and
Atgasuk and breeding pairs of Spectacled Eiders are regularly recorded there (Larned et al. 2009,
Obritsekewich and Ritchie 2009; see Appendix D, Figures 1 and 2).
During brood -rearing (mid -July to early September), Spectacled Eiders use a variety of aquatic habitats
r including water bodies with emergent vegetation on their margins, basin wetland complexes, and
occasionally deep open lakes (Warnock and Troy 1992, Anderson and Cooper 1994, Johnson et al.
2000). When young are capable of flight, Spectacled Eiders move to near shore marine waters, and then
depart the coastal plain, usually by mid -September. After leaving breeding areas, Spectacled Eiders
move to molting areas along the western coast of Alaska (Ledyard Bay, Norton Sound) and the eastern
coast of Russia (USFWS 1996). Spectacled Eiders are found concentrated during winter in polynas of the
Bering Sea near (Petersen et al. 1999).
Within weeks of females nesting, male Spectacled Eiders depart the coastal plain. Most males (71 %)
outfitted with satellite transmitters in the Prudhoe Bay region did not stopover along the Beaufort Sea
Coast, but took more inland flights to molting areas in the Chukchi Sea (TERA 1993). Females, however,
flew to coastal waters and followed a more marine route to the Chukchi Sea during their outbound
migration (TERA 1993). During the molt and non -breeding season, Spectacled Eiders are primarily
benthic feeders that prefer deeper marine waters where crustaceans and mollusks are available as a food
source, but during the breeding season, they forage for crustaceans and other invertebrate prey in
shallower ponds and lakes (USFWS 2006).
In 1993, the Alaska breeding population of Spectacled Eider was listed as threatened. Although critical
wetland habitats were proposed for Spectacled Eiders on the North Slope by USFWS, none was
designated because nesting habitat was not considered to be limiting for this species. Only Ledyard Bay
in the Chukchi Sea was delineated as critical marine habitat for molting eiders (USFWS 2001).
Spectacled Eiders regularly occur as nesting birds in the project area and are widely distributed from
Barrow to Atqasuk (Appendix D, Figures 1 and 2). The maps on Figures 1 and 2 display observations of
males made during aerial surveys in the pre -nesting period (the presence of a male is often, though not
always, associated with a nest nearby). Concentrations of observations of males during the pre -nesting
period are variable depending on the years of survey data being evaluated and consistent spatial patterns
in occurrence generally are lacking (compare Figures 1 and 2). Nesting habitats preferred by Spectacled
1 37 Atgasuk Power Line Transmission Study
September 15, 2011
Report of Findings
Eiders are widely distributed in the project area (see Appendix D, Figure 3 and text below) and this
explains, at least in part, the wide distribution of Spectacled Eider observations in the area.
C.3 Steller's Elder
Most of the world population of Steller's Eiders breeds in arctic Russia and winters in northern Europe or
along the Alaska Peninsula (Pacific population) (Frederickson 2001; USFWS 2002). The Alaska breeding
population of Steller's Eider occurs in two regions, the Yukon-Kuskokwim Delta (Y-K Delta) and near
Barrow in northern Alaska. Once a common breeder on the Y-K Delta (Kertell 1991), nests are rarely
reported there now (Flint and Herzog 1999), Similarly, although their former nesting range in arctic Alaska
extended from Wainwright to Cape Halkett, the Steller's Eider currently is an uncommon breeder there
(Johnson and Herter 1989, Frederickson 2001), with the greatest frequency of birds nesting within —20
km (12 miles) of Barrow (Quakenbush et al. 2002; see also Appendix D, Figure 4). Aerial surveys support
this northern concentration of eiders as sightings of Steller's Eider pairs decline south of Barrow (USFWS,
unpublished data; Obritsekewich and Ritchie 2009), although pairs are observed as far south as the
Atqasuk area (USFWS, unpublished database; ABR, field survey data, 2010; see Appendix D, Figure 4).
The population size of Steller's Eiders breeding on the Arctic Coastal Plain, including Barrow, is difficult to
determine because of the variability of sightings among years and low numbers of birds recorded during
annual aerial surveys (e.g., Larned et al. 2010, Ritchie and King 2004). The recovery plan for Steller's
Eiders estimated the breeding population in northern Alaska at hundreds to low thousands (USFWS
2002).
Steller's Eiders arrive in pairs on the coastal plain near Barrow in late May to early -June, often
concentrating in wetland areas along Gaswell Road and Footprint Lake (e.g., Quakenbush et al. 1995,
2000; Obritschkewitsch and Martin 2002; Obritschkewitsch et al. 2001; Rojeck and Martin 2003, Rojek
2008). Pairs start to scatter across the tundra, and begin to nest in mid -June soon after tundra habitats
are snow free (Obritschkewitsch and Martin 2002; Quakenbush et al. 2004). The preferred habitats of
Steller's Eiders near Barrow are water bodies with pendant grass (Arctophila fulva), but streams and
Carex ponds are also used during summer (Quakenbush et al. 2000). Importantly, whether they breed in
a given year in the Barrow area is influenced by the occurrence and abundance of lemmings and their
predators such as Snowy Owls (Quakenbush and Suydam 1999). Nesting has been verified for Steller's
Eiders at Barrow in only 10 of 17 years since 1991 (Rojek 2008).
After hatch in late June through mid -July, Steller's Eider broods use tundra ponds, often with Arctophila
vegetation, within 1 km of natal ponds until fledging (-40 days; Quakenbush et al. 2000). Failed and post -
breeding birds also use water bodies with Arctophila present, but have been recorded in larger lakes,
lagoons, and near shore waters of the Chukchi Sea (Quakenbush et al. 2000). Steller's Eiders actually
spend most of the year in shallow coastal habitats, especially in the littoral zone and coastal lagoons
where they feed on mollusks and other benthic invertebrates (Fredrickson 2001).
Most of the Russian -Pacific population, including the Alaska breeding population, of Steller's Eiders move
to near shore habitats along the Alaska Peninsula, where they undergo a flightless molt for about three
weeks (Jones 1965, Petersen 1980). Some eiders remain in these molting areas through the winter, but
many move to wintering areas on the south side of the Alaska Peninsula from Cook Inlet through the
Aleutians (USFWS 2002).
In 1997, the Alaska breeding population of Steller's Eider was listed as threatened based on the
contraction of the Alaskan breeding range and resulting increased vulnerability of the remaining
population to extirpation (62 FR 31748; USFWS 2002). Critical habitat has been designated for Steller's
38 Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
Eiders only in western Alaska (66 FR 8850); no critical habitat has been designated in northern Alaska
including the Barrow area.
As noted above, the nesting of Steller's Eiders on the Arctic Coastal Plain currently is concentrated in the
region surrounding Barrow. The frequency of nesting by Steller's Eiders (as indicated by observations of
pre -nesting males) declines as one moves south of Barrow towards Atqasuk (Appendix D, Figure 4).
Other spatial patterns in nesting are generally lacking and the species has been found to breed
throughout the northern portion of the project area. It should be noted that surveys for this species
generally have not been conducted south to Atqasuk (with the exception of the 2010 surveys by ABR
along the original coastal alignment for the proposed power line). The frequency of nesting of this species
in the Atqasuk area, however, is expected to be lower than in the northern portion of the project area.
CA Yellow -billed Loons
Yellow -billed Loons are uncommon breeders on the Arctic Coastal Plain of Alaska (Johnson and Herter
1989, Earnst 2004), but concentrations of nesting birds occur in some areas such as the Colville River
Delta and between the Meade and Ikpikpuk Rivers (Earnst et al. 2005, J. Schmutz, USGS, pers. comm.).
They occur in low densities between Barrow and Atqasuk (<1 bird/259 km2 or 100 mi), and increase in
densities along the Meade River (Earnst 2004). Few nests of Yellow -billed Loons have been recorded in
the project area (Appendix D, Figure 5).
Yellow -billed Loons arrive on the breeding grounds in northern Alaska in the last week of May and early
June (Earnst 2004). Nest initiation begins by mid -June, hatching occurs in mid -July, and broods usually
are raised in the nesting lake (Earnst 2004). Nests are built on peninsulas, shorelines, islands, or in
emergent vegetation, usually in or adjacent to large deep, fish -bearing lakes, often with complex
shorelines (Earnst et al. 2006).
Although few Yellow -billed Loons nest in the study area, they regularly use the Chukchi and Beaufort
coastlines near Barrow during migration in spring and fall (North 1994). In spring they will follow leads in
the ice north and east and in fall they migrate west along the coast. Peak migration occurs before late
August, while some birds linger in coastal areas into late October (North 1994). Generally considered
coastal during migration, many birds migrate overland (Anaktuvuk Pass: Irving 1960). Recent telemetry
studies show birds banded east of Barrow flying overland through the study area (J. Schmutz, USGS,
unpublished data).
Currently, the Yellow -billed Loon is classified as a candidate species under the ESA (72 FR 31256;
USFWS 2010a). The ESA does not provide any statutory protection, but the UFSWS does encourage
cooperation with other state and federal agencies and industry to limit detrimental effects of activities on
this species.
Rather few observations of either Yellow -billed Loons or nests of Yellow -billed Loons have been recorded
in the project area, but there is a notable concentration of observations to the east of Atqasuk and east of
both of the proposed power line alignments (Appendix D, Figure 5).
C.5 Other Species of Concern
Twenty-one other bird species of conservation concern occur in the area (Table 1). All of these species
are protected under the Migratory Bird Treaty Act. One of those 21 species (Brant, a small arctic -nesting
goose) nests in small colonies near the proposed power line alignments in the project area (Ritchie 1996;
see Appendix D, Figure 5), and is valued as a subsistence resource on the North Slope. Brant
39 Atqasuk Power Line Transmission Study
September 15, 2011
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00 Report of Findings
10
populations throughout North America have declined substantially because of habitat changes on their
wintering grounds (Reed et al. 1998).
Two additional species (Golden Eagle and Rough -legged Hawk) are noted here because of their history
of, or potential for, electrocution at OH power lines. The Golden Eagle is considered a species of
conservation concern but the Rough -legged Hawk is not (Table 1). Both Golden Eagles and Rough -
legged Hawks breed in the northern foothills of the Brooks Range (Kochert et al. 2002, Bechard and
Swem 2002), while Golden Eagles, primarily sub adult birds, occur on the coastal plain in low numbers
(Ritchie et al. 2003).
D. SPECTACLED EIDER HABITATS IN THE PROJECT AREA
A total of 110,102 hectares (272,067 acres) of high -value Spectacled Eider breeding habitat was
identified in the region surrounding the proposed power line project between Barrow and Atqasuk (Table
3, Appendix D, Figure 3). The majority of the breeding habitats in the mapped area were nesting habitats
(65% of the total mapped area). Nesting habitats were represented by seven NWI wetland types, which
roughly correspond to two broad wildlife habitat types (Patterned and Non -patterned Wet Meadows)
identified as nesting habitats in other studies (Tables 2 and 3). Brood -rearing habitats accounted for the
remaining 35% of the mapped area and were represented by 21 NWI types. These 21 NWI types were
interpreted as three broad habitat types (Shallow Open Water without Islands, Sedge Marsh, and Grass
Marsh).
Deriving wildlife habitat types from existing NWI maps was effective in identifying general areas with a
high density of preferred breeding habitats for Spectacled Eiders, but there were limitations in equating
NWI wetland types to water bird breeding habitats. The primary limitation was developing a "clean"
crosswalk between NWI types and wildlife habitat types. NWI wetland types are classified based on
vegetation structure and hydrology whereas wildlife habitats, as mapped by ABR, are classified based on
geomorphology, surface form, vegetation structure, and disturbance (see Burgess et al. 2003; Schick and
Davis 2008). The effect of this likely would be an overestimation of the amount of preferred breeding
habitats in the mapped area because the NWI classification does not differentiate wetland types based on
landscape variables such as geomorphology and local -scale variables such as surface form. Additionally,
because the NWI mapping for the region was completed over 25 years ago, with aerial photography
dating from 1979 and 1985, there may be errors in habitat determinations due to landscape changes over
time and also due to variations in the NWI mapping techniques used across the mapped area.
14 Nevertheless, with the understanding that the amount of high -value Spectacled Eider breeding habitat
16 may be overestimated in the mapping area, the Western Route for the proposed power line was sighted
11116 to try to avoid crossing large concentrations of high -value Spectacled Eider breeding habitat as much as
possible (Appendix D, Figure 3). This effort was challenging, however, given the widespread occurrence
of high -value habitats in the project area.
w
A
r. 40 Atgasuk Power Line Transmission Study
September 15, 2011
I�
0 Report of Findings
VP
E. POTENTIAL AFFECTS OF POWER LINES ON BIRDS AT THE NORTH
SLOPE
10
16 EA Collisions
The greatest environmental concern for birds associated with the development of OH power lines is the
potential risk of injury or mortality caused by collision with overhead wires, including any guy wires. For
the Barrow—Atqasuk power line, the primary periods of concern for bird collisions would be spring (May —
June) and fall (August —October). A few species (ptarmigan, Snowy Owls, and possibly Gyrfalcons and
Common Ravens) may winter in the area and they would be at risk throughout the year.
Estimates of mortality rates of birds at power lines are quite variable (e.g., Day et al. 2007), but when it
occurs mortality can be substantial (Manville 2005). Although information on bird mortality at power lines
in Alaska generally is limited, some studies in northern Alaska have been conducted. In the Prudhoe Bay
area, species involved in fatal collisions with OH power lines included Pacific Loon, unidentified Eider,
White -fronted Goose, Long-tailed Duck, Northern Pintail, shorebirds, and passerines (Anderson and
Murphy 1988). Four non -fatal collisions of waterfowl species, including a male King Eider, also were
recorded. In 3 of the non -fatal 4 collisions, the birds flew up into wires after being disturbed by vehicles or
humans on the ground. The estimated annual mortality of birds at the Lisburne power line in Prudhoe Bay
was 2.7-19.9 birds/km/year (Anderson and Murphy 1988).
In Barrow, most records of dead birds found beneath power lines were recorded during USFWS ground -
based surveys for nesting Steller's Eiders; often data on these specimens are incomplete or anecdotal
(USFWS unpublished database, Fairbanks, AK). However, during specific power line surveys in Barrow
between 2007 and 2009, 43 dead birds were located during searches of 1190 km of power lines; 25%
percent of all birds found were waterfowl (NSB 2010). Limitations of this study included the absence of
estimates of the detectability of carcass and estimates of the level of predator scavenging, and the
authors believed their counts were underestimates of the actual number of bird collisions with the power
lines. Note that the NSB (2010) report is in draft form only, and hence any conclusions should be
considered preliminary at this time. Importantly, however, eider mortalities due to collisions at power lines
were documented in the NSB study. Bird flight diverters were installed on some segments of the Barrow
power transmission lines studied. In the USFWS data on mortality of ESA -listed species (USFWS,
unpublished database, Fairbanks, AK), four Steller's Eider power line collision records are present,
including two recorded during NSB surveys near Barrow (NSB 2010). Only one Spectacled Eider was
found during power line searches near Barrow (NSB 2010). Steller's Eiders also have been recorded
colliding with OH wires at Cold Bay on the Alaska Peninsula (USFWS, unpublished database, Fairbanks,
AK).
On the other hand, no eiders have been recorded during mortality monitoring of OH power lines in
western Alaska (Stebbins to Saint Michael and Nelson Island; Gall and Day 2007, 2008), although the
power lines studied occur in areas where eiders are known to migrate and breed. Other species,
particularly ptarmigan, were recorded as collision victims in the western Alaska studies. Portions of the
Nelson Island power line studied did have bird flight diverters installed (Gall and Day 2008).
