Transcript
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HISTORIC AMERICAN ENGINEERING RECORD

HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAERNO. CT-185-C (J Note: This documentation encompasses the Terry Turbine Building, HAER No. CT -185-E

Location:

Dates of Construction:

Engineers:

Present Owners:

Significance:

Project Information:

362 Injun Hollow Road, Haddam, Middlesex County, Connecticut

U.S. Geological Survey Haddam & Deep River Quadrangles UTM Coordinates 18.708748.4595057

1964-1966 Major modifications c 1978 (concrete sumps in Auxiliary Bay), 1979-1982 (waste treatment facilities), 1986-1987 (low-pressure turbine replacement).

Westinghouse Electric Company (turbines, generator, related equipment), Stone & Webster Engineering Corporation (foundations and superstructure), Utility Power Corporation and Kraftwerk Union AG (replacement low-pressure turbine rotors)

Connecticut Yankee Atomic Power Company (CY APCO) 362 Injun Hollow Road, Haddam Neck CT 06424-3022

The Haddam Neck Nuclear Power Plant was one of the earliest commercial scale nuclear power stations in the United States, and was eligible for the National Register of Historic Places. Its function was to generate electricity using steam generated in the reactor. Equipment design was typical of contemporary choices in nuclear-fueled turbines and generators, and had turbine and condenser problems common to plants of this vintage.

CY APCO ceased electrical generation at the Haddam Neck plant in 1996 and initiated decommissioning operations in 1997, subject to authority of the Nuclear Regulatory Commission (NRC). NRC authority brought the project under the purview of federal acts and regulation protecting significant cultural resources from adverse project effects. 1 This documentation was requested by the Connecticut State Historic Preservation Office to mitigate the effects of demolishing a historic power generating facility.

1 National Historic Preservation Act of 1966 (PL 89-655), the National Environmental Policy Act of 1969 (PL 91-190), the Archaeological and Historical Preservation Act (PL 93-291), Executive Order 11593, Procedures for the Protection of Historic and Cultural Properties (36 CFR Part 800).

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 2)

Proj ect Manager and Historian - Michael S. Raber Raber Associates 81 Dayton Road, P.O. Box 46 South Glastonbury, CT 06073 (860) 633-9026

Steam and Electric Power Historian - Gerald Weinstein Photo Recording Associates 40 West 77th Street, Apt. 17b New York, NY 10024 (212) 431-6100

Industrial Archaeologist - Robert Stewart Historical Technologies 1230 Copper Hill Road West Suffield, CT 06093 (860) 668-2928

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 3)

Building Description

Like most structures at the Haddam Neck Nuclear Power Plant, the Turbine Building was oriented on a northwest-southeast axis with the northwest end "called north" on plant drawings. Framed in welded and bolted steel with columns forming 20 and 25-foot-wide bays, the building was structurally continuous with the Service Building and Control Room and housed the turbines and generator which rested on a reinforced concrete pedestal. There were two Turbine Building sections, each with metal roofs; the gable-end 122-foot-high, 106-by-268-foot main building, and a flat-roofed, 38-foot high, 27-foot wide auxiliary bay running along the southeast side of the main building. The auxiliary bay was 240 feet long on the ground floor and 268 feet long above (Figure 1).1

Enameled fluted aluminum siding sheathed all auxiliary bay exterior walls, and most of the north, east, and west walls of the main building. Except at the main building north end, where expansion for a second nuclear unit was originally planned, the exterior siding and metal roof panels were insulated using (in many places) Galbestos, the original asbestos insulated zinc coated steel panee.a The publicly-visible west and south sides presented more finished appearances. A 94-foot-high facade of glazed brown brick covered the south wall to the roof line and wrapped around the west facade almost to the first column line, with the same brick continuing along the rest of the west and north sides as a 4.5-foot-high base. North of the high brick face on the west side, paired 2.5-foot-wide vertical plastic strips flanked insulated aluminum panels on alternating exterior columns, providing natural interior light and dividing most of the west facade into five exterior bays. The northernmost of these bays was hidden by the west facade of the adjacent Administration Building and was blank except for a personnel door. The remaining four bays, 45 or 50 feet wide, were each distinguished by an 8-foot-high, 30.5- or 35-foot-wide arched louvered aluminum panels, which mirrored the two, somewhat larger arched sections on the west side of the Administration Building. As discussed below, the second and third arched panels from the south were removable to allow for condenser tube replacement, and a 20-by-9.5-foot area of removable wall panels above the southernmost of the removable arched sections allowed for withdrawal of certain feed water heater tubes.

