UNITED STATES ENVIRONMENTAL PROTECTION AGENCY REGION III 1650 Arch Street Philadelphia, Pennsylvania 19103 Date: May 17, 2006 Subject: Technical Support Document ( TSD) Revisions to Pennsylvania SIP Additional NOx Emission Reductions for the Philadelphia Trenton Wilmington One Hour Nonattainment Area and Remaining NOx SIP Call Requirements From: Marilyn Powers, Environmental Engineer Rose Quinto, Environmental Engineer Air Quality Planning Branch ( 3AP21)

To: File Reviewed by: ___________________________________ Makeba Morris, Chief Air Quality Planning Branch ( 3AP21)

I. INTRODUCTION On March 29, 2005, the Pennsylvania Department of Environmental Protection ( PADEP) submitted the following State Implementation Plan ( SIP) revisions:

A. To satisfy its commitments under the Commonwealth's approved SIP for the Philadelphia Trenton Wilmington one hour ozone nonattainment area ( Philadelphia Area), PADEP submitted additions to Chapter 121 ( definitions) and new Sections 129.201, 129.202, 129.203, and 129.204 ( Additional NOx Requirements) under Chapter 129.

Also included in this submission are requirements pertaining to zero emission renewable energy production within the five counties that comprise the Pennsylvania portion of the Philadelphia area. These are set forth in new Section 129.205 ( Zero Emission Renewable Energy Production Credit).

B. Chapter 145 ( Pennsylvania's NOx Budget Trading Program) is amended as follows: Section 145.42 is amended to assure accountability that zero emission renewable energy, where credited under Section 129.205, replaces NOx emissions from the sources identified in Sections 129.201 thru 129.203; and new Subchapter B ( Emissions of NOx From Stationary Internal Combustion Engines) and Subchapter C ( Emissions of NOx From Cement Manufacturing) are added to address the State's remaining NOx emission reduction obligations under the NOx SIP Call. 2 On February 6, 2006, PADEP submitted a letter providing supplementary information clarifying alternative calculation and recordkeeping procedures to determine actual emissions.

II. DISCUSSION OF REVISIONS A. Additional NOx Requirements under Chapter 129 ( Standards for Sources) to satisfy the Philadelphia SIP 1. Background Amendments to Sections 129.201, 129.202, 129.203, and 129.204 are additional NOx requirements submitted to satisfy the Commonwealth's commitments under the attainment demonstration EPA approved for the Philadelphia Area SIP. These requirements will apply in Bucks, Chester, Delaware, Montgomery and Philadelphia Counties ( five county Southeast Pennsylvania area), which comprise the Pennsylvania portion of the Philadelphia Area. New definitions associated with these additional NOx requirements are included as amendments to Chapter 121. These NOx requirements establish additional emission reductions needed to support the attainment demonstration for the Philadelphia Area ( 64 FR 70428, December 16, 1999 and 66 FR 54143, October 26, 2001). Sections 129.201, 129.202, and 129.203 are based on the model rule for additional NOx control measures developed by the Ozone Transport Commission ( OTC) intended to address ozone problems in the Ozone Transport Region ( OTR).

As part of its commitment to reduce NOx emissions in the Philadelphia Area, Pennsylvania established an incentive program that will promote new zero emission renewable energy production in this area. Section 129.205 is intended to spur development of clean energy projects within this five county area by allowing a source to take credit for generating zero emission renewable energy. To provide accountability for emissions that qualify to be credited, Section 142.42 ( Allocation of Allowances under the NOx Budget Trading Program) is revised to require retirement of NOx allowances.

2. Description of Revision Chapter 121 is amended to add the following new definitions:

1. MWH  megawatt hour. 2. ppmvd  parts per million dry volume. 3. Stationary internal combustion engine  An internal combustion engine of the reciprocating type that is either attached to a foundation at a facility or is designed to be capable of being carried or moved form one location to another and is not a mobile air contamination source. 4. Tradable renewable certificate  A certificate issued by a tradable renewable certificate issuing body in recognition of renewable energy generation. A certificate represents a specific amount of electricity or thermal power equivalent that was generated. 5. Tradable renewable certificate issuing body  An entity approved by PADEP to issue and account for tradable renewable certificates in accordance with a protocol consistent with the laws 3 and renewable energy programs of the Commonwealth.