Although power line monitoring studies in interior Alaska (generally a forested landscape) pose issues of
comparability with tundra habitats on the coastal plain in northern Alaska, they offer valuable insights into
some of the species groups most vulnerable to collision with OH power lines. Intensive monitoring of the
230 kV GVEA Northern Intertie transmission line on the Tanana Flats revealed that numerous species
collided with the power line (Shook et al. 2009). Prominent species included water birds in the Tanana
Flats section of the Intertie: in decreasing order of occurrence, Mallard, Northern Shoveler, and Green-
41
Atqasuk Power Line Transmission Study
September 15, 2011
i
b Report of Findings
1b
winged Teal, were identified during ground -based surveys (Shook et al. 2009). In upland portions of the
` Intertie route, where collision rates were greater, passerines and galliform birds (especially ptarmigan)
were commonly found (Shook et al. 2009). A corrected estimate for collisions ranged from 11 to 15
birds/kart of power line per year for the entire line; the variation in collisions was substantial, however,
resulting in large confidence intervals for the estimated collision rates (Shook et al. 2009).
i
E.2 Electrocutions
power lines also pose a risk of mortality to birds by electrocution, particularly for larger perching birds like
raptors when they ground themselves landing or departing from cross beams at the tops of power line
poles (APLIC 2006). Golden Eagles, Rough -legged Hawks, Gyrfalcons, and Peregrine Falcons, all
summer residents in northern Alaska, would be at the greatest risk. This risk can be mitigated
substantially, I1owever, if raptors are considered in the design of wire junctions at poles. Perch guards, for
i example, can deter landings on power poles (APLIC 2006).
E.3 Habitat Loss
Direct loss of wildlife habitats associated with the construction of a power line from Barrow to Atqasuk
probably would be minor and is unlikely to substantially affect bird populations in the area. However,
some additional functional loss/alteration of avian habitats in the vicinity of the proposed power line from
disturbance and associated infrastructure construction could occur. The amount of habitat loss expected
can be calculated after final engineering design work for the project has been completed.
E.4 Increased Predation Due to Habitat Enhancement
The increasing number of towers, utility poles, and other man-made structures in northern Alaska have
become a concern to the USFWS because this infrastructure provides potential perches and nesting
i platforms for predatory and scavenging birds, particularly the Common Raven, which preys on threatened
eiders and other birds species (largely by taking eggs during nesting). Raptorial birds, including Peregrine
i Falcons and Gyrfalcons, also will use man-made structures as nest platforms (Ritchie 1991) and Golden
Eagles will undoubtedly use power poles for perches from which to hunt, increasing the potential for these
birds to prey on tundra -nesting birds and increasing the level of bird predation in the region. As noted
above, perch guards on power poles can help to deter the use of power poles as perches by predatory
and scavenging birds.
F. WILDLIFE AND HABITAT RELATED REGULATIONS AFFECTING THE
PROPOSED POWER LINE
Several federal environmental laws and regulations related to wildlife and wildlife habitats will be pertinent
to the development and operation of the proposed power line and its associated facilities, including the
Endangered Species Act, Migratory Bird Treaty Act, Bald and Golden Eagle Protection Act, National
Environmental Policy Act, and the Clean Water Act (Section 404).
ij♦ The Endangered Species Act will affect the proposed power line project because of the presence of the
two threatened eider species and the candidate species (Yellow -billed Loon) in the project area.
Consultation with the USFWS under Section 7 of the ESA will be required to determine the potential for
take of these species under the ESA; Section 7 consultation should begin as soon as final alignment
I•
`.� 42 Atgasuk Power Line Transmission Study
- September 15, 2011
Repod of Findings
10
It designs are developed because the consultation process can be lengthy. The Migratory Bird Treaty Act
will apply if the removal of Common Raven nests, for example, is requested by the USFWS; this species,
like all migratory birds, is protected under the Migratory Bird Treaty Act. According to the act, all native
birds are considered migratory, even if they may be resident in a particular region. The Bald and Golden
Eagle Protection Act provides specific protections for Golden Eagles, which can be vulnerable to
electrocutions at OH power lines.
The National Environmental Policy Act, which requires environmental analyses such Environmental
Assessments or Environmental Impact Statements for actions by federal agencies, will apply to the
Barrow—Atqasuk power line because federal lands (e.g., the NPRA) under jurisdiction of the Bureau of
Land Management will be affected. The Clean Water Act requires a Section 404 permit for any dredging
and/or filling of wetlands, which will occur during drilling foundations for power poles, gravel filling at
associated facilities, and road construction.
G. RECOMMENDATIONS FOR POWER LINE ALIGNMENT:
IN REGARDS TO BIRDS AND WETLAND HABITATS
Based on the information gathered to date and knowledge of potential collisions risks for threatened
species using the project area, any OH power line developed will cross through high -value breeding
habitats used by the two threatened eider species, the candidate loon species, and other water bird
species. In addition to breeding -bird considerations, the study area also is used by birds migrating
between the Arctic Coastal Plain in the western Beaufort Sea area and the Chukchi Sea to the west. Most
migration of water birds, however, probably takes place along the coast outside of the project area.
The USFWS has concerns about OH power lines and their potential impacts on birds, particularly
threatened eiders in northern and western Alaska. Required operating procedures listed in the Record of
Decision for the Northeastern NPRA EIS (BLM 2008) state that: "to reduce the possibility of Spectacled
and/or Steller's Eiders colliding with above -ground utility lines, such lines shall either be buried in access
roads or suspended on vertical support members except in rare cases, which are to be few in number."
The procedures go on to note exceptions, which include: "overhead power lines may be allowed when
engineering constraints at the specific and limited [emphasis added] location make it unfeasible to bury or
connect the lines to a VSM."
With these points in mind, the Western Route for the proposed power line was designed with eider and
other water bird resources considered. In particular, the Western Route was designed to (1) follow
existing power lines and gas pipelines (connected to VSMs) south from Barrow to Walapka; (2) avoid
high -value nesting habitats for Spectacled Eiders as much as possible (see Figure 3); (3) cross areas of
the coastal plain with lower densities of Yellow -billed Loons and traditionally used Brant colonies (see
Appendix D, Figure 5); (4) avoid crossing the main channel of the Meade River; and (5) maintain a
relatively short route for economic and engineering reasons. Avoiding areas of concentrated nesting of
the two threatened eider species was difficult to accomplish in the design of the Western Route because
both eider species are widespread in the project area with no clear spatial patterns of occurrence (see
Appendix D, Figures 1, 2, and 4). Because burying the entire power line is not an economically viable
option, hanging the power line on the VSMs of the gas pipeline south to Walapka would reduce the
amount of OH power line and reduce collision potential accordingly. Importantly, the existing gas pipeline
in the project area crosses the most important breeding habitats for Steller's Eider (immediately south of
Barrow), so using any portion of the gas pipeline infrastructure could reduce collision potential with this
species. The design of the Western Route only took into consideration possible breeding habitat for
Spectacled Eiders, but similar habitats are used by other water bird species during breeding on the North
to< 43 Atgasuk Power Line Transmission Study
September 15, 2011
b
r
b
1
Report of Findings
Slope. Additionally, other water bird species use these same habitats during migration in terrestrial and
freshwater areas.
Using reflective power transmission line cable (e.g.. T2) may help minimize collision hazard for birds.
Another option to increase the visibility of {power lines to birds is to install bird flight diverters. Bird flight
diverters Dave been shown to reduce avian interactions with power lines (Day et al. 2007), however they
have not been found to weather arctic environments well (Gall and Day 2008) and therefore may have
limited utility for this project.
Although the height of power lines may result in different effects on birds depending on flight behavior
(e.g_, lower local flights versus higher migratory flights, power line height and collision hazard has not
been adequately studied in Alaska. it is possible, however, that higher pole heights could reduce the
number of poles needed and reduce perch and electrocution potential, especially for raptors. In addition,
higher line height might reduce the number of collisions of breeding birds when making local flights, as
their local -flight altitudes may generally be lower than during longer migratory movements.
L. List of Exhibits or Figures
See Section 9. List of Exhibits or Figures — Environmental Considerations
Figure 1 - Western Spectacled Eider Observations: 1992 to 2005
Figure 2 - Spectacled Eider Observations: 1999 to 2010
Figure 3 - High -value Breeding Habitats — Spectacled Eiders
Figure 4 - Steller's Eider Observations: 1999 to 2010
Figure 5 - Yellow -Billed Loon Observations: 1950 to 2010
44
Atqasuk Power Line Transmission Study
September 15, 2011
IP
10
Report of Findings
10
No
Table 1. Threatened and candidate bird species listed under the Endangered Species Act
Ir
(ESA)
and bird species of conservation concern likely to occur regularly in the
10
Barrow—Atqasuk region, North Slope, Alaska. Conservation status categories are
shown
for each species and listing organization.
r
Species
USFWSa
BLW ADFG° WCAd ASGe BPIF'
r
Brant
-B
Sensitive
_ -
r
(Branta bernicla)
species
Threatened
Species of
Steller's Eider
species under
T - - -
special
(Polysticta stelleri)
ESA
concern
Threatened
Species of
Spectacled Eider
species under
--- special — — —
i
(Somateria fischeri)
ESA
concern
Featured
King Eider
—
Sensitive species for — — —
(Somateria spectabilis)
species
conservation
Featured
Common Eider
—
species for — — —
(Somateria mollissima)
conservation
Long-tailed Duck
Sensitive Featured
species for
S
(Clangula hyemalis)
species
conservation
Species of
Featured Species of
Red -throated Loon
conservation
Sensitive
species for high
(Gavia stellata)
concern
species
conservation concern
Featured
Pacific Loon
—
species for — — —
i
(Gavia pacifica)
conservation
Yellow -billed Loon
Candidate
Sensitive Featured Species of
(Gavia adamsii)
species for
species for high
species
ESA
conservation concern
Northern Harrier
Featured
.
(Circus cyaneus)
—
_ species for -- - -
conservation
Golden Eagle
Featured
(Aquila chrysaetos)
—
— species for — --
conservation
Gyfalcon
Featured Priority
for
(Falco rusticolus)
— species for — - species
conservation conservation
Peregrine Falcon
Species of
Featured
(Falco pereginus ssp.
conservation
— species for — — - -
tundrius)
concern
conservation
American Golden -Plover
Species of
(Pluvialis dominica)
— — high
concern
45 Atqasuk Power Line Transmission
Study
September 15, 2011
i
i
Report of Findings
Species
USFWSa
BLW ADFGe
WCA'
ASGe
BPIF'
Species of
Species of
Whimbrel
conservation
— ---
—
high
—
(Numenius phaeopus)
concern
concern
Species of
Species of
Bar -tailed Godwit
conservation
— —
—
high
--
(Limosa lapponica)
concern
concern
Species of
Western Sandpiper
—
— —
—
high
—
(Calidris mauri)
concern
Dunlin
Species of
Species of
(Calidris alpina ssp.
conservation
— —
—
high
—
arcticola)
concern
concern
Buff -breasted Sandpiper
Species of
Featured
Sensitive
Species of
(Tryngites subruficollis)
conservation
species for
species
—
high
—
concern
conservation
concern
Species of
Featured
Species of
Arctic Tern
conservation
— species for
high
—
—
(Sterna paradisaea)
concern
conservation
concern
Snowy Owl
Featured
Priority
(Bubo scandiacus)
— species for
—
--
species for
conservation
conservation
Short -eared Owl
Featured
(Asio flammeus)
—
— species for
—
—
conservation
Smith's Longspur
Species of
Featured
Priority
(Calcarius pictus)
conservation
— species for
—
—
species for
concern
conservation
conservation
Hoary Redpoll
Priority
(Acanthis hornemanni)
--
— —
—
species forconservation
a. USFWS: U.S. Fish and Wildlife Service, Birds of Conservation Concern (for Bird Conservation Region 3, Arctic Plains and
Mountains) (USFWS 2008); and Endangered, Threatened, Proposed, Candidate, and Delisted Species in Alaska (USFWS
2010a).
b. BLM: Bureau of Land Management, Alaska Threatened, Endangered, and Sensitive Species List (BLM 2005); sensitive
species only are shown, threatened and candidate species listed by BLM duplicate the listings by USFWS 2010b.
c. ADFG: Alaska Department of Fish and Game, Species of Special Concern (ADFG 1998) and Comprehensive Wildlife
Conservation Strategy (ADFG 2006).
d. W CA: Water bird Conservation for the Americas, North American Water bird Conservation Plan (Kushlan et al. 2002 and
2006); species in the higher concern classes only, species of moderate and low concern are not shown.
e. ASG: Alaska Shorebird Group, Alaska Shorebird Conservation Plan Version II (ASG 2008); species of high concern only,
species of moderate and low concern are not shown.
f. BPIF: Boreal Partners in Flight Working Group, Landbird Conservation Plan for Alaska Biogeographic Regions (BPIFWG
1999).
g. Dash indicates the species is not listed or its conservation ranking is below the threshold for inclusion in this study (see notes d
and a above).
North 51ope Borough
46
Atqasuk Power Line Transmission
September 15, 2011
Report of Findings
No
10 Table 2. Identification of high -value nesting habitats for Spectacled Eiders in the Barrow—
Atqasuk region, North Slope, Alaska. Only coarse -scale habitats were identified
as derived from National Wetlands Inventory mapping of the area (see Table 3).
Regularly Used Habitats Equivalent Wildlife Habitat
on the North Slope" Sourceb Type in Project Area
Salt -killed Tundra
2
No equivalent type
Aquatic Sedge with Deep Polygons
2
Sedge Marsh
Sedge Marsh
1
Sedge Marsh
Carex Ponds
3
Sedge Marsh
Old Basin Wetland Complex
1
Patterned and Non -patterned Wet Meadow
Patterned Wet Meadow
2
Patterned Wet Meadow
Non -patterned Wet Meadow
1, 2, 3
Non -patterned Wet Meadow
a When in proximity (usually <100 meters) to water, including water bodies and aquatic marsh habitats (see text).
b 1 = Kuparuk oilfield (Stickney et al. 2010; Anderson et al. 2009); 2 = Colville River Delta (Johnson et al. 2004); 3 = Prudhoe
Bay oilfield (Warnock and Troy 1992).
■
1.0
e?,
Study 47 Atgasuk Power Line Transmission
lb
September 15, 2011
Table 3.
NWI Code
L2USA
L2USC
L1UBHb
L2UBHb
PUBF
PUBH
PEMl/UBH
PEMl/UBF
PUB/EMIF
PUB/EM1H
PEMI/2F
PEMl/2H
PEM1H
L2EM2/UBH
L2EM2/UBF
L2EM2F
L2EM2H
L2UB/EM2H
PUB/EM2H
PEM2/IF
PEM2/IH
PEM2/UBF
PEM2/UBH
PEM2F
PEM2H
PEMl/2E
PEM1C
r
PEM1E
PEM1F
PEMl/SS1F
.
PEM1/SS1E
Classification crosswalk table between National Wetlands Inventory (NWI)
wetland types and wildlife habitat types. Acreages represent the areas of each
wetland type illustrated on the map of high -value Spectacled Eider habitats (see
Figure 3).
Wildlife Habitat Type
Lacustrine Barrens
Lacustrine Barrens
Shallow and Deep Open Water without Islands
Shallow Open Water without Islands
Shallow Open Water without Islands
Shallow Open Water without Islands
Sedge Marsh
Sedge Marsh
Sedge Marsh
Sedge Marsh
Sedge Marsh
Sedge Marsh
Sedge Marsh
Grass Marsh
Grass Marsh
Grass Marsh
Grass Marsh
Grass Marsh
Grass Marsh
Grass Marsh
Grass Marsh
Grass Marsh
Grass Marsh
Grass Marsh
Grass Marsh
Non -patterned Wet Meadow
Non -patterned Wet Meadow
Non -patterned Wet Meadow
Non -patterned Wet Meadow
Patterned Wet Meadow
Patterned Wet Meadow
IP Total Acreage of High -value Nesting and Brood -rearing Habitats
Breeding Use
by Spectacled Eiders
None
None
Low value brood -rearing
Low value brood -rearing
Brood -rearing
Brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting and brood -rearing
Nesting
Nesting
Nesting
Nesting
Nesting
Nesting
Acres
n/a
n/a
n/a
n/a
9
24,986
14,436
23,016
172
3,033
1,265
1,239
1,873
2,920
37
164
6,987
7,168
507
2,003
2,165
36
1,073
120
2,676
7
10,432
30,451
41,040
70,248
24,004
272,067
a NWI codes used on publicly available wetland maps for the Barrow—Atqasuk area from USFWS (2010b); codes follow the
classification described in Cowardin (1979).
n NWI code refers to large lakes (>20 acres in area) following Cowardin (1979).
r
48
1
r
r
Atgasuk Power Line Transmission Study
September 15, 2011
Report of Findings
7. — Permitting Considerations
A. objective
Solstice Alaska Consulting, Inc (Solstice) was engaged to determine potential permit requirements for the
construction of a proposed electrical intertie between Barrow and Atqasuk, Alaska.