Additional natural light was admitted by strips of bronze colored-plastic windows along the wall/roof junctions of the east and west sides, by vertical plastic panels in the pediments under the gable ends, and by a 107 -foot-long strip of 4.5-foot-high aluminum-sash windows along the east side of the operating floor. The east, north, and south exterior walls were otherwise almost blank, penetrated by one man door each at the north and south ground

a Profiled metal sheeting with asbestos felt on both sides coated with either bitumen or polyester resin

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 4)

levels, a rolling steel garage door on the south side, and a man door on the east side of the operating floor which accessed the roof of the auxiliary bay. Eleven transverse gravity roof ventilators at 25-foot-centers topped the main Turbine Building exterior.

Substructure and turbine-generator pedestal components were completed in 1964, during the earliest phases of plant construction (Historic aerial view 1965-Figure 12). Beneath the condensers described below as part of the plant heat cycle, steel and concrete circulating "vater intakes and discharges were installed to depths reaching elevation -6 feet. The ground floor concrete slab over these features was poured at the typical plant ground elevation of 21.5 feet, and supported steel superstructure columns. The reinforced-concrete pedestal had footings below the ground floor and extended to the operating floor elevation of 59.5 feet. The pedestal consisted of large columns and 10-foot-deep beams, with open construction allowing for placement of condensers and auxiliary equipment within the pedestal. Bottle­shaped in plan, the pedestal was widest under the low-pressure turbines (Figure 2, [Historic photo 1967-002.jpg]).3 The operating floor elevation was presumably dictated by approximate 3 I-foot height of the condenser tops above the circulating water pipe entries.4

F our openings in the operating floor level allowed for the insetting of the three turbine casings and generator.

The perimeter columns of the main Turbine Building superstructure were largest up to the 94.8-foot elevation and formed a shelf to support bridge crane rails. Smaller-section columns were attached to the outer portions of the perimeter columns to support the upper wall section and roof girders (Photograph Figure 9) Surrounding the turbine-generator pedestal, but structurally independent from it, were the steel-framed mezzanine (el. 37.5 feet) and re­heater (el. 47.5 feet) levels, which contained most of the auxiliary equipment systems dedicated to turbine operation. The mezzanine level continued across the auxiliary bay. 5 An electrically-powered Manning, Maxwell and Moore Company bridge crane traversed the entire length of the main building, supported on crane rails reaching an elevation of 98.25 feet. The main hook capacity was 125 tons. There was also an auxiliary 20-ton hook. Components could be brought up to the various levels by the crane through a large hoist way opening through the floors at the southwest comer.6 Trolley beams mounted on the steel framing of the mezzanine and re-heater levels facilitated withdrawal of moisture separator re­heater, condenser, and feed water heater tubes for repairs. The main ventilation system comprised natural and forced-air flow from the louvers along the base of the west wall and out through vents in the roof. 7 The natural flow relied on the stack effect of rising warm air.8 Fans also supplied forced air flow. For heating, air warmed by radiation from equipment was collected by fans and directed down to lower levels.

The major equipment in the Turbine Building served two main functions; conversion of steam to electrical energy, and condensation of steam for feed water return to the steam

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 5)

generators in Reactor Containment., These operations were controlled to maintain the overall plant heat balance as well as to supply power to the grid and the rest of the plant. Most equipment critical to the heat balance was located in the Turbine Building. A variety of secondary systems supplied and regulated water and air for these functions, often controlled by a wide range of control valves. Housed on the ground floor primarily in the Auxiliary Bay, secondary systems included the compressors, receivers, filters, and driers of the Control Air System, the intake filters, compressors, moisture separators, and receiver for the Service Air System, and components of the Water Treatment System.

