[Federal Register Volume 82, Number 145 (Monday, July 31, 2017)]
[Notices]
[Pages 35571-35572]
[FR Doc No: 2017-15999]

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SECURITIES AND EXCHANGE COMMISSION

[Release No. 34-81198; File No. S7-24-89]

Joint Industry Plan; Notice of Filing and Immediate Effectiveness
of the Thirty-Ninth Amendment to the Joint Self-Regulatory Organization
Plan Governing the Collection, Consolidation and Dissemination of
Quotation and Transaction Information for Nasdaq-Listed Securities
Traded on Exchanges on an Unlisted Trading Privileges Basis

July 25, 2017.
    Pursuant to Section 11A of the Securities Exchange Act of 1934
(``Act''),\1\ and Rule 608 thereunder,\2\ notice is hereby given that
on June 30, 2017, the Participants \3\ in the Joint Self-Regulatory
Organization Plan Governing the Collection, Consolidation and
Dissemination of Quotation and Transaction Information for Nasdaq-
Listed Securities Traded on Exchanges on an Unlisted Trading Privileges
Basis (``NASDAQ/UTP Plan'' or ``Plan'') filed with the Securities and
Exchange Commission (``Commission'') a proposal to amend the NASDAQ/UTP
Plan.\4\

These amendments represent Amendment 39 to the NASDAQ/UTP Plan
(``Amendments''). The Amendments propose to effectuate changes that
certain Participants have made to their names and addresses, as set
forth in Section I(A) of the NASDAQ/UTP Plan and to update the listing
of Participant identifying codes set forth in Section VIII(C) of the
Plan. Pursuant to Rule 608(b)(3)(ii) under Regulation NMS,\5\ the
Participants designate the Amendments as concerned solely with the
administration of the Plans and as ``Ministerial Amendments'' under
Section XVI of the Nasdaq/UTP Plan. As a result, the Amendments were
effective upon filing and were submitted by the Chairman of the Plan's
Operating Committee. The Commission is publishing this notice to
solicit comments from interested persons on the proposed Amendments.
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    \1\ 15 U.S.C. 78k-1.
    \2\ 17 CFR 242.608.
    \3\ The Participants are: Bats BYX Exchange, Inc., Bats BZX
Exchange, Inc., Bats EDGA Exchange, Inc., Bats EDGX Exchange, Inc.,
Chicago Board Options Exchange, Inc., Chicago Stock Exchange, Inc.,
Financial Industry Regulatory Authority, Inc., International
Securities Exchange LLC, Investors' Exchange LLC, NASDAQ BX, Inc.,
NASDAQ PHLX, Inc., NASDAQ Stock Market LLC, New York Stock Exchange
LLC, NYSE Arca, Inc., NYSE MKT LLC, and NYSE National, Inc.
(collectively, the ``Participants'').
    \4\ The Plan governs the collection, processing, and
dissemination on a consolidated basis of quotation information and
transaction reports in Eligible Securities for each of its
Participants. This consolidated information informs investors of the
current quotation and recent trade prices of Nasdaq securities. It
enables investors to ascertain from one data source the current
prices in all the markets trading Nasdaq securities. The Plan serves
as the required transaction reporting plan for its Participants,
which is a prerequisite for their trading Eligible Securities. See
Securities Exchange Act Release No. 55647 (April 19, 2007), 72 FR
20891 (April 26, 2007).
    \5\ 17 CFR 242.608(b)(3)(ii).
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I. Rule 608(a)

A. Purpose of the Amendments

    The Amendments effectuate changes that certain Participants have
made to their names and addresses, as set forth in Section I(A) of the
NASDAQ/UTP Plan and to update the listing of Participant identifying
codes set forth in Section VIII(C) of the Plan.

B. Governing or Constituent Documents

    Not applicable.

C. Implementation of the Amendments

    Because the Amendments constitute ``Ministerial Amendments'' under
Section XVI of the Nasdaq/UTP Plan, the Chairman of the Plan's
Operating Committee may submit the Amendments to the Commission on
behalf of the Participants in the Plan. Because the Participants have
designated the Amendments as concerned solely with the administration
of the NASDAQ/UTP Plan, the Amendments become effective upon filing
with the Commission.

D. Development and Implementation Phases

    Not applicable.

E. Analysis of Impact on Competition

    The Participants assert that the Amendments do not impose any
burden on competition because they merely effectuate a change in the
names and addresses of certain Participants. For the same reasons, the
Participants do not believe that the Amendments introduce terms that
are unreasonably discriminatory for purposes of Section 11A(c)(1)(D) of
the Exchange Act.

F. Written Understanding or Agreements Relating to Interpretation of,
or Participation in, Plan

    Not applicable.

G. Approval by Sponsors in Accordance With Plan

    See Item I.C. above.

H. Description of Operation of Facility Contemplated by the Proposed
Amendments

    Not applicable.

I. Terms and Conditions of Access

    Not applicable.

J. Method of Determination and Imposition, and Amount of, Fees and
Charges

    Not applicable.

K. Method and Frequency of Processor Evaluation

    Not applicable.

L. Dispute Resolution

    Not applicable.

II. Rule 601(a)

A. Equity Securities for Which Transaction Reports Shall Be Required by
the Plan

    Not applicable.

B. Reporting Requirements

    Not applicable.

C. Manner of Collecting, Processing, Sequencing, Making Available and
Disseminating Last Sale Information

    Not applicable.

D. Manner of Consolidation

    Not applicable.

E. Standards and Methods Ensuring Promptness, Accuracy and Completeness
of Transaction Reports

    Not applicable

F. Rules and Procedures Addressed to Fraudulent or Manipulative
Dissemination

    Not applicable.

G. Terms of Access to Transaction Reports

    Not applicable.

H. Identification of Marketplace of Execution

    Not applicable.

III. Solicitation of Comments

    The Commission seeks general comments on the Amendments. Interested
persons are invited to submit written data, views, and arguments
concerning the foregoing, including whether the proposed Amendments are
consistent with the Act. Comments may be submitted by any of the
following methods:

Electronic Comments

     Use the Commission's Internet comment form (http://www.sec.gov/rules/sro.shtml); or
     Send an email to<EMAIL_ADDRESS>Please include
File Number S7-24-89 on the subject line.

Paper Comments

     Send paper comments in triplicate to Brent J. Fields,
Secretary, Securities and Exchange Commission, 100 F Street NE.,
Washington, DC 20549-1090.

All submissions should refer to File Number S7-24-89. This file number
should be included on the subject line if email is used. To help the
Commission process and review your comments more efficiently, please
use only one method. The Commission will post all comments on the
Commission's Web site (http://www.sec.gov/rules/sro.shtml). Copies of
the submission, all written statements with respect to the proposed
Amendments that are filed with the Commission, and all written
communications relating to the proposed Amendments between the
Commission and any person, other than those that may be withheld from
the public in accordance with the provisions of 5 U.S.C. 552, will be
available for Web site viewing and printing in the Commission's Public
Reference Room, 100 F Street NE., Washington, DC 20549, on official
business days between the hours of 10:00 a.m. and 3:00 p.m. Copies of
the filing also will be available for Web site viewing and printing at
the principal office of the Plans. All comments received will be posted
without change; the Commission does not edit personal identifying
information from submissions. You should submit only information that
you wish to make available publicly. All submissions should refer to
File Number S7-24-89 and should be submitted on or before August 21,
2017.

    By the Commission.
Brent J. Fields,
Secretary.
[FR Doc. 2017-15999 Filed 7-28-17; 8:45 am]
 BILLING CODE 8011-01-P


Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 A B C D Date Modified: 2/ 13/ 03 By: Abt Associates Inc.

Data Sources: NERC level IPM outputs of new capacity additions for 1d, 2d, 3d, and 4d Description: Input into the IPM market analysis for the section 316( b) Phase II NODA Key to IPM runs:

1d  Base case with EPA electricity demand growth assumptions 2d  Base case with AEO electricity demand growth assumptions 3d  Preferred option with EPA electricity demand growth assumptions 4d  Waterbody/ capacity based option with AEO electricity demand growth assumptions March 10, 2003 Page 1 of 18 dwcgi 20798 1049815895 87640000. xls  File Info Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 A B C D E F G H I Abt2_ 1d_ NewBuildsToAbt_ 020503. xls Year NERC Region NERC& Year Tech Type Total Energy Revenue ( Million $) Capacity Revenue ( Million $) FOM Costs ( MM$) Total VOM Costs ( MM$) Total Fuel Costs ( MM$)

