NEPOOL Operating Procedure No. 6

SYSTEM RESTORATION

APPROVED:	July 22, 1998, by the NEPOOL Regional Market Operations Committee and the NEPOOL Regional Transmission Operations Committee to be implemented for the Second Effective Date for Market Implementation

REFERENCE:	1 NERC Policy 5 ‑ Emergency Operations
	2 NPCC Emergency Operation Criteria
	3 NEPOOL Operating Procedure No. 4  Action During a Capacity Deficiency
	4 NEPOOL Operating Procedure No. 7  Action in an Emergency
	5 NEPOOL Operating Procedure No. 8  Operating Reserve
	6 NEPOOL Operating Procedure No. 12  Voltage and Reactive Control
	7 NEPOOL Operating Procedure No. 19  Transmission Operations

SATELLITE INSTRUCTION NUMBER:

CONVEX:			Operating Instruction No. 6 ‑ Restoration
MAINE:			Operating Procedure No. 6 ‑ Restoration
NEW HAMPSHIRE: 		Operating Procedure No. 6 ‑ Restoration
REMVEC II:			Operating Procedure No. 6 ‑ Restoration

Table of Contents

I.	INTRODUCTION	3
II.	RESPONSIBILITIES	3
A.	CONVEX, Maine and New Hampshire Satellites	3
B.	REMVEC II Satellite	5
C.	ISO New England Responsibilities	6

Appendix A - System Restoration Guidelines

Appendix B - Flow Chart of System Restoration Following a Complete Blackout

Appendix C - Charging of 345 KV Circuits in New England

Appendix D - New England Transmission Reactors

Appendix E – New England Transmission Capacitors

Appendix F – Inter-Satellite Ties

Appendix G – Inter-Area Ties

Appendix H – Phone Numbers of Control Centers

    
I.	INTRODUCTION

This procedure addresses restoration of the bulk power system (115 KV and above) after a partial or complete system blackout.  Expeditious restoration of the bulk power system depends on independent actions and interactions by NEPOOL Participants, Satellites and the ISO.  Depending on the expanse of the blackout (local area or widespread) numerous Participant and Satellite restoration procedures, and this procedure, may need to be implemented simultaneously.

During system restoration, a high priority must be given to the restoration of off‑site AC power sources to nuclear generators.  Also, technical aspects of system restoration (i.e. unit startups, load pickups, switching surges, voltages, frequency, synchronization of islands, etc.) will be crucial.  Recognizing these concerns, this procedure and all Satellite and Participant restoration procedures have been developed in a coordinated fashion.  This document:

1.	Outlines the responsibilities of the Satellites and the ISO  (including independent actions and interactions between these organizations) and,

2.	Provides technical guidelines for the restoration of transmission and generation facilities.

Responsibilities are outlined in the body of this procedure.  Satellites are grouped according to the relationship established between them and the ISO.  Specifically, the CONVEX, Maine and New Hampshire Satellites' relationships to the ISO are the same, therefore, their responsibilities during system restoration are the same.  The REMVEC II Satellite has a unique relationship with the ISO and thus has its own set of responsibilities.  Furthermore, because of its structure, the REMVEC II Satellite relies heavily on the restoration plans of the numerous utilities within REMVEC II.  Details on the interactions of REMVEC II and its companies can be found in the REMVEC II restoration procedure.

Technical guidelines for restoration are provided in Appendix A.

II.	RESPONSIBILITIES

A.	CONVEX, Maine and New Hampshire Satellites

1.	Determine the extent of the blackout within the CONVEX, Maine and New Hampshire Satellites and inform the ISO as soon as possible of existing generation and transmission capabilities.  (The ISO will determine the extent of the blackout within New England and adjacent power systems and inform the Satellites.)

2.	Implement the CONVEX, Maine and New Hampshire Satellite restoration procedures (including necessary coordination with the ISO and adjacent Satellites).