Our assumptions for the intertie are as follows:
The intertie would be overhead and approximately 60 to 70 miles long.
The utility poles would range in height from 40 feet to 80 feet tall.
The intertie alignment would cross wetland complexes and anadromous streams.
The project could cross property owned by the State of Alaska, the Federal government, the
North Slope Borough, and Arctic Slope Regional Corporation.
Below is a list of potential permits and authorizations that could be required for the project, based on
current understanding and knowledge of the project.
B. Federal Permits and Authorizations
Wetlands (Section 404 and Section 10) Permit
It is likely that a wetland permit would be required for this project because utility poles would be placed in
wetlands under the jurisdiction of the USACE. Also, a wetlands permit would be required if any poles
were placed below ordinary high water of any navigable stream.
Responsible Agency:
U.S. Army Corps of Engineers (USACE)
Statutes:
Section 404 of the Clean Water Act (1977) and Section 10 of the Rivers and Harbors Act (1890)
Rationale:
Section 10 of the Rivers and Harbors Act regulates construction, excavation, or deposition of materials in,
over, or under ordinary high water of any navigable water of the United States. Section 404 of the Clean
Water Act regulates discharge of dredged and fill material into waters of the United States, including
wetlands.
Timing:
Permits are issued following a Coastal Consistency Determination by the Alaska Department of Natural
Resources (ADNR) Division of Coastal and Ocean Management (DCOM) (see below for timing).
Contact:
Section USACE, Regulatory Branch
P.O. Box 6898
Elmendorf AFB, AK 99506-6898
Phone: 907.753.2724
Fax: 907.753.5567
49
Atqasuk Power Line Transmission Study
September 15, 2011
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T
T
R
i T
h
p
R
i AD
i S
i S
i
i s
pr
i re
Ti
re
1
N
Th
pr
fu
i
Ju
55
An
Ph
Fa
jud
i
fur
eport of Findings
ational Historic Preservation Act (NHPA) Section 106 Consultation
o
o
here is the potential to find cultural or historic resources in the Barrow - Atgasuk Intertie project area.
make the permitting process more efficient, consultation with the Alaska Department of Natural
esources (ADNR) State Historic Preservation Office (SHPO) should occur during the permitting process
he project could wait for the permitting agencies to complete this consultation as a part of their process;
wever, Solstice has found that completing the NHPA consultation with the SHPO helps to move the
ermitting process forward.
esponsible Agency:
NR SHPO
tatute:
ection 106 of the National Historic Preservation Act (1966)
ationale:
ection 106 requires Federal agencies to take into account the effects of their undertakings on historic
operties. The project must consult the SHPO regarding potential impacts to cultural and historic
sources in the vicinity of the project.
H
ming:
PO is required to respond within 30-days of the submittal of a findings letter. If no response is
ceived, the project can assume there would be no impacts to historic properties.
otes:
e SHPO could request a field survey for cultural resources, which could increase the timing on this
ocess. The SHPO could also find that the project could impact cultural resources. If this is the case,
her consultation would be needed.
o
intact:
dith Bittner, State Historic Preservation Officer
0 West 7th Avenue, Suite 1380
chorage, AK 99501
one: 907.269.8721
c 907.269.8908
y_bittner@dnr.state.ak.us
50
Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
10
Endangered Species Act Clearance
r Spectacled eider and the polar bear, both listed as threatened under the Endangered Species Act (ESA),
r may be found in the Barrow - Atgasuk Intertie project area. (Polar bears are also regulated under the
Marine Mammal Protection Act, which has separate consultation requirement, which could occur
concurrently with this process.) To make the permitting process more efficient, consultation with the U.S
Fish and Wildlife Service (USFWS) regarding impacts to listed endangered species assist in moving the
permitting process forward. The project could wait for the permitting agencies to complete this
i consultation as a part of their process; however, Solstice has found that completing the ESA consultation
helps to move the permitting process forward.
Responsible Agency:
r U.S Fish & Wildlife Service (USFWS)
r Statutes:
Section 7 of the Endangered Species Act (1973)
Rationale:
A consultation required by Section 7 must be performed for any activities that may affect species formally
listed as threatened or endangered.
Timing:
The USFWS has 30 days to respond to a findings letter.
Notes:
The USFWS could request additional information on the project or species and could require a field
survey, which could increase the timing on this process. The USFWS could also find that the project
could impact ESA -listed species. If this is the case, formal consultation with the USFWS would be
r needed and could take additional time.
r
Contact:
Ted Swem, Branch Chief
Endangered Species Fairbanks Fish and Wildlife Field Office
i U.S. Fish and Wildlife Service
r 101 12th Ave., Room 110
r Fairbanks, AK 99701
Phone: 907-456-0441
Fax:907-456-0208
ted_swem@fws.gov
r
C. State Permits and Authorizations
r
Coastal Consistency Determination
Most of the intertie project would occur within the North Slope Borough Coastal Management District;
therefore, it is subject to review under the Alaska Coastal Management Program. Although the North
Slope does not have a final coastal management plan in place, a consistency determination with the
' State's coastal zone enforceable policies would be needed.
51 Atqasuk Power Line Transmission Study
September 15, 2011
Report of Findings
10
fo
r Responsible Agency:
Alaska Department of Natural Resources (ADNR) Division of Coastal and Ocean Management (DCOM)
Statute:
. Federal Coastal Zone Management Act (1972), Alaska Statute (AS) 46.40 (Water, Air, Energy, and
Environmental Conservation; The Alaska Coastal Management Program)
Rationale:
Using the statewide standards and local enforceable policies established by a local coastal planning
r board, the Alaska Coastal Management Program (ACMP) evaluates the effects a project within coastal
zone boundaries will have on coastal resources and uses.
Timing:
The coastal zone review process begins after a Coastal Project Questionnaire is submitted and approved
and after the USACE has issued their Public Notice. After initiated, and if the process is not paused after
a request of additional information or elevated because of major issues, the process takes 60 days to
complete. Within this 60 day process, there is a 30 day public comment period.
Contact:
Christine Ballard, Project Review Assistant
DNR, Division of Coastal & Ocean Management
550 West 7t' Ave., Ste. 705
Phone:907.269.7478
Fax: 907.269.3981
christine.ballard@alaska.gov
Fish Habitat (Title 16) Permit
Because the Barrow — Atgasuk Intertie could involve crossing anadromous fish (salmon)
streams, it is likely that a Fish Habitat Permit would be needed. A Fish Habitat Permit is needed
A for any work in an anadromous stream, including crossing an anadromous fish stream during
the winter on ice.
■
Responsible Agency:
Alaska Department of Fish and Game (ADF&G), Division of Habitat
Statutes:
AS 16.05.841-871 (Fish and Game, Fish and Game Code)
A
Rationale:
Any activity or project that is conducted below the ordinary high water mark of an anadromous fish
stream requires a Fish Habitat Permit. ADF&G has statutory responsibility for protecting freshwater
::.
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r
anadromous fish habitat and providing free passage for anadromous and resident fish in fresh water
r bodies.
r
Timing:
The Fish Habitat Permit cannot be issued until DNR DCOM issues the Coastal Consistency
Determination. It is reasonable to expect this permit to be issued within five days of the issuance of the
Coastal Consistency Determination.
• Contact:
Mac McLean, Regional Supervisor
r Alaska Department of Fish and Game, Division of Habitat
1300 College Rd
Fairbanks, AK 99701-1599
Phone: 907.459.7281
r Fax:907.459.7303
mac.mclean@alaska.gov
r
State of Alaska Land Use Permit
• Because the Barrow —Atqasuk Intertie would cross land owned by the State of Alaska at the crossing of
the Meade River, and potentially at the crossing of the Inaru River, a land use permit would be needed.
r
Responsible Agency:
ADNR Division of Mining, Land and Water (DMLW)
Statutes:
11 Alaska Administrative Code (AAC) 96.010
r
Rationale:
. Land use permits are authorizations issued to use State land, on a temporary basis, for a variety of
purposes. The permits range in duration from one to five years. They are intended for temporary, non-
permanent uses. Land use permits are also issued for most activities in navigable waters because the
State owns most land below the ordinary high water.
r Timing:
The Land Use Permit application requires a 30-day public review. The Land Use Permit cannot be issued
r until DNR DCOM issues the Coastal Consistency Determination. It is reasonable to expect this permit to
be issued within five days of the issuance of the Coastal Consistency Determination.
Notes:
A $100.00 non-refundable filing fee is required by regulation (11 AAC 05.010(5)(B)). Checks should be
r payable to the "State of Alaska".
r
Contact:
Alexander Wait
53 Atgasuk Power Line Transmission Study
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Repot of Findings
DNR, DMLW, Northern Region Lands Section
3700 Airport Way
Fairbanks, AK 997094699
Phone: 907.451.2777
Fax: 907.451.2751
aj.wait@alaska.gov
State of Alaska Easement
Because the Barrow — Atgasuk Intertie would cross land owned by the State of Alaska, a permanent utility
easement could be needed.
Responsible Agency:
# ADNR Division of Mining, Land and Water (DMLW)
1
Statutes:
Q AS 38.05.850 (Public Land, Alaska Land Act, Permits)
Rationale:
Easements are issued on state land for uses including telephone or electric transmission and distribution
lines.
Timing:
The easement application requires a 30-day public review. The easement cannot be issued until DNR
DCOM issues the Coastal Consistency Determination. After the public and agency notice, a written
decision document will be completed and an Early Entry Authorization (EEA) is issued for construction
and survey. Once construction is completed and an approved as -built survey is received, a legal
easement is issued and recorded.
Notes:
A $100.00 non-refundable filing fee is required by regulation (AS 38.05.850). Checks should be payable
to the "State of Alaska
Contact:
Dianna Leinberger
DNR, DMLW, Northern Region Lands Section
3700 Airport Way
Fairbanks, AK 99709-4699
Phone: 907. 451-3014
Fax: 907. 451.2751
dianna.leinberger@alaska.gov
1
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D. North Slope Borough Permits and Authorizations
North Slope Borough (NSB) Land Use Permit
All projects occurring within the NSB outside of a village must acquire a NSB Land Use Permit. Because
. most of the Barrow-Atqasuk Intertie area would be on NSB managed lands, a Land Use permit would be
. required. It is likely that the project would be administratively approved by the Borough.
Responsible Agency:
NSB
. Statutes:
NSBMC Title 19
Rationale:
All conditional development or uses and master plans must receive approval prior to commencement.
. Timing:
. Approximately 35calendar days from the time of permit acceptance to obtain an approved permit,
assuming the review is not paused for additional information or elevated.
Notes:
. There is a $1,500 fee for an Administrative Approval and a $3,000 fee for a Conditional Development
Permit.
Contact:
Susan Kittick-Atos
Planning and Community Services Department
North Slope Borough
P.O. Box 69
Barrow, AK 99723
1
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Repot of Findings
Form 700-Village District Permit
All projects occurring within the NSB within a village district require Village District Permit. Because a
portion of the Barrow-Atqasuk Intertie area would be in the Atqasuk Village District and likely the Barrow
Village District, a village district permit would be required.
Responsible Agency: NSB
Statutes: North Slope Borough Municipal Code (NSBMC) §19.30.070, NSBMC §19.40.060, NSBMC
§19.40.110, NSBMC §19.50.030
Rationale:
The NSB requires permits for all use and development (as defined in the NSBMC §19.20.020), including
residential, commercial and public structures, operations, and facilities in Village Districts. This permit
application must be used to obtain approval for uses and development in Point Hope, Point Lay,
Wainwright, Atqasuk, Nuiqsut, Anaktuvuk Pass and Kaktovik. There is a separate Barrow Zoning District
r Application.
Timing:
Approximately 35calendar days from the time of permit acceptance to obtain an approved permit,
assuming the review is not paused for additional information or elevated.
Notes:
A $200 permit application fee is required. Checks should be made out to the North Slope Borough.
Contact:
Susan Kittick-Atos
Planning and Community Services Department
North Slope Borough
P.O. Box 69
Barrow, AK 99723
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10
Report of Findings
Form 500-Certificate of Inupiat History, Language and Culture/ Traditional Land Use
Inventory (IHLC/TLUI) Clearance
Because the Barrow-Atqasuk Intertie project would be seeking a NSB Land Use Permit, a Certificate
of Inupiat History, Language and Culture/Traditional Land Use Inventory (IHLC/TLUI) Clearance could
be required from the NSB.
Responsible Agency:
NSB
Statutes:
NSBMC§2.16.110, NSBMC §19.50.030(F) and §19.60.040(K)
Rationale:
All projects seeking a new Land Use Permit from the NSB for industrial/commercial development in a
Resource Development, Conservation, Scientific Research, and Transportation Corridor District for a use
or development that consists of an earth -moving activity, ice road, or seismic survey that has not already
been issued a Certificate of Inupiat History, Language and Culture/ Traditional Land Use Inventory
(IHLC/TLUI) Clearance. According to the NSB, while Applicants are required to obtain clearance from the
SHPO to obtain state permits, SHPO clearance alone may not be sufficient to ensure that sites listed in
the NSB's TLUI are protected. The IHLC clearance process is to protect TLUI sites.
Timing:
Timing for this process is unclear. The approved Certificate of IHLC/TLUI Clearance should be submitted
with the NSB Land Use application.
Notes:
A $100 permit application fee is required. Checks should be made out to the "North Slope
Borough."
Contact:
North Slope Borough Department of Planning and Community Services
Inupiat History, Language & Culture Division, IHLC Coordinator
P.O. Box 69
Barrow, AK 99723
Phone: 907.852.0422
Fax: 907.852.4224
E. Permitting Support - Engineering
Should the need arise, or if there is a continuation of this effort, engineering will provide technical support
to personnel charged with examining and identifying the permitting requirements for this project.
Information developed during this phase of the project will be secured and provided to the relevant
personnel upon client request. Providing accurate design engineering and project basis information to a
permitting effort is considered a priority support function for our Team members. Successful debrief of
i
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1
r Report of Findings
accurate project design basis project in support of the permitting effort, can be instrumental in making
1 the interested permitting agencies aware that due diligence has been done; development of a project capable
of being successfully permitted
1
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Report of Findings
g. — Economic Analysis
A. Objective
This section presents the economic analysis of the proposed electric power transmission line' (intertie)
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 system
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 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.
This study evaluates a number of options as shown below (more detailed description of these options is
provided in a prior section of this report):
The Western Route (WR1) versus the Eastern Route (ER2);
An Alternating Current (AC) line versus a High Voltage Direct Current (DC) line;
Electrical generation for Power only versus Electrical generation for Power and Heat.
Eight configurations arise from the combination of these options for route (Western vs. Eastern), current
type (AC vs. DC), and electric usage (for power only vs. for power and heat).
4 and Figure (enclosed in this section for clarity) show the net present value of the cost savings for each
project alternative. The results of the economic analysis indicate that the intertie option through the
Eastern Route with AC current used for power and heat has the highest net benefit with an NPV of cost
savings of $50.7 million. In general, a higher NPV is achieved with the Eastern Route than with the
Western Route, with the AC type of current than with the DC type of current, and 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.
5, on the other hand, shows the calculated benefit -cost (B/C) ratios of the different project alternatives. As
shown in the table, all eight 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 4 .Net Present Value of Cost Savings of the Intertie Project Alternatives
Eastern Route Western Route
AC current DC current AC current DC current
Power Only $35,324,295 $27,156,697 $17,246,575 $15,621,944
Power and Heat $50,675,352 $42,507,754 $32,597,631 $30,973,001
Source: Northern Economics, Inc
'Electric transmission lines are interconnections between electrical utility systems permitting exchange or delivery of power between
those systems. They can transfer electricity from a centralized power plant that produces low cost energy to high cost areas.
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Report of Findings
Figure 3. Net Present Value of Cost Savings by Project Alternative
o $30
- -- — - i
$_ ,— —,
40
Source: Northern Economics, Inc.