Sections 129.201, 129.202, and 129.203 are additional NOx requirements to satisfy the Commonwealth's commitments under the EPA approved SIP revision for the Philadelphia Area. These NOx requirements establish additional emission reductions needed to support the attainment demonstration for the Philadelphia Area ( 64 FR 70428, December 16, 1999 and 66 FR 54143, October 26, 2001). Sections 129.201, 129.202, and 129.203 are based, in part, on the model rule for additional NOx control measures developed by the OTC, of which Pennsylvania is a member. The OTC was created to address ozone problems in the Ozone Transport Region ( OTR).

Sections 129.201, 129.202, and 129.203 establish ozone season ( May 1 through September 30) emission limits for NOx from boilers, turbines and stationary internal combustion engines located at industrial, utility and commercial sites in the five county Southeast Pennsylvania area. The emission limits are required to be implemented by May 1, 2005 and shall comply with Section 129.204 ( relating to emission accountability). Sections 129.201, 129.202, and 129.203 do not affect the large sources that are regulated under Chapter 145. In addition, Sections 129.201, 129.202, and 129.203 establish methods in determining NOx allowable emissions. The owner or operator of a unit covered by these sections is required to calculate the difference between NOx allowable emissions and NOx actual emissions under Section 129.204. Boilers and turbines with an emission rate of greater than 250 million Btu/ hour heat input may demonstrate compliance through the opt in provisions of Sections 145.80 through 145.88.

Section 129.201 is designed to reduce the emissions of NOx from industrial boilers. This section applies to any person that owns or operates boilers with a rated capacity of greater than 100 million Btu/ hour but less than or equal to 250 million Btu/ hour. This section does not apply to units that combust municipal waste at a facility that is permitted as a resource recovery facility under Part I, Subpart D, Article VIII ( relating to municipal waste).

The owner or operator subject to Section 129.201 shall calculate allowable emissions by multiplying the unit's cumulative heat input for the period by the applicable emission rate set forth below:

1. The emission rate for a boiler with a rated capacity of greater than 100 Btu/ hour but less than or equal to 250 million Btu/ hour shall be as follows:

a. For a boiler firing natural gas or a boiler firing a noncommercial gaseous fuel, 0.10 pounds NOx per million Btu heat input.

b. For a boiler firing solid or liquid fuel, 0.20 pounds of NOx per million Btu heat input.

2. The emission rate for a boiler with a rated capacity of greater than 250 million Btu/ hour that is not subject to Sections 145.1  145.7, 145.10  145.14, 145.30, 145.31, 145.40  145.43, 145.50  145.57, 145.60  145.62 and 145.70  145.76 shall be 0.17 pounds per NOx per million Btu heat input. 4 Section 129.202 is designed to reduce the emissions of NOx from stationary combustion turbines. This section applies to any person that owns or operates stationary combustion turbines with a rated capacity of greater than 100 million Btu/ hour.

The owner or operator subject to Section 129.202 shall calculate allowable emissions by multiplying the unit's cumulative heat input for the period by the applicable emission rate set forth below:

1. The emission rate for a stationary combustion turbine with a rated capacity of greater than 100 Btu/ hour but less than or equal to 250 million Btu/ hour shall be as follows:

a. A combined cycle or regenerative cycle stationary combustion turbine:

 When firing natural gas or a commercial gaseous fuel, 0.17 pounds NOx/ MMBtu or 1.3 pounds NOx/ MWH.

 When firing oil, 0.26 pounds NOx/ MMBtu or two pounds NOx/ MWH.

b. A simple cycle stationary combustion turbine:

 When firing natural gas or a commercial gaseous fuel, 0.20 pounds NOx/ MMBtu or 2.2 pounds NOx/ MWH.

 When firing oil, 0.30 pounds NOx/ MMBtu or three pounds NOx/ MWH.

2. The emission rate for a stationary combustion turbine with a rated capacity of greater than 250 million Btu/ hour that is not subject to Sections 145.1  145.7, 145.10  145.14, 145.30, 145.31, 145.40  145.43, 145.50  145.57, 145.60  145.62 and 145.70  145.76 shall be 0.17 pounds per NOx per million Btu heat input.