3.	If the blackout is severe and unit dispatch must be temporarily returned to the Satellite(s), assign a loader to direct the startup and loading of units.  The loader must;

a)	Follow the technical guidelines which relate to unit startups, synchronization and loading and,

b)	Closely coordinate unit operations with switching operations.  If unit loading by a Satellite is warranted, the Satellite can request that an ISO operator be sent to the Satellite to assist with unit loading.  Once the Satellite is sufficiently restored and interconnected, the ISO will resume unit dispatch.

4.	Assign CONVEX, Maine and New Hampshire Satellite restoration coordinators to perform the following duties:

a)	Establish communications with restoration coordinators at the ISO and adjacent Satellites to provide a flow of information that promotes coordinated system restoration.

b)	Monitor, advise and help coordinate with the ISO and adjacent Satellites, the following;

(1)	Energizations of 345 kV circuits,

(2)	Energizations of inter‑Satellite and inter‑Area ties

(3)	Unit startups, load pickups, generation reserves and load shedding within interconnected systems after an inter-Satellite or inter-Area tie has been established.

c)	Maintain records of the Satellite blackouts and restorations.

d)	Provide updates on Satellite status.

5.	Monitor transmission and generation facilities and, as practical, take action to promote system reliability.

6.	Should communications with the ISO fail, 345 kV circuits and inter-Satellite and inter-Area ties may be energized if prudent to total system restoration and communications between the affected parties exist.

B.	REMVEC II Satellite

1.	Determine the extent of the blackout within REMVEC II and inform the ISO as soon as possible of existing generation and transmission capabilities.  (The ISO will determine the extent of the blackout within New England and adjacent power systems and inform the Satellites.)

2.	Implement the REMVEC II Satellite restoration procedures (including necessary coordination with REMVEC II companies, the ISO and adjacent Satellites).

3.	If the blackout is severe and unit dispatch must be temporarily returned to the REMVEC II Satellite and its companies, the REMVEC II Participant companies will assign a loader in their own dispatch control rooms to oversee and coordinate the startup and loading of units within their respective areas.  The loader must ensure that;

a)	The technical guidelines which relate to unit startups, synchronization’s and loading are followed and,

b)	Unit operations are closely coordinated with switching operations.  If unit loading by REMVEC II and its companies is warranted, REMVEC II can request that an ISO operator be sent to REMVEC II to assist with unit loading. If the REMVEC II companies are black starting their service territories, REMVEC II’s responsibility will be to oversee and keep track of the developing islands.  As REMVEC II companies interconnect, REMVEC II will become responsible for coordinating unit loading to enhance overall Satellite restoration.  Once the REMVEC II Satellite is sufficiently restored and interconnected, unit dispatch will be resumed by the ISO.

4.	Assign a REMVEC II Satellite restoration coordinator to perform the following duties:

a)	Establish communications with restoration coordinators in the REMVEC II companies, the ISO and adjacent Satellites to provide a flow of information, which promotes coordinated system restoration.

b)	Monitor, advise and help coordinate with the ISO and adjacent Satellites, the following;

(1)	Energizations of 345 KV circuits,

(2)	Energizations of inter‑Satellite and inter‑Area ties,

(3)	Unit startups, load pickups, generation reserves and load shedding within interconnected systems after an inter‑Satellite or inter‑Area tie has been established.

c)	Maintain a record of the REMVEC II Satellite blackout and restoration.

d)	Provide updates on the status of the REMVEC II Satellite.

5.	Monitor transmission and generation facilities and, as practical, take action to promote system reliability.

6.	Should communications with the ISO fail, 345 KV circuits and inter‑Satellite and inter‑Area ties may be energized if prudent to total system restoration and communications between the affected parties exist.

C.	ISO New England 

1.	Determine the extent of the blackout throughout New England and adjacent power systems and inform all Satellites of existing generation and transmission capabilities.

2.	Implement the ISO restoration procedure (including necessary coordination with the Satellites and adjacent power systems).