The flow of steam, gases, and water through the turbine building was controlled by on/off and volume control (throttling) valves. These valve types, operated by threaded spindles, 'were in use before the Industrial Revolution. 9 For simple shut-off service, gate valves blocked the flow with a sliding wedge. For volume control, globe valves with circular discs pressing on circular seats were preferred. To insure flow in the correct direction, non-return valves were used, also a very old design. Pressure-reducing valves enabled low pressure devices to take steam from the main supply without damage. 10 '

There were three main systems actuating plant valves: air, electric, and oil. The choice of actuation was based on the type of valve, the medium being controlled, and the requirements for safety backup redundancy. Many valves were actuated by the lOO-psigb Control Air System, which ran through the plant and had backup receivers to provide emergency activation power even if the system failed. 11 The admission of air to the activation mechanism was made by solenoids operated from the control room with several backup electrical systems. 12 The air-operated valves were often designed so that if they failed, they would automatically go to the safe position. 13 Valves for isolating portions of the systems were generally electric-motor operated with both actuation signals and power coming from un-interruptible supplies which would continue to operated even in an emergency.14 Both classes of valves could be set to operate automatically when signaled by an unsafe condition in the plant. 1S In most cases they also had manual overrides and hand wheels for local control. A third type of valve operated by oil pressure was used on the main turbine. These 'were powered by oil from the bearing-lube system and were actuated by electric solenoids. Redundancy was insured by backup pumps, backup electrical supply to the solenoids and fail-to-safe-position construction. 16

h Steam pressure was stated as pounds per square inch gage (psig) which was the pressure over the nominal atmospheric pressure at sea level of 14.7 pounds per square inch (psi). Pressure over true 0 was known as pounds per square inch absolute (psia).

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 6)

Pour 24-inch-diameter main steam lines (one from each steam generator) entered the auxiliary bay through the east wall at the 47.5-foot elevation, in line with the main building's re-heater level. The steam lines were constructed of nearly l-inch-thick carbon steel pipe, and hung from ceiling steelwork to allow movement during thermal expansion and contraction. 17 As it entered the turbine building the steam was measured by flow detectors on each line. Pressure differential devices automatically regulated the feed flow into the generators based on the steam flow out and signaled the control room. If the steam flow exceeded the feed flow by more than 20 percent the detectors sent a trip signal to the reactor to protect the steam generators from low water. 18 The main steam lines were welded 19 into the south side of the 36-inch-diameter, 1.33-inch-thick manifold suspended from the ceiling on an east/west axis. 20 The manifold served as a header from which steam could be taken to run various systems discussed below. In addition to the two turbine supply lines, auxiliary steam pipes went to the re-heater sections of the four moisture separator re-heaters, steam jet air and priming ejectors, turbine gland seal valve, and steam heating system?1 The High-Pressure Steam Dump System came out of the header with two 12-inch-diameter steam lines. They could send steam directly to the condensers in the event of a turbine trip without reactor trip?2 Two valve stations in the turbine building consisting of five valves on each line gave reliability to the critical steam dump function, and provided security against an accidental dump?3 The main steam pipes were insulated with asbestos and covered with stainless steel casings. The insulation minimized the heat losses that inevitably occur when bringing steam to different locations. The design basis of this system was for 985 psig steam pressure at 650oP.24

Two 30-inch-diameter, 1.23-inch-thick main steam pipes were welded to the north side of the manifold and made a large diameter arc west into the turbine building at the 50-foot elevation, from which point they then made another large diameter arc south and formed S bends to rise up through the operating floor?5 The steam pipes terminated at two main stop valves anchored to the floor at the high-pressure end of the turbine. The total steam flow was between 7.341 and 7.670 million pounds per hour. By the time the steam had reached the stop valves, it had lost pressure and heat.