2008 ECAR ECAR2008 Turbine 83.48939 596.266 50.4361 2.591535 77.44015 2008 FRCC FRCC2008 Comb. Cycle Gas 1579.16 572.959 125.216 62.1486 1158.73 2008 MAAC MAAC2008 Turbine 83.2844 247.562 21.25443 2.30236 72.8613 2008 MAIN MAIN2008 Comb. Cycle Gas 16.0795 10.5945 1.78404 0.704387 10.7898 2008 MAIN MAIN2008 Turbine 68.6577 466.789 39.142 2.27634 63.1936 2008 MAPP MAPP2008 Turbine 44.0807 199.397 16.8553 1.51304 37.6973 2008 NPCC NPCC2008 Comb. Cycle Gas 432.57 126.355 24.4484 16.7676 308.155 2008 SERC SERC2008 Comb. Cycle Gas 1621.9752 599.202 121.69896 77.75017 1205.4133 2008 SERC SERC2008 Turbine 192.6572 855.0985 81.2192 5.700242 173.9994 2008 SPP SPP2008 Comb. Cycle Gas 29.532 8.49442 1.99754 1.36999 19.8022 2008 WSCC WSCC2008 Comb. Cycle Gas 971.179 220.81882 60.3668 41.40181 630 2008 Total 2008 Total 5122.66509 3903.53624 544.41877 214.526074 3758.08205 2010 ECAR ECAR2010 Turbine 88.845826 435.08384 51.200735 2.7809376 81.863601 2010 ERCOT ERCOT2010 Comb. Cycle Gas 401.535 26.0118 25.4585 17.4604 240.85 2010 ERCOT ERCOT2010 Turbine 6.82058 0.622751 0.427134 0.223283 4.28482 2010 FRCC FRCC2010 Comb. Cycle Gas 1588.56 343.336 125.216 64.6663 1190.85 2010 FRCC FRCC2010 Turbine 113.78 41.8884 10.7058 3.55255 87.7338 2010 MAAC MAAC2010 Comb. Cycle Gas 263.824 64.0559 16.6741 11.4357 204.181 2010 MAAC MAAC2010 Turbine 113.3475 217.5118 29.92209 3.160928 90.0865 2010 MAIN MAIN2010 Comb. Cycle Gas 19.1943 6.4897 1.78404 0.917672 13.9274 2010 MAIN MAIN2010 Turbine 157.2306 387.5913 49.4577 5.456734 131.0802 2010 MAPP MAPP2010 Turbine 87.8828 157.3642 20.41377 3.54802 74.5339 2010 NPCC NPCC2010 Comb. Cycle Gas 466.9969 71.18771 26.43685 18.13136 335.775 2010 SERC SERC2010 Comb. Cycle Gas 1970.0042 543.4995 156.80646 98.63481 1491.6735 2010 SERC SERC2010 Turbine 535.6745 791.5874 118.15574 18.870188 433.94115 2010 SPP SPP2010 Comb. Cycle Gas 178.4301 34.34603 12.59704 8.63951 118.9765 2010 WSCC WSCC2010 Comb. Cycle Gas 1649.794 180.1326 105.1954 72.14701 1048.043 2010 Total 2010 Total 7641.920306 3300.708931 750.451359 329.6254026 5547.800371 2013 ECAR ECAR2013 Turbine 209.63364 630.3842 74.18948 6.9619042 192.56038 2013 ERCOT ERCOT2013 Comb. Cycle Gas 737.992 109.768 50.4803 34.6213 477.568 2013 ERCOT ERCOT2013 Turbine 387.48 83.9406 27.0524 14.1416 271.377 2013 FRCC FRCC2013 Comb. Cycle Gas 1797.332 393.904 139.591 73.46651 1354.64 2013 FRCC FRCC2013 Turbine 219.143 93.0483 23.1079 6.70507 166.522 2013 MAAC MAAC2013 Comb. Cycle Gas 424.63 116.733 29.9848 18.235 321.193 2013 MAAC MAAC2013 Turbine 168.3893 245.36 34.41073 5.128328 138.144 2013 MAIN MAIN2013 Comb. Cycle Gas 71.4956 23.45203 6.07775 3.434862 50.6815 2013 MAIN MAIN2013 Turbine 239.6361 528.0152 67.05682 9.142283 205.9939 2013 MAPP MAPP2013 Turbine 173.5739 193.0609 27.4776 7.49201 145.3972 2013 NPCC NPCC2013 Comb. Cycle Gas 638.609759 115.3236433 36.6933883 25.1656713 462.273702 2013 SERC SERC2013 Comb. Cycle Gas 2374.9126 664.7806 186.93046 120.27067 1811.7151 2013 SERC SERC2013 Turbine 1089.73683 1190.0491 190.25708 39.694993 876.841 2013 SPP SPP2013 Comb. Cycle Gas 372.4754 80.23616 26.80194 18.38179 252.4336 2013 SPP SPP2013 Turbine 25.3185 14.4547 2.63654 1.07707 20.1414 2013 WSCC WSCC2013 Comb. Cycle Gas 2675.293 438.893 179.34538 123.0019 1764.06 2013 Total 2013 Total 11605.65163 4921.403433 1102.093568 506.9209615 8511.541782 2020 ECAR ECAR2020 Turbine 929.28 1357.4733 183.14761 34.9354662 788.07377 2020 ERCOT ERCOT2020 Comb. Cycle Gas 1671.12 331.007 119.218 81.7642 1127.86 2020 ERCOT ERCOT2020 Turbine 847.735 321.592 81.1701 30.2492 581.284 2020 FRCC FRCC2020 Comb. Cycle Gas 2270.837 575.257 176.8826 95.9381 1762.141 2020 FRCC FRCC2020 Turbine 336.2496 213.5238 43.46501 10.612628 269.7645 2020 MAAC MAAC2020 Comb. Cycle Gas 958.439 254.8849 66.4828 42.0434 722.621 2020 MAAC MAAC2020 Turbine 259.62599 299.05991 42.607163 8.3946069 218.169526 2020 MAIN MAIN2020 Comb. Cycle Gas 152.5142 53.17499 13.02164 7.505712 110.1209 2020 MAIN MAIN2020 Turbine 410.97338 700.4391 90.81521 16.30718 356.62749 March 10, 2003 Page 2 of 18 dwcgi 20798 1049815895 87640000. xls  1d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 J K L M N O Capital Costs ( MM$) Capacity ( MW) Total Generation ( GWh) Total Revenues ( mill., $ 2002) Total O& M Cost ( mill., $ 2002) Capital Cost ( mill., $ 2002)

435.421 8268.2101 2591.5335 737.76 141.60 472.58 634.667 9859.5208 56498.7253 2,335.78 1,460.97 688.83 180.2232 3484.3304 2302.3584 359.08 104.65 195.60 10.8366 140.4757 640.3518 28.95 14.41 11.76 337.9171 6416.7151 2276.3344 581.14 113.54 366.75 145.514 2763.1607 1513.0397 264.26 60.85 157.93 166.632 1925.0681 15243.2915 606.62 379.19 180.85 657.7841 9582.6068 70681.9369 2,410.73 1,524.75 713.92 619.1032 13314.6229 5700.2471 1,137.17 283.18 671.94 12.174 157.2864 1245.4433 41.27 25.15 13.21 376.417 4753.2905 37638.0416 1,293.72 794.22 408.54 3576.6892 60665.2875 196331.3035 9,796.47 4,902.50 3,881.91 441.33351 8393.5601 2780.9352 568.64 147.44 479.00 143.779 2004.6084 15873.1166 464.03 307.99 156.05 2.50809 47.9926 223.2834 8.08 5.36 2.72 634.667 9859.5208 58787.5261 2,096.76 1,498.56 688.83 53.6758 1202.9 3552.5516 168.95 110.70 58.26 95.0147 1312.92 10396.1118 355.86 252.11 103.12 231.5104 4458.2247 3160.9314 359.09 133.68 251.27 10.8366 140.4757 834.2477 27.88 18.05 11.76 407.4734 7802.5727 5456.7346 591.32 201.87 442.25 166.8912 3162.9892 3548.0276 266.18 106.90 181.13 179.5585 2081.6392 16483.0703 584.11 412.80 194.88 837.5129 12346.981 89667.9922 2,728.00 1,896.21 908.98 836.2394 17594.012 18870.1858 1,440.53 619.69 907.60 73.7578 991.8905 7854.0995 230.93 152.18 80.05 642.0586 8283.1051 65588.2182 1,986.09 1,329.96 696.85 4756.8169 79683.392 303077.032 11,876.45 7,193.48 5,162.75 612.948 11978.4798 6961.9075 911.70 297.07 665.26 285.091 3974.8298 31473.9458 920.11 610.69 309.42 158.849 3039.5899 14141.5704 511.65 339.25 172.40 704.1695 10991.409 66787.7282 2,378.23 1,701.48 764.26 115.856 2596.3984 6705.0744 338.83 213.09 125.74 170.864 2361.0109 16577.2667 587.56 400.94 185.45 258.0702 4962.5696 5128.3299 449.06 192.85 280.09 35.7398 478.5634 3122.6048 103.05 65.33 38.79 528.923 10250.1172 9142.2793 833.16 306.27 574.06 209.3263 3956.6719 7492.0111 397.92 195.76 227.19 246.233981 2889.2393 22877.9007 818.27 568.86 267.25 991.7291 14718.9513 109336.9771 3,299.09 2,299.74 1,076.36 1241.9 26043.5254 39695.0383 2,474.34 1,201.24 1,347.88 156.29 2110.3909 16710.7361 491.34 323.02 169.63 15.9182 296.2407 1077.0722 43.17 25.89 17.28 1085.1512 14121.6809 111819.8882 3,379.94 2,242.75 1,177.76 6817.059281 114769.6684 469050.3307 17,937.43 10,984.22 7,398.81 1316.4877 25685.4233 34935.5087 2,481.90 1,092.02 1,428.83 673.291 9387.2441 74331.1363 2,172.98 1,442.24 730.75 476.624 9120.239 30249.2388 1,269.11 751.82 517.30 884.473 13927.7549 87216.4121 3,088.97 2,208.62 959.95 225.9313 5169.6942 10612.629 596.69 351.48 245.21 378.843 5234.8721 38221.2409 1,316.87 902.08 411.17 307.15128 5901.3607 8394.6067 606.36 292.14 333.36 76.0137 1025.3251 6823.3777 223.24 141.80 82.50 686.6883 13369.2418 16307.1738 1,206.26 503.33 745.29 March 10, 2003 Page 3 of 18 dwcgi 20798 1049815895 87640000. xls  1d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 57 58 59 60 61 62 63 64 65 A B C D E F G H I 2020 MAPP MAPP2020 Turbine 289.96184 261.19583 37.464879 13.176751 246.6995 2020 NPCC NPCC2020 Comb. Cycle Gas 1120.86555 224.488567 64.864817 44.486734 817.85009 2020 SERC SERC2020 Comb. Cycle Gas 3887.6209 1130.9554 311.59386 193.90077 2944.281 2020 SERC SERC2020 Turbine 1591.5889 1758.7177 276.1461 57.698712 1286.9329 2020 SPP SPP2020 Comb. Cycle Gas 609.7432 154.13855 45.22414 31.01639 425.5116 2020 SPP SPP2020 Turbine 204.9716 168.6012 26.75455 8.24213 161.7141 2020 WSCC WSCC2020 Comb. Cycle Gas 4837.799 1032.0181 335.4835 229.25122 3306.288 2020 WSCC WSCC2020 Turbine 110.4066 119.9254 16.11613 4.714398 94.2806 2020 Total 2020 Total 20489.73176 8956.452747 1930.458109 910.2375981 15220.21998 March 10, 2003 Page 4 of 18 dwcgi 20798 1049815895 87640000. xls  1d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 57 58 59 60 61 62 63 64 65 J K L M N O 270.94321 5127.2362 13176.7441 598.19 322.72 294.06 429.37046 5107.4666 40442.5187 1,460.16 1,006.33 466.01 1638.3858 24534.9588 176273.3496 5,446.85 3,744.17 1,778.20 1788.0185 38133.2941 57698.7645 3,636.21 1,759.09 1,940.60 263.324 3560.9578 28196.7786 829.07 544.57 285.80 176.8619 3466.6472 8242.1388 405.45 213.50 191.95 2036.0663 26416.0313 208410.1785 6,370.73 4,201.37 2,209.82 114.5023 2246.1323 4714.4015 249.99 124.93 124.27 11742.97575 197413.8795 844246.1983 31,959.05 19,602.19 12,745.09 March 10, 2003 Page 5 of 18 dwcgi 20798 1049815895 87640000. xls  1d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 A B C D E F G H I Abt2_ 2d_ NewBuildsToAbt020503. xls Year NERC Region NERC& Year Tech Type Total Energy Revenue ( Million $) Capacity Revenue ( Million $) FOM Costs ( MM$) Total VOM Costs ( MM$) Total Fuel Costs ( MM$)