Section 129.203 is designed to reduce the emissions of NOx from stationary internal combustion engines. This section applies to any person that owns or operates stationary internal combustion engines rated at greater than 1,000 horsepower. This section does not apply to stationary combustion engines regulated under Chapter 145, Subchapter B ( relating to emissions of NOx from stationary internal combustion engines).

The owner or operator subject to Section 129.203 shall calculate allowable emissions by multiplying the cumulative hours of operations for the unit by the horsepower rating of the unit by the applicable emission rate set forth below:

1. For a spark ignited engine, 3.0 grams of NOx per brake horsepower hour.

2. For a compression ignition stationary internal combustion engine firing diesel fuel or a combination of diesel fuel and natural gas, 2.3 grams of NOx per brake horsepower hour. 5 Emissions from a stationary internal combustion engine that has been replaced by an electric motor may be counted as allowable emissions:

1. For a replaced spark ignited engine, 3.0 grams of NOx per brake horsepower hour of the replacement motor, less 1.5 pounds of NOx per MWH of electricity consumed by the replacement motor.

2. For a replaced compression ignition stationary internal combustion engine that fired diesel fuel or a combination of diesel and natural gas, 2.3 grams of NOx per brake horsepower hour, less 1.5 pounds of NOx per MWH of electricity consumed by the replacement motor.

Section 129.204 establishes emissions accountability for small sources of NOx that are subject to Section 129, and apply in the five county Southeast Pennsylvania area. This section sets forth the methodologies available to an owner or operator to determine actual emissions of a source, and requires that actual emissions during the ozone season be reconciled against allowable emissions. An owner or operator may apply unused allowable emissions to its other facilities, but if actual emissions exceed allowable emissions, NOx allowances in the amount of the exceedance must be surrendered to the State by November 1 of each year starting in 2005. Failure to surrender the required allowances by this date triggers a requirement to surrender three allowances for every one ton of excess NOx emitted. These small NOx sources are not part of the State's NOx Budget Trading Program, do not receive allowances from the State's NOx budget, and must therefore secure NOx allowances on the open market.

Section 129.205 establishes requirements for an owner who generates zero emission renewable energy to deduct from its actual emissions an equivalent amount of emissions that would be attributable to each MWH of electricity or thermal energy generated via conventional means. This section establishes certain conditions that must be met in order for an owner or operator to apply such a deduction to its actual emissions, including:

1. Certification that the zero emission renewable energy produced with a tradable renewable certificate, 2. Certification that the renewable energy source was brought into production after December 11, 2004 and located within one of these five counties, 3. The renewable tradable certificate must be surrendered to the State, and 4. Certification that all of these conditions have been met.

Section 142.42 is amended to require that for each ton of NOx deducted under Section 129.205 ( i. e., the credit for zero emissions renewable energy produced), the State will retire one NOx allowance from the State's new source set aside pool ( under its NOx Budget Trading Program) for the subsequent ozone season. 6 3. EPA analysis The March 29, 2005 submittal and February 6, 2006 supplemental letter pertaining to amendments to Chapters 121 and 129 satisfy the Commonwealth's commitments under its attainment demonstration for the Philadelphia Area and establish emission reductions that are, in part, integral in maintaining EPA's approval of the Philadelphia SIP. This control measure is based on the model rule developed by the OTC to reduce NOx emissions from certain existing and new boilers, turbines and stationary internal combustion engines.

The requirement that an equivalent amount of NOx allowances be retired for every ton of NOx that is deducted from a source's actual emissions provides assurance that zero emissions renewable energy replaces NOx emissions from conventional generation.

Section 129.204 sets forth a provision that allows Director's discretion for approval of alternate calculation and recordkeeping procedures to determine actual emissions, based upon emission testing and correlations with operating parameters. PADEP's February 6, 2006 letter explains that the process for approval of such an alternate parametric monitoring procedure would be through its incorporation into a permit provision that would be subject to EPA review. PADEP affirms any such requests would be forwarded to EPA when they are received from a source.

B. Amendments to Chapter 145  Pennsylvania's Remaining NOx Reduction Requirements under the NOx SIP Call 1. Background EPA issued the NOx SIP Call ( 63 FR 57356, October 27, 1998) to require 22 Eastern states and the District of Columbia to reduce specified amounts of one of the main precursors of groundlevel ozone, NOx, in order to reduce ozone transport across State boundaries. EPA found that the sources in these states emit NOx in amounts that contribute significantly to nonattainment of the 1 hour ozone national ambient air quality standard ( NAAQS) in downwind states. In the NOx SIP Call, the amount of reductions required by states were calculated based on application of available, highly cost effective controls on source categories of NOx.