3.	If the blackout is severe and unit dispatch must be temporarily returned to the Satellites, be prepared to send operators to the Satellites to assist with the loading function if the Satellites request such assistance.  Loaders must ensure that;

a)	the technical guidelines which relate to unit startups, synchronizations and loadings are followed and,

b)	unit operations are closely coordinated with switching operations.  Once the Satellites are sufficiently restored and interconnected, unit dispatch will be resumed by the ISO. 

4.	Assign a restoration coordinator to perform the following duties:

a)	Establish communications with restoration coordinators in the Satellites and adjacent power systems and a flow of information that promotes coordinated system restoration.

b)	Monitor, advise and help coordinate with the Satellites and adjacent power systems, the following;

(1)	Energizations of 345 KV circuits,

(2)	Energizations of inter‑Satellite and inter‑Area ties,

(3)	Unit startups, load pickups, generation reserves and load shedding within interconnected systems after an inter‑Satellite or inter‑Area tie has been established.

c)	Maintain a record of the New England blackout and restoration.

d)	Provide updates on the status of the New England system to the Satellites and adjacent power systems.

5.	Authorize the closing of inter‑Satellite and inter‑Area transmission lines.

6.	Once inter‑Satellite or inter‑Area tie lines are energized, oversee and coordinate load pickups within the interconnected parties.

7.	Select priority for start‑up power supply to generating stations when the choice is to supply a station in one Satellite or a station in another Satellite from the same source.

8.	Direct load shedding, if necessary, to enable continued reliable restoration of interconnected parties or the closing of inter‑Satellite or inter‑Area ties.

9.	Monitor bulk power system transmission and generation facilities and, as practical, take action to promote system reliability. 

Document History
SYSTEM RESTORATION GUIDELINES

The following lists guidelines regarding the technical aspects of system restoration.  Recognizing the numerous scenarios of possible system blackouts (the expanse of the blackout and resources available for restoration), knowledge of these guidelines is important.  They represent a general‑purpose tool for system restoration.  A more specific set of guidelines for restoration of the 345 KV system in the event of a complete blackout is presented in the flow chart in Appendix B.  This flow chart and the various Satellite restoration procedures reflect the general guidelines.  Where appropriate, the Satellite and the ISO procedures have been coordinated.

A. Restoration of Off‑Site AC Power to Nuclear Generators

The most critical power requirement after a blackout is the assurance of reliable shutdowns of nuclear generators.  The NRC requires these units to have reliable on‑site power sources for shutdown operations.  The expeditious restoration of alternative off‑site AC power sources to nuclear units is imperative to promote the continued reliability of shutdown operations.  Beyond this, the station service demands to return some nuclear generators on‑line cannot be met until off‑site AC power is provided.

Between the Satellite and the ISO restoration procedures, at least two options for restoring off‑site AC power to nuclear generators have been provided.

B. Opening Circuit Breakers and Switches

Satellite and company restoration procedures contain detailed instructions regarding the opening of circuit breakers and switches.  In most cases, in‑place substation procedures provide specific switching instructions to be followed in the event of a substation blackout.  Some substations have equipment, which automatically switches into a desired post‑blackout configuration.

In general, capacitors and customer loads will be opened and disconnected from the 345/230/115 KV transmission system.  Similarly, circuit breakers or switches on the 345/230/115 KV transmission system will be opened.  On the 345 and 230 KV, step‑down transformers will be opened on the high side to avoid the simultaneous energization of a 345 or 230 KV circuit along with a step‑down transformer.  Step‑down transformers off the 115 KV system will be opened on either the high or low side.

Operators should have station and distribution capacitors opened in locations where customer load can effectively absorb charging from transmission lines.  This will help prevent high voltage conditions on the transmission system and excessive under excitation on generators.  Along these lines, operators should anticipate the use of any available reactors to help absorb charging and prevent high voltage.