� G G
Lb Table 5. Benefit -Cost Ratios of the Proposed Intertie Project Alternatives
Eastern Route Western Route
AC current DC current AC current DC current
Power Only 3.35 2.25 1.58 1.51
Power and Heat 4.00 2.80 2.00 1.94
4 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 72 cents per kWh. As shown in Figure , the variable cost per kWh under any of the project
alternatives would be considerably lower at 20 cents per kWh if electricity is used for power only and 11
cents per kWh if electricity is used for power and heating.
While the North Slope Borough currently incurs the cost of 72 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 AtgaSLik has not changed since 1984: residential customers only pay $0.15 per kWh for the first
f 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
60
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September 15. 2011
Report of Findings
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 North Slope Borough would potentially realize a significant benefit from reducing the cost of electric
generation through the proposed intertie project and the homeowners and commercial users would
benefit from the added safety and security associated with a more stable energy system
Figure 4. Variable Costs per kWh, Current Situation versus Project Alternatives
$0.80
$0.70 f-_ --- - - --
$0.50
$0.40 --
$0.30 -- - - - - - --- —
$0.20 — --
$0.10 -i— — - - -
Electric Power Only Electric Power and
Source: Northern Economics, Inc.
The figure above calculates the cost per kWh of the different scenarios given current price and cost
levels, if however all the future stream of fuel and non -fuel costs are considered (including repair and
replacement costs of existing facilities) the estimated cumulative variable cost per kWh (in real terms,
undiscounted) would be as follows:
1. Electric Power Only: $0.20 per kWh;
2. Electric Power and Heat: $0.11 per kWh;
3. Diesel Generated Power: $0.72per kWh.
B. 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
61
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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 gene+ation and transmission of
electricity from Barrow to Atqasuk, and costs for conversion to electric heating systems at facilities and
residences in Atqasuk-
The following are the main assumptions used in the economic analysis:
The economic analysis covers the period between the years 2011 and 2049.
All the costs are reported in real terms and expressed in constant 2010 dollars.
i 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.
1 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.
1 The rest of this section is organized in the following order:
1a 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 eight proposed projects alternatives, i.e. the "with project' situations;
' A comparison of the economics of the "without project' case with the "with project' alternatives;
1 Estimates of potential financing costs associated with the project alternatives;
/ A sensitivity analysis considering changes in key assumptions; and
• Conclusions.
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IP
10
r C. "Without Project" Case: Diesel -Based Power Generation and Heating
System
The transmission line concept impacts directly several utilities and municipal services in both Barrow and
i Atqasuk. This section will provide an overview of the following existing facilities BUECI, Barrow Utilities
Electric Coop Facilities, the NSB Barrow Gas Fields; and the NSB Atqasuk P&L Electric Power Facilities
and Fuel Tank Farm.
• Description of existing Barrow electric power facilities
Barrow Utilities & Electric Coop Inc. (BUECI) is a member -owned cooperative (not -for -profit organization).
It is governed by a nine member board of directors. The utility cooperative was established in 1964
. providing electricity, natural gas, water and sewer services to this community of approximately 4,500.
BUECI operates a total of seven generators using high-pressure natural gas or diesel fuel when needed
for temporary back-up. Five generators are turbine engines manufactured by (2 Solar each 5MW Tarus
. Gas Turbines and 3 each 2.5 MW Centaur Gas Turbines), and two are reciprocating generators from
Caterpillar.
i
The BUECI Power Plant has a maximum generating capacity of 20,500 kilowatts (20.5 megawatts). In FY
2010 BUECI generated 51,391,520 kWH. The average daily demand was 5,867 kWH and had a peak
load of 8,400 kWH.
Description of existing Barrow Gas Fields
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.
R In 1984 management of the Barrow Gas Fields was transferred from the federal government to the North
Slope Borough with the passage of the Barrow Gas Field Transfer Act of 1984. This Act also gave the
Borough the permission to extend the natural gas to surrounding North Slope Villages of Atqasuk and
Wainwright via gas pipeline or electric transmission from Barrow.
lb
16
From the last reserve analysis report performed by PRA in 2006. The reserves of the Barrow Gas Fields
are presented in the Table 6 below.
Table 6: Barrow Gas Field Gas Reserves
Gas Field
South Barrow gas Field
East Barrow Gas Field
Walakpa Gas Field
Total
Reserves
8 to 9 billion cubic feet
5 to1 0 billion cubic feet
150 to 240 billion cubic feet
163 to 259 billion cubic feet
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Report of Findings
The City of Barrow consumes
has a100 to 160lion Cubic
Feet a e capacity. . At this annual consumption rate the
Walapka Gas Field alone
Description of Existing Power and Heating System in Atqasuk
Atqasuk is an inland community in the North Slope Borought 4iated (30 � miles Southe com o Barrow tpowalong the
hanks of the Meade River. Atgasuk's 2010 estimated pap a
Y
i-equirernents are provided by the Atqasuk Power & Light (ATQP&L), an enterprise formed under the
North Slope Borough (NSS) . Currently. 100 percent of the power is generated by diesel fuel- The
community's heating system is also primarily based on diesel fuel. The heating equipment in each
residential and non-residential building is typically boiler -based hydronic or forced air.
The price of diesel fuel delivered to Atqasuk in FY 2010 was $5.16 per gallon, consisting of $2.99 per
gallon of landed Fuel in Barrow plus $2.16 per gallon of delivery cost of fuel from Barrow to Atqasuk. The
City ofe Atqasuk isf fuel delivery is heeforethat the nr relatty is ively hisolated gh- The1journey tohout terways get ft ei into Atqasuk star roads that rts with
to the
village, the oast o
the delivery of a one year supply of fuel to Barrow's Tank Farm in late summer. Throughout tile year, fuel
is transported from Barrow to Atqasuk by airplane owned by Everts Air Fuel or driven overland by
Crowley's CATCQ All Terrain vehicles.
The Atqasuk fuel facilities are currently operated by the NSB Public Works Department. The current
system consists ffive 1(totalstoanks rage(total capac capage capacity of 85,000 acity at the Atqasuk farm d spens nl) at the power gnt
and two 250,00 gallon -tanks
station.
The quantity of diesel fuel consumed for power generation and heating in Atqasuk during FY 2010 is
shown in Table 7. The power plant consumed 250,238 gallons of diesel fuel or power generation and a
variety of user's consumed about 216,000 gallons for space/water treating. Out of theestimated465,238
gallons of total fuel consumption for energy, the majority was used by the power plant (54 percent),
followed by (including Bp VV, Health, o
re
Department,
and
Mayors Department). The school and residentialuses accounted for 10 percent each
and commercial users for the remaining 3 percent.
In FY2010, the power plant Lased 250,238 gallons of diesel fuel to generate 3,259,832 kWh of electricity.
During the same period• the community's electric power load (total sales or demand) was 2.916,985 kWh
for 57 residential customers, 2 community facilities, 41 commercial customers and one federal customer.
Generation and distribution losses account for roughly 12 percent of the power generation.
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Report of Findings
Table 7. Diesel Fuel Consumption in Atqasuk, Fiscal Year 2010
Diesel Fuel Consumption (Gallons)
Percentage
Power Generation
Power Plant
250,238
54%
Diesel used for Power:
250,238
54%
Heating
3%
Commercial
15,480
Residential
48,833
10%
School
47,893
10%
NSB Departments
103,795
22%
r Diesel used for Heating
216,000(*)
46%
Total Diesel for Power
466,238 100%
and Heat
Source: North Slope Borough Fuel Division
(*) Note: According to NSB Fuel Division records, the total fuel consumption of the community was 490,148 gallons.
The power plant used 250,238 gallons, leaving a balance of almost 240,000. It is estimated that 10 percent of this
balance was used by vehicles, hence the diesel fuel consumption for heating is inferred to be 216,000 gallons.
C.1 Annual O&M Costs
In FY 2010, the total costs of operating and maintaining the NSB power and fuel facilities amounted to
approximately $3.65 million, with $2.40 million for fuel costs and $1.25 million for non -fuel costs (Table 8).
® Fuel costs accounted for 68 percent of the cost of providing power generation and heating to the
community. About $1.29 million was spent on fuel for the power plant and $1.11 million for heating fuel
(Table 8).
Non -fuel costs in FY 2010 consisted of $1.07 million for power and $0.18 million for heating (Table 8).
d Non -fuel costs include staff, inspections, equipment maintenance, and other miscellaneous costs.
Table 8. Annual 0&M Costs of NSB Power and Fuel Facilities, Fiscal Year 2010
i O&M Cost Component
IrY 2010 ($)
Power
Fuel Costs
$1,290,327
i Non -Fuel Costs
$1,070,104
Sub -total:
$2, 360,431
i Heating
Fuel Costs
$1,113,785
Non -Fuel Costs
$179,488
Sub -total:
$1,293,273
Total:
$3,653,704
Source: North Slope Borough, Fuel Division
1
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10
it osts were estimated for the existing system assuming that the intertie is not built ("without
I-t,tuoe&M c
r project" situation).Ftrture fuel costs are determined given the current fuel consumption for power and heat
and po,oiected diesel fuel prices. The quantity of fuel consumed in future years is assumed to stay at the
current consumption lska Dlevels. This epartment of PublicpPion is -lealth�l3urea of Vital Statistics). ased on the forecast of zero percent growth of Atgasuk's
r population
rThe 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 ail fuel prices under the Energy information Administration's mid -case projections (Annual Energy
❑ut[oolt) These projections are available until 2030; fuel prices for the years beyond 2030 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 Atqasuk is projected to increase at an average annual rate
of 1.6 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.
• C.2 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
P 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.
C.3 Summary of Cost Flows Associated with the Existing Diesel -Based Power and
Heating System ("Without Project" Case)
Table 9 shows some of the future annual costs for Atqasuk power generation and heating if the proposed
intertie project is not built (the "Without Project" Case). Projected annual costs for the years 2011 (start
year of the analysis), 2015, 2020, 2025, 2030, 2035, and 2049 (end year of the analysis) are shown in the
® table The estimated present value of all the annual future costs from 2011 through 2049 is
approximately $118.5 million.
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Report of Findings
Annual Costs Incurred in Selected
Future Years under the "Without Project" Case
( millions
Table 9.
2011
2015
2020
2025
2030
2035
2049
Cost Item:
`
3.633
4.203
4.620
4.699
4.897
5.104
6.759
O&M Costs
2.383
2.953
3.271
3.450
3.647
3.854
4.510
�
Fuel Costs
Fuel Cost for Power Generation
1.279
1.585
1.755
1.851
1.957
2.069
2.420
5.11
6.33
7.01
7.40
7.82
8.27
9.67
Price ($/gallon)
Gallons (in thousands)
0.250
0.250
0.250
0.250
0.250
0.250
0.250
Fuel Cost for Heating
1.104
1.368
1.515
1.598
1.690
1.786
2.089
Price ($/gallon)
5.11
6.33
7.01
7.40
7.82
8.27
9.67
Gallons (in thousands)
0.216
0.216
0.216
0.216
0.216
0.216
0.216
1.260
1.250
1.250
1.250
1.250
1.250
1.250
`
Non Fuel Costs
Power Generation
1.070
1.070
1.070
1.070
1.070
1.070
1.070
i
0.179
0.179
0.179
0.179
0.179
0.179
0.179
Heating
`
Scheduled Repair and Replacement Costs
-
0.510
0.330
7.510
0.330
0.610
-
Replacement of diesel generators (in 2025)
-
-
-
7.000
-
-
1
Top End Overhaul(every 2 yrs starting in 2013)
0.180
-
0.180
-
0.180
Major Overhaul (every 5 yrs starting in 2015)
-
0.330
0.330
0.330
0.330
0.330
Total Costs
3.633
4.713
4.850
12.209
5.227
5.614
5.708
PV of Costs (2011-2049), 3% discount rate
118.534
Source: Northern Economics, Inc. estimates
1
1
1
67
Transmission
Study
f;
Atqasuk Power Line
September 15, 2011
i
i Report of Findings
i
i D. Proposed Intertie Project Alternatives: "With Project" Case
i p,1 Costs Associated with the Proposed Intertie Project
For all project alternatives, the environmental studies are assumed to take place during 2011 and 2012 at
i an estimated cost of $60,000, including the environmental assessment and possible Section 7
consultations-7
Construction of the intertie is assumed to take place over a 2-year period, with capital costs varying by
alternative as shown in Table10. The corresponding supporting engineering and construction
i management activities also occur during the same period and are estimated to be about 12 percent of the
i capital cost.
The operation of the proposed intertie begins in 2015 and lasts 35 years. The annual operation and
maintenance costs for the intertie vary by project alternative as shown in Table 11. These costs include a
basic O&M cost of $1,315 per mile for all alternatives, an annual cost of $50,000 for VSM inspection for
the Western Route altematives, and $50,000 for converter inspections for the DC alternatives.
Table 10. Estimated Capital Costs of the Intertie (2010 $)
Year Eastern Route Western Route
AC DC AC DC
Environmental Studies 2011-2012 60,000 60,000 60,000 60,000
Construction Cost 2013-2014 15,123,237 22,029,108 31,430,744 32,047,314
i Engineering &Construction
Management (12%) 2013-2014 1,814,788 2,643,493 3,771,689
Source: Estimates are based on information provided by consulting engineers for this project.
i
Intertie O&M
VSM Inspection
Converter Inspection
Total O&M:
Table 11. Annual O&M Costs of the Intertie3 (2010 $)
3,845,678
Year Eastern Route
Western Route
AC DC
AC
DC
2015-2049 89,946 89,946
96,521
96,521
2015-2049
50,000
50,000
2015-2049 50,000
50,000
195,521
10 Source: Estimates are based on information provided by AEA program managers and consulting engineers for this
project.
2 The cost of a potential EIS process is not included since at this time it has not been determined as required.
89,946 139,946
146,521
3 The estimated O&M cost per mile was determined in consultation with AEA program managers, Jim Strandberg and Chris Mello.
VSM and converter inspection costs are based on estimates from the project's consulting engineers.
' ► - nkow" 68 Atgasuk Power Line Transmission Study
September 15, 2011
Report of Findings
to
40 D.2 Cost of Purchasing Electricity from Barrow
40 The annual cost of purchasing electricity from BUECI depends on the price of electricity in Barrow and the
110 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 scenario considered-- electric power only or electric
power and heat (see Table 12).
D.3 Electric Power Only Scenario
The actual electric power sold in Atqasuk (based on FY2010 data) is 2,916,985 kWh. This electric power
demand is increased by 15 percent to account for 12 percent distribution and transmission losses in
to Atqasuk plus 3 percent transmission losses through the intertie. Hence, the annual electric power
requirement in Atqasuk assumed in this analysis is 3,354,533 kWh. The corresponding cost of purchasing
No electricity for power is $287,957 (=3,354,533 kWh* $0.0846/kWh+$4,164) (see Table 12).
40 DA Electric Power and Heat Scenario
1111110 Under the alternative scenario of electric power and heat, the estimated quantity of electricity is
so significantly higher. The community would require additional purchases of 8,895,101 kWh to meet
Atgasuk's requirements for heating. This amount was determined by multiplying 216,000 gallons of fuel
10 consumed under the existing diesel -based heating system by a factor of 130,500 BTU/gal and by a factor
10 of 97 percent for the assumed efficiency of the heaters. The resulting quantity in kWh is 8,013,604. This
amount is increased by 11 percent to take into account electric heating distribution losses in Atqasuk (8
go percent) plus transmission losses through the intertie (3 percent), which results in the estimated
00 8,895,101 kWh electric heating requirement. The corresponding cost of purchasing electricity for the
combined power and heating scenario is estimated to amount to $1,040,483(= 12,2249,634 kWh*
so $0.0846/kWh+$4,164); see in the following Table 12.
Table 12 .Annual Electricity Requirements and Cost of Purchased Electricity from Barrow
Scenario
Electric Power Only Electric Power and Heat
Quantity of Electricity Required (kWh) 3,354,533 12,249,634
For Power 3,354,533 3,354,533
For Heating 8,895,101
Cost of Electricity ($) $287,957 $1,040,483
For power $287,957 $287,957
For heating $752,526
Source: Estimates based on information provided by NSB Fuel Division
D.5 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.