2008 ECAR ECAR2008 Turbine 196.0858 1042.831 86.1917 6.013505 186.73377 2008 ERCOT ERCOT2008 Comb. Cycle Gas 109.741 24.1549 6.91144 4.74013 71.81 2008 FRCC FRCC2008 Comb. Cycle Gas 1944.97 704.751 149.93 75.4644 1452.01 2008 FRCC FRCC2008 Turbine 9.47365 17.1342 1.75082 0.212893 7.57598 2008 MAAC MAAC2008 Comb. Cycle Gas 154.4902 70.6669 12.40606 6.14683 114.9261 2008 MAAC MAAC2008 Turbine 110.2246 343.808 28.9997 2.97358 98.3333 2008 MAIN MAIN2008 Comb. Cycle Gas 109.015 55.9824 9.55576 4.91528 78.9967 2008 MAIN MAIN2008 Turbine 99.1896 552.353 46.7018 3.13445 90.2944 2008 MAPP MAPP2008 Comb. Cycle Gas 140.823 73.4705 13.0116 6.69289 98.3589 2008 MAPP MAPP2008 Turbine 57.2518 245.741 20.9036 1.92033 50.0567 2008 NPCC NPCC2008 Comb. Cycle Gas 807.1678 208.68514 43.71176 29.979195 569.4023 2008 NPCC NPCC2008 Turbine 0.777453 2.66831 0.220022 0.0145416 0.536378 2008 SERC SERC2008 Comb. Cycle Gas 2805.267 1036.9528 210.3138 128.72161 2066.664 2008 SERC SERC2008 Turbine 247.8715 1096.7913 101.89306 6.855863 219.3265 2008 SPP SPP2008 Comb. Cycle Gas 304.547 93.431 20.4129 13.9999 210.711 2008 SPP SPP2008 Turbine 2.43212 6.72773 0.593043 0.0721117 1.99443 2008 WSCC WSCC2008 Comb. Cycle Gas 2242.847 424.1352 132.9349 91.17187 1426.997 2008 Total 2008 Total 9342.174523 6000.28438 886.441965 383.0293793 6744.727458 2010 ECAR ECAR2010 Turbine 488.76888 859.7657 113.76737 16.96466 426.40577 2010 ERCOT ERCOT2010 Comb. Cycle Gas 385.994 64.9394 26.23264 17.99133 260.8331 2010 ERCOT ERCOT2010 Turbine 372.628 98.6046 27.9136 13.3211 266.091 2010 FRCC FRCC2010 Comb. Cycle Gas 2088.413 429.377 158.15611 83.02948 1575.086 2010 FRCC FRCC2010 Turbine 153.80515 73.80431 18.24722 4.342503 112.77478 2010 MAAC MAAC2010 Comb. Cycle Gas 632.1051 173.8562 46.27059 26.44528 473.1979 2010 MAAC MAAC2010 Turbine 199.155 297.7794 40.7582 6.0328 170.5494 2010 MAIN MAIN2010 Comb. Cycle Gas 106.784 34.6132 9.55576 4.91528 77.5306 2010 MAIN MAIN2010 Turbine 267.8058 475.6979 63.42556 9.63539 225.3525 2010 MAPP MAPP2010 Comb. Cycle Gas 134.884 50.6356 13.0116 6.69289 95.7238 2010 MAPP MAPP2010 Turbine 208.1144 236.2989 32.9571 8.58671 177.1963 2010 NPCC NPCC2010 Comb. Cycle Gas 1280.7038 233.06936 71.9713 49.360675 940.9331 2010 NPCC NPCC2010 Turbine 7.358754 11.63938 1.401669 0.1913376 5.817981 2010 SERC SERC2010 Comb. Cycle Gas 3168.443 849.6552 244.2783 153.91692 2418.799 2010 SERC SERC2010 Turbine 847.3211 1054.4704 168.2392 27.865733 685.85631 2010 SPP SPP2010 Comb. Cycle Gas 535.782 115.861 37.6958 25.8531 375.751 2010 SPP SPP2010 Turbine 61.00057 35.69343 6.368943 2.4594567 48.54427 2010 WSCC WSCC2010 Comb. Cycle Gas 3479.97 470.7912 220.1806 151.00817 2307.294 2010 Total 2010 Total 14419.03655 5566.55218 1300.431562 608.6128153 10643.73681 2013 ECAR ECAR2013 Turbine 891.73322 1194.48253 164.456233 32.297635 757.42297 2013 ERCOT ERCOT2013 Comb. Cycle Gas 894.054 159.0082 61.26094 42.01513 606.0851 2013 ERCOT ERCOT2013 Turbine 639.723 215.219 58.1074 21.6923 433.94 2013 FRCC FRCC2013 Comb. Cycle Gas 2312.17 528.69 171.9335 93.3935 1775.962 2013 FRCC FRCC2013 Turbine 326.02244 168.0087 37.48552 9.941853 256.93065 2013 MAAC MAAC2013 Comb. Cycle Gas 872.1823 239.7673 62.88056 36.86891 651.8362 2013 MAAC MAAC2013 Turbine 288.07396 372.4566 51.53241 9.013346 245.3998 2013 MAIN MAIN2013 Comb. Cycle Gas 141.5238 48.4428 12.10753 6.64961 103.8255 2013 MAIN MAIN2013 Turbine 529.5631 748.1676 102.9889 20.536132 448.8902 2013 MAPP MAPP2013 Comb. Cycle Gas 132.141 52.8566 13.0116 6.69289 94.526 2013 MAPP MAPP2013 Turbine 321.20928 309.6156 43.23723 14.021156 278.1284 2013 NPCC NPCC2013 Comb. Cycle Gas 1544.9117 302.59694 87.56898 60.058195 1146.7184 2013 NPCC NPCC2013 Turbine 11.169295 23.68624 2.712536 0.2779746 8.909561 2013 SERC SERC2013 Comb. Cycle Gas 4404.4381 1213.4229 340.14228 212.6773 3369.8698 2013 SERC SERC2013 Turbine 1042.22095 1334.40254 207.129411 34.6147548 833.71724 2013 SPP SPP2013 Comb. Cycle Gas 627.161 153.2758 45.14616 30.96284 448.6975 2013 SPP SPP2013 Turbine 201.28786 153.68791 25.150643 7.7602851 157.83075 March 10, 2003 Page 6 of 18 dwcgi 20798 1049815895 87640000. xls  2d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 J K L Capital Costs ( MM$) Capacity ( MW) Total Generation ( GWh)

744.103 14129.7938 6013.5026 40.9282 544.2079 4309.2081 759.931 11805.4903 68604.0397 12.6151 287.0197 212.893 74.0964 976.855 5588.0279 245.899 4754.0654 2973.5775 58.0434 752.4223 4468.4366 403.1818 7656.0333 3134.4544 79.0348 1024.536 6084.4476 180.463 3426.8247 1920.3284 297.92452 3441.8688 27253.7941 2.13147 36.0691 14.5416 1153.1171 16560.163 117019.6155 782.2013 16703.7828 6855.8651 124.406 1607.314 12727.2153 5.13283 97.2201 72.1117 826.9007 10467.3102 82883.4376 5790.10962 94270.9764 350135.4967 909.7618 17228.1811 16964.6631 150.0452 2065.5594 16355.7451 163.906 3136.3628 13321.0543 799.7039 12453.2152 75481.3518 95.3231 2140.5448 4342.5054 267.0687 3643.3565 24041.1223 315.4752 6075.2502 6032.7991 58.0434 752.4223 4468.4366 503.6483 9535.1053 9635.3842 79.0348 1024.536 6084.4476 252.8735 4781.1532 8586.7145 481.63388 5667.031 44873.3242 11.82785 214.9162 191.3372 1326.9941 19234.5344 139924.3746 1149.9674 24158.4088 27865.7326 224.821 2968.1689 23502.8902 40.00496 746.1975 2459.457 1355.6287 17337.0473 137280.1654 8185.76179 133161.9909 561411.5052 1215.73093 22967.226 32297.628 347.8702 4823.6957 38195.532 341.201 6528.9194 21692.2695 866.317 13538.0461 84903.1959 191.7781 4302.1505 9941.8578 361.7174 4951.2236 33517.1619 383.1555 7406.1812 9013.3518 72.8435 953.3493 6045.0967 753.5008 14344.5545 20536.097 79.0348 1024.536 6084.4476 316.80964 6001.3795 14021.1064 583.03122 6895.1938 54598.3019 23.20236 429.8125 277.9743 1820.1957 26782.8796 193343.0508 1387.63009 29231.6622 34614.7619 268.1082 3554.8117 28148.1116 164.82773 3199.7847 7760.2809 March 10, 2003 Page 7 of 18 dwcgi 20798 1049815895 87640000. xls  2d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 A B C D E F G H I 2013 WSCC WSCC2013 Comb. Cycle Gas 4771.703 965.5931 321.24302 218.56533 3311.734 2013 WSCC WSCC2013 Turbine 3.70115 14.0887 1.60618 0.133604 3.27755 2013 Total 2013 Total 19954.98916 8197.46906 1809.701033 858.1727455 14933.70162 2020 ECAR ECAR2020 Comb. Cycle Gas 717.599 253.0975 60.7922 31.771 523.789 2020 ECAR ECAR2020 Turbine 1409.82098 1875.0952 256.62981 51.019178 1198.13259 2020 ERCOT ERCOT2020 Comb. Cycle Gas 2113.416 487.762 149.78844 102.73063 1505.0325 2020 ERCOT ERCOT2020 Turbine 1090.47 575.264 123.801 38.0652 776.916 2020 FRCC FRCC2020 Comb. Cycle Gas 2205.996 574.7978 171.9335 88.6149 1714.073 2020 FRCC FRCC2020 Turbine 473.90951 329.2374 64.58626 14.227765 378.11726 2020 FRCC FRCC2020 IGCC 851.708 179.975 136.069 35.8135 216.196 2020 MAAC MAAC2020 Comb. Cycle Gas 1203.60866 323.23417 86.295255 50.560684 886.61259 2020 MAAC MAAC2020 Turbine 405.6932 507.6459 70.37646 12.427085 340.5408 2020 MAAC MAAC2020 IGCC 446.344 113.139 70.8846 18.6569 73.6871 2020 MAIN MAIN2020 Comb. Cycle Gas 358.391 119.8595 29.03766 17.03138 266.3114 2020 MAIN MAIN2020 Turbine 674.5692 996.90933 131.082363 26.0141139 591.94312 2020 MAPP MAPP2020 Comb. Cycle Gas 305.679 111.7831 27.2912 15.64068 219.6415 2020 MAPP MAPP2020 Turbine 358.4335 382.7867 51.6094 15.4189 311.1113 2020 NPCC NPCC2020 Comb. Cycle Gas 2357.203 503.15982 133.9569 91.872725 1772.5138 2020 NPCC NPCC2020 Turbine 54.176029 83.79033 10.124202 1.5091616 44.635729 2020 SERC SERC2020 Comb. Cycle Gas 7763.73 2163.661 597.471 365.41581 5918.354 2020 SERC SERC2020 Turbine 1314.13661 1849.0786 281.07748 43.593122 1056.45279 2020 SPP SPP2020 Comb. Cycle Gas 1146.6267 313.0615 83.88473 57.23592 837.983 2020 SPP SPP2020 Turbine 412.98982 341.48133 54.337953 16.1133731 330.54938 2020 WSCC WSCC2020 Comb. Cycle Gas 7497.161 1986.0925 520.8043 355.86764 5496.195 2020 WSCC WSCC2020 Turbine 72.0195 300.71224 34.45833 2.775212 63.5867 2020 Total 2020 Total 33233.68071 14371.62392 3146.292043 1452.37488 24522.37456 March 10, 2003 Page 8 of 18 dwcgi 20798 1049815895 87640000. xls  2d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 J K L 1968.7434 25294.7175 198695.7738 12.7725 263.308 133.6043 11158.47007 182493.4318 793819.6041 352.589 4786.7838 28882.7346 1842.2881 35501.3286 51019.1428 847.8342 11794.362 93391.4485 726.948 13910.2166 38065.2454 866.317 13538.0461 80558.972 339.0615 7754.4361 14227.759 643.606 4238.9061 32557.7572 495.142 6794.9037 45964.2621 509.4701 9977.273 12427.0862 395.105 2208.2431 16960.8479 171.0364 2286.4285 15483.0595 967.12569 18842.2161 26014.1095 161.8554 2148.9148 14218.8053 381.0394 7358.6714 15418.8697 884.58932 10547.7875 83520.6819 81.94097 1496.0667 1509.1646 3168.6091 47044.9893 332196.2772 1866.1316 40126.2987 43593.112 493.1824 6605.0989 52032.7021 353.36916 6849.4173 16113.3811 3193.9117 41008.2065 323516.0483 271.83452 5585.6217 2775.2134 19012.98656 300404.2165 1340446.68 March 10, 2003 Page 9 of 18 dwcgi 20798 1049815895 87640000. xls  2d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 A B C D E F G H I Abt2_ 3d_ NewBuildsToAbt. xls Year NERC Region NERC& Year Tech Type Total Energy Revenue ( Million $) Capacity Revenue ( Million $) FOM Costs ( MM$) Total VOM Costs ( MM$) Total Fuel Costs ( MM$)