Connecticut Yankee documents show the pressure at the valves at around 640 psig, 50 pounds less than that issued by the steam generators; steam temperature at the stop valves was about 490oP, about 11 degrees less than that at the steam generator outlets?6 The steam was described as dry and saturated, meaning it had moisture content under 0.25 percent and a temperature that was the same as that of the water from which it was liberated.27

The thermal energy to rotating energy conversion device was a Westinghouse/KWU three­casing, tandem compound turbine direct-connected to a Westinghouse generator. The turbine included one high-pressure and two low-pressure units, which was typical of many large

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 7)

power plants from the early 20th century. The nominal turbine output was 619,328 KW with a maximum output of 648,527 KW or almost 1,000,000 hp.28 At that load, the turbine was taking 7.463 million pounds of steam per hour. The casings of the Connecticut Yankee unit were all on a single shaft with a high-pressure element exhausting into twin low-pressure units. This design was known as a tandem- compound arrangement to distinguish it from cross-compound types which had two or three separate turbine shafts. 29 Turbines were also typed according to the directional flow of steam through the casing. The Connecticut Yankee units were double-axial flow types, in which the steam entered the center of the casing and flowed outward to each end. 30 One advantage of this design was that the thrust on the blades "vas well balanced which simplified the design of the support bearings. 31 The Connecticut Yankee turbines were also categorized by their exhaust arrangements. The steam exhausted each casing from two ports at each end, called quadruple exhaust. The splitting of the exhaust path allowed a greater flow without greatly increasing the size of the casing ends. This was an additional benefit of the double-flow design. 32 The steam flow volume dictated the size of the exhaust ports, which in turn dictated the length of the last row of blades in each stage. Blade size is a critical factor in turbines because of centrifugal forces acting to pull the blades out by the roots. (See Appendix A) Blade length and thus casing size had to be increased as steam pressure dropped and steam volume increased during the flow of steam through the turbine?3 The constraint of relatively poor steam conditions from the pressurized water reactor generators on exhaust-port design and blade-tip speed required larger-diameter blading in the last stages than were found in fossil-fuel power stations. This limited the rotor speed to 1800 rpm?4

The steam entered the turbine through the two hydraulic, on/off, swinging clapper type stop valves. 35 Their main purpose was to provide emergency shut off to prevent turbine over­speed. 36 The valves had a built-in safety feature: they were held open by oil pressure but closed by a s,fring and steam flow, thus defaulting to shutdown (trip) in the event of a power supply 10ss.3 Other malfunction scenarios such as over speed, low condenser vacuum or low bearing oil would shut off the steam flow?8 They would also close by solenoid signal if the reactor scrammed.39 The stop valves were sized so that one valve could supply enough steam for 2/3 output with the other valve closed for testing or repair. 40 Steam flowed through the stop valves and into four hydraulic plug type governor valves which were welded in pairs to each stop-valve body.41 They were actuated by servomotors linked to the turbine-governing devices as the main method of speed control and emergency shutoff during turbine run. 42 G-enerally the plant ran with three of the valves fully open with governor actuation on the fourth valve. 43 High-pressure hydraulic oil for shutoff and governing valves was provided by the main oil pump though the Turbine Control Oil System (TCOS).44 Since the main oil pump was driven directly by the rotor, an AC electric motor pump supplied the system during startup and shutdown.45 The TCOS also supplied low-pressure oil to the governor control block, located in the governor pedestal, which detected speed variations via an oil