The NOx SIP Call ( including the Technical Amendments to the 2007 EGU budgets ( 64 FR 26298, May 14, 1999 and 65 FR 11222, March 2, 2000)) was challenged by a number of state, industry, and labor groups. A detailed background of the NOx SIP Call, including the court decisions that were made in response to challenges to the rule and impacts of the court decisions on certain aspects of the rule may be found in EPA's rulemaking dated April 21, 2004 ( 69 FR 21604) entitled Interstate Ozone Transport: Response to Court Decisions on the NOx SIP Call, NOx SIP Call Technical Amendments, and Section 126 Rules, and is not included in full here. The portions of the April 21, 2004 rulemaking pertaining to Pennsylvania's obligations under Phase II of the NOx SIP Call are included herein to provide a background on the State's requirements for additional NOx reductions. 7 On March 3, 2000, the DC Circuit Court issued its decision on the NOx SIP Call. It ruled largely in favor of EPA in support of its requirements under the 1 hour ozone NAAQS, but in part ruled against EPA on several issues. The portions of the NOx SIP Call that were upheld by the Court were termed Phase I of the rule, and, with the exception of the remand of the EGU growth factors used in the NOx SIP Call and the requirements for the 8 hour ozone NAAQS ( which EPA stayed due to uncertainty created by the court rulings), the other portions that were remanded for further rulemaking were finalized on April 21, 2004 and are termed Phase II of the rule. The rulings against EPA included two areas of the NOx SIP Call that were remanded and vacated, and two areas in which EPA was found to have failed to provide adequate notice of changes in the rule. In the latter case, the rulings included a failure to provide adequate notice of the change in the definition of electric generating unit ( EGU) as applied to cogeneration ( cogen) units that supply electricity to a utility power distribution system for sale in certain specified amounts, and a failure to provide adequate notice of the change in control level EPA assumed for large stationary internal combustion ( IC) engines, both of which were remanded to EPA for further rulemaking.

The two rulings pertaining to inadequate notice potentially required additional adjustments in states' approved Phase I budgets to incorporate the changed definition of cogen units and to incorporate the changed control level noted above.

2. EPA requirements The April 21, 2004 rule finalized specific changes to the definition of EGUs as applied to cogen units, finalized the control levels assumed for large stationary IC engines in the NOx SIP Call, adjusted states' total budgets ( as necessary) to reflect these changes, established a SIP submittal date of April 1, 2005 for States to address the Phase II portion of the budget, and set a compliance date of May 1, 2007 for reductions to meet Phase II of the NOx SIP Call. As a result of these changes, States are required to achieve an incremental reduction of NOx emissions, that, added to their Phase I reductions would achieve the total required reductions needed to fully meet the NOx SIP Call.

The large stationary IC engines that comprise states' Phase II NOx SIP Call inventory are IC engines that emitted more than 1 ton of NOx per average ozone season day during the baseline 1995 ozone season. The amount of Phase II reductions required to be made by states is based on controlling IC engines to the following levels, which were determined by EPA to be highly cost effective:

 For lean burn engines, 82 percent reduction  For rich burn engines, 90 percent reduction  For diesel and dual fuel engines, 90 percent reduction In Phase II, each state's total budget was adjusted downward to reflect the additional reductions that correspond to these control levels as applied to the engines in the NOx SIP Call inventory. States have flexibility in how to achieve the additional reductions, but must adopt rules that will, by the start of the 2007 ozone season, achieve the incremental reduction, and submit the rules to EPA as a SIP revision. 8 Pennsylvania's NOx trading program under the NOx SIP Call was approved as part of the Pennsylvania SIP on August 21, 2001 ( see 66 FR 43795). The Phase II change to the definition of cogen units did not affect the Phase I budget previously established for Pennsylvania and will not be discussed in any detail here, but a full discussion may be found in the April 21, 2005 rulemaking. In order to meet its additional NOx SIP Call Phase II obligations, the Commonwealth is required only to achieve the incremental reductions that EPA calculated based on controlling large IC engines to prescribed levels.