2008 ECAR ECAR2008 Turbine 84.46271 594.824 50.4361 2.600923 77.7073 2008 FRCC FRCC2008 Comb. Cycle Gas 1583.72 568.702 125.147 61.9583 1155.18 2008 MAAC MAAC2008 Comb. Cycle Gas 16.3911 5.76382 1.0256 0.703395 12.8473 2008 MAAC MAAC2008 Turbine 87.1669 242.862 20.75642 2.40575 76.8195 2008 MAIN MAIN2008 Comb. Cycle Gas 70.2331 43.3584 7.38445 3.09021 47.4538 2008 MAIN MAIN2008 Turbine 70.4795 439.104 37.1081 2.27448 63.2883 2008 MAPP MAPP2008 Turbine 45.6047 198.605 16.8553 1.55836 38.9226 2008 NPCC NPCC2008 Comb. Cycle Gas 406.578 109.346 22.6632 15.5433 285.655 2008 SERC SERC2008 Comb. Cycle Gas 1807.4802 665.4658 136.09597 86.10392 1333.134 2008 SERC SERC2008 Turbine 178.2979 814.3335 77.53325 5.23385 160.2299 2008 SPP SPP2008 Comb. Cycle Gas 6.62044 1.8843 0.446756 0.306402 4.42883 2008 WSCC WSCC2008 Comb. Cycle Gas 975.384 221.01033 60.59362 41.55743 632.3021 2008 Total 2008 Total 5332.41855 3905.25915 556.045766 223.33632 3887.96863 2010 ECAR ECAR2010 Turbine 89.589026 435.35985 51.200735 2.7903386 82.128001 2010 ERCOT ERCOT2010 Comb. Cycle Gas 393.528 7.37396 23.8719 16.3723 225.84 2010 FRCC FRCC2010 Comb. Cycle Gas 1589.36 334.296 125.147 64.2699 1183.55 2010 FRCC FRCC2010 Turbine 112.572 40.8078 10.7058 3.46352 85.5352 2010 MAAC MAAC2010 Comb. Cycle Gas 273.8478 66.60069 17.4214 11.846158 211.6679 2010 MAAC MAAC2010 Turbine 112.7566 213.5951 29.62695 3.137586 89.2823 2010 MAIN MAIN2010 Comb. Cycle Gas 78.8129 27.4518 7.38445 3.7984 57.6477 2010 MAIN MAIN2010 Turbine 150.9572 382.7373 48.50701 5.305017 126.6873 2010 MAPP MAPP2010 Turbine 87.0556 158.7458 20.41377 3.52332 74.0627 2010 NPCC NPCC2010 Comb. Cycle Gas 432.22168 70.265549 24.462305 16.777195 310.71404 2010 SERC SERC2010 Comb. Cycle Gas 2054.1233 568.44002 164.26927 102.54939 1551.5772 2010 SERC SERC2010 Turbine 507.43115 770.9696 115.48408 17.841626 412.08785 2010 SPP SPP2010 Comb. Cycle Gas 194.1146 37.67515 13.722656 9.411532 129.06544 2010 WSCC WSCC2010 Comb. Cycle Gas 1650.436 180.5348 105.25652 72.18893 1048.6951 2010 Total 2010 Total 7726.805856 3294.853419 757.473846 333.2752126 5588.540731 2013 ECAR ECAR2013 Turbine 215.64906 644.8602 75.69273 7.2342066 199.25287 2013 ERCOT ERCOT2013 Comb. Cycle Gas 678.414 90.2726 45.7719 31.3921 433.023 2013 ERCOT ERCOT2013 Turbine 421.042 81.0941 28.815 15.063 289.059 2013 FRCC FRCC2013 Comb. Cycle Gas 1793.192 365.9314 137.3998 72.43033 1336.317 2013 FRCC FRCC2013 Turbine 243.256 93.471 24.5952 7.3086 181.511 2013 MAAC MAAC2013 Comb. Cycle Gas 444.6363 118.73298 30.7275 19.101158 337.6819 2013 MAAC MAAC2013 Turbine 171.0412 238.6684 33.75742 5.218554 140.2817 2013 MAIN MAIN2013 Comb. Cycle Gas 127.1098 41.9537 10.6962 6.17364 92.2669 2013 MAIN MAIN2013 Turbine 252.6089 538.9328 68.32012 9.674619 218.1055 2013 MAPP MAPP2013 Turbine 168.7389 190.8714 27.0665 7.26986 141.4063 2013 NPCC NPCC2013 Comb. Cycle Gas 618.8116 110.56467 35.39485 24.275145 447.7921 2013 SERC SERC2013 Comb. Cycle Gas 2442.0238 683.3878 192.50397 123.44476 1860.5072 2013 SERC SERC2013 Turbine 1054.51401 1163.1604 185.15206 38.345925 851.82489 2013 SPP SPP2013 Comb. Cycle Gas 371.36163 79.71162 26.704956 18.315292 251.03544 2013 SPP SPP2013 Turbine 24.0641 13.725 2.50502 1.02334 19.1366 2013 WSCC WSCC2013 Comb. Cycle Gas 2672.7119 436.1249 179.02602 122.78297 1761.1468 2013 Total 2013 Total 11699.1752 4891.46297 1104.129246 509.0534996 8560.3482 2020 ECAR ECAR2020 Turbine 929.43714 1357.4733 183.1536 34.9451182 788.14271 2020 ERCOT ERCOT2020 Comb. Cycle Gas 1614.33 317.825 115.051 78.9064 1088.44 2020 ERCOT ERCOT2020 Turbine 879.263 325.421 82.5533 31.5437 605.842 2020 FRCC FRCC2020 Comb. Cycle Gas 2282.777 533.161 175.2354 95.1625 1748.287 2020 FRCC FRCC2020 Turbine 392.817 205.493 47.3312 12.0979 301.576 2020 MAAC MAAC2020 Comb. Cycle Gas 951.4429 251.50674 65.8628 41.691058 716.8229 2020 MAAC MAAC2020 Turbine 258.7483735 292.2494099 41.97978022 8.350537452 216.7920027 2020 MAIN MAIN2020 Comb. Cycle Gas 146.5859 52.9291 13.02163 7.1032 105.9018 2020 MAIN MAIN2020 Turbine 413.71461 702.68092 90.81384 16.43155 360.25821 March 10, 2003 Page 10 of 18 dwcgi 20798 1049815895 87640000. xls  3d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 J K L M N O Capital Costs ( MM$) Capacity ( MW) Total Generation ( GWh) Total Revenues ( mill., $ 2002) Total O& M Cost ( mill., $ 2002) Capital Cost ( mill., $ 2002)

435.421 8268.2117 2600.9216 737.26 141.90 472.58 634.318 9854.1 56325.7192 2,336.10 1,456.83 688.45 6.12549 80.7558 639.4497 24.05 15.82 6.65 176.001 3402.6934 2405.7518 358.19 108.51 191.02 44.8544 581.4525 2809.2791 123.29 62.87 48.68 320.3582 6083.2988 2274.4826 553.07 111.43 347.70 145.514 2763.1607 1558.3587 265.05 62.23 157.93 154.465 1784.5062 14130.2784 559.95 351.50 167.65 739.9151 10716.2495 78276.2531 2,683.98 1,688.06 803.06 591.0058 12710.3613 5233.8482 1,077.34 263.73 641.44 2.72275 35.1776 278.5475 9.23 5.62 2.96 377.8232 4771.1564 37779.5092 1,298.49 797.13 410.07 3628.52394 61051.1239 204312.3991 10,026.00 5,065.65 3,938.17 441.33351 8393.5617 2790.337 569.75 147.74 479.00 134.818 1879.6802 14883.8958 435.11 288.79 146.32 634.318 9854.1 58427.2234 2,087.82 1,490.13 688.45 53.6758 1202.9 3463.5225 166.47 108.21 58.26 99.55439 1371.7626 10769.1936 369.50 261.50 108.05 228.4886 4399.3822 3137.582 354.20 132.46 247.99 44.8544 581.4525 3453.0921 115.33 74.70 48.68 398.2903 7646.7314 5305.0218 579.24 195.90 432.28 166.8912 3162.9892 3523.329 266.78 106.36 181.13 166.16054 1926.1676 15251.9977 545.37 381.99 180.34 884.1449 12934.6238 93226.6875 2,846.37 1,973.57 959.60 807.70922 17048.6761 17841.6353 1,387.50 591.96 876.64 79.85685 1080.5251 8555.9363 251.57 165.19 86.67 642.4848 8287.9194 65626.3391 1,987.22 1,330.78 697.31 4782.58051 79770.4718 306255.7931 11,962.22 7,249.28 5,190.71 623.8997 12204.8306 7234.2114 933.94 306.26 677.14 258.499 3604.0855 28538.2769 834.28 553.73 280.56 169.199 3237.6376 15062.9793 544.99 361.35 183.64 693.5598 10818.8865 65845.7572 2,343.38 1,678.09 752.75 123.313 2763.5002 7308.5996 365.46 231.63 133.84 175.37749 2419.4873 17364.6568 611.45 420.58 190.34 252.9287 4863.4754 5218.5544 444.67 194.56 274.51 64.0623 842.2206 5612.4009 183.49 118.45 69.53 535.7034 10422.6635 9674.6134 859.09 321.37 581.42 206.8571 3910.4892 7269.862 390.30 190.74 224.51 237.23071 2786.9983 22068.3246 791.62 550.77 257.48 1028.6891 15157.8287 112222.5485 3,392.13 2,362.19 1,116.47 1206.6999 25395.236 38345.9263 2,406.93 1,167.09 1,309.68 155.28505 2102.7533 16650.2594 489.57 321.32 168.54 15.1241 281.4628 1023.3427 41.01 24.60 16.41 1083.3829 14096.5409 111620.8212 3,374.14 2,239.00 1,175.84 6829.81125 114908.0964 471061.1346 18,006.44 11,041.71 7,412.65 1316.5004 25685.4223 34945.0852 2,482.07 1,092.11 1,428.85 649.758 9059.1393 71733.0997 2,097.04 1,391.83 705.21 484.745 9275.6473 31543.6805 1,307.49 781.38 526.11 876.493 13798.0648 86511.3888 3,056.24 2,190.95 951.29 237.305 5318.1134 12097.898 649.37 391.81 257.56 375.58949 5186.043 37900.9825 1,305.61 894.73 407.64 301.5942227 5787.7309 8350.5356 598.02 289.92 327.33 77.5496 1025.325 6457.457 216.54 136.78 84.17 684.85291 13369.2375 16431.5546 1,211.67 507.40 743.30 March 10, 2003 Page 11 of 18 dwcgi 20798 1049815895 87640000. xls  3d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 57 58 59 60 61 62 63 64 65 A B C D E F G H I 2020 MAPP MAPP2020 Turbine 290.96426 261.12865 37.506268 13.222082 247.45556 2020 NPCC NPCC2020 Comb. Cycle Gas 1131.9667 227.4205 65.50604 44.926642 826.8139 2020 SERC SERC2020 Comb. Cycle Gas 3951.6988 1148.4206 316.9531 196.57599 2994.0532 2020 SERC SERC2020 Turbine 1554.13405 1737.01807 272.161174 56.2469781 1254.574263 2020 SPP SPP2020 Comb. Cycle Gas 592.25823 149.74773 43.929056 30.128262 412.85744 2020 SPP SPP2020 Turbine 206.9952 170.64036 27.11299 8.318443 163.0335 2020 WSCC WSCC2020 Comb. Cycle Gas 4843.2922 1030.3551 335.68862 229.39174 3308.5576 2020 WSCC WSCC2020 Turbine 110.4653 119.86648 16.11613 4.714399 94.2806 2020 Total 2020 Total 20550.89066 8883.33696 1929.975928 909.7564998 15233.68869 March 10, 2003 Page 12 of 18 dwcgi 20798 1049815895 87640000. xls  3d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 57 58 59 60 61 62 63 64 65 J K L M N O 271.03565 5127.2362 13222.1262 599.21 323.63 294.17 432.97759 5157.9626 40842.362 1,475.39 1,017.23 469.93 1670.333 24956.9685 178705.3918 5,535.35 3,806.91 1,812.87 1763.42839 37690.7071 56246.9212 3,572.01 1,718.07 1,913.91 255.35895 3458.9829 27389.3098 805.33 528.47 277.15 179.17059 3511.2744 8318.4383 409.86 215.40 194.46 2037.4185 26432.1684 208537.9559 6,374.89 4,204.20 2,211.29 114.50233 2246.1323 4714.4015 249.99 124.93 124.27 11728.61262 197086.1559 843948.5886 31,946.07 19,615.76 12,729.50 March 10, 2003 Page 13 of 18 dwcgi 20798 1049815895 87640000. xls  3d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 A B C D E F G H I Abt2_ 4d_ NewBuildsToAbt020603. xls Year NERC Region NERC& Year Tech Type Total Energy Revenue ( Million $) Capacity Revenue ( Million $) FOM Costs ( MM$) Total VOM Costs ( MM$) Total Fuel Costs ( MM$)

