assumptions, and results to the PAC, who provided input on draft items at every stage of the study during 12 PAC meetings held from April 2016 through January 2017. Topics Addressed The sections that follow describe the scenarios (Section 3), the methodology used and metrics analyzed (Section 4), the assumptions applied (Section 5), and the main results and observations (Section 6). Section 7 discusses the key conclusions and next and how policymakers and other stakeholders might be able to use this information and data. The report includes hyperlinks throughout to presentations and other materials that contain more detailed information. These links are to PAC presentations on the background and scope of the analysis; the development of the scenarios, assumptions, methodology, and metrics used; and the draft and final results. The links also reference the draft reports, stakeholder comments, and data spreadsheets. The links are up to date as of the publication of the report.
Table 520 Detailed Congestion-Relief System Components and Their Assumed Costs for Scenarios 1, 2, 3, and 6 Congestion-Relief System Scenario 1 RPSs + Gas Scenario 2 ISO Queue Scenario 3 Renewables Plus Scenario 6 RPSs + Geodiverse Renewables 1,471 MW (2 HVDC Ties) 9,043 MW (8 HVDC Ties) 1,839 MW (2 HVDC Ties) 3,596 MW (3 HVDC Ties) Equipment $ per unit Quantities Total $ (Billions) Quantities Total $ (Billions) Quantities Total $ (billions) Quantities $ (Billions) DC portion HVDC overhead lines $3.5 million/ mi 2 × 200 = 400 mi. $1.40 (5 × 400) + (3 × 300) = 2,900 mi. $10.15 2 × 200 = 400 mi. $1.40 (2 × 400) + ( 1 × 300) = 1,100 mi. $3.85 Converters $300 million/ converter 4 $1.20 16 $4.80 4 $1.20 6 $1.80 Misc. DC additional equipment $200 million/tie 2 $0.40 8 $1.60 2 $0.40 3 $0.60 Total DC portion $3.00 $16.55 $3.00 $6.25 AC portion Sending end— reactive devices $0.25 million/MVAR (included in integrator system) -- Approx. 1/3 × 9,000 = 3,000 MVAR $0.75 (included in integrator system) -- Approx. 1/3 × 3,600 = 1,200 MVAR $0.30 Sending end— AC terminations $10 million/ terminal expansion (assumed two terminal expansions per tie) 2 x 2 = 4 $0.04 -- -- 2 x 2 = 4 $0.04 -- -- Sending end— New AC substations $40 million/AC substation (included in integrator system) -- 8 (to connect POI to converter station at each tie) $0.32 (included in integrator system) -- 3 (to connect POI to converter station at each tie) $0.12
RPS + Geo Renew 70,638 13,928 19.72% 5,174 11,254 6,456 80.80% 2025 Unconstrained RPS + Gas 37,707 31 0.08% Unconstrained reference 21 Unconstrained reference 68.72% ISO Queue 42,833 185 0.43% Unconstrained reference 126 Unconstrained reference 68.05% Renew Plus 58,645 432 0.74% Unconstrained reference 93 Unconstrained reference 21.52% No Retire 32,123 5 0.02% Unconstrained reference 5 Unconstrained reference 86.64% ACP + Gas 32,125 3 0.01% Unconstrained reference 2 Unconstrained reference 66.54% RPS + Geo Renew 43,041 102 0.24% Unconstrained reference 68 Unconstrained reference 67.34% 2030 Unconstrained RPS + Gas 41,178 10 0.02% Unconstrained reference 5 Unconstrained reference 49.51% ISO Queue 71,777 8,693 12.11% Unconstrained reference 4,833 Unconstrained reference 55.59% Renew Plus 69,750 17,129 24.56% Unconstrained reference 1,550 Unconstrained reference 9.05% No Retire 33,016 5 0.02% Unconstrained reference 4 Unconstrained reference 70.49% ACP + Gas 33,019 3 0.01% Unconstrained reference 1 Unconstrained reference 57.56% RPS + Geo Renew 37,707 31 0.08% Unconstrained reference 21 Unconstrained reference 68.72% 6-22 also shows the need for control systems to spill renewable energy from wind, hydro, and import resources for the unconstrained cases (see Section 6.2; Figure 616 ). Storage may operate differently than in the past system. The large-scale development of variable energy resources also poses operating challenges for regulation, ramping, and reserves. As discussed in Section 7.2, Phase II of this Scenario Analysis will analyze these issues.