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING ( Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 8)

line pressurized by an impeller on the turbine shaft.46 The variations could be caused by changes in the steam supply and/or the electrical load. The control block magnified variations enough to operate the governor valve-control servomotors. 47 Changes in speed or malfunction scenarios generally caused a differential of oil pressure on one side of a relay piston allowing springs to activate the valve servomotors controlling the oil actuators of the valves. In the case of the control valves, as the electrical load on the generator rose and fell, the governor raised or lowered the oil pressure to open and close the fourth valve in small increments, modifying the steam flow to keep the speed at 1800 rpm. 48 Once connected to the grid, the grid maintains 60 cycles and changes to governor valve position increase or decrease the load on the governor. The control block also contained an auxiliary governor and malfunction trip devices. For critical over speed protection, a centrifugal weight device on the shaft automatically contacted a trip relay if the speed increased by more than 45 rpm, shutting all the valves. 49 The stop and governor valves were also remotely controlled by personnel in the control room to admit and throttle steam admission during startup, synchronizing, and shutdown. 50

The casing for the high-pressure turbine was a fabricated weldment of carbon steel, consisting of upper and lower shells bolted together at machined mating surfaces. 51 These surfaces were so precisely finished that no gasketing material was needed; only boiled 1 inseed oil was used as a seal. 52 The lower outer casing was attached to the concrete foundation by lugs and keys to allow movement with expansion and contraction. The stationary blade rings were doweled into the inside surfaces of the casings. 53 The casing was insulated with asbestos and clad with sheet metal for a neat appearance. 54 A separate sheet metal enclosure covered the stop valves, governor and control valves.

Steam leaving each governor valve was sent through a pipe to a sector of the first rows of stationary blades or vanes. 55 Two pipes were in the upper casing and two in the lower, serving as nozzles for steam admission to the moving element. The rotative motion was caused by a flow of steam passing alternate rows of stationary blades mounted on the inner casing and rotating rows attached to a spindle. In the 1884 Parsons design, the pressure drop in the steam flow path was equal between the fixed and moving blades. The fixed blades served as nozzles in which the steam expanded and reached the speed of the moving blades. The steam continued to expand in the moving blades, changing its momentum and producing a rotative force via reaction. 56 Each blade row utilized an additional expansion of the steam and the rows got larger in diameter as the steam flowed through the turbine. 57 Rateau in France and General Electric in the United States brought out a competing design around 1905 using differently-shaped impulse blades: In impulse turbines, steam issuing from the stationary nozzle blades was reduced in pressure and increased the velocity. The high velocity steam impinged on the moving blades causing rotation by impulsive force. 58 By I 907 Westinghouse designers realized that an efficient turbine combined elements of both

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 9)

types. 59 An impulse turbine needs fewer rows of blades for the same power output.60 That advantage was somewhat negated by the difficulties of sealing the ends of the blades against steam leakage. Impulse blading also facilitated steam throttling, and allowed for turbine designs which were more efficient at partial loads. 61Thus the Connecticut Yankee high­pressure (hp) element had Rateau type impulse blading on the first stage meeting the steam, and seven reaction stages following on each half of the rotor.62

The rotor for the high-pressure turbine section was of solid-forged construction. 63 A stub extension shaft was bolted to the governor end to carry the main oil pump, governor impeller and over speed trip weight. 64 The forging was made large enough so that the blade mounting discs were created by machining away the surrounding metal. The airfoil-shaped blades were rooted into the discs. The rotating blades resisted ejection from centrifugal force with inverted serrated "Christmas-tree" roots in the impulse section and inverted "T" roots in the reaction section. 65 The stationary nozzles and blades were doweled or keyed into the casing to ensure correct position relative to the moving blades. Both moving and stationa7 elements had shroud or seal strips to limit steam leakage past the ends and provide rigidity. 6

At various stages in the steam flow, steam was extracted or bled to supply auxiliaries described below. In addition, steam exiting the high-pressure turbine was diverted down to the re-heater floor below for reheating and drying before being sent to the low pressure turbines. Shaft penetrations at either end of the casing were leak points. 67 Two sets of gland seals attached to the casings and closely surrounding the shaft prevented air from entering the turbine or steam from exiting. These consisted of labyrinth packing in which steam and air moving along the spinning shafts were forced to travel in a zigzag pattern between grooves cut in the shaft and surrounding soft seal rings. At each change in direction there was a loss in velocity.68 Expansion chambers in the glands provided a space for the leaking steam to loose energy.69 High pressure steam from the auxiliary steam header was admitted to a portion of the gland to provide an additional screen against air leakage in during low power operation.70 Once pressure rose in the casing this was not needed. Leakage and sealing steam were drawn from the glands by blowers and condensed in adjacent gland seal condensers. 71