2008 ECAR ECAR2008 Turbine 194.75009 991.347 82.164 5.975497 185.492 2008 ERCOT ERCOT2008 Comb. Cycle Gas 9.92591 1.76521 0.603214 0.413707 6.2674 2008 FRCC FRCC2008 Comb. Cycle Gas 2075.99 705.061 153.567 80.4096 1547.16 2008 MAAC MAAC2008 Comb. Cycle Gas 200.5056 91.328 16.08109 7.9717 148.7647 2008 MAAC MAAC2008 Turbine 103.2464 327.49 27.5755 2.733536 90.5452 2008 MAIN MAIN2008 Comb. Cycle Gas 159.043 80.4754 13.8639 7.13129 114.612 2008 MAIN MAIN2008 Turbine 107.1246 544.049 46.2631 3.31089 95.8275 2008 MAPP MAPP2008 Comb. Cycle Gas 165.167 85.3181 15.2397 7.83899 115.202 2008 MAPP MAPP2008 Turbine 55.3024 236.095 20.2558 1.84661 48.1056 2008 NPCC NPCC2008 Comb. Cycle Gas 803.8472 206.5336 43.42077 29.77966 566.5104 2008 SERC SERC2008 Comb. Cycle Gas 3031.9246 1119.6222 227.47977 138.43958 2231.5814 2008 SERC SERC2008 Turbine 246.2579 1064.2215 99.34401 6.782556 216.0468 2008 SPP SPP2008 Comb. Cycle Gas 285.373 90.6467 19.2783 13.2218 199 2008 SPP SPP2008 Turbine 4.3583 12.0644 1.06316 0.129276 3.57545 2008 WSCC WSCC2008 Comb. Cycle Gas 2349.1019 475.3139 140.34372 96.25309 1511.9908 2008 Total 2008 Total 9791.9179 6031.33101 906.543034 402.237782 7080.68125 2010 ECAR ECAR2010 Turbine 497.50902 851.5998 114.15887 16.975219 429.29655 2010 ERCOT ERCOT2010 Comb. Cycle Gas 225.7176 34.25252 14.951314 10.254197 150.5284 2010 ERCOT ERCOT2010 Turbine 426.081 102.682 31.4101 14.6289 298.287 2010 FRCC FRCC2010 Comb. Cycle Gas 2209.622 417.3659 160.37118 86.64837 1670.281 2010 FRCC FRCC2010 Turbine 158.013 64.9628 17.4928 4.37906 113.4 2010 MAAC MAAC2010 Comb. Cycle Gas 810.6437 213.626 58.45169 33.55803 603.4148 2010 MAAC MAAC2010 Turbine 159.3714 252.5232 33.76855 4.646916 140.0166 2010 MAIN MAIN2010 Comb. Cycle Gas 155.243 52.6385 13.8639 7.13129 114.612 2010 MAIN MAIN2010 Turbine 299.4044 512.203 69.61471 10.63708 247.8525 2010 MAPP MAPP2010 Comb. Cycle Gas 159.588 60.4635 15.2397 7.83899 114.454 2010 MAPP MAPP2010 Turbine 197.6324 232.068 31.6931 8.01488 169.0161 2010 NPCC NPCC2010 Comb. Cycle Gas 1348.78 233.49101 74.43493 51.0504 989.35 2010 SERC SERC2010 Comb. Cycle Gas 3438.373 927.3714 267.21052 162.74181 2621.7618 2010 SERC SERC2010 Turbine 705.725 982.4591 154.86471 22.290156 565.8428 2010 SPP SPP2010 Comb. Cycle Gas 545.631 113.5704 37.7012 25.8569 383.025 2010 SPP SPP2010 Turbine 58.3751 36.78362 6.366997 2.2854583 46.50856 2010 WSCC WSCC2010 Comb. Cycle Gas 3652.4113 481.0327 227.36452 155.93529 2436.3594 2010 Total 2010 Total 15048.12092 5569.09345 1328.958791 624.8729463 11094.00651 2013 ECAR ECAR2013 Turbine 917.6378 1205.7822 165.54627 32.869249 783.14112 2013 ERCOT ERCOT2013 Comb. Cycle Gas 744.02426 128.55626 50.183614 34.417907 504.7664 2013 ERCOT ERCOT2013 Turbine 678.308 224.627 61.4495 22.4544 458.206 2013 FRCC FRCC2013 Comb. Cycle Gas 2427.851 488.8877 170.0256 94.7621 1832.624 2013 FRCC FRCC2013 Turbine 378.036 164.306 40.0448 11.153 290.371 2013 MAAC MAAC2013 Comb. Cycle Gas 938.8135 254.0359 66.88819 39.17282 703.2388 2013 MAAC MAAC2013 Turbine 264.93224 355.03933 48.82604 8.112252 225.92196 2013 MAIN MAIN2013 Comb. Cycle Gas 236.5932 76.6501 19.00838 11.16228 177.022 2013 MAIN MAIN2013 Turbine 520.84586 771.21783 103.499401 19.7730096 446.90765 2013 MAPP MAPP2013 Comb. Cycle Gas 157.663 61.864 15.2397 7.83899 113.051 2013 MAPP MAPP2013 Turbine 304.19711 300.3516 41.68576 12.978853 263.77888 2013 NPCC NPCC2013 Comb. Cycle Gas 1583.5156 304.89765 88.65649 60.80404 1178.8539 2013 NPCC NPCC2013 Turbine 8.86465 22.0982 2.509426 0.2066942 6.90064 2013 SERC SERC2013 Comb. Cycle Gas 4623.3845 1261.9066 354.57951 219.08437 3543.9421 2013 SERC SERC2013 Turbine 971.6562 1283.69697 198.848396 31.616568 777.25879 2013 SPP SPP2013 Comb. Cycle Gas 698.964 168.1429 49.5919 34.012 501.801 2013 SPP SPP2013 Turbine 164.43566 138.40763 22.09409 6.166915 129.01954 2013 WSCC WSCC2013 Comb. Cycle Gas 4903.7428 961.2314 323.65124 220.95625 3421.4334 2013 WSCC WSCC2013 Turbine 9.45326 35.2869 4.0234 0.334672 8.38748 2013 Total 2013 Total 20532.91864 8206.98617 1826.351707 867.8763698 15366.62566 March 10, 2003 Page 14 of 18 dwcgi 20798 1049815895 87640000. xls  4d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 J K L Capital Costs ( MM$) Capacity ( MW) Total Generation ( GWh)

709.332 13469.5153 5975.499 3.57212 47.4971 376.0972 778.368 12091.9054 73099.5961 96.0459 1266.2279 7246.9956 233.8225 4520.5801 2733.5381 84.2116 1091.6446 6482.9876 399.3945 7584.1145 3310.8982 92.5688 1199.9793 7126.3584 174.87 3320.6189 1846.6087 295.9415 3418.9591 27072.3882 1246.809 17911.8021 125854.1552 762.9842 16285.8915 6782.5557 117.492 1517.9794 12019.8358 9.20172 174.2882 129.2759 874.7704 11050.6896 87502.8188 5879.38424 94951.693 367559.6085 901.5388 17064.4429 16975.223 84.60402 1177.2705 9321.9967 184.437 3529.2244 14628.9415 811.266 12627.6679 78771.215 87.704 1965.4875 4379.0621 337.4884 4602.4948 30507.2975 270.4673 5216.4289 4646.9093 84.2116 1091.6446 6482.9876 539.6775 10207.893 10637.0757 92.5688 1199.9793 7126.3584 243.5787 4605.71 8014.874 497.55836 5861.0245 46409.4268 1450.2056 21040.2061 147947.0661 1071.689 22524.1863 22290.1612 224.53 2968.5978 23506.2859 41.22379 770.2251 2285.4581 1402.9364 17902.7237 141759.3692 8325.68527 134355.2073 575689.7081 1214.5557 22967.2206 32869.249 283.58012 3951.4684 31288.9634 360.826 6904.4357 22454.4437 857.9448 13387.8608 86147.3251 200.773 4499.4202 11153.0325 385.5619 5266.7875 35611.7125 364.93267 7072.7569 8112.2505 114.0492 1496.7217 10147.5284 768.75839 14778.206 19773.0423 92.5688 1199.9793 7126.3584 306.8679 5825.9363 12978.9007 590.009 6980.8251 55276.3576 21.34614 399.9481 206.6938 1903.2177 27919.6605 199167.5752 1334.00368 28156.2239 31616.551 293.616 3904.874 30920.0139 146.62904 2851.3013 6166.9121 1987.7081 25484.3551 200869.3582 31.9946 659.5731 334.6719 11258.94274 183707.5545 802220.9402 March 10, 2003 Page 15 of 18 dwcgi 20798 1049815895 87640000. xls  4d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 A B C D E F G H I 2020 ECAR ECAR2020 Comb. Cycle Gas 723.237 254.62 61.1583 31.9786 528.243 2020 ECAR ECAR2020 Turbine 1432.24907 1873.5384 257.65301 51.581215 1216.05841 2020 ERCOT ERCOT2020 Comb. Cycle Gas 1942.85369 447.85583 137.494214 94.298807 1382.6174 2020 ERCOT ERCOT2020 Turbine 1119.53 594.926 127.996 38.909 795.975 2020 FRCC FRCC2020 Comb. Cycle Gas 2192.691 573.2965 170.0256 88.5153 1717.45 2020 FRCC FRCC2020 Turbine 494.7826 318.4432 65.0208 15.019024 394.20763 2020 FRCC FRCC2020 IGCC 951.831 203.226 152.341 40.0963 242.049 2020 MAAC MAAC2020 Comb. Cycle Gas 1201.0825 329.74111 87.62273 50.292938 885.1242 2020 MAAC MAAC2020 Turbine 375.9531 492.27423 67.17865 11.4503 315.952 2020 MAAC MAAC2020 IGCC 506.317 128.38 80.4136 21.165 83.5966 2020 MAIN MAIN2020 Comb. Cycle Gas 413.862 135.8788 32.9197 19.74515 310.341 2020 MAIN MAIN2020 Turbine 655.35182 1006.74052 132.232606 25.3512421 573.61479 2020 MAPP MAPP2020 Comb. Cycle Gas 329.292 121.0979 29.5671 16.77603 236.425 2020 MAPP MAPP2020 Turbine 333.1208 374.6296 50.164 14.22072 288.7969 2020 NPCC NPCC2020 Comb. Cycle Gas 2418.7549 514.6686 137.22371 94.11329 1818.8705 2020 NPCC NPCC2020 Turbine 32.0782 69.31665 8.01937 0.825276 25.85128 2020 SERC SERC2020 Comb. Cycle Gas 7823.6719 2176.2983 600.78927 367.59885 5974.179 2020 SERC SERC2020 Turbine 1302.785053 1839.27618 278.868512 43.1772026 1048.282406 2020 SPP SPP2020 Comb. Cycle Gas 1150.5523 313.0373 84.00627 57.31569 840.614 2020 SPP SPP2020 Turbine 422.29408 340.76396 54.80257 16.469365 337.57554 2020 WSCC WSCC2020 Comb. Cycle Gas 7346.7133 2032.471 514.68692 352.38702 5443.7207 2020 WSCC WSCC2020 Turbine 91.896045 362.978747 41.692312 3.5263465 80.975522 2020 Total 2020 Total 33260.89936 14503.45883 3171.876244 1454.812666 24540.51988 March 10, 2003 Page 16 of 18 dwcgi 20798 1049815895 87640000. xls  4d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 J K L 354.713 4815.612 29071.4295 1839.9986 35472.5001 51581.2537 776.67212 10826.3195 85726.1858 751.58 14381.5481 38909.023 857.9448 13387.8608 80468.3951 329.6567 7436.4221 15019.0487 720.571 4745.8131 36451.1564 503.714 6899.4263 45720.8331 488.90187 9605.8473 11450.2979 448.219 2505.095 19240.8781 194.7336 2592.0998 17950.1776 975.58372 19029.5498 25351.2702 175.6665 2328.1199 15250.9357 371.974 7202.2978 14220.72 905.7343 10805.0197 85557.5273 66.6989 1237.6146 825.2754 3190.287 47306.2055 334180.7575 1852.95227 39906.8875 43177.2014 493.5661 6614.6645 52105.2302 354.54162 6839.8534 16469.3685 3156.9264 40526.5386 320352.1168 328.500231 6745.5844 3526.3412 19139.13573 301210.8798 1342605.423 March 10, 2003 Page 17 of 18 dwcgi 20798 1049815895 87640000. xls  4d Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 A B C D E F G H I J K L M N Electric Power PPI obtained from the BLS website http:// stats. bls. gov/ ppihome. htm series ID WPU0543 ( 2/ 3/ 2003)