C.  Reviewing Load Tap Changer (LTC) Positions

During system collapse, LTCs on autotransformers could move toward/to extreme tap positions.  For example, if a gradual voltage collapse occurs (over several minutes), LTCs could move to full boost positions in an attempt to maintain subtransmission or distribution voltage.  Upon collapse, the LTCs would remain in these positions and subsequent reenergization of the autotransformers could result in excessively high voltages on the low side systems that could result in equipment or load damage.  Consequently, LTC positions should be checked prior to energization of autotransformers.  If LTC positions are substantially off nominal, taps should be moved to nominal positions before energizing autotransformers.

D.  Generator Start Ups and MW Loadings 

During system restoration, generator MW loadings will be primarily dictated by minimum MW loading requirements to ensure unit stability and the need to provide station service power to units without black start capability.  Operators at generating stations should, in concert with Satellite operators, endeavor to start as many units as possible.  More units mean stronger sources in terms of synchronized inertia and control of frequency and voltage.

Stronger sources will also afford more circuit energizations, unit start‑ups, spinning reserve, and load pickups (including larger block sizes of load pickups).

Once initial units have been brought on line and synchronized, they should pick up some/all the minimum load requirements for other units just prior to their startup/synchronization.  Once these units start and synchronize, their minimum load requirements should be transferred to them by adjusting unit loadings in the synchronized subsystem.  This method of providing minimum load requirements to units is generally preferable to doing load pickups after a unit has been synchronized.

E. Spinning Reserves

Initially, when few units are on‑line, operators will not have many options regarding spinning reserves.  As restoration progresses and more units are phased in, operators should establish and maintain enough spinning reserve to cover loss of the unit generating the most MW.  Eventually, spinning MW reserves should be adequate to cover loss of the largest generating unit and have additional reserve for continuing unit start‑up demands.

F. Load Pickups

1. Load Block Sizes

In general, pick up loads in block sizes that do not exceed 5% of total synchronized generating capability.  One exception to this would involve initial phases of restoration where a large unit with slow governor response is synchronized to a small unit with fast governor response.  To avoid overloading the smaller unit after load pickup, block sizes should be restricted to 5% of the smaller unit's MVA capability until (an) additional unit(s) is/are synchronized.

2. 	Frequency Increase Prior to Load Pick up, Automatic Underfrequency Load Shedding

Large frequency excursions are to be expected during system restoration.  To allay these excursions and prevent compounding them by the triggering of Automatic Underfrequency Load Shedding (AULS) and other subsequent cascading problems, operators should employ the following methods.

During initial stages of system restoration (electrical island sizes are roughly 500 MW or less) the block sizes of load pickups are most likely to be at/near the general limit of 5% of synchronized generation capability and large frequency excursions are most probable.  Operators can compensate for the frequency dips by first increasing frequency to as high as 60.3 hertz prior to load pickup.  Operators may achieve another layer of reliability by initially avoiding, if possible, the restoration of feeders with AULS.  (Initially avoiding AULS is preferred but may not be possible based on substation design).  If AULS feeders must be picked up, operators should initially opt, if possible, to restore those set at 58.8 hertz.

As island sizes grow to several hundred MW and the ratio of load block sizes to synchronized generation decreases, smaller increases in frequency prior to load pickup will become appropriate.  Also, load pickups should now restore the 15% portion of load with AULS at 58.8 hertz.

Finally, as island/system sizes reach a thousand(s) of MW, load block sizes should become a small percent of synchronized generation and increasing/maintaining frequency after rather than prior to load pickups should be sufficient.  Full AULS capability (10% at 59.3 hertz and 15% at 58.8 hertz) should be restored and maintained.  This will provide backup protection for generation contingencies in these larger size islands/systems.

During restoration, operators should observe analog/instantaneous recordings of frequency response to actual load pickups (if available) and tailor their frequency increases and load block sizes to prevent excessive frequency excursions.