Table 13 summarizes the estimated annual fuel costs for power and for heating under the two electric
usage scenarios. It is assumed that the utility will purchase one month's worth of fuel supply (equivalent
N to 20,853 gallons for power and 18,000 gallons for heating) to be kept in storage as backup. Since the
69
Atqasuk Power Line Transmission Study
September 15, 2011
Ph
Report of Findings
10 fuel cost per year will vary depending on the protected price of fuel, the table below shows the estimated
10 annual fuel costs given the current fuel price of $5.156 per gallon as well as the estimated average
it annual fuel costs given the projected average fuel price over the 35-year period.
Table 14 shows the estimated annual non -fuel costs for power (Atgasuk power plant) and for heating
10 (primarily related to the tank farm/dispensing station operations) associated with each of the scenarios.
The esti}mated annual non -fuel costs for the power only scenario represent about 36 {percent of the total
non -fuel cast currently incurred by the utility ($1.25 million); a reduction in cost of about 64 percent. For
the power and heat scenario, the estimated non -fuel costs represent 29 percent of the current total non-
* fuel cost of the utility, a 71-percent reduction in annual non -fuel cost.
in addition to offsetting fuel and non -fuel ❑&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.
41
Table 13. Estimated Annual Fuel Costs for Power and for Heating under Various Scenarios
Cost Item
For Power
For Heating
Total:
Scenario
Electric Power Only
Electric Power and Heat
Current Fuel Price
Ave over 35 years
Current Fuel Price
Ave over 35 years
107,527
167,527
107,527
167,527
1,113,785
1,735,269
92,815
144,606
1,221,312
1,902,796
200,342
312,133
A Source: Northern Economics, Inc. estimates based on information from the North Slope Borough, Fuel Envision
Table 14. Estimated Annual Non -Fuel Costs for Utility Operations and Maintenance Facilities in Atqasuk
S under Various Scenarios
d Scenario
Cost Item
Electric Power Only Electric Power and Heat
For Power 268,457 268,457
Ilk
For Heating 179,488 89,744
p 447,945 358,201
Total:
Source: Estimates are based on information obtained from the North Slope Borough, Fuel Division
D.6 Capital Costs of Electric Heating Conversion
Under the scenario of electric power and heat, the existing diesel oil fired boilers and furnaces in buildings
would be replaced by electric heat. Residential buildings would likely have base -board heaters in each
room. In the larger non-residential buildings (i.e., school), the central heating boiler or furnace may be
converted or replaced with an electric unit. The existing heat distribution system may be usable in these
cases.
The capital costs for the conversion to electric heating systems in residences and Borough facilities are
estimated at $1,952,000. These costs would take place in 2013 and are estimated at $880,000 and
$1,072,000 for facilities and residences, respectively.
* 70
�: Atgasuk Power Line Transmission Study
V.September 15, 2011
R
Report of Findings
r D.7 cost Flows for Project Alternatives
The costs described in the previous subsections are reflected in the next eight tables (15-23) that show
r detailed future stream of annual costs (for selected years) associated with each of the proposed intertie
he
r well as theNPtV of thelle last row costs av s of each table show ngs compared to thetcase without projectNPV or the cost of the shown previously in Table gas
well a
r
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71
Atqasuk Power Line Transmission Study
September 15, 2011
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Report of Findings
to
No
"D E. Financing Costs
The NPV results from the previous section are equivalent to a baseline scenario where the project is
financed with 100 percentdebt-equity untand n see Table 2section we consider four alternative financing
schemes with varying ( )•
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, the financing costs for the power transmission line vary depending on the project
me alternative and depending on the debt to equity ratio. Project alternatives with higher capital costs and
me larger percentage of debt imply higher financing costs. For example, the annual financing costs of the
Eastern Route with AC current are estimated at $659,492 assuming that 50 percent is financed with
is debt through bonds and 50 percent with equity.
Table23. Annual Financing Costs by Project Alternative
Eastern Route Western Route
AC
DC
AC
DC
Power only
50 percent debt
659,492
960,642
1,370,627
1,397,515
70 percent debt
923,289
1,344,899
1,918,878
1,956,520
20 percent debt
263,797
384,257
548,251
559,006
100 percent debt
1,318,984
1,921,284
2,741,255
2,795,029
Power and Heat
50 percent debt
744,614
1,045,765
1,455,750
1,482,637
70 percent debt
1,042,460
1,464,071
2,038,050
2,075,692
00
20 percent debt
297,846
418,306
582,300
593,055
111111111
100 percent debt
1,489,229
2,091,529
2,911,500
2,965,274
00
Source: Northern Economics estimates.
1�
N
01
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Report of Findings
E.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
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 5 shows the NPV of cost saving after debt financing costs for the eight project alternatives,
considering different percentage of debt. The results show positive measures for all Eastern Route
alternatives, indicating that the Eastern intertie would be attractive regardless of the percentage of debt
required. The results for the Western Route are mixed; the DC option and the AC option with electric
power only would not be attractive Linder very conservative assumptions (i.e., highest financial costs due
to 100 percent of debt required).
Figure S. NPV of Cost Savings with Financing Costs
.c
50
40
30--
20 =-
O
10
% 0�
_1 -,-
-10
-20
Qi�y1 �16 G ��1
Q°fie 4 ��t Q°
Q°Qo
20 percent debt 50 percent debt
Source: Northern Economics, Inc.
r01
70 percent debt 100 percent debt
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■ Report of Findings
■
■
■ E.2 Sensitivity Analysis
r A sensitivity analysis was conducted to establish the extent to which the NPV results are sensitive to the
values assumed for certain key parameters.
The NPV of each of the eight project alternatives are re -estimated by modifying one assumption at a time
r while maintaining the rest of the assumptions as in the base case. Each of the key assumptions is
■ modified into a favorable and an unfavorable scenario as follows.
■ Price of diesel fuel landed in Atqasuk:
■ -� The favorable scenario for the project consists of high diesel fuel prices. in this sensitivity
r scenario, fuel prices are assumed to increase at an average annual rate of 2.9 percent. This
■ rate is consistent with the trend in crude oil prices projected by EIA in its high case scenario.
■ -3 The unfavorable scenario for the project consists of low diesel fuel prices. In this sensitivity
scenario, fuel prices are assumed to decrease at an average annual rate of 0.9 percent. This
■ rate is consistent with the trend in crude oil prices projected by EIA in its low case scenario.
■
■ Electric load requirements:
■ — The favorable scenario for the project consists of a high electric load. In this sensitivity
scenario, the quantity of electricity purchased from Barrow is assumed to increase at an
average annual rate of 0.5 percent. This rate is consistent with the high growth rate
population forecast for Atqasuk (NSB 2011).
* — The unfavorable scenario for the project consists of a low electric load. In this sensitivity
* scenario, the quantity of electricity purchased from Barrow is assumed to decrease at an
average annual rate of 0.5 percent. This rate is consistent with the low growth rate
M population forecast for Atqasuk (NSB 2011).
■
Real discount rate:
The favorable scenario for the project assumes a low discount rate of 2.3 percent (i.e. 0.7
percent points lower than the baseline case). The 2.3 percent corresponds to the real
discount rate for projects that last more than 20 years recommended by the Office of
Management and Budget (OMB), Circular A-94.
-j The unfavorable scenario for the project assumes a high discount rate of 3.7 percent. This
rate was chosen to be the symmetric opposite from the unfavorable scenario since it
assumes a discount rate 0.7 percent higher than in the base case scenario.
■
Table 24 and Table 25 summarize the results of the sensitivity analysis for the Eastern Route and the
Western Route alternatives, respectively. The results indicate a positive NPV of cost savings in all cases
under the Eastern Route. Under the Western Route however, the analysis shows negative NPVs under
low electric loads for the Power only scenario.
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10
ID
Table 24. Sensitivity Analysis of NPV for Eastern Route Alternatives
East Route — AC
East Route — DC
Power
Power and Heat
Power
Power and Heat
•
Baseline - Mid case for all
35,324,295
50,675,352
27,156,697
42,507,754
Fuel Price - High
63,400,756
97,542,322
55,233,158
89,374,724
Fuel Price- Low
20,895,076
20,133,290
12,727,478
11,965,692
Load - High
19,219,446
36,317,913
11,051,848
28,150,315
Load - Low
13,112,155
26,920,865
4,944,557
18,753,267
Real Discount Rate — High
29,702,117
42,930,688
21,765,906
34,994,477
Real Discount Rate— Low
42,001,258
59,890,001
33,579,242
51,467,985
Source: Northern Economics, Inc. estimates
Table 25. Sensitivity Analysis of NPV for Western
Route Alternatives
West Route - AC
West Route - DC
Power
Power and Heat
Power
Power and Heat
Baseline - Mid case for all
17,246,575
32,597,631
15,621,944
30,973,001
Fuel Price - High
45,323,035
79,464,601
43,698,405
77,839,971
Fuel Price- Low
2,817,355
2,055,570
1,192,725
430,939
Load - High
1,141,726
18,240,192
-482,905
16,615,562
Load - Low
-4,965,565
8,843,144
-6,590,196
7,218,514
Real Discount Rate — High
12,034,086
25,262,657
10,531,342
23,759,913
Real Discount Rate — Low
22,394,380
41,372,876
21,717,290
39,606,033
Source: Northern Economics, Inc. estimates
0P F. Economic Summary
16 In conclusion, the best alternative appears to be the Eastern Route with AC current used for electric power
and heat, both from an economic feasibility point of view and from the project's owner point of view.
All the eight 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 intertie project appears
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 intertie.
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Report of Findings
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prepared for Bureau of Land Management, Fairbanks, AK, and ConocoPhillips Alaska, Inc., Anchorage, by
!� ABR, Inc., Fairbanks, AK. 15 pp.
Petersen, M. R., P. L. Flint, W. W. Larned, and J. B. Grand. 1999. Monitoring Beaufort Sea waterfowl and
marine birds. Annual Progress Report prepared by U.S. Geological Survey, Alaska Biological Science
Center, Anchorage, AK, 1999. pp. 33.
Pitelka, F. A. 1974. An avifaunal review for the Barrow region and the North Slope of arctic Alaska. Arctic
* and Alpine Research 6: 161-184.
Quakenbush, L., and R. Suydam. 1999. Periodic nonbreeding of Steller's eiders near Barrow, Alaska, with
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Canada.
■ Quakenbush, L., R. Suydam, and T. Obritschkewitsch. 2000. Habitat use by Steller's Eiders during the
breeding season near Barrow, Alaska, 1991-1996. Unpublished report by University of Alaska Fairbanks,
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A of Wildlife Management, Barrow, AK. 53 pp.
01
A
Quakenbush, L., R. H. Day, B. A. Anderson, F. A. Pitelka, B. J. McCaffrey. 2002. Historical and present
breeding season distribution of Steller's Eiders in Alaska. Western Birds 33: 99-120.
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(Polysticta stellen) near Barrow, Alaska, 1991-1999. Arctic 57: 166-182.
Atqasuk Power Line Transmission Study
September 15, 2011
89
Report of Findings
J. S. Sedinger. 1998. Brant (Branta bernicla). In: A. Poole and F.
Reed, A., D. H. Ward, D. V. Derksen and
Gill, eds., The Birds of North America, No. 337. The Birds of North America, Inc., Philadelphia, PA.
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to Fish Creek, Alaska, 1995. Unpublished report for North Slope Borough, Department of Wildlife
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legged Hawks in northern Alaska. Condor 93: 180-184.
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mapping at U. S. Air Force radar sites in northern Alaska, 2003. Prepared for U. S. Air Force, 611th Civil
Engineering Squadron, Environmental Planning, Elmendorf AFB, AK, by ABR, Inc. Environmental Research
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northern Intertie Power line, Interior Alaska, 2004-2006. Unpublished Report prepared for Golden Valley
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Anchorage, AK, by ABR, Inc., Fairbanks, AK.. 41 pp.
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region. Report for BP Exploration (Alaska) Inc., Anchorage, by Troy Ecological Research Associates,
111111011 Anchorage, AK. 17 pp.
11110 U.S. Fish and Wildlife Service. (US FWS). 1996. Spectacled Eider recovery plan. U.S Fish and Wildlife
Service, Anchorage, AK, 1996. 157 pp.
U.S. Fish and Wildlife Service (USFWS). 2002. Steller's Eider recovery plan. U.S Fish and Wildlife Service,
Fairbanks, AK. 27 pp.
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Fish and Wildlife Field Office, Anchorage, Alaska.
Atgasuk Power Line Transmission Study
September 15, 2011
90
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EXHIBIT 1
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No
No
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EXHIBIT 2
WEATHER DATA PARAMETERS
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Wind at Barrow Alaska - Data sources
Hourly data from the NWS (1945 - 2002). When the data was
collected with greater frequency, only one observation was
taken per hour.
Daily statistics - To summarize the hourly data on a daily
basis, the following statistics were used.
Maximum daily wind -speed
75th percentile daily wind -speed. Since
periods with sustained winds appear to cause
the greatest damage, this was done to capture
days with a greater duration of high winds.
Wind Speed Barrow, Alaska
75{" Percentile Daily Wind speed — max monthly values
EXHIBIT 3 - Recommended RUB Conductor Tension
TABLE 9-2
RECOMMENDED REA CONDUCTOR AND OVERHEAD
--^Tymn "Tfl r TrMCIM AMn TEMPERATURE LIKITS*
Is
EXHIBIT 4
JAN VIBRATION
_ TP-69 STRUCTURE with 700 R.S
PLS-CADD Version 6.33L 1:21:29 AM Sunday, October 10, 2010
Sakata Engineering Services
Project Name: 'h:\barrow-atqasuk line asrc\sag and
tension\barrow_atgasuk.loa'
Criteria notes:
Double loop galloping with wire spacing at one quarter of span
between structures # and # with wind from Right
Structure
Ahead
Set
Phase
Span
#
#
Len
(ft)
------------------
1
1
700.0
2
1
700.0
3
1
700.0
Mid Insul Span
Span Swing Swing
Sag Angle Angle
(ft) (deg) (deg)
---------------------
16.65 0.0 -22.9
16.65 0.0 -22.9
16.65 0.0 -22.9
Major Minor Dist.
Axis
Axis
'B'
Len.
Len.
Len.
(ft)
--------------------
(ft)
(ft)
6.9
4.9
1.4
6.9
4.9
1.4
6.9
4.9
1.4
Minimum clearances between ellipses (Set:Phase)(0 clearance means
ellipses intersect)
1:1 2:1 3:1
1:1 0.04 4.99
2:1 0.04 2.60
3:1 4.99 2.60
Double loop galloping with wire spacing at one quarter of span
between structures # and # with wind from Left
Structure Ahead
•Set Phase Span
# # Len
(ft)
-------------------
1 1 700.0
Mid Insul Span
Span Swing Swing
Sag Angle Angle
(ft) (deg) (deg)
Major
Axis
Len.
(ft)
16.65 0.0 22.9 6.9
Minor Dist.
Axis ' B'
Len. Len.
(ft) (ft)
---------------
4.9 1.4
00
2 1 700.0 16.65 0.0 22.9 6.9 4.9 1.4
3 1 700.0 16.65 0.0 22.9 6.9 4.9 1.4
4inimum clearances between ellipses (Set:Phase)(0 clearance means
ases intersect)
1:1 2:1 3:1
1:1 0.81 4.52
?:1 0.81 1.89
3:1 .4.52 1.89
Double loop galloping with wire spacing at three quarters of span
between structures # and # with wind from Right
Structure
Ahead
Mid
Insul
Span
Major
Minor
Dist.
Set
Phase
Span
Span
Swing
Swing
Axis
Axis
`B`
#
#
Len
Sag
Angle
Angle
Len.
Len.
Len.
---------------------------------------------------------•--•---
(ft)
(ft)
(deg)
(deg)
(ft)
(ft)
(ft)
1
1
700.0
16.65
0.0
-22.9
6.9
4.9
1.4
2
1
700.0
16.65
0.0
-22.9
6.9
4.9
1.4
3
1
700.0
16.65
0.0
-22.9
6.9
4.9
1.4
Minimum clearances
between
ellipses (Set:Phase)(0
clearance means
ellipses
intersect)
1:1
2:1
3:1
1:1
0.04
4.99
2.1
0.04
2.60
3:1
4.99
2.60
I
1
1
1
'
Double loop galloping
with wire spacing at
Left
three
quarters
of span
between structures # and # with
wind
from
'
Structure Ahead
Mid
Insul
Span
Major
Minor
Dist.