As part of the NOx SIP Call, States are also required to reduce NOx emissions equivalent to those achieved by applying highly cost effective controls to cement kilns that emitted more than 1 ton of NOx per day during the 1995 ozone season. For this source category, it was determined that 30 percent reductions are available and highly cost effective. As noted on page 29066 of the May 29, 2002 EPA rulemaking proposing approval of Pennsylvania's NOx Budget Trading Program, Pennsylvania was required to submit SIP revisions to address any additional emission reductions to meet the Commonwealth's overall emissions budget.

3. Description of Revisions The Pennsylvania SIP revision amends Chapter 145, Interstate Pollution Transport Reduction Requirements ( Pennsylvania's approved cap and trade program under the NOx SIP Call), by adding Subchapters B and C. These amendments establish ozone season NOx emission limits for large stationary internal combustion engines and Portland cement kilns across the State to satisfy the remainder of EPA's requirements under the NOx SIP Call.

Subchapter B, titled Emissions of NOx From Stationary Internal Combustion Engines, establishes applicability, adds new definitions that apply to IC engines, establishes allowable emissions for each of the three categories of large stationary internal combustion engines, sets forth monitoring requirements, establishes methods for calculating actual and allowable NOx emissions, establishes requirements for surrender of allowances when actual emissions exceed allowable emissions, and establishes a ratio for surrender of NOx allowances when, upon reconciliation, a source has excess emissions. An affected source must comply by May 1, 2005.

Subchapter C, entitled Emissions of NOx From Cement Manufacturing, establishes emission limit requirements for large Portland cement kilns across the state, and includes applicability, new definitions, standard requirements for compliance monitoring, and establishes requirements for determing allowable and actual emissions, and establishes requirements for surrender of NOx allowances to the State when a unit has excess emissions. An affected source must comply by October 31, 2005.

Both Subchapter B and C set forth methodologies available to the sources to determine actual emissions, and establish requirements for units or sources to reconcile actual emissions against allowable emissions, requiring sources that exceed allowable emissions to surrender NOx allowances to the Commonwealth's NOx allowance account. For both source categories above, the state allows an owner to apply excess allowable emissions at one facility towards actual emissions at the owner's other facilities within the Commonwealth. 9 4. EPA Analysis of Revisions Stationary IC engines There are a total of 14 IC engines that meet the definition of " large NOx SIP Call engines" in Pennsylvania. Section 145.113 establishes emission limits for IC engines as follows:

a. For a rich burn stationary IC engine with an engine rating equal to or greater than 2,400 brake horsepower shall be 1.5 grams per brake horsepower hour. b. For a lean burn stationary IC engine with an engine rating equal to or greater than 2,400 brake horsepower shall be 3.0 grams per brake horsepower hour c. For a diesel stationary IC engine with an engine rating equal to or greater than 3,000 brake horsepower, or a dual fuel stationary IC engine with an engine rating equal to or greater than 4,400 brake horsepower shall be 2.3 grams per brake horsepower hour In the NOx SIP Call Phase II, EPA determined an incremental reduction that States would have to achieve to fully meet the requirements of the NOx SIP Call. The additional emission reductions were based on application of controls to several categories of IC engines based on available historical information.

In the April 21, 2004 Phase II rulemaking, EPA determined that an average emission rate of 16.8 g/ hp hr is appropriate to represent uncontrolled emissions from large lean burn engines. 1 The available test data on large lean burn engines in the NOx SIP Call area indicated that highly costeffective controls can achieve a reduction level of 82%. The emission limit of 3.0 g/ hp hr for leanburn engines achieves this level of control. For rich burn engines, the uncontrolled emission rate is 15.8 g/ hp hr 2. The emission limit of 1.5 g/ hp hr for rich burn engines achieves the 90% control required under Phase II. There were no dual fuel engines in the Commonwealth's NOx SIP Call Inventory. The emission limits set forth in Section 145.113 achieve the reductions required under Phase II.

Provisions for approval of alternate calculation and reporting procedures are identical to those in Chapter 129. As addressed in PADEP's February 6, 2006 letter, the process for approval of such an alternate parametric monitoring procedure would be through incorporation of the change in a permit provision that would be subject to EPA review. As noted above, PADEP affirms any such requests would be forwarded to EPA when they are received from a source.