3. 	Cold Load Pickup

During system restoration, operators will be restoring feeder loads that have been deenergized for unusually long periods of time (commonly referred to as "cold load").  The longer the deenerization period, the greater the loss of typical on/off cycling and other types of diversity in the load.  Upon reenergization of the load, simultaneous full demands of all the various load components can be encountered.  Consequently, operators should anticipate cold load pickups that are 1.5 ‑ 3 times greater than normal feeder loads.  Also, the longer the deenergization period, the longer it will take for the cold load magnitude to decay to a more typical value.  After performing several load pickups, operators should get a better feel of cold versus typical feeder loads.

G. Salient Electrical Concerns During System Restoration

Reliable frequency and voltage performance (both transient and steady state) and reliable circuit energizations are major concerns during system restoration, especially during initial stages.  The following general guidelines address these concerns.

1. 	Transmission Line Charging

Anticipate the introduction of shunt MVAR charging from line energizations and ensure that adequate reactive control exists prior to line energizations.  The following are typical charging values: .88 MVAR/mile for 345 KV, .28 MVAR/mile for 230 KV, and .07 MVAR/mile for 115 KV.  These figures show charging to be a critical concern on the 345 KV, a significant factor on the 230 KV but much less of a concern on the 115 KV.  A list of 345 KV circuits and their charging levels, and a list of shunt devices within New England are provided in Appendices C‑E.

2. 	Voltage Schedules at Generators

Generating stations should work to maintain voltage schedules below normal levels during system restoration.  This will help combat shunt MVAR charging from lightly loaded transmission lines and consequential high voltage and excessive switching surges.  Lower voltage schedules will reduce transmission line MVAR charging (which is a function of voltage squared) and promote leading operation of generators and thus the absorption of transmission line MVAR charging.  As island/system sizes increase and significant real power MW flows start to occur on transmission circuits, normal voltage schedules at generating stations may become preferable.  In any case, decisions on voltage schedules should be based on actual system voltage levels and leading reactive power limits on generators.  If a unit is at/near its leading reactive power limit, other options for absorbing reactive power or reducing the amount of reactive power that has to be absorbed should be exercised to restore leading reactive reserve on generators.

3. 	Circuit Energizations

Perform circuit energizations in a deliberate manner, checking the status of all associated facilities before and after energization.  Synchronism, reactive conditions, and switching surges should be considered.  In general, excessive switching surges are not anticipated for energizations on the 115 or 230 KV.

In the early stages of system restoration, 345 KV line or 345/115 KV transformer energizations should be done with a source that is electrically close to the energization, and has a total capability of 100 MVA or more (could be one or more synchronized units).  Even then, only one to three 345 KV facilities could be energized reliably depending on line length or transformer characteristics.  As restoration progresses and the total capability of synchronized sources builds up to several hundred MVA spread out over the 345 KV system, the possibility of excessive switching surges decreases substantially.

The simultaneous energization of a 345 KV transmission line and a 345 KV step‑down transformer should be avoided.  In cases where this is not possible (no breaker between the line and transformer), the energization of these circuits should be done with a strong nearby source or in later stages of system restoration when sources are strong.

In general, a reactor connected to the tertiaries of 345 KV step‑down transformers should be closed‑in prior to energization of the transformers.  This will help prevent excessively high switching and steady state voltages.  Prior to switching, operators should confirm that the reactor will be beneficial, and be able to be supported after switching.  In cases where multiple reactors are available, operators should decide how many reactors can/should be energized along with the 345 kV transformer.

If upon energization, a circuit immediately trips out due to relay protection, operators should try to have the lightning arrestors at the terminals of the circuit visually inspected for damage before making another attempt to energize the circuit.  If inspection is not possible/timely, parties should be aware of and accept an increased risk for equipment damage during subsequent attempts to energize the circuit and other nearby circuits.  The transmission equipment of most concern would be autotransformers.

4. 	Synchronizations

Generating stations are the preferred locations for synchronizing units, islands or systems together.  These stations have synchronizing equipment which is needed for regular unit phasing.  Also, station operators are well versed in synchronizing techniques.  In the restoration procedures, some synchronizations are planned at transmission (vs.  generating) stations.  For these cases, the necessary synchronizing equipment, operator knowledge and communication links to predefined generating stations (to match frequency) have been considered.