'B'
'
Set Phase Span
Span
Swing
Swing
Axis
Axis
'
# # Len
Sag
Angle
Angle
Len.
Len.
Len.
(ft)
(ft)
(deg)
(deg)
(ft)
(ft)
(ft)
--1-- ----------------------------
1 700..0
16.65
0.0
22.9
6.9
4.9
1.4
2 1 700.0
16.65
0.0
22.9
6.9
4.9
1.4
3 1 700.0
16.65
0.0
22.9
6.9
4.9
1.4
1
1
Minimum clearances
between
ellipses (Set:Phase)(0
clearance means
'
ellipses intersect)
1:1 2:1
3:1
1.1 0.81 4.52
2:1 0.81 1.89
3:1 4.52 1.89
1
I
I
I
1
1
B. TH-1 STRUCTURE with 1200 FT RS
PLS-CARD Version 6.33L 1:42:10 AM Sunday, October 10, 2010
Sakata Engineering Services
Project Name: 'h:\barrow-atqasuk line asrc\sag and
tension\barrow_atgasuk.loa'
Criteria notes:
Double loop galloping with wire spacing at one quarter of span
between structures # and # with wind from Right
Structure Ahead
Mid
Insul
Span
Major
Minor
Dist.
'B'
Set Phase Span
Span
Swing
Swing
Axis
Axis
Len.
Len.
# # Len
Sag
(ft)
Angle
(deg)
Angle
(deg)
Len.
(ft)
(ft)
(ft)
(ft)
-------------------------------------------------------------
1 1 1200.0
46.40
0.0
-22.9
17.5
8.1
3.5
2 1 1200.0
46.40
0.0
-22.9
17.5
8.1
3.5
3.5
3 1 1200.0
46.40
0.0
-22.9
17.5
8.1
Minimum clearances
between
ellipses
(Set:Phase)(0
clearance
means
ellipses intersect)
1:1 2:1
3:1
1:1 2.24
12.64
2:1 2.24
2.24
3:1 12.64 2.24
i
I
I
1
1
1
1
Double loop galloping with wire spacing at one quarter of span
between structures # and # with wind from Left
structure Ahead Mid Insul Span Major Minor Dist.
Set Phase Span Span Swing Swing Axis Axis 'B'
# # Len Sag Angle Angle Len. Len. Len.
(ft) (ft) (deg) (deg) (ft) (ft) (ft)
--------------------------------------------------------------
1 1 1200.0 46.40 0.0 22.9 17.5 8.1 3.5
3 1 1200.0 46.40 0.0 22.9 17.5 8.1 3.5
Minimum clearances between ellipses (Set:Phase)(0 clearance means
ellipses intersect)
1:1 2:1 3:1
1:1 2.24 12.64
2:1 2.24 2.24
3:1 12.64 2.24
Double loop galloping
with wire spacing at three quarters
of span
between
structures # and # with wind
from Right
Structure Ahead
Mid
Insul
Span Major
Minor
Dist.
Set
Phase Span
Span
Swing
Swing Axis
Axis
'B`
#
# Len
Sag
Angle
Angle Len.
Len.
Len.
(ft)
(ft)
(deg)
(deg) (ft)
(ft)
(ft)
----------------------------------------------------.-.--
1
1 1200.0
46.40
0.0
-22.9 17.5
8.1
3.5
2
1 1200.0
46.40
0.0
-22.9 17.5
8.1
3.5
3
1 1200.0
46.40
0.0
-22.9 17.5
8.1
3.5
Minimum clearances
between
ellipses
(Set:Phase)(0
clearance means
ellipses
intersect)
1:1 2:1
3:1
1:1
2.24
12.64
2.24 2.24
12.64 2.24
Double loop galloping with wire spacing at three quarters of span
between structures # and # with wind from Left
Structure Ahead Mid
set Phase span Span
# Len Sag
(ft) (ft)
-1 _ 1 1200.0 45.40
2 1 1200.0 45..40
3 1 1200.0 46.40
Insul Span Major
Swing Swing Axis
Angle Angle Len.
(deg) (deg) (ft)
--------------------
0.0 22.9 17.5
0.0 22.9 17.5
0.0 22.9 17.5
Minor Dist.
Axis 'B'
Len. Len.
(ft) (tt)
-------------
8.1 3.5
8.1 3.5
8.1 3.5
Minimum clearances between ellipses (Set:Dhase)(0 clearance means
ellipses intersect)
1:1 2:1 3:1
1;1 2.24 12.64
2:1 2.24 2.24
3:1 12.64 2.24
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l0 W dl .�Mto r0N
r61 W MV'r�OO
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to NNNNNNr-1 r-1 00 O 1 01v-W torso Q7 r-1M
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Q'srMW Mdl lON W ® 1 NNri r-f ri r�-lr-1 t~M
l0 m t}l O N Cl; to W 0
V• N N M MCI) M M IM U 1
[�Vv to t0 mt0 O rO H Q i NMHr W Lo til0 O]
W M M d' t0 0 W O .-i H to [� N r I ri W lO
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M to w to to to to w -W t$ L7 ! Vt r-I ram{ r-1 r-t r4 H N N
r [- 1
ti}N NN NN NrV-4 10 1 ON mr V'0 Lo r-M
Ol N I WtoN V'r V'to0 -1
ON W r V'�rrN ri w H Q i r{• mMmM MNN
W to N V'r Htl)M to
M 01 W t0 V' M r•I Ol r -A 1 O E I
r M M M M M M N N
I co 0) to%D to N 01 Or
00-iM_ 1
I v+t0a�O1Mtrot 1 QH { W rnror-Ir-
t rM MMcr)MMNN O N +' 1 �OOr10rOrkD V'N�
1 •j i N N r^I r-1 ri c i H r•1
1 o i
I
I OINNNNNNNN Ci
1 W lD r-1 [% to DVN to
tD !0 W tG7 t0 0 tI M r-I to r N 01 O1 N O1
��0H�H-ir-IOOOOOOOO,o Di
NBNdPt0 t0 t0 tD t0 t0 D
1
i
0• t c-10000000 r-� 1 ON W rHro 1- to M tN
l0 to N C r-r O
1 N0000CD 000 H is •r'� •4J 1 M01 W��'M ��r
I t000000000 H 14 E0 i rMMM MMMNN
1 . .
t o00000000
} Q 1
I
m
1
l H k 1
m H t 1 o
1 f�y`O Or 1p 1 N 000N tON
t .Ti I OM l001 eN-I�rN-I Q 41 l 1 oe")tD 01 r•!e-•I C�V
I U A W 147 �I N Q Id, Ca W W
ExW0 o I0
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I
1 .--IN('')�vto lOr W 01 E 1 4t i r1NMd'to tO l- m01 I
EXHIBIT 6
CON�Il 3TOR LOADING AND OVERLOAD FACTOR
w
TABLE 11-3
REA GRADE B (NEW CONSTRUCTION)
RECOMMENDED OVERLOAD CAPACITY FACTORS
TO BE APPLIED TO NESC LOADING DISTRICTS LOADS
-.; h.
ESC
x.
D .POLES'; �IOD_ .. ram;
prtica
�.::.:-'.i.:Yi:
wind
•'�
' •6
: h .,
Lori Tr-. C skti
TJe' a -end
�
�y•'�.w � Ste'..;,
GUYS AND-: ANCi•FORS-% � � ���.. ...
1.009v
{�L si
ENV
Transverso� oats' siE=c - .f:'-=-.•:�'r}.:��K=cry=t;..-
.:.... _ 'Oki:.:;. ;=•
Wind. r. 90
tension
1()t]
Wire
I►C$. a
i O�J.s
D6,adenda _
UUY ATTAC:fiFI I S
40$
ansvez
Wire Tansi.011 LucC
xr p
5e.
. 8 _ 5
iNSL►LATC]R;.y''
See. ,re i
CONDUCTOR..
w
!
! EXHIBIT 7 - CONDUCTOR GROUND CLEARANCES
! TABLE 4-1
RECOMMENDED MINIMUM VERTICAL CLEARANCE OF
CONDUCTORS -TO -GROUND IN METERS (FEET)
�c
GCS - - •rF H ���._:- �l�n.L'::. ., ;.....
-<;a�;..,,� ?��:.-';fit:; ?>:1�s.; - s'� ::b �.a°�• _ ��.. k• �: _ -. £�.x�:���,�_£�n _ �.;�• '.�.- .� �f:',.
ga. � : F �� � te• of ::•.e-�-::' i�� a'{.£� :"'_ �-. .. vr+� !'� �-.;
.:i��'-4�.'••?' �'H:r7 a _ e:'sz' a�t.t -=Y3,,• _-'nc;2��ri �k � �s3.+.=
''- � ' �'�:: '�� -.q air �'>�',� � •..:.
r' �yvx _
rg
<�;•: _ ��• _ _ ,. � , gig:= `:'.� ,�-.r:,.•� �� Y�'-3
ii
TABLE 4-1 (CONT-)
RECOMMENDED MINIMUM VERTICAL CLEARANCE
OF CONDUCTORS -TO -GROUND IN METERS (FEET)
'f- rl.ab 6c L1'
[`:
�.rnsi-r�er_ecl
rss oTi . a ;
,r. tire. s�zall .be.:basedt'te
ng..._ .
1TS!�7OILZ"1dlilC iZ GS.
o vex
�<
- 1 .t'4U
�`�
F�
t
w
1
EXHIBIT 8
r LOAD FLOW REPORT AT 34.5 KV AC
Basis - Information from the following EDSA Report: Line Length - 75 Miles @ 2 Mw Load,
r Using 477 MCM wire produce the following: 2.8% losses and 4.66% voltage drop,
rEDSA Advanced Power Flow Program V5.70.00
Project No.
Page 1
.
Project Name:
Date : 10/06/2010
.
Title
Drawing No.
Time : 04:38:50 am
Company
.
Revision No.:
Jobfile Name: barrow test
Engineer
Check by :
Scenario : 1 -
Date
•
Base KVA
Frequency
Unit System
.
MaxIterations
Error Tolerance
of Buses entered
# of Active Buses
# of Swing Buses
# of Generators
# of Loads
# of Shunts
# of Branches entered
# of Transformers
# of Reactors
# of C.B.
System Information
100000 (kva)
60 (HZ)
U.S. Standard
= 1000
10.000 (kva), 0.000100 (pu), 0.0100 M
2
2
= 1
= 0
= 1
0
= 1
0
0
0
Abbreviations
2-W xfmr =
2-winding transformer
3-W xfmr -
Autoxfmr -
3-winding transformer
Autotransformer
'
DReactor =
F Load w
Duplex Reactor
Functional load
FeederM -
Feeder in Magnetic Conduit
'
Gen =
Generator
I Load =
Constant current load
None
= None contributing
P Load
= Constant power load
PhS xfmr
= Phase -Shift Transformer
SeriesC
= Series Capacitor
ShuntC
= Shunt Capacitor
ShuntR
= Shunt Reactor
Z_Load
= Constant impedance load
Ref °C
= Reference Temperature
Power Flow By Fast Decoupled CONVERGED
Iteration: 3
R
EXHIBIT 8 (CONT.)
LOAD FLOW REPORT AT 34.5 KV AC
EDSA Advanced Power Flow Program V5.70.00
Project No_ :
Page 2Date : 10/06/2010
Date
project Name.
04:38:50 am
Title
Company
Drawing No.
Engineer
Revision No.:
Jobfile Name: barrow test
Check_ by
Scenario : 1 -
Date
Summary of Total Generation and Demand
F(KW)
Q(KVAR)
S(KVA)
PF M
Swing Bus(es):
2055.590
187.605
2064.152
0.000
99.59
0.00
Generators
0.000
0.000
0.000
0.000
0.000
0.00
Shunt
Static Load
2000.000
1000.000
2236.068
89.44
0.00
Motor Load
0.000
0.000
0.000
Total Loss
52.921
-806.641
-_^-5.555
Mismatch x
- 2.670
Bus Data
Bus Name
Type
V
Mag(V) Ang(deg)
P Q
(Kw) (KVAR)
C
(KVAR)
Barrow
Swing
34500 0
39500 0
0
-2000 -1000
0
Atqasuk
oa
P Ld
--------
----- _..__ .--
0
0 0
Total Generating Sources
-2000 -1000
Total Bus Loads
Branch Data
Branch Name
Library CodeName
CO Type y
R
(Ohms)
X B/2 Ref °C
(Ohms) (Mhos)
1 Feeder ACSR 417-4.69
13.3503
44.0933 0-000432 40.0
101001
1
1
1
I
I
EXHIBIT UCONT.)
LOAD FLOW REPORT AT 34.5 KV AC
EDSf. A varced Power Flow Program V5.70.00
Project No. : Page 4
Project flame: Date IDI0612010
Title - Time 04:38:51) am
Drawing No. Company
Revision No.: Engineer
Jobfile Name: barrow test Check by
Scenario 1 - Date
Bus Voltage Results
Bus Name Type V DROP ANG P Q PF
(VOLTS) (S) (DEG) (KW) MARI IWl
Barrow Swing 34500 0.00 O.D 2056 188 99.59
Atgasuk P-Load 32892 4.66 -4.1 -2000 -1000 89.44
Branch power Flow Values
Branch ?lame Ck Type Library CodeName From -> To Flow To -] From Flow Losses
(Kwl (ffVAR) (KW) (KVAR) (M (kVAR)
101001 1 Feeder ACSR 477-4.69 205E 18$ -2003 -994 53 -801
6DSA Advanced Power Flow Program V5.70.00
Project No. Page :5
Project. Name: Date : 1010612010
Title _ Time : 04:38:50 am
Drawing No. : Company _
Revision NO.: Engineer -
Job€ile Name: barrow test Check by
Scenario : l - Date
Branch Current. Flow Values
Branch Name CN Type Library Code -Name Current Angle Ampacity loading
(A) (Deg) {Al {t}
101001 1 Feeder ACSR 477-4.69 35 -5.2 590 6%
EXHIBIT 9
LOAD FLOW REPORT AT 69 KV AG
EDSA Advanced Power Flow Program V5.70.00
Project No. : Page : 1
Project Name: Date 01/09/2011
Title Time 06:00:27 pm
Drawing No. Company
Revision No.: Engineer :
Jobfile Name: brw to ata,_ awi_w_69._10-22-10 Check by
Scenario : 1 - Date
System Information
Base KV'A = 100000 (kva)
Frequency = 60 (HZ)
Unit System = U.S. Standard
MaxIterations = 1000
Error Tolerance = 10.000 (kva), 0.000100 (pu), 0.0100 M
# of Buses entered - 5
# of Active Buses = 4
of Swing Buses = 1
# of Generators = 0
# of Loads = 2
#. of Shunts = 0
# of Branches entered = 4
k of Transformers = 1
# of Reactors = 0
# of C.E. = 0
Abbreviations
2-W xfmr •-
2-winding transformer
None
= *done contributing
3-W xfmr =
3-winding transformer
P Load
= Constant power load
AL1t Cxfmr -
Autotransformer
PhS xfmr
= Phase -Shift Transformer
DReactor -
Duplex Reactor
SeriesC
= Series Capacitor
F Load
- Functional load
ShuntC
= Shunt Capacitor
FeederM
= Feeder in Magnetic Conduit
ShuntR
= Shunt Reactor
Gen
- Generator
Z Load
= Constant impedance load
I Load
= Constant current load
Ref 'C
= Reference Temrerature
Power Flow By Fast Decoupled CONVERGED
Iteration: 4
EXHIBIT 9 (CONT.)
LOAD FLOW REPORT AT 69 KV AC
EDSA Advanced Power Flow Program V5.70.00
Project No. :
Page : 2
Project Name:
Date : 01/09/2011
Title
Time : 06:00:27 pm
Drawing No.