Annual Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Elect PPI 1999 128.9 126.1 125.5 125.5 125.2 127.4 131.6 133.9 133.9 134.1 129.5 127.5 126.5 Elect PPI 2000 131.5 126.8 126.7 126.7 126.8 128.6 133.6 136.2 137.4 137.8 134.1 130.9 132.7 Elect PPI 2001 141.1 136.4 136.4 136.5 135.1 136.2 148.4 149.5 148.9 148.2 143.8 137.3 136.9 Elect PPI 2002 139.9 136.3 135.4 135.7 135.4 137.9 143.6 144.9 145 145.7 139.6 140.1 139.6 P : Preliminary.

March 10, 2003 Page 18 of 18 dwcgi 20798 1049815895 87640000. xls  Rates


  SEQ CHAPTER \h \r 1 SIP SUBMITTAL COMPLETENESS CRITERIA CHECKLIST

(in accordance with 40 CFR Part 51 - App. V)

 SIP Submitted by:	Delaware Department of Natural Resources and
Environmental Control

 Date Submitted:	May 2, 2007

 Subject:	Regulation No. 1113 – Open Burning

 Completeness Review

 Completed by:	Rose Quinto

 Date Completed:     May 17, 2007

Administrative Materials

        SEQ CHAPTER \h \r 1 ACCEPTABLE

  SEQ CHAPTER \h \r 1 EPA REQUIREMENT	STATE SUBMITTAL 	(X)

1. A formal letter of submittal from the Governor or his designee,
requesting EPA approval of the plan or revision thereof.	1.  Letter
dated May 2, 2007 from John A. Hughes, Secretary, Delaware Department of
Natural Resources & Environmental Control to Donald S. Welsh, Regional
Administrator.	 X

2. Evidence that the State has adopted the plan in the State code or
body of regulations; or issued the permit, order, consent agreement in
final form.  That evidence shall include the date of adoption or final
issuance as well as the effective date of the plan, if different from
the adoption/issuance date.	2.  The Order has an issuance date of March
15, 2007, effective date April 15, 2007.  The Order was signed by the
Secretary on March 15, 2007.	 X

3. Evidence that the State has the necessary legal authority under State
law to adopt and implement the plan.	3. Delaware has legal authority to
adopt this RACT certification under Title 7, Delaware Code, Chapter 60.
X

4. A copy of actual regulation, or document submitted for approval and
incorporation by reference into the plan, including indication of the
changes made to the existing approved plan, where applicable.  The
submittal shall be a copy of the official State regulation/document
signed, stamped, dated by the appropriate State official indicating that
it is fully enforceable by the State.  The effective date of the
regulation/document shall, whenever possible, be indicated in the
document itself.	4.  Document entitled, “Regulation 1113 – Open
Burning”, effective April 11, 2007.  Cover letter dated May 2, 2007,
transmitting the document has an effective date of April 11, 2007.

 X

5. Evidence that the State followed all of the procedural requirements
of the State's laws and constitution in conducting and completing the
adoption/issuance of the plan.	5.  Secretary’s Order No. 2007-A-0010
dated March 15, 2007.  Cover letter transmitting the SIP revision dated
May 2, 2007.  Copy of public hearing notices.  Certification of public
hearing notice.	 X

6. Evidence that public notice was given of the proposed change
consistent with procedures approved by EPA, including the date of
publication of such notice.	6.  Affidavit of publications dated December
27, 2006 from two local newspapers: The News Journal and Independent
Newspapers, Inc.	 X

7. Certification that public hearings were held in accordance with the
information provided in the public notice and the State's laws and
constitution, if applicable.	7.  Certification dated April 3, 2007
signed by the Administrator, Air Quality Management.  Public hearing was
held on January 31, 2007.	 X

8. Compilation of public comments and the State's response thereto.	8.
Hearing Officer’s Report dated March 13, 2007.	 X

  SEQ CHAPTER \h \r 1 Technical Materials

  SEQ CHAPTER \h \r 1 EPA REQUIREMENT	STATE SUBMITTAL 	(X)

  SEQ CHAPTER \h \r 1 1. Identification of all regulated pollutants
affected by the plan.	1.  Control of VOC from open burning activities.
X

2. Identification of the locations of affected sources including the EPA
attainment/nonattainment designation of the locations and the status of
the attainment plan for the affected area(s).	2.  State of Delaware.

  X

3. Quantification of the changes in plan allowable emissions from the
affected sources; estimates of changes in current actual emissions from
affected sources or, where appropriate, quantification of changes in
actual emissions from affected sources through calculations of the
differences between certain baseline levels and allowable emissions
anticipated as a result of the revision.	3.  Not applicable.  The plan
established requirements to control VOC from open burning activities.
X

4. The State's demonstration that the national ambient air quality
standards, prevention of significant deterioration increments,
reasonable further progress demonstration, and visibility, as
applicable, are protected if the plan is approved and implemented. 	4.
The SIP revision consists of regulation amendments to expand the
geographic applicability of the control measures to implement open
burning seasonal restrictions as part of plans to reduce and maintain
VOC emissions in Delaware.  	  X

5. Modeling information required to support the proposed revision,
including input data, output data, models used,  ambient monitoring data
used, meteorological data used, justification for use of offsite data
(where used), modes of models used, assumptions, and other information
relevant to the determination of adequacy of the modeling analysis.	5.
Not applicable.  No modeling demonstration was required to support the
required revision.  No additional modeling beyond UAM attainment
modeling is needed.	  X

6. Evidence, where necessary, that emission limitations are based on
continuous emission reduction technology.	6. Not applicable.  The plan
established requirements to control VOC emissions from open burning
activities.	  X

7. Evidence that the plan contains emission limitations, work practice
standards and recordkeeping/reporting requirements, where necessary, to
ensure emission levels.	7. Not applicable.  The plan established
requirements to control VOC emissions from open burning activities.	  X

8. Compliance/enforcement strategies, including how compliance will be
determined in practice.	8.  Not applicable.  The plan established
requirements to control VOC emissions from open burning activities.	  X

9. Special economic and technological justifications required by any
applicable EPA policies. (If a policy is not appropriate, explain why.)
9.  No special justifications are required.	  X

10. A Section 107 request must be accompanied by a maintenance plan
demonstrating maintenance to the relevant NAAQS for at least 10 years
after redesignation.	10.  Not applicable because this is not a section
107 request.	  X


[Federal Register: February 27, 2006 (Volume 71, Number 38)]
[Notices]
[Page 9820]
[DOCID:fr27fe06-50]

-----------------------------------------------------------------------

DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Project No. 2183-035--Oklahoma]

Grand River Dam Authority; Notice of Availability of
Environmental Assessment

February 17, 2006.
    In accordance with the National Environmental Policy Act of 1969,
as amended, and Federal Energy Regulatory Commission (FERC or
Commission) regulations (Order No. 486, 52 FR 47879), the Office of
Energy Projects has reviewed the application for a new license for the
Markham Ferry Project (FERC No. 2183-035), located on the Grand River
in Mayes County, Oklahoma, and has prepared an environmental assessment
(EA). The EA contains the staff's analysis of the potential
environmental effects of relicensing the project and concludes that
issuing a new license, with appropriate environmental measures, would
not constitute a major Federal action that would significantly affect
the quality of the human environment.
    A copy of the EA is on file with the Commission and is available
for public inspection. The EA also may be viewed on the Commission's
Web site at http://www.ferc.gov using the ``eLibrary'' link. Enter the

docket number excluding the last three digits in the docket number
field to access documents. For assistance, contact FERC Online Support
at<EMAIL_ADDRESS>or toll-free at 1-866-208-3676, or for
TTY,<PHONE_NUMBER>.
    Any comments on the EA should be filed within 30 days of the date
of this notice and should be addressed to the Secretary, Federal Energy
Regulatory Commission, 888 First Street, NE., Room 1-A, Washington, DC
20426. Please reference ``Markham Ferry Project, FERC Project No. 2183-
035'' on all comments. The Commission strongly encourages electronic
filings. See 18 CFR 385.2001(a)(1)(iii) and the instructions on the
Commission's Web site under the ``eFiling'' link. For further
information, contact John Ramer at<PHONE_NUMBER>.

Magalie R. Salas,
Secretary.
 [FR Doc. E6-2706 Filed 2-24-06; 8:45 am]

BILLING CODE 6717-01-P


[Federal Register Volume 85, Number 123 (Thursday, June 25, 2020)]
[Notices]
[Pages 38136-38137]
[FR Doc No: 2020-13717]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Docket No. IC20-12-000]

Commission Information Collection Activities (FERC-73); Comment
Request; Extension

AGENCY: Federal Energy Regulatory Commission, Department of Energy.