H.	Inter‑Satellite Ties

	The synchronization/energization of inter‑Satellite ties should occur during fairly early stages of system restoration.  This would minimize problems associated with having to synchronize many small islands or trying to match frequencies of two large islands.  It would also promote the most effective use of available resources to restore the system in the least amount of time.  Appendix F lists the inter‑Satellite ties operating at 115 kV and above.  

I.   Inter‑Area Ties

The same reasons for early establishment of inter‑Satellite ties apply to inter‑Area ties.  However, the lack of direct control over switching operations in other pools and their overall status/reliability should be considered before establishing ties.  Also, reliable operation of HVDC converters requires that strong AC systems exist.  For this reason, operators should not attempt to energize HVDC ties during early phases of system restoration.  Appendix G lists the inter‑Area ties.

OP 6 & AppA-H.rtf
9/10/97

APPENDIX B GOES HERE.
(Flow chart of system restoration following a complete blackout - this remains unchanged from your existing OP 6)

Charging of 345KV Circuits in New England
(all MVAR values at nominal voltage)

	Circuit			Charging
	#		Terminals	(MVAR)
	301	Ludlow ‑ Carpenter Hill	20.8
	302	Carpenter Hill ‑ Millbury No. 3	13.1
	303	Brayton Point ‑ West Medway	30.7
	307	Deerfield ‑ Newington	21.5
	310	Millstone ‑ Manchester	41.8
	312	Berkshire ‑ Northfield Mountain	31.6
	314	Millbury No. 3 ‑ Sandy Pond	31.3
	315	Brayton Point ‑ West Farnum	33.6
	316	Holbrook ‑ West Walpole	13.4
	319	Woburn ‑ Lexington	7.5
	320	Connecticut Yankee ‑ Haddam Neck	0.2
	321	Long Mountain ‑ Pluntree	15.6
	322	Canal ‑ Carver	13.4
	323	Millbury No. 3 ‑ West Medway	13.4
	325	West Medway ‑ West Walpole	6.8
	326	Sandy Pond ‑ Scobie Pond	25.5
	328	West Farnum ‑ Sherman Road	7.7
	329	Frost Bridge ‑ Southington	8.6
	331	Carver ‑ West Walpole	22.3
	332	West Farnum ‑ Kent County	17.7
	333	Ocean State ‑ Sherman Road	.1
	334	Ludlow ‑ Stony Brook	4.4
	335	Auburn Street ‑ Holbrook	6.6
	336	Sherman Road ‑ N.E.A. Tap ‑ West Medway 	19.2
	337	Tewksbury ‑ Sandy Pond	13.9
	338	Tewksbury ‑ Woburn	11.5
	339	Tewksbury ‑ Golden Hills	15.8
	340	Vermont Yankee ‑ Coolidge	42.7
	342	Canal ‑ Pilgrim ‑ Auburn Street	53.9
	343	Millbury No. 3 ‑ Sandy Pond	31.8
	344	Bridgewater ‑ West Medway	25.3
Charging of 345KV Circuits in New England
(all MVAR values at nominal voltage)
	Circuit			Charging
	#		Terminals	(MVAR)
	346X	North Cambridge ‑ Woburn	120.4
	346Y	North Cambridge ‑ Woburn	120.4
	347	Card ‑ Sherman Road	38.9
	348	Millstone ‑ Southington	46.1
	349X	Mystic ‑ Golden Hills	120.0
	349Y	Mystic ‑ Golden Hills	120.0
	352	Long Mountain ‑ Frost Bridge	13.9
	353	Manchester ‑ Scovill Rock	14.2
	354	Ludlow ‑ Northfield Mountain	25.2
	355	Bridgewater ‑ Pilgrim	21.7
	357	Millbury No. 3 ‑ West Medway	13.5
	358	Mystic ‑ North Cambridge	91.4
	362	Haddam Neck ‑ Southington	21.3
	363	Seabrook ‑ Scobie Pond	26.6
	364	Haddam Neck ‑ Montville	19.5
	368	Manchester ‑ Card	13.6
	369	Seabrook ‑ Timber Swamp Road‑ Newington 	15.2
	371	Millstone ‑ Montville	10.9
	372	Mystic ‑ Kingston Street	87.5
	373	Scobie Pond ‑ Deerfield	15.5
	374	Buxton ‑ Surowiec	21.9
	375	Buxton ‑ Maine Yankee	46.3
	376	Haddam Neck ‑ Scovill Rock	4.4
	377	Surowiec ‑ Maine Yankee	24.3
	378	Mason ‑ Maine Yankee	2.9
	379	Vermont Yankee ‑ Amherst ‑ Scobie Pond	56.6
	381	Northfield Mountain ‑ Vermont Yankee	16.7
	383	Millstone ‑ Card	24.9
	384	Middletown ‑ Scovill Rock	2.4
	385	Deerfield ‑ Buxton	40.6
	386	Buxton ‑ South Gorham ‑ Yarmouth	25.3
	387	East Shore ‑ Scovill Rock	26.7
Charging of 345KV Circuits in New England
(all MVAR values at nominal voltage)