Company
Revision No.:
Engineer
Jobfile Name: brw to atq_awi w_69._10-22-10
Check by
Scenario : 1 -
Date
Summary of Total Generation and Demand
P(KW)
Q(KVAR)
S(KVA)
PF M
Swing Bus(es):
5100.561
-797.748
5162.570
98.80
Generators
0.000
0.000
0.000
0.00
Shunt
0.000
0.000
0.000
0.00
Static Load
5000.000
2500.000
5590.170
89.44
Motor Load
0.000
0.000
0.000
0.00
Total Loss
99.823
-3314.608
Mismatch
_w 0.739r
16.860
Bus Data
Bus Name
Type
V
P Q
C
Mag(V) a.ng(deg)
(KW) (KVAR)
(KVAR)
Barrow
Swing
4160 0
0
0
Atqasuk
P Load
69000 0
-2000 -1000
Junction
None
69000 0
0
0
Wainwright
P,Load
69000 0 --
-3000 _----- --------
Total Generating Sources
0
0 0
Total Bus Loads
-5000 -2500
Branch Data
Branch Name
C# Type
Library CodeName
R
X B/2
Ref °C
(Ohms)
(Ohms) (Mhos)
Atqasuk Fdr
1 Feeder
ACSR 477-4.69
6.2937
20.7868 0.000102
40.0
Junction Fdr
1 Feeder
ACSR 477-4.69
7.0566
23.3064 0.000114
40.0
40.0
Wainwright Fdr
1 Feeder
ACSR 477-4.69
12.0153
39.6840 0.000194
Transformer & Line Voltage Regulator Data
Branch Name
C# Type
Library CodeName R
X F_Tap T_Tap
M
M (PU) (PU)
Barrow Xfmr
1 2-W xfmr 5000-3-L
0.6000
6.9700 1.000 1.000
EXHIBIT 9 (CONT.)
LOAD FLOW REPORT AT 69 KV AC
EDSA Advanced Power Flog =PrrogramV5.70.00
Page 3
Project No.
Date Ol/09/2011
project Name:
Time 06:00:27 pm
Title
Company .
Drawing No.
Engineer :
Revision No-:
brw to atq_awi_�r 69__10-22-IO k by ?
Jobfile Name:
Date
Scenario
Bus Voltage Results
Bus Name
Type V DROP ANG
(£) (DEG)
2
(KW)
4
(KVAR)
PF
(g)
-(VOLTS)
-
---r-----------
Swing 4160 -0.00 0.0
5101
-798
96_80
Barrow
P_Load 69897 0.15 24.0
-�GGG
-10
51
99.88
Atgasuk
Junction
None 69239 -0.35 24.4
0.95 23.1
032
-3000
-1500
89.44
Wainwright
P Load 68345
Branch Power Flow Values
Name C#
->
Type Library CodeName F(oKWW)
To Flow
(KNAR)
To -> From
(KV?)
Flow
(KVAR)
Losses
(KK)
Branch
(i'VFIR)------ - -_
-------- - ._ _ ---- ---------
--------
---- ------
-------�
- ------ ----
1
Feeder ACSR 477-4.69 2006
51
-2001
-1004
6 -
Atqasuk Fdr
953
5069
-1173
-5031
200
38 r
Junction Fdr 1
Feeder ACSR 47"1-9.69
24 -
973
1
Feeder ACSR 477-4.69 3025
-254
-3001
-1507
Wainwright Fdr
-5069
1169
32
1760
Barrow Xfmr 1
2-W xfmr 5000-3-L 5101
-798
372
Branch Current Flow Values
Library CodeName Current
Angle Ampacity Loading
M
Branch Name
C# Type
(A)
(Deg)
(A)
------------------------
Fdr
- - ---
1 Feeder ACSR 477-4-69
17
43
230
.
23.
590
590
3g
3%
Atqasuk
Junction Fdr
1 Feeder ACSR 477-4.69
477-4.69
2
590
4%
Wainwright Fdr
1 Feeder ACSR
1 2-W xfmr 5000-3-L
726
8.9
Barrow Xfmr
Transformer & Line Voltage Regulator
Loa�dinq
Loading
T)p
Branch Name
C# Type Library CodeName
Capacity
KVA)g)
(PU)p (PU__
_____..__-______....
..
�---- �_---__..-_-..--.-__—
6100
5163 85%
1.000 1.000
Barrow Xfmr
1 2-W xfmr 5000-3-L
EXHIBIT 9 (CONT.)
LOAD FLOW REPORT AT 69 KV AC
EDSA Advanced Power Flow Program V5.70.00
Project No. :
Page : 1
Project Name:
Date : 01/11/2011
Title
Time : 01:49:38 am
Drawing No.
Company
Revision No.:
Engineer
Jobfile Name: brw to atq_awi w 69._10-22-10
Check by
Scenario : 1 -
Date
System Information
Base KVA
= 100000
(kva)
Frequency
= 60
(HZ)
Unit System
= U.S. Standard
MaxIterations
= 1000
Error Tolerance
= 10.000
(kva), 0.000100 (pu), 0.0100 (%)
# of Buses entered
= 5
# of Active Buses
= 4
# of Swing Buses
= 1
# of Generators
= 0
# of Loads
= 2
# of Shunts
= 0
# of Branches entered = 4
# of Transformers = 1
# of Reactors = 0
# of C.B. = 0
Abbreviations
2-W xfmr = 2-winding transformer
3-W xfmr = 3-winding transformer
Autoxfmr = Autotransformer
DReactor = Duplex Reactor
F Load = Functional load
FeederM = Feeder in Magnetic Conduit
Gen = Generator
I Load _ Constant current load
None = None contributing
P_Load = Constant power load
PhS xfmr = Phase -Shift Transformer
SeriesC = Series Capacitor
ShuntC = Shunt Capacitor
ShuntR = Shunt Reactor
Z Load = Constant impedance load
Ref "C = Reference Temperature
Power Flow By Fast Decoupled CONVERGED
Iteration: 5
T
EXHIBIT 9 (CONT.)
LOAD FLOW REPORT AT 69 KV AC
EDSA Advanced Power Flow Program V5.70.00
Project No.
Page : 2
Date : 01/11/2011
Project Name:
Time : 01:49:38 am
Title
Drawing No.
Company
Revision No.:
Engineer
Jobfile Name:
brw to atq awi w_69._10-22-10 Check by
Scenario :
1 - Date
Summary of Total Generation and Demand
P(Kw)
Q(KVAR)
S(KVA)
PF(%)
Swing Bus(es):
8262.924
1417.423
8383.615
98.56
Generators
0.000
0.000
0.000
0.000
0.00
0.00
Shunt
0.000
0.000
Static Load
8000.000
4000.000
8944.272
89.44
Motor Load
0.000
0.000
0.000
0.00
Total Loss
261.396
r
-2588.178
Mismatch
--
1.528
5.601
Bus Data
Bus Name
----_-----------------
Type
----------
V
Mag ) A
------- l -------
P
(Kw)
_
4 C
--- )
---- ---
Barrow
Swing
P_Load
4160 0
69000 0
-0
-2000
-0
-1000
Atqasuk
Junction
None
69000 0
0
-0
-0
Wainwright
P Load
69000
-- Y6000 `-^_3000
p
0 0
Total Generating Sources
_5000
-4000
Total Bus Loads
Branch Data
Branch Name
C$ Type
Library CodeName (Ohms)
x
(Ohms)
B�2 Ref `c
(Rhos)
Atgasuk Fdr
1 Feeder
ACSR 477-4.69
6.2937
7.0566
20.7868
23.3064
0.000102 40.0
0.000114 40.0
Junction Fdr
1 Feeder
ACSR 477-4.69
ACSR 477-4.69
12.0153
39.6840
0.000194 40.0
Wainwright Fdr
1 Feeder
Transformer &
Line Voltage
Regulator
Data
Branch Name
C# Type Library CodeName
( ) (X F Tap T (TaTa p
($)
-
-'
_
7500-3-L
W - --
0.5700
7.4700 1.000 1.050
Barrow Xfmr
1 2-W
xfmr
EXHIBIT 9 ICONT.)
LOAD FLOW REPORT AT 69 KV AC
EDSA Advanced Power Flow Program V5.70.00
Project No. : Page 3
Project Name: Date 01/11/2011
Title Time : 01:49:38 am
Drawing No. Company
Revision No.: Engineer
Jobfile Name: brw to atq_awi w_69._10-22-10 Check by
Scenario : 1 -
Bus Voltage Results
Bus Name
Type
V
DROP
ANG
P
Q
PF
M
(VOLTS)
(%)
(DEG)
(KW)
(KVAR)
Swing
4160
-0.00
0.0
8263
1417
98.56
Barrow
Atqasuk
P_Load
69691
-1.00
22.7
-2000
-1000
89.44
Junction
None
70025
-1.49
1.96
23.2
20.6
8117
-6000
1536
-3000
98.26
89.44
Wainwright
P_Load
67649
Branch Power Flow Values
Branch Name C# Type Library CodeName From > To(Flooww) To(-> KWI From(FloowR) (�L;sses
(KVAR) --- ------- ----_---
Ataasuk Fdr 1 Feeder ACSR 477-4.69 2007 25 -2001 -1001 6
976 -
junction Fdr 1 Feeder ACSR 477-4.69 8208 716 -8112 -I538 9G
821 -
Wainwright Fdr 1 Feeder ACSR 477-4.69 6111 1511 -6004 -3002 1
1491 r 8263 1417 -8210 -717 53
Barrow Xfmr 1 2-W xfmr 7500-3-L
700
Branch Current Flow Values
Branch Name C# Type Library CodeName Current Angle Ampacity Loading
(A) (Deg) (A) M
-------- ------�----�------ -- -- ---- `---590 3%
Atgasuk--- ~- --Fdr 1 Feeder ACSR 477-4.69 67 2.3 590 1
21
Junction Fdr 1 Feeder ACSR 477-4.69 52 9 3 590 %
Wainwright Fdr 1 Feeder ACSR 477-4.69
Barrow Xfmr 1 2-W xfmr 7500-3-L 1164 -9.7
Transformer & Line Voltage Regulator Loading
Branch Name C# Type Library CodeName Capacity Loading F Tap T_Tap
(KVA) (KVA) M (PU) (PU.
-----
Barrow Xfmr 1 2-W xfmr 7500-3-L 9150 8364 92% 1.000 1.050
EXHIBIT 10
LOAD FLOW REPORT AT 30 KV DC
'
EDSAfDC'Load _Flow —Program V6.10-00
'
Project No. :
Page :
:
08/11/2010
1Date
Project Name:
Time :
08:27:44 pm
'
Title
Company
Drawing No.
Engineer :
Revision No.:
Jobfile Name: barrow to atqasuk do
Check b y
'
Date .
/
system Information
Number of Buses
2
'
Number of Branches
1
'
Number of Rectifiers 0
Number of Inverters
0
'
Number of Batteries
0
Number of Dc/Dc Converters 0100
BaseKw
kw
Default voltage
250 v
Periods
1
0.00010
pu 0.010 kw
0.010
'Tolerance
20000
^
Iterations
'
Low voltage limit
90 %
Abbreviations
rNone
'
C
= Temperature in C
P Load
= None contributing
= Constant P load
Batt
D switch
= Battery
= Dynamic switch
Rect
= Rectifier
Dc Gen
= Dc generator
Res
RX1
= Resistence
= Double circuit resistence
De/dc
= uconverter
RX2
= Single circuit resistance
F Load
Functional load
= F
load
SplitL
= Battery split lower bus
I-Load
- Constant I
Splitu
= Battery split upper bus
Invert
IF Ref
= Inverter
= Load flow reference
Z Load
= Constant Z load
Mstart
- Motor starting
i
+j
EXHIBIT 10(CONT.)
LOAD FLOW REPORT AT 30 KV DC
Bus Input Data
# Bus Name Type Description SystemV RatedV Load
M M (kw)
1 1---------------- Dc Gent ------------------------------
--- -
(period: 11 30000
2 101013 P Load 30000 30000
(period_ 1)
2000.00
Branch Input Data
(Feeder Resistances in editor are at 25.0 QC)
# Branch Name Description RX2(ohms) LF Ref °C
^- ------ -------•--------------••--
--'
1 10101334.4785 90.0
Branch Connection Information
# Branch Name From Bus Name To Bus Name
- - - -
----------------
1 101013 101010 101013
DC Load Flow Results
Period : 1 DC load flow converged !
Max mismatch : 0.000001 pu 0.000 kw at bus: 101013
Total time : 30.00 min
Time for the period: 30.00 min
Bus Result in Period 1
# Bus Name Type V V Load I LowVFlag
(v) (Pu) (kw) (A)
------------------------ ------ ------ ------ -------
1 101010 Dc Gen 30000.0 1.0000 2182.48 72.75
2 101013 P Load 27491.7 0.9164 2000.00 72.75
Branch Result in Period 1
# Branch Name Type og -
--Ladin --- Loss Voltage
(Amps) (KW) (KW) Drop (V)
-_--- - _ - - -- -
1 101013 Feeder 72.752182.475 182.475 2508.28
EXHIBIT 11
LOAD FLOW REpf�RT AT 50 KV DC
EDSA DC Load Flow Program V6.10.00
Project No- : Page : 1
Project Name: Date : 06/11/2010
Title Time : 09:06:53 pm
Drawing No. Company
Revision No.: Engineer
Check b
Jobfile Name: barrow to atqasuk do Date y -
System Information
Number of Buses
- 2
Number of Branches
1
Number of Rectifiers
0
Number of Inverters
0
Number of Batteries
0
Number of Dc/Dc Converters •_ 00
BaseKW
10100 kw
Default voltage
v
Periods
- 1
Q.00010 pu
0.010 kw
0.010
Tolerance
20000
Iterations
90
Low voltage limit
-
Abbreviations
in °C
None
= None contributing
°C
= Temperature
P_Load
= Constant P load
Batt = Battery
D switch = Dynamic switch
Rect
= Rectifier
Dc Gen
= Dc generator
Res
= ResistenceRX1 = Double circuit resistence
= converter
RX2
= single circuit resistance
F Load
F Loa
= Functional load
FunctDc/dcional
split'
p
= Battery split lower bus
I Load
= Constant I load
Splitu
= Battery split upper bus
Invert
IF Ref
= Inverter
= Load flow reference
Z_Load
= Constant Z load
Mstart
= Motor starting
EXHIBIT 11 (CONT.)
LOAD FLOW REPORT AT 50 KV DC
Bus Input Data
# Bus Name Type Description SystemV RatedV Load
(v) (v) (kw)
` ' -___ ----------------------
- 1 AtqasukP_Load 50000 50000
(period: 1) 2000.00
2 Barrow Dc Gen 50000
(period: 1) 50000
Branch Input Data
(Feeder Resistances in editor are at 25.0 'C)
# Branch Name Description RX2(ohms) LF Ref °C
1 T Line W 94.4692 90.0
Branch Connection Information
# Branch Name From Bus Name To Bus Name
T _^-Y 1 TLine Barrow Atqasuk
DC Load Flow Results
Period : 1 DC load flow converged !
Max mismatch : 0.000OOI pu 0.000 kw at bus: Atqasuk
Total time 30.00 min
Time for the period: 30.00 min
Bus Result in Period 1
# Bus Name Type V V Load I LowVFlag
(v) (pu) (kw) (A)
1 Atqasuk _ - P Load 45882.1 0.9176 2000.00 43.59
2 Barrow DC Gen 50000.0 1.0000 2179.50 43.59
Branch Result in Period 1
# Branch Name Type ------Loading------ Loss Voltage
(Amps) (KW) (KW) Drop(V)
rv-y-_______-_- ----- - 1 T LineFeeder 43.59 2179.500 179.500 4117.91
EXHIBIT 12
ONE LINE DESCRIPTION FOR AC OPERATION
The BUECI feeder circuit from the power plant will be configured utilizing a 4160V Breaker and from there
it will be routed to the Barrow Gas Field South Pad. A 2 MVA Transformer will be located there with a
34.5 kV Re -closer installed at the Barrow and Atqasuk ends of the power line. When using the 69 kV
option, 69 kV SF6, Low Profile Type Breakers will be considered for installation. Atqasuk will be
configured with a 2 MVA Transformer, a 4160V Re -closer, as well as a 34.5 kV Re -loser. See the
enclosed One -Line Diagram.
❑.
T
Zf) "26
One -Line Diagram — AC Operation
EXHIBIT 12. (CONT.)
ONE LINE DESCRIPTION FOR AC OPERATION
At the Atqasuk Power Plant a new 2MVA Transformer will be installed on a pad configured in a similar
manner to the ewsting 1 MVA Transformer located there.