A separate Cylinder Heating Steam system supplied steam to the glands to prevent leaks from uneven thermal expansion. 72

The entire weight of the rotor was literally floated on a film of oil in two split-shell, spherical babbitted bearings at each end outside of the casings of each low pressure and high pressure turbine. In this design, going back to the earliest days of power machinery, a cast-steel pedestal held a split cylindrical shell around the shaft. Babbitt antifriction metal, a lead and tin alloy patented in 1839, was poured into the shell and finished to very close tolerance with the shaft journals.73 The bottom of the shell rested in a spherical bored seat which allowed the bearing to move and align itself with the shaft.74 The main oil pump forced oil into the

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 10)

bearing, forming a fluid wedge between the metal surfaces. While the double-row flow arrangement provided well balanced loads, a Kingsbury-type thrust bearing was also provided. This design originally pioneered by Westinghouse for supporting the weight of hydraulic turbines, had a collar around the shaft with oil-immersed babbitted pads on either side maintaining very precise shaft position.75 A complex system maintained pressure and flow in the bearings and then cooled and filtered the used oil. 76 During turbine start up an auxiliary electric pump pressurized the supply lines until sufficient speed was reached for a rotor shaft mounted centrifugal pump to take over. Separate oil lift pumps on each low pressure turbine bearing lifted the rotor before the turning gear was started.77 Because loss of oil pressure could lead to a destructive failure, there was an additional electric emergency pump run from the plant's station batteries. Clearance space between the shaft and bearing resulted in continuous flow of oil. Used oil was cooled in shell and tube coolers. Impurities such as water and entrained bearing metal were removed in filters and centrifugal purifiers. 78

New and processed circulating oil was stored in two 12,500 gallon tanks in the free-standing oil storage room on the ground floor at the north end of the turbine building. 79 The 10,000 gallon main reservoir was at the same level north of the condensers.

All the attachment points between high-temperature elements and ambient temperature parts had to allow for relative movement. The very close tolerance between the moving and stationary blades required monitoring. Differential expansion probes measured the relative movement between the rotor and the casing.80 Vibration monitors mounted at each bearing facilitated balancing of the rotors at low speeds. They also indicated problems during run. At the rear end of the high pressure turbine shaft a bolted coupling attached to the mating coupling on the first low-pressure rotor. Steam leaving the high-pressure turbine81 could be diverted directly to the condenser by the Low-Pressure Steam Dump System. This ·would prevent over-speeding of the turbine during trip scenarios by reducing the low-pressure turbines' input. The safe limit of this over-speed protection function was set at 128 percent of 1800 rpm.

Towards the end of reciprocating steam engine development in the late 19th century, builders experimented with reheating. 82 By adding more heat to the steam (superheating) between expansion stages they hoped to improve efficiency. Turbine builders first applied reheat cycles to American power stations in the mid 1920s, but the practice remained uncommon until after W orId War II.83 Steam conditions at the high-pressure end of the Connecticut Yankee turbine were generally adequate for reliability, but once the steam left the high pressure unit, it was severely degraded. The drop in pressure through the unit from 640 to 195 psig, and in temperature from 490 to 371°F, resulted in partial condensation of the steam. 84 When entrained in the steam flow, the resulting 9-10 percent moisture could cause erosion of the low-pressure turbine blades and stress corrosion cracking of rotor parts.85 To reduce this problem, the steam was dried and reheated after leaving the high-pressure