1 Stationary Reciprocating Internal Combustion Engines TSD for NOx SIP Call, October 2003.

2 Alternative Control Techniques ( ACT) document, " NOx Emissions from Stationary Reciprocating Internal Combustion Egnines," EPA 453/ R 93 032, July 1993, Table 2 1 on page 2 3. 10 Cement Kilns The NOx SIP call also identified large cement kilns as a source category having large contributions to transported emissions and determined that highly cost effective controls are available on these sources that achieve 30 percent emission reductions. There are 19 cement kilns within the Commonwealth that are subject to the NOx SIP Call. Since 1995, these kilns have had varying levels of control based on other state or federal requirements   in some cases levels of control were more restrictive than that required by the NOx SIP Call. Of the 19, five are long wet kilns, eight are long dry kilns, four are of the dry preheater type, and one is a dry precalciner type of kiln. One kiln has shut down.

The NOx SIP Call requirements for cement kilns were based on EPA's Alternative Control Techniques ( ACT) guidance document that addressed NOx emissions from cement manufacturing sources. 3 In the ACT, average uncontrolled emissions for the four types of kilns are:

Wet kilns  9.7 pounds of NOx per ton of clinker produced Long Dry kilns  8.6 pounds of NOx per ton of clinker Dry preheater kiln  5.9 pounds of NOx per ton of clinker Dry precalciner kiln  3.4 pounds of NOx per ton of clinker The Commonwealth's regulation under Subchapter C establishes an emission limit of 6 pounds of NOx per ton of clinker produced by a kiln. For the wet kiln and long dry kiln type of process, this emission limit meets or exceeds the 30% reduction requirement ( i. e., 6 pounds per ton of clinker, is at least 30 percent less than the average uncontrolled emissions for these type of kilns, as noted above). One cement kiln, Kosmos Cement Company, has shut down permanently, resulting in 511 tons of NOx that are creditable to the Commonwealth towards its reduction requirements. The analysis of the adequacy of the Commonwealth's submission then focused on a comparison of total amount of emissions from the dry preheater and dry precalciner kilns taking into consideration the credits that accrue to the State from the shutdown of Kosmos, the control of some units as required under other programs, and the expanded applicability beyond the original inventory. See Attachment A for a summary of the analysis for these sources.

As can be seen in Attachment A, in the aggregate, the Commonwealth's regulation meets the reduction requirements of the NOx SIP Call for cement kilns.

III. CONCLUSION As described above, the March 29, 2005 SIP revisions and February 6, 2006 supplemental letter submitted by the Commonwealth of Pennsylvania for revision of Chapter 121 ( definitions), addition of new Sections 129.201 though 129.205 ( Additional NOx Requirements), revision of Section 145.42 ( pertaining to accountability of NOx credit under Section 129.205), and addition of Subchapters B and C to Chapter 145 ( pertaining to the Commonwealth's remaining NOx SIP Call 3 Alternative Control Techniques document, " NOx Emissions from Cement Manufacturing", EPA 453/ R 94 004, March 1994, Table 2 1 on page 2 3. 11 obligations for IC engines and cement kilns, respectively), are approvable. These revisions strengthen the Pennsylvania SIP.

IV. RECOMMENDATION It is recommended that a Notice of Proposed Rulemaking be published proposing approval of these SIP revisions.


[Federal Register Volume 76, Number 51 (Wednesday, March 16, 2011)]
[Notices]
[Pages 14389-14390]
[FR Doc No: 2011-6052]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

Notice of Attendance at NYISO Meetings

    The Federal Energy Regulatory Commission hereby gives notice that
members of the Commission and Commission staff may attend upcoming New
York Independent System Operator, Inc. (NYISO) meetings, as well as
other subcommittee or working group meetings that are not currently
scheduled, but that are typically scheduled on short notice or meetings
that are scheduled on short notice based on items arising from the
agenda as posted on the NYISO Web site.\1\ The Commission and
Commission staff may attend the following meetings:
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    \1\ NYISO Subcommittees, Task Forces, and Working Groups of the
three primary committees (Management, Business Issues, and
Operating) meet on a variety of topics; they convene and dissolve on
an as-needed basis. Therefore, staff may monitor different working
groups as issues arise and according to postings on the NYISO Web
site.
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NYISO Business Issues Committee