ACTION: Notice of information collection and request for comments.

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SUMMARY: In compliance with the requirements of the Paperwork Reduction
Act of 1995, the Federal Energy Regulatory Commission (Commission or
FERC) is soliciting public comment on the currently approved
information collection FERC-73 (Oil Pipeline Service Life Data) and
submitting the information collection to the Office of Management and
Budget (OMB) for review. Any interested person may file comments
directly with OMB and should address a copy of those comments to the
Commission as explained below.

DATES: Comments on the collection of information are due July 27, 2020.

ADDRESSES: Send written comments on FERC-73 to OMB through
www.reginfo.gov/public/do/PRAMain, Attention: Federal Energy Regulatory
Commission Desk Officer. Please identify the OMB control number (1902-
0019) in the subject line. Your comments should be sent within 30 days
of publication of this notice in the Federal Register.
    Please submit copies of your comments to the Commission (identified
by Docket No. IC20-12-000) by either of the following methods:
     eFiling at Commission's Website: http://www.ferc.gov/docs-filing/efiling.asp.
     Mail/Express Services: Persons unable to file
electronically may mail similar pleadings to the Federal Energy
Regulatory Commission, 888 First Street NE, Washington, DC 20426. Hand
delivered submissions in docketed proceedings should be delivered to
Health and Human Services, 12225 Wilkins Avenue, Rockville, Maryland
20852.
    Instructions:
    OMB submissions must be formatted and filed in accordance with
submission guidelines at www.reginfo.gov/public/do/PRAMain; Using the
search function under the ``Currently Under Review field,'' select
Federal Energy Regulatory Commission; click ``submit'' and select
``comment'' to the right of the subject collection.
    FERC submissions must be formatted and filed in accordance with
submission guidelines at: http://www.ferc.gov/help/submission-guide.asp. For user assistance, contact FERC Online Support by email at
<EMAIL_ADDRESS>or by phone at:<PHONE_NUMBER> (toll-free).
    Docket: Users interested in receiving automatic notification of
activity in this docket or in viewing/downloading comments and
issuances in this docket may do so at http://www.ferc.gov/docs-filing/docs-filing.asp.

FOR FURTHER INFORMATION CONTACT: Ellen Brown may be reached by email at
<EMAIL_ADDRESS>and telephone at<PHONE_NUMBER>.

SUPPLEMENTARY INFORMATION:
    Title: FERC Form No. 73, Oil Pipeline Service Life Data.
    OMB Control No.: 1902-0019.
    Type of Request: Three-year extension of the FERC Form No. 73
information collection requirements with no changes to the current
reporting requirements.
    Abstract: The Commission collects FERC Form No. 73 information as
part of its authority under the Interstate Commerce Act, 49 U.S.C.
60501, et al. FERC Form No. 73 contains necessary information for the
review of oil pipeline companies' proposed depreciation rates, as
regulated entities are required to provide service life data
illustrating the remaining physical life of an oil pipeline's
properties, in order to calculate the company's cost of service and its
transportation rates to access customers. The Commission implements
these filing reviews under the purview of 18 CFR part 357.3, FERC Form
No. 73, Oil Pipeline Data for Depreciation Analysis, and 18 CFR part
347. Parts 357.3 and 347 require an oil pipeline company to submit
information under FERC Form No. 73 when: (1) Requesting approval for
new or changed depreciation rates of an oil pipeline; or (2) being
directed by the Commission to file the service life data during an
investigation of its book depreciation rates.
    On April 16, 2020, the Commission published a Notice in the Federal
Register in Docket No. IC20-12-000 requesting public comments.\1\ The
Commission received no public comments.
---------------------------------------------------------------------------

    \1\ 85 FR 21229.
    \2\ ``Burden'' is the total time, effort, or financial resources
expended by persons to generate, maintain, retain, or disclose or
provide information to or for a Federal agency. For further
explanation of what is included in the information collection
burden, refer to 5 CFR 1320.3.
---------------------------------------------------------------------------

    Type of Respondent: Oil pipeline companies.
    Estimate of Annual Burden: \2\ The Commission estimates the annual
public reporting burden for the information collection as below:
---------------------------------------------------------------------------

    \3\ The Commission staff estimates the average cost in salary
and benefits for the average respondent based on the Commission's
2019 average cost for salary plus benefits at $80/hour.
    \4\ The total number of responses entailing the submittal of a
depreciation study in the past three years was 96. The average
response from those three years is 96/3 years = 32 responses per
year.

                                                    FERC Form No. 73, Oil Pipeline Service Life Data
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                   Annual  number                                                                             Cost per
                                      Number of    of  responses    Total number  of   Average burden and cost   Total annual  burden and    respondent
                                     respondents   per respondent      responses          per  response \3\         total  annual cost           ($)
                                            (1)              (2)    (1) * (2) = (3)   (4).....................  (3) * (4) = (5)...........    (5) / (1)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Oil Pipelines Undergoing                     32                1             32 \4\   40 hrs.; $3,200.........  1,280 hrs.; $102,400......       $3,200
 Investigation or Review.
--------------------------------------------------------------------------------------------------------------------------------------------------------

    Comments: Comments are invited on: (1) Whether the collection of
information is necessary for the proper performance of the functions of
the Commission, including whether the information will have practical
utility; (2) the accuracy of the agency's estimate of the burden and
cost of the collection of information, including the validity of the
methodology and assumptions used;

(3) ways to enhance the quality, utility and clarity of the information
collection; and (4) ways to minimize the burden of the collection of
information on those who are to respond, including the use of automated
collection techniques or other forms of information technology.

    Dated: June 19, 2020.
Kimberly D. Bose,
Secretary.
[FR Doc. 2020-13717 Filed 6-24-20; 8:45 am]
BILLING CODE 6717-01-P


[Federal Register Volume 78, Number 62 (Monday, April 1, 2013)]
[Notices]
[Page 19477]
[FR Doc No: 2013-07491]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

Combined Notice of Filings 1

    Take notice that the Commission received the following electric
rate filings:

    Docket Numbers: ER13-630-000.
    Applicants: Arizona Public Service Company.
    Description: Supplement to December 28, 2012 Arizona Public Service
Company Triennial Market Power Update.
    Filed Date: 3/19/13.
    Accession Number: 20130319-5124.
    Comments Due: 5 p.m. ET 4/9/13.

    Docket Numbers: ER13-1137-000.
    Applicants: Midwest Independent Transmission System Operator, Inc.
    Description: 03-20-2013 Module D Clarification to be effective 3/
26/2013.
    Filed Date: 3/20/13.
    Accession Number: 20130320-5090.
    Comments Due: 5 p.m. ET 4/10/13.

    Docket Numbers: ER13-1138-000.
    Applicants: Duke Energy Indiana, Inc.
    Description: 2013 Annual Reconciliation Filing RS 253 to be
effective 7/1/2012.
    Filed Date: 3/21/13.
    Accession Number: 20130321-5014.
    Comments Due: 5 p.m. ET 4/11/13.

    Docket Numbers: ER13-1139-000.
    Applicants: Imperial Valley Solar 1, LLC.
    Description: Application for Market-Based Rate Authority to be
effective 3/22/2013.
    Filed Date: 3/21/13.
    Accession Number: 20130321-5027.
    Comments Due: 5 p.m. ET 4/11/13.

    Docket Numbers: ER13-1140-000.
    Applicants: Southern California Edison Company.
    Description: Letter Agreement NRG Solar Alpine II Project to be
effective 3/11/2013.
    Filed Date: 3/21/13.
    Accession Number: 20130321-5042.
    Comments Due: 5 p.m. ET 4/11/13.

    The filings are accessible in the Commission's eLibrary system by
clicking on the links or querying the docket number.
    Any person desiring to intervene or protest in any of the above
proceedings must file in accordance with Rules 211 and 214 of the
Commission's Regulations (18 CFR 385.211 and 385.214) on or before 5:00
p.m. Eastern time on the specified comment date. Protests may be
considered, but intervention is necessary to become a party to the
proceeding.
    eFiling is encouraged. More detailed information relating to filing
requirements, interventions, protests, service, and qualifying
facilities filings can be found at: http://www.ferc.gov/docs-filing/efiling/filing-req.pdf. For other information, call<PHONE_NUMBER>
(toll free). For TTY, call<PHONE_NUMBER>.

    Dated: March 21, 2013.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
[FR Doc. 2013-07491 Filed 3-29-13; 8:45 am]
BILLING CODE 6717-01-P


[Federal Register Volume 80, Number 52 (Wednesday, March 18, 2015)]
[Notices]
[Pages 14193-14195]
[FR Doc No: 2015-06091]

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SECURITIES AND EXCHANGE COMMISSION

[Release No. 34-74487; File No. SR-CHX-2015-02]

Self-Regulatory Organizations; Chicago Stock Exchange, Inc.;
Notice of Filing and Immediate Effectiveness of a Proposed Rule Change
Concerning the CHX Routing Services

March 12, 2015.
    Pursuant to Section 19(b)(1) of the Securities Exchange Act of 1934
(``Act''),\1\ and Rule 19b-4 \2\ thereunder, notice is hereby given
that on March 4, 2015, the Chicago Stock Exchange, Inc. (``CHX'' or the
``Exchange'') filed with the Securities and Exchange Commission
(``Commission'') the proposed rule change as described in Items I and
II below, which Items have been prepared by the Exchange. The

Commission is publishing this notice to solicit comments on the
proposed rule change from interested persons.
---------------------------------------------------------------------------

    \1\ 15 U.S.C. 78s(b)(1).
    \2\ 17 CFR 240.19b-4.
---------------------------------------------------------------------------

I. Self-Regulatory Organization's Statement of the Terms of Substance
of the Proposed Rule Change

    CHX proposes to clarify for Participants and non-Participants the
Exchange's smart versus direct routing protocol.\3\ On September 8,
2014, the Exchange filed a proposed rule change adopting, among other
things, the CHX Routing Services, which is a Regulation NMS compliant
outbound order routing service that is not yet operational (``the
initial rule filing''), with the Securities and Exchange Commission
(the ``Commission'').\4\ The Exchange now submits this supplemental
filing. The Exchange has designated this proposed rule change as non-
controversial and provided the Commission with the notice required by
Rule 19b-4(f)(6)(iii) under the Act.\5\
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    \3\ CHX Article 1, Rule 1(s) defines ``Participant,'' in
pertinent part, as ``any Participant Firm that holds a valid Trading
Permit and any person associated with a Participant Firm who is
registered with the Exchange under Articles 16 and 17 as a Market
Maker Trader or Institutional Broker Representative, respectively. A
Participant shall be considered a `member' of the Exchange for
purposes of the Exchange Act.''
    \4\ See Exchange Act Release No. 73150 (September 19, 2014), 79
FR 57603 (September 25, 2014) (SR-CHX-2014-15).
    \5\ 17 CFR 240.19b-4(f)(6)(iii).
---------------------------------------------------------------------------

    The text of this proposed rule change is available on the
Exchange's Web site at (www.chx.com) and in the Commission's Public
Reference Room.

II. Self-Regulatory Organization's Statement of the Purpose of, and
Statutory Basis for, the Proposed Rule Change

    In its filing with the Commission, the CHX included statements
concerning the purpose of and basis for the proposed rule changes and
discussed any comments it received on the proposed rule change. The
text of these statements may be examined at the places specified in
Item IV below. The CHX has prepared summaries, set forth in sections A,
B and C below, of the most significant aspects of such statements.