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 11)

turbine. 86 The "crossover" exhaust steam87 was directed from the four high-pressure exhaust ports through 29-inch lines to four moisture separator re-heaters (MSRs) mounted on the mezzanine floor adjacent to each side of the low-pressure turbines. 88 These were 9-foot­diameter, 41-foot-Iong tubular pressure vessels. Upon entering the MSRs, the exhaust steam passed through demisting screens which trapped the entrained water and drained it away, leaving the steam essentially dry.89 Approximately 265 tons of water was removed every hour and drained to the feed water heating system.90 After passing through the screens, exhaust steam flowed over a tube bundle charged with 690° F steam tapped directly from the steam manifold in the auxiliar(' bay. Baffles caused the exhaust steam to separate and pass through four groups of tubes. 9 The high pressure steam gave up heat to the exhaust adding 90-1000 F of superheat and brought the steam temperature back up to 461°F, This process consumed 5% of the steam generator flow.92 Plant engineers acknowledged that while, in theory, the thermal benefits were uncertain, the moisture reduction function made them worth their cost and maintenance. 93 The reheated dried steam left the MSR units by four pipes 'which went through the operating floor, to meet over and enter the center of the adjacent low-pressure turbine casings (two pipes/casing).94 The condensed heating steam was collected and sent to the feed heating system and helped to maintain system heat balance.95

The MSR's were laid out with clearance for their tubes to be pulled south for repair, using trolley beams mounted from steel building framing. 96

The two low-pressure turbines were numbered 1A and I B to distinguish them from those in the projected #2 unit. They had separate casings and rotors. Each was split horizontally like the high-pressure unit, and in addition had separate outer and inner sections. 97 The outer casing formed the exhaust hood which directed the exhaust steam to the condensers. The shape of the hoods was critical to the free flow of the exhaust from the casing. 98 During low­steam conditions the rotating blades could act as fans, overheating the exhaust hoods (outer casings).99 This was controlled with condensate spray manifolds in the hoods. The casings formed the supports for the rotor bearings, which were of similar construction to the high­pressure unit. 100 The inner casings were supported by the outer casings and held the stationary blades.

i\S described below, steam was also extracted between stages of the low pressure turbines to heat feed water sent back to the steam generators in Reactor Containment (HAER No. CT -I85-B). Steam extraction from the three turbines reduced steam flow to approximately 4.40 million pounds per hour passing into the condensers. 101 The low-pressure turbines contributed about 70 percent of the output to the condensers. 102 Unlike the high-pressure unit, the low-pressure casings were not insulated. 103 Steam entered the units at around 174 psi. Because the steam had increased in volume by hundreds of cubic feet after leaving the high pressure turbine, the low-pressure units were much larger to accommodate that expansion. 104

The larger casings required rotors of a size that exceeded forging capacity, so they were of

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 12)

built-up design. Steel alloy blade mounting discs were expanded, pressed, and shrunk on to the spindle and locked with keys to prevent rotation. 105

As originally constructed, there were ten reaction stages on each half of the rotors.106

As the steam flowed through the low-pressure blades it continued to gain in volume so even with four exhaust paths, the last stage of blades had to be 44 inches long to cover the passages. "Vith the increase in volume there was also an increase in steam velocity to over 600 ft. per second. 107 Coupled with the increase in moisture content as the temperature dropped, these steam conditions put the last three rows of blades at risk. The ends of their leading edges vvere protected with strips of Stellite, a hard cobalt based alloy. 108 The long blades in the last stages were highly twisted in shape, and subject to torsional and resonance vibrations. 109

Metal wedges between the blades helped to stabilize them. "Christmas-tree"-style blade roots vvere used, similar to those in the high-pressure reaction stages. 110 To control moisture, the last blade rows had slots to allow steam to flow directly to the condensers pulling out entrained water. As in the high-pressure turbine, steam was extracted between blade rows to heat feed water. The extraction points at the bottom of the casings were an additional source of moisture removal. 111 Each low-pressure casing was mounted directly over and exhausted into a surface condenser described below.