     March 9, 2011 (Rensselaer, NY)
     April 13, 2011 (Rensselaer, NY)
     May 11, 2011 (Rensselaer, NY)
     June 1, 2011 (Rensselaer, NY)
     July 13, 2011 (Rensselaer, NY)
     August 10, 2011 (Rensselaer, NY)
     September 14, 2011 (Rensselaer, NY)
     October 12, 2011 (Rensselaer, NY)
     November 9, 2011 (Rensselaer, NY)
     December 14, 2011 (Rensselaer, NY)

NYISO Management Committee

     March 30, 2011 (Rensselaer, NY)
     April 27, 2011 (Rensselaer, NY)
     May 25, 2011 (Rensselaer, NY)
     June 14, 2011 (Rensselaer, NY)
     July 27, 2011 (Rensselaer, NY)
     August 31, 2011 (Rensselaer, NY)
     September 27, 2011 (Rensselaer, NY)
     October 26, 2011 (Rensselaer, NY)
     November 23, 2011 (Rensselaer, NY)
     December 21, 2011 (Rensselaer, NY)

NYISO ICAP Working Group

     March 10, 2011 (Rensselaer, NY)
     March 18, 2011 (Rensselaer, NY)
     March 24, 2011 (Rensselaer, NY)
     April 18, 2011 (Rensselaer, NY)
     May 16, 2011 (Rensselaer, NY)
     July 11, 2011 (Rensselaer, NY)
     August 19, 2011 (Rensselaer, NY)
     September 12, 2011 (Rensselaer, NY)
     October 17, 2011 (Rensselaer, NY)
     November 14, 2011 (Rensselaer, NY)

NYISO Operating Committee

     March 17, 2011 (Rensselaer, NY)
     April 14, 2011 (Rensselaer, NY)
     May 12, 2011 (Rensselaer, NY)
     June 2, 2011 (Rensselaer, NY)
     July 14, 2011 (Rensselaer, NY)
     August 11, 2011 (Rensselaer, NY)
     September 15, 2011 (Rensselaer, NY)
     October 13, 2011 (Rensselaer, NY)
     November 30, 2011 (Rensselaer, NY)
     December 15, 2011 (Rensselaer, NY)

NYISO Transmission Planning Advisory Subcommittee

     Various dates

NYISO Budget and Priorities Working Group

     Various dates

NYISO Credit Policy Task Force

     Various dates

NYISO Price Responsive Load Working Group

     Various dates

Interconnection Issues Task Force

     Various dates
    For additional meeting information, see: http://www.nyiso.com/public/committees/calendar/index.jsp.
    The discussions at each of the meetings described above may address
matters at issue in pending proceedings before the Commission including
the following:

Docket Nos. EL07-39 and ER08-695, New York Independent System
Operator, Inc.

Docket No. EL09-57, Astoria Gas Turbine Power LLC v. New York
Independent System Operator, Inc.
Docket No. EL10-033, New York Independent System Operator, Inc.
Docket No. EL10-70, TC Ravenswood, LLC v. New York Independent
System Operator, Inc.
Docket No. ER01-3155, New York Independent System Operator, Inc.
Docket Nos. ER01-3001-021/ER03-647-012 and ER01-3001-022/ER03-647-
013, New York Independent System Operator, Inc.
Docket No. ER04-449, New York Independent System Operator, Inc.
Docket No. ER04-230, New York Independent System Operator, Inc.
Docket No. ER07-612, New York Independent System Operator, Inc.
Docket No. ER08-850, New York Independent System Operator, Inc.
Docket No. ER08-867, New York Independent System Operator, Inc.
Docket No. ER08-1281, New York Independent System Operator, Inc.
Docket No. ER09-1142, New York Independent System Operator, Inc.
Docket No. ER09-1204, New York Independent System Operator, Inc.
Docket No. ER09-1682, New York Independent System Operator, Inc.
Docket No. ER09-405, New York Independent System Operator, Inc.
Docket No. ER10-65, New York Independent System Operator, Inc.
Docket No. ER10-424, New York Independent System Operator, Inc.
Docket No. ER10-290, New York Independent System Operator, Inc.
Docket No. ER10-554, New York Independent System Operator, Inc.
Docket No. ER10-555, New York Independent System Operator, Inc.
Docket No. ER10-573, New York Independent System Operator, Inc.
Docket No. ER10-1657, New York Independent System Operator, Inc.
Docket No. ER10-1359, New York Independent System Operator, Inc.
Docket No. ER10-2220, New York Independent System Operator, Inc.
Docket No. ER11-2224, New York Independent System Operator, Inc.
Docket No. ER10-3043, New York Independent System Operator, Inc.
Docket No. ER11-2842, New York Independent System Operator, Inc.
Docket No. ER11-2547, New York Independent System Operator, Inc.
Docket No. ER06-1014, New York Independent System Operator, Inc.
Docket No. ER11-1844, New York Independent System Operator, Inc.
Docket No. ER11-2048, New York Independent System Operator, Inc.
Docket No. RM04-7, Market-Based Rates for Wholesale Sales of
Electric Energy, Capacity, and Ancillary Services by Public
Utilities.
Docket No. RM10-11, Integration of Variable Energy Resources.
Docket No. RM10-15, Mandatory Reliability Standards for
Interconnection Reliability Operating Limits.
Docket No. RM10-16, System Restoration Reliability Standards
Docket No. OA08-52, New York Independent System Operator, Inc.
Docket No. OA09-26, New York Independent System Operator, Inc.