	Circuit			Charging
	#		Terminals	(MVAR)
	388	Maxcys ‑ Orrington	44.9
	389	West Medway ‑ West Walpole	8.8
	391	Buxton ‑ Scobie Pond	56.1
	392	Maine Yankee ‑ Maxcys	21.1
	393	Alps ‑ Berkshire	25.8
	394	Seabrook ‑ Tewksbury	35.7
	395	Manchester ‑ Ludlow ‑ North Bloomfield	34.1
	396	Orrington ‑ Keswick, N. B.	121.4
	398	Pleasant Valley ‑ Long Mountain	15.3

OP 6 & AppA-H
2/9/94

NEW ENGLAND TRANSMISSION REACTORS
(All MVAR Values at Nominal Voltage)

	STATION	NUMBER	SIZE	TOTAL
			(MVAR)	(MVAR)
	Orrington	2	40	80
	Surowiec	2	40	80
	Scobie	2	40	80
	Woburn	1	80	80
	Mystic	1	80	80
	North Cambridge	2	51*	102
	Comerford	12	19.8	237.6
	Sandy Pond	3	160	480

The Chester SVC has a nominal leading capability of 125 MVAR.

* The high impedance of the tertiary windings to which these reactors are connected, significantly depresses the tertiary voltage thereby reducing substantially the reactors MVAR capability.

OP 6 & AppA-H.rtf
9/10/97

	NEW ENGLAND TRANSMISSION CAPACITORS
	(All Values at Nominal Voltage)

Station	Size
MVAR		Station	Size
MVAR	
CONVEX			REMVEC II		
N. Bloomfield #1	52.4		E. Fairfax, VT	24.8	
N. Bloomfield #2	52.4		Sandbar, VT	24.8	
N. Bloomfield #3	52.4		Essex, VT #1	24.8	
Manchester #1	52.4		Essex, VT #2	24.8	
Manchester #2	52.4		Williston, VT	24.8	
Manchester #3	52.4		Middlebury, VT	22.9	
Manchester #4	52.4		N. Rutland, VT	24.3	
Manchester #5	52.4		Berlin, VT	24.8	
Manchester #6	52.4				
Berlin #1	39.8		Millbury	63.0	
Berlin #2	39.8		Pratts Jct.	63.0	
Berlin #3	39.8		Tewksbury #1	63.0	
Frost Bridge #1	52.4		Tewksbury #2	63.0	
Frost Bridge #2	52.4		Kent County	63.0	
Frost Bridge #3	52.4		Manchester St.	63.0	
Plumtree #1	39.8		Barnstable	40.0	
Plumtree #2 	39.8		K-Street-1	53.6	
East Shore #1	42.0		K-Street-2	53.6	
East Shore #2	42.0		Mystic	53.6	
North Haven	42.0		Lexington	53.6	
Sacket	42.0		Baker Street #1	53.6	
Norwalk #1	39.7		Baker Street #2	53.6	
Norwalk #2	39.7		Needham	53.6	
Glenbrook #1	37.8		Framingham/Leland	53.6	
Glenbrook #2	37.8				
Glenbrook #3	37.8		Comerford - AC system     8 @	  31.5	
Glenbrook #4	37.8		Comerford - filters       4 @	  63.0	
Glenbrook #5	39.6		Comerford - AC system     5 @	  63.0	
Darien 	39.6		Sandy Pond - filters      2 @	 178.0	
Waterside	39.6		Sandy Pond - filters      2 @	  85.0	
Agawam #1	52.2		Sandy Pond - filters      2 @	 175.0	
Agawam #2	52.2		Sandy Pond - AC system    2 @	 186.0	
Montville #1	52.4		Sandy Pond - AC system    2 @	  93.0	
Montville #2	52.4				
Southington #1	52.4		TOTAL	3295.8	
Southington #2	52.4				
Southington #3	52.4				
                           TOTAL	1711.6				