Both the 34.5 kV feeder circuit and the 69 kV feeder circuit option will use a re -closer for protection, and
an SF6 Low Profile Circuit Breaker. The 4160V Stepped -down voltage will be routed through a re -closer
that should connect to TIP2 or B1 UP as is needed or convenient. See the following schematic for clarity.
POWER HOUSE
�
45OKW (G� --
1500 AT
1600 AFC
425KW
r-,
6WKW —
480V,
25M
I110KW
910KW �--�
1500 AT
1600 AF
1000 KVA-PAD MM
3-
180Y2400V T 3KV
NOTES
JIW4160Y2400V
1000 KVA-PAD-MrD T 3KV
NOTE 6
TAP2 CsSA------
---
NC '
B11.3P1
0 TIP1
B112P3
611-2P2
TIP7
TIP3 T X 1
o
NO
3x15 ®6
TIPS ix
Schematic For AC Operation -- Step Down Transformer & Protection
EXHIBIT 13
ONE LINE ON FOR DC OPERATION
See the following one -Line Diagram for clarity.
300013 V
6 MVAXfmr AT
V-
Darmw 0mv
AC V`l 5,0000 V
Or
181016
4
k
101039
vys4kP2 eDry
W: 480 V
Z r
"WO25
Watalva uYad
W; 120 V
Jundion
60000 V
IDIOM
k Cone
v
=4-06V"t r-onv
ro
3
2 T01.A.X*2
101046
IDIO46
Apsuk
wbk"gta
%A'. 4160 V
\t: 12470 V
One -Line pigggm — DC -ovqMt�lon
EXHIBIT 14
HIGH VOLTAGE DIRECT CURRENT EVALUATION
DC CONVERTER COSTS
A TIER QUOTE - 480VAC TO 150OVDC SCENARIO
Gmaii
Change from I MW to 30kw
1 message
Jeff Reichard <jaF@tedc.com>
To: Albert T Sakata <atsakataa@gmail.com>
Albert T 5akata <atsakata@gmaILcom>
Wed, Aug 11, 2010 at 10:32 AM
New cost is $1,900,100 for the system. It wig be the same physical size but each module will be 480VAC to
150OWC for a +1-15kV output (30kV total).
The added costs are for a higher level of isolation, higher voltage 1 number of IGBT's and the transformer
size will increase slightly. The transformers are in the enclosures.
So it is a 480VAC to 30kVDC system with 2 identical converter assemblies, one for each end.
Jeff Reichard iar(a�teAc.com
Tier Electronics LLC www.TiprBectronics.co
262-251-6900 Fax250-1999
EXHIBIT 14 (CONTD.)
DC-CoNvERTER COSTS
Gmail
gL:xrJk
HV sysbm
3 messagss _
ID Jeff Reichard <jaF@!WII:.cerrP
To: Albert T Sakata <atsakata@gmaitcom>
10 The 30kV system could be easily made as large as 5MW
Albert T Sokoto <atsakatafgmail.com>
Fry Sep 3, 2010 at 12:38 PM
V
If we went to 50kV we could also go to 5MW but that would be higher in cost than the 30kV 5MW system
Jeff Reichard ian9teic.com
Tier Electronics LLC www.TierElectronirs.com
262-251-6900 Fax250-1999
1P
Albert T Sakata <atsakata@gmaiLcom>
To: Jeff Reichard <jar@tellc_com>
Bca Albert Sakata <atsakata@gci.net>
J off
How much the cost will be for the 50 kV with 5MW.
Thanks
Albert T. Sakata
Sakata Engineering Services
907-351-5532, 907-344£508 fax
[QM1Ad%A hidden]
Jeff Reichard <jar@te8c.com>
To: Albert T Sakata <atsakata@gmaiLcom>
Sat, Sep 4, 2010 at 10:37 PM
Mon, Sep 13, 2010 at 5.25 AM
$3,985,000 forthe 50kV 5MW system that consists of 40X modules for each side stacked to make the 5OWDC.
This is a 480VA:C to 50kVDC design consisting of 2 AC to DC converter assemblies.
This system has an AC disconnect per converter module.
Thank you
Jeff Reichard jarftetic.com
Tier Electronics LLC www.TierElectrorlcs.com
262-251-6900 Fax250-1999
EXHIBIT 14 (CONTD.)
Albert T Sakata<atsakata@gmail.com>
DC transmission system
1 message
Jeff Reichard <jar@te0c.com> Tue, Aug 10, 2010 at 10:28 AM
To: Albert T Saketa <atsakata@gmaiicom>, "Albert T. Sakata" <atsakata@gcinet>
The HV transmission system consists of:
Each side has 20 units that are in parallelforthe AC side and operate at 480VAG and in series onthe DC
side and operate at 75MC each
The 20 units are broken down into 2 sets of 10 to form a +/- 7.5kV line (15kV total), center DC grounded
thru resistance
Allthe units are bi-directional so they can be set to push power into the grid or pug power fromthe grid
On the opposite side there are 20 more units configured the same way
One side is set to deliver power the other side set to supply power
All the blocks are the same for the power cubes
Each set of 20 power cubes has a single master controller
If one power cube fads thenthe system can keep running with slightly lower power until the cube is replaced
All power cubes have over voltage protection on the DC side
Fiber optics are used for isolation to insure safe operation
To build a higher power system the number of cubes could be doubled to make a 4MW +1-15kV system
Spare power cubes can be ordered and kept on hand for rapid field replacement and minimum down time
All the power cubes and their software is identical
Power cubes have simple status lights (Running / Faulted)
Available options are:
Touch screen display
System circuit breaker
Fiber Optic to Ethernet interface
Energy storage units
Added VAR capability for poor bads
r
1
1
1
1
1
1
1
1
I
I
I
i
i
i
1I•
iiP
OP
OP
ilP
A
OP
OR
ow
EXHIBIT 14 (CONTO.1
Note: We Will be final testing this unit at a Northrop Grumman l acPlitj( so you can witness the system in
operation
Jeff Reichard ' rAW com
Tier Electrorics LLC wwwlorElectrarrics.com
262 251-Fi9W Fax 250-1999
EXHIBIT 14 (CONTD.)
DC CONVERTER COSTS - CONVERTER ARCHITECTURE
EXHIBIT 14 (CONTD.)
ABB E"C Budgetary Quotation
From: "Huntley & Associates" <hundey_8i associates@us.abb.com>
To: atsakata@gd.net
Date: 09/29/2010 02:30:26 AKDT
Subject: KVDC Light -- Transmission Line
Albert
I received this response while we were on the phone: amazing I
Christer is very familiar with Alaska as we've had marry discussions over the past several years. As for the ABB HVDC
technology, he is the Busines Devebpmert Manager for ABB HVDC in North America and has been with ABB for 45 years;
how about that? He is available for further discussion regarding HVDC. I think he is clear on where the areas of opportunity
exist.
We can discuss further on Friday -
G? 7AFO=l
Christer Erilmon TPSNSTRNASS
O 29=101208 PM
To Huntley&Associ WF1eKJLUrkdbngN5TRAM0NABB
oc
subject HWC Light—Transmisslm Line
Chuck,
In reference to email from Mr Albert Sakata of Sakata Engineering Services, dated 9/812010, 1 would like to clarify where
we stand today regarding the our HVDC Light technology with respect to low power application
The technical papers that M r Sakata refers to in his email were written in the late 1999s to early 2000's. These papers
describe some of the early efforts of ABB to get the HVDC Light to market and are indeed discussing systems of relatively
small capacity ( 3MW - 50 MW). The technology as described in these papers has evolved, but the fundamentals are the
same.
The original intent of the HVDC Light was to cover the lower range of HVDC transmission projects (> 300 MW), however the
market has driven the development in the opposite direction, due to the flexibility and black start capability of the technology.
Therefore we are now offering HVDC Light systems for 1100 MW at a transmission voltage of +/- 320 KV.
In discussing the Barrow to Atqasuk transmission project, the lowest DC voltage, we are able to offer today is 80 KV DC and
with a power rating 40 MW. Converters of this size cost in the order of US $ 30- 35 million total for the two converters and
associated DC/AC switchyards. No transmission line cost included. Therefore, at first glance, it appears that a 115 W AC
line would be more cost effective, however, if there are other circumstances, such as you have to underground the
transmission for some considerable distance, we do not see the economics in using our HVDC Light technology.
Having said, this, I would be happy to continue the discussion concerning thus and other possible HVDC Light applications, via
email or in person here in the Pacific l\W or in Alaska during my next visit.
Best Regards,
Christer Eriksson
EXHIBIT 14 (CONTD.)
Barmy
1A:30000 V
` G
5 MVAXtnr
Banvw Conv
w 60DW V
0C
` 10f018
101039
■ 1Mb" Oonv
■ Cr W:4B0 V
er �
1010?5 �
1 Junction
IA:5=0 V
1 Oaa C O
U
O
i iD1D5s
' 1Di060
Atgawlc Conv
!1C 1� 480 V
' 11Ya�nwright Conv
1h:480 V �C
r
o y
o �
3 MV/AXt3 i
� 2 M%U3
101046
101D49
eov
W. 12470 V
EXHIBIT 14 (CONTD.)
Advantages of HVDC over AC transmission
The advantage of HVDC is the ability to transmit large amounts of power over long
distances with lower capital costs and with lower losses than AC. High -voltage direct
current transmission allows efficient use of energy sources remote from load centers.
In a number of applications HVDC is more effective than AC transmission. Examples
include:
• Undersea cables, where high capacitance causes additional AC losses.
• Endpoint -to -endpoint long -haul bulk power transmission without intermediate
'taps', for example, in remote areas
• increasing the capacity of an existing power grid in situations where additional
wires are difficult or expensive to install
• Power transmission and stabilization between unsynchronized AC distribution
systems
• Connecting a remote generating plant to the distribution grid.
Stabilizing a predominantly AC power -grid, without increasing short circuit
current
Reducing line cost. HVDC needs fewer conductors as there is no need to support
multiple phases. Also, thinner- conductors can be used since HVDC does -not
suffer from the skin effect
Facilitate power transmission between different countries that use AC at differing
voltages and/or frequencies
Synchronize AC produced by renewable energy sources
Disadvantages of HVDC over AC- transmission
The disadvantages of HVDC are in conversion, switching, control, availability and
maintenance.
HVDC is less reliable and has lower availability than AC systems, mainly due to the
extra conversion equipment. Single pole systems have availability of about 98.5%, with
about a third of the downtime unscheduled due to faults. Fault redundant bipole systems
provide high availability for 50% of the link capacity, but availability of the full capacity
is about 97% to 98%.htt •//en wikipedia or /wiki/HVDC - cite note- 15#cite note-15
The required static inverters are expensive and have limited overload capacity. At smaller
transmission distances the losses in the static inverters may be bigger than in an AC
transmission line. The cost of the inverters may not be offset by reductions in line
construction cost and lower line loss.
In contrast to AC systems, realizing multiterminal systems- is complex, as is expanding
existing schemes to multiterminal systems. Controlling power flow in a multiterminal DC
system requires good communication between all the terminals; power flow must be
10
EXHIBIT 14 (CONTD.)
actively regulated by the inverter control system instead of the inherent impedance and
phase angle properties of the transmission line. Multi -terminal lines are rare.
High voltage DC circuit breakers are difficult to build because some mechanism must be
included in the circuit breaker to force current to zero, otherwise arcing and contact wear
would be too great to allow reliable switching.
Operating a HVDC scheme requires many spare parts to be kept, often exclusively for
one system as HVDC systems are less standardized than AC systems and technology
changes faster.
Line Configurations
Monopole and earth return
DC line
In a common configuration, called monopole, one of the terminals of the rectifier is
connected to earth ground. The other terminal, at a potential high above or below ground,
is connected to a transmission line. The -earthed terminal may be -connected to the
corresponding connection at the inverting station by means of a second conductor.
If no metallic conductor is -installed,1current flows in the -earth between the -earth
electrodes at the two stations. Therefore it is a type of single wire earth return
httu•//en wikipedia org/wiki/Single wire earth return. The issues surrounding earth -
return current include:
• Electrochemical corrosion of long buried metal objects such as pipelines.
• Underwater earth -return electrodes in seawater may produce chlorine or otherwise
affect water chemistry.
• An unbalanced current path may result in a net magnetic field, which can affect
magnetic navigational compasses for ships passing over an underwater cable.
IF • Permafrost ground resistivity can be very variable.
IF
These effects can be eliminated with installation of a metallic return conductor between
Op
the two ends of the monopolar transmission line. Since one terminal of the converters is
IP
connected to earth, the return conductor need not be insulated for the full transmission
11P
voltage which makes it less costly than the high -voltage conductor. Use of a metallic
return conductor is decided based on economic, technical and environmental factors.
EXHIBIT 14 (CONTD.)
W Most xonopolar systems are designed for future bipolar expansion. Transmission line
towers may be designed to carry two conductors, even if only one is used initially for the
monopole transmission system. The second conductor is either unused, used as electrode
line or connected in parallel with the other.
Bipolar
DC line
..... —�
AC
3
3
DC line
httn://en.wikinedia.org/wiki/File:Hvdc -bipolar schematic svR
In bipolar transmission a pair of conductors is used, each at a high potential with respect
to ground, in opposite polarity. Since these conductors must be insulated for the full
voltage, transmission line cost is higher than a monopole with a return conductor.
However, there are a number of advantages to bipolar transmission which can make it the
attractive option.
Under normal load, negligible earth -current flows, as in the case of monopolar
transmission with a metallic earth -return. This reduces -earth return loss and
environmental effects.
• When a fault develops in a line, with earth return electrodes installed at each end
of the line, approximately half the rated power can continue to flow using the
earth as a return path, operating in monopolar mode.
Since for a given total power rating each conductor of a bipolar line carries only
half the current of monopolar lines, the cost of the second conductor is reduced
compared to a monopolar line of the same rating.
1
In very adverse terrain, the second conductor may be carried an an independent
set of transmission towers, so that some power may continue to be transmitted
1
even if one line is damaged.
1
■
A bipolar system may also be installed with a metallic earth return conductor.
Bipolar systems may carry as much as 3,200 MW at voltages of +/-600 M Submarine
cable installations initially commissioned as a monopole may be upgraded with
additional cables and operated as a bipole.
■
f
EXHIBIT 14 (CONTD.)
A bipolar scheme can be implemented so that the polarity of one or both poles can be
changed. This allows the operation as two parallel monopoles. If one conductor fails,
1 transmission can still continue at reduced capacity. Losses may increase if ground
electrodes and lines are not designed for the -extra current in this mode. To reduce losses
in this case, intermediate switching stations may be installed, at which line segments can
1 be switched off or parallelized.
M
1
1
i
1
1
1
1
1
i
i
0
EXHIBIT 1 - IRS FRP Pole Structure Examples
■
r
Exhibit `i — RS Fiber Reinforced
Polymer (FRP) Utility Pole Structure
Examples & Product Applications
10
r
■
r
r
r
■
■
■
■
i
r
i
r
configuration that optimizes logistics costs.
i FRP Utility Poles, H-Structures
Figure 3 - Sectional, H-Structure Transmission Pole,
compL-ted. with guy anchors and conductors in place.
0
Sectional FRP Utility Poles, are Manufactured by
IRS Group, Calgary, Alberta, Canada.
Figure 2 - Sectional, Single Pole structure assembled at site
and erected. Light weight and simple connections make site
assembly less complex; which equates to lower field costs.
R
Figure 4 - Sectional, H-Structure Transmission Pole installation
utilizing Boom Truck. Light Weight assembly optimizes lifting
equipment.
EXHIBIT 1 - IRS FRP Pole Structure Examples
+
FRP utility Poles, Single Pole
Structures
i
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Figure 5 — Sectional, Single Pole Structure: Transmission
i
Pole, completed, with conductors in place.
ti
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rlgure r — 5ectlonal, Single Pole Structure: Transmission
Pole, completed, with guy anchors and conductors in place.
jfl
Figure 6 - Sectional, Single Pole Structure: Transmission Pole
installation utilizing Boom Truck; optimized lifting equipment.
4 -
�'
5 5
t b1
1 � 1
Figure 8 — Sectional, Single aPole Structure'. Installation near or
at existing infrastrucutre. Light weight allows easy install at
areas with multiple interference.
2
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