    The meetings are open to stakeholders. For more information,
contact Jesse Hensley, Office of Energy Market Regulation, Federal
Energy Regulatory Commission at<PHONE_NUMBER> or
<EMAIL_ADDRESS>
    Dated: March 9, 2011.
Kimberly D. Bose,
Secretary.
[FR Doc. 2011-6052 Filed 3-15-11; 8:45 am]
BILLING CODE 6717-01-P


[Federal Register Volume 77, Number 242 (Monday, December 17, 2012)]
[Notices]
[Pages 74653-74654]
[FR Doc No: 2012-30281]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

Combined Notice of Filings 2

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

    Docket Numbers: ER12-2258-000; ER12-2258-001.
    Applicants: Midwest Independent Transmission System Operator, Inc.
    Description: Answer to Deficiency Letter of Midwest Independent
Transmission System Operator, Inc.
    Filed Date: 11/30/12.
    Accession Number: 20121130-5253.
    Comments Due: 5 p.m. ET 12/21/12.

    Docket Numbers: ER13-513-000.
    Applicants: Electricity NH, LLC.
    Description: Electricity NH, LLC submits tariff filing per 35.1:
Electricity New Hampshire FERC Tariff (revision 2) to be effective 12/
5/2012.
    Filed Date: 12/5/12.

    Accession Number: 20121205-5001.
    Comments Due: 5 p.m. ET 12/26/12.

    Docket Numbers: ER13-514-000.
    Applicants: Appalachian Power Company.
    Description: 20121205 Attachment K Revision to be effective 1/4/
2013.
    Filed Date: 12/5/12.
    Accession Number: 20121205-5062.
    Comments Due: 5 p.m. ET 12/26/12.

    Docket Numbers: ER13-515-000.
    Applicants: Southwest Power Pool, Inc.
    Description: Revisions to Attachment J, Section IV--Approved
Balanced Portfolios to be effective 1/29/2013.
    Filed Date: 12/5/12.
    Accession Number: 20121205-5064.
    Comments Due: 5 p.m. ET 12/26/12.

    Docket Numbers: ER13-516-000.
    Applicants: PJM Interconnection, L.L.C.
    Description: First Revised Original Service Agreement No. 3403;
Queue No. U3-004 to be effective 11/15/2012.
    Filed Date: 12/5/12.
    Accession Number: 20121205-5065.
    Comments Due: 5 p.m. ET 12/26/12.

    Docket Numbers: ER13-517-000.
    Applicants: PJM Interconnection, L.L.C.
    Description: Notice of Cancellation of Service Agreement No. 3056
in Docket No. ER12-4526-000 to be effective 11/5/2012.
    Filed Date: 12/5/12.
    Accession Number: 20121205-5140.
    Comments Due: 5 p.m. ET 12/26/12.
    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: December 5, 2012.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
[FR Doc. 2012-30281 Filed 12-14-12; 8:45 am]
BILLING CODE 6717-01-P