New Hampshire	Size
MVAR		Maine	 Size
 MVAR	
Beebe	20.0		Orrington #1	  67.0	
Merrimack #1	37.5		Orrington #2	  67.0	
Merrimack #2	37.5		Orrington #3	  67.0	
			Maine Yankee	  30.6	
TOTAL	95.0		 **TOTAL	 231.6	

** Chester SVC has a nominal lagging capability of 425 MVAR

OP 6 & AppA-H.rtf
9/10/97

INTER-SATELLITE TIES OPERATING AT 115 KV AND ABOVE

REMVEC II - PSNH

	A253	Merrimack 230/115/KV	Autotransformer
	I135N	Monadnock Tap - Monadnock	115KV
	N186	Keene - Westport -Vernon	115KM
	Q195	Moore - Whitefield	115KV
	Y151	Hudson - Pelham - Dracut Jct.	115KV
	K174	North Rd. - Ascutney	115KV
	K 29/60	Littleton - St. Johnsbury	115KV
	D204	Littleton Tap - Littleton	230KV
	379	Vt. Yankee - Amherst - Scobie	345KV
	326	Scobie - Sandy Pond	345KV
	394	Seabrook - Tewksbury	345KV

PSNH - MAINE

	197	Three Rivers - Quaker Hill	115KV
	214	Saco Valley – Lovell	115KV
	250	Three Rivers - Maguire - Louden	115KV
	385	Deerfield - Buxton	345KV
	391	Scobie - Buxton	345KV

CONVEX – REMVEC II

	Y177	Montague - MA. Yankee	115KV
	B128	Harriman - Montague - Millbury	115KV
	F132	Doreen - Partridge - Adams	115KV
	X176	Ludlow - Palmer	115KV
	1870	Mystic - Wood River	115KV
	381	Northfield Mt. - Vt. Yankee	345KV
	302/301	Millbury - Carpenter Hill - Ludlow	345KV
	347	Card - Sherman Rd.	345KV

OP 6 & AppA-H.rtf
5/3/94

INTER‑AREA TIES

New York ‑ New England

	PV20	Plattsburgh ‑ So. Hero ‑ Sandbar 	115KV
	K7	Whitehall ‑ Blissville	115KV
	K6	Hoosick ‑ Bennington	115KV
	E205W	Rotterdam ‑ Bear Swamp	230KV
	393	Alps ‑ Berkshire	345KV
	398	Pleasant Valley ‑ Long Mountain	345KV
	1385	Norwalk Harbor ‑ Northport	138KV
	690	Salisbury – Smithfield	69KV

Brunswick ‑ New England

	396	Keswick ‑ Chester ‑ Orrington	345KV

Hydro Quebec ‑ New England

	Highgate back‑to‑back HVDC 
	Phase II HVDC

OP 6 & AppA-H.rtf
2/9/94

OP 6 Appendix H is available by contacting the ISO directly