A. Self-Regulatory Organization's Statement of the Purpose of, and
Statutory Basis for, the Proposed Rule Change

1. Purpose
    The Exchange proposes to clarify for Participants and non-
Participants the Exchange's smart versus direct routing protocol
related to the CHX Routing Services. As described in the initial rule
filing, upon the triggering of a Routing Event,\6\ the Exchange will
route away Routable Orders,\7\ or portions thereof, through CHXBD, LLC,
which is an affiliated routing broker that will operate as a facility
of the Exchange, which would then forward orders to a third-party
routing broker for routing to the ultimate routing destination. All
orders routed to the third-party routing broker will include
instructions for the third-party routing broker to either direct route
the order to a specific destination or to smart route the order,
utilizing the third-party routing broker's routing technology, pursuant
to a routing table provided and maintained by the Exchange.
---------------------------------------------------------------------------

    \6\ CHX Article 19, Rule 3(a), which is not yet operative,
details Routing Events.
    \7\ CHX Article 1, Rule 1(oo), which is not yet operative,
defines ``Routable Order'' as ``any incoming limit order, as defined
under Article 1, Rule 2(a)(1), of any size, not marked by any order
modifiers or related terms listed under Article 1, Rule 2 that
prohibit the routing of the order to another Trading Center.''
---------------------------------------------------------------------------

    The Exchange would like to clarify the smart versus direct routing
protocol and to propose special handling of Routable Orders in relation
to Protected Quotations \8\ displayed on the Alternative Display
Facility (``ADF'') operated by the Financial Industry Regulatory
Authority (``FINRA'').\9\ The Exchange does not propose to amend any
CHX Rules nor substantively modify the CHX Routing Services in any
other way.
---------------------------------------------------------------------------

    \8\ See 17 CFR 242.600(b)(58).
    \9\ See FINRA Rule 6210.
---------------------------------------------------------------------------

    Under footnote 50 of the initial rule filing,\10\ the Exchange
utilized the term ``routed order'' to describe smart versus direct
routing. For clarity, ``routed order'' describes the portion of a
Routable Order that is to be routed to satisfy Protected Quotations of
external markets at a single price point. Thus, by replacing the term
``routed order'' with the more descriptive phrase ``the portion of a
Routable Order that is to be routed'' and adding references to ``a
single price point,'' the meaning of footnote 50 becomes clearer. The
revised footnote 50 would read as follows:
---------------------------------------------------------------------------

    \10\ Footnote 50 of the initial rule filing provides:
    Where the routed order is smaller than the aggregate size of two
or more contra-side Protected Quotations that could be satisfied,
the Exchange will rely on the third-party routing broker to utilize
its smart-routing technology to route the order pursuant to a
routing table provided by the Exchange. Thus, the relevant snapshot
of the NBBO for Regulation NMS purposes will be taken by the third-
party routing broker and the third-party routing broker would route
orders IOC and ISO. However, where the routed order is smaller than
the size of one Protected Quotation that could be satisfied or is
the same size as the aggregate size of one or more contra-side
Protected Quotations that could be satisfied, the Exchange will
direct the third-party routing broker to route orders to specific
routing destinations. Thus, the relevant snapshot of the NBBO will
be taken by the Exchange and the Exchange would mark the directed
orders IOC and ISO. See supra note 4.

    Where the portion of a Routable Order that is to be routed at a
certain price point is smaller than the aggregate size of two or more
contra-side Protected Quotations that could be satisfied at a single
price point, the Exchange will rely on the third-party routing broker
to utilize its smart-routing technology to route the order pursuant to
a routing table provided by the Exchange. Thus, the relevant snapshot
of the NBBO for Regulation NMS purposes will be taken by the third-
party routing broker and the third-party routing broker would route
orders IOC and ISO. However, where the portion of a Routable Order that
is to be routed is smaller than the size of one Protected Quotation
that could be satisfied or is the same size as the aggregate size of
one or more contra-side Protected Quotations that could be satisfied at
a single price point, the Exchange will direct the third-party routing
broker to route orders to specific routing destinations. Thus, the
relevant snapshot of the NBBO will be taken by the Exchange and the
Exchange would mark the directed orders IOC and ISO.
    The Exchange also proposes to adopt special routing handling for
Protected Quotations displayed on the ADF, as an exception to the
aforementioned price point by price point determination to either smart
or direct route an order. Specifically, upon the triggering of any
Routing Event based on a Protected Quotation displayed on the ADF, the
Exchange will route away the entire remaining balance of the Routable
Order for smart routing by a third-party routing broker. The Exchange
submits that this special handling is the most efficient way for the
Exchange to meet its Regulation NMS obligations regarding Protected
Quotation(s) displayed on the ADF and is consistent with the routing-
related rules adopted pursuant to the initial rule filing.\11\
Unexecuted remainders of smart routed orders returned to the Matching
System from the third-party routing broker will be handled pursuant to
Article 20, Rule 8(b)(7), as described under the initial rule
filing.\12\
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    \11\ In the event the Exchange decides to modify its smart
versus direct routing protocol, the Exchange will submit a proposed
rule filing to that effect, pursuant to Rule 19b-4 under the Act.
    \12\ See CHX Article 20, Rule 8(b)(7), which is not yet
operative.

---------------------------------------------------------------------------

2. Statutory Basis
    The Exchange believes that the proposed clarification of the smart
versus direct routing protocol described in the initial rule filing and
special handling of the Protected Quotations displayed on the ADF is
consistent with Section 6(b) of the Act in general \13\ and furthers
the objectives of Sections 6(b)(1) \14\ and 6(b)(5) in particular.\15\
Specifically, the Exchange believes that the proposed filing would
further enable the Exchange to be so organized as to have the capacity
to be able to carry out the purposes of the Act and to comply, and to
enforce compliance by its Participants and persons associated with its
Participants, with the provisions of the Act, the rules and regulations
thereunder, and the rules of the Exchange, by clarifying the smart
versus direct routing protocol for the benefit of Participants and non-
Participants, in furtherance of the objectives of Section 6(b)(1). For
similar reasons, the Exchange believes that the proposal is also
designed to prevent fraudulent and manipulative acts and practices, to
promote just and equitable principles of trade, to foster cooperation
and coordination with persons engaged in facilitating transaction in
securities, to remove impediments to, and perfect the mechanisms of, a
free and open market and, in general, by protecting investors and the
public interest, in furtherance of the objectives of Section 6(b)(5).
---------------------------------------------------------------------------

    \13\ 15 U.S.C. 78f(b).
    \14\ 15 U.S.C. 78f(b)(1).
    \15\ 15 U.S.C. 78f(b)(5).
---------------------------------------------------------------------------

B. Self-Regulatory Organization's Statement on Burden on Competition

    The Exchange does not believe that the proposed rule change will
impose any burden on competition that is not necessary or appropriate
in furtherance of the purposes of the Act. Given that the proposed
changes promote clarity as to existing rules and does not amend any
rules, the Exchange believes that any burden on competition is
necessary and appropriate as clarity of the Exchange's rules further
the purposes of the Act.

C. Self-Regulatory Organization's Statement on Comments on the Proposed
Rule Change Received From Members, Participants, or Others

    No written comments were either solicited or received.

III. Date of Effectiveness of the Proposed Rule Change and Timing for
Commission Action

    The foregoing rule change has been filed by the Exchange as a
``non-controversial'' rule change pursuant to Section 19(b)(3)(A)(i) of
the Act \16\ and Rule 19b-4(f)(6).\17\ Because the foregoing proposed
rule change does not: (i) Significantly affect the protection of
investors or the public interest; (ii) impose any significant burden on
competition; and (iii) become operative for 30 days from the date on
which it was filed, or such shorter time as the Commission may
designate, it has become effective pursuant to Section 19(b)(3)(A) of
the Act \18\ and Rule 19b-4(f)(6).\19\
---------------------------------------------------------------------------

    \16\ 15 U.S.C. 78s(b)(3)(A)(i).
    \17\ 17 CFR 240.19b-4(f)(6).
    \18\ 15 U.S.C. 78s(b)(3)(a)(ii).
    \19\ 17 CFR 240.19b-4(f)(6). In addition, Rule 19b-4(f)(6)
requires a self-regulatory organization to give the Commission
written notice of its intent to file the proposed rule change at
least five business days prior to the date of filing of the proposed
rule change, or such shorter time as designated by the Commission.
The Exchange has satisfied this requirement.
---------------------------------------------------------------------------

    A proposed rule change filed under Rule 19b-4(f)(6) normally does
not become operative prior to 30 days after the date of the filing.
However, pursuant to Rule 19b-4(f)(6)(iii), the Commission may
designate a shorter time if such action is consistent with the
protection of investors and the public interest. The Exchange asserts
that waiver of this requirement would allow the Exchange to clarify its
initial rule filing prior to the CHX Routing Services becoming
operational, and notes that the Exchange provides these services in a
highly competitive market in which market participants may avail
themselves of a wide variety of options offered by self-regulatory
organizations, alternative trading systems and other broker-dealers.
The Commission believes that waiving the 30-day operative delay is
consistent with the protection of investors and the public interest
because it will allow the Exchange to clarify its rules in a timely
manner and thereby avoid potential confusion. Therefore, the Commission
hereby waives the 30-day operative delay and designates the proposed
rule change to be operative upon filing with the Commission.\20\
---------------------------------------------------------------------------

    \20\ For purposes only of waiving the 30-day operative delay,
the Commission has considered the proposed rule's impact on
efficiency, competition, and capital formation. See 15 U.S.C.
78c(f).
---------------------------------------------------------------------------

IV. Solicitation of Comments

    Interested persons are invited to submit written data, views and
arguments concerning the foregoing, including whether the proposal is
consistent with the Act. Comments may be submitted by any of the
following methods:

Electronic Comments

     Use the Commission's Internet comment form (http://www.sec.gov/rules/sro.shtml); or
     Send an email to<EMAIL_ADDRESS>Please include
File No. SR-CHX-2015-02 on the subject line.

Paper Comments

     Send paper comments in triplicate to Brent J. Fields,
Secretary, Securities and Exchange Commission, 100 F Street NE.,
Washington, DC 20549.

All submissions should refer to File No. SR-CHX-2015-02. This file
number should be included on the subject line if email is used. To help
the Commission process and review your comments more efficiently,
please use only one method. The Commission will post all comments on
the Commission's Internet Web site (http://www.sec.gov/rules/sro.shtml). Copies of the submission, all subsequent amendments, all
written statements with respect to the proposed rule change that are
filed with the Commission, and all written communications relating to
the proposed rule changes between the Commission and any person, other
than those that may be withheld from the public in accordance with the
provisions of 5 U.S.C. 552, will be available for Web site viewing and
printing in the Commission's Public Reference Room, 100 F Street NE.,
Washington, DC 20549 on official business days between the hours of
10:00 a.m. and 3:00 p.m. Copies of the filing also will be available
for inspection and copying at the principal office of the CHX. All
comments received will be posted without change; the Commission does
not edit personal identifying information from submissions. You should
submit only information that you wish to make available publicly. All
submissions should refer to File No. SR-CHX-2015-02 and should be
submitted on or before April 8, 2015.

    For the Commission, by the Division of Trading and Markets,
pursuant to delegated authority.\21\
Brent J. Fields,
Secretary.
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    \21\ 17 CFR 200.30-3(a)(12).
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[FR Doc. 2015-06091 Filed 3-17-15; 8:45 am]
BILLING CODE 8011-01-P