Entry points of the rotor shafts were sealed with glands similar to those used on the high­pressure turbine. On the low-pressure units, where there was a vacuum at the ends of the casings, the main problem was keeping the exterior air from rushing in. 112 Steam was continuously injected into these seals to maintain equilibrium. 113 The rotors were each about 60 feet long and weighed over 118 tons. The long span between bearings and the weight of the rotors made it imperative that the unit never be stopped for any length of time, or sagging vvould occur. To avoid this problem when the units were not operating, a motorized turning gear was mounted alongside the IB turbine (closest to the generator). The gear automatically began rotating the shaft at 1. 5 rpm as soon as coast-down was completed. 114 During long shutdowns, after the rotors had cooled to ambient temperature, the unit was manually engaged to turn the rotor daily. 115

I)esign and construction of the original Westinghouse low-pressure units had flaws causing reliability problems. These led to refurbishments and reconstructions, and finally to their replacement during the 1987 refueling outage. 116 The new low pressure rotors were supplied by the Utility Power Corporation, a subsidiary of the German firm Kraftwerk Union AG (KWU). Their engineers measured the units and utilized original drawings to design the replacements, which were made to metric specifications and required metric tools for maintenance. 117 The new units were generally similar to the originals but with impulse blading in the first rows, and eight reaction stages following making nine stages at each end, one less than in the original units.1l8 The last-stage blade length was the same in as the

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 13)

'Vestinghouse units, but the last three rows were made free standing. Root designs were changed to "T" slots for the first six rows. 119 Though also of built-up construction, the new rotors had advanced engineering, metallurgy and manufacturing making them reliable. The disc bore keyways, an area prone to stress corrosion cracking, were of improved design.

120

Mean hours between inspections went up from 60,000 to 100,000.121 The new blade configuration of the rotors required completely new upper and lower inner casings. 122 In spite of having one less blade row, the new rotors used the same extraction points as the originals. 123 The casings had II crash rings II ( strengthened sections) for improved protection against ejected rotor or blade parts due to over speed failure. 124 The new inner casings were designed to fit into the original Westinghouse outer casings, avoiding modifications to the turbine-generator pedestal. The hood sprays were improved with outside casing accessibility.125 The heavier replacement rotors made it necessary to increase the capacity of the bearing oil lift system. Improved vibration and differential expansion monitoring probes \vere installed, and exhaust pressure monitoring probes were added for the first time. 126The two rotors were attached to each other by bolted coupling flanges. As the original bolts had proven to be hard to install and remove, new quick connect types were used on the

1 . 127 rep acement unIts.

The new components were barged up the Connecticut River and then up the discharge canal. Multi-wheeled Halliwell conveyors moved the units across the underground condensing water discharge structure and to the southwest end of the turbine building. 128 Parts were then hoisted by the traveling crane through the access opening running through the floors. New calculations were done for the loads on the ground and for staging on the main floor as the units were somewhat heavier than the originals. 129 This documentation has not determined how the original components were disposed of, or whether any warranty action was taken on 'Vestinghouse. Generally, the life span of fossil-fuel turbine-generator sets was taken to be a minimum of 20 years. 130 The original low-pressure elements of the Connecticut Yankee turbine/generator just reached that milestone.

After the steam finished its work in the turbines, it was condensed back to water and recycled. Two surface condensers (nos. IA and IB) stood directly below the low-pressure turbines. The condensers were of shell and-tube construction in which cooling water and exhaust steam were not mixed, a standard design evolved from mid-19th -century steamships which needed fresh water for feeding high pressure boilers. 131 In principal the Connecticut Yankee condensers simply reversed the heat exchange of the steam generators. Water flowing through tubes cooled and condensed the surrounding steam. At full load, 93,000 gallons per minute (gym) of water was required for condensation. 132

Each condenser was a welded steel tank mounted rigidly on the ground floor and connected to the bottom of its respective low-pressure turbine by a rubber expansion joint. Mounted in

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 14)

each condenser neck, just under the turbine connection were two feed water heater shells. Below them was the condenser tube section containing over 13,000 50-foot-Iong, l-inch­diameter tubes.133 The total tube surface area was 350,000 square feet, about three times more than that of the steam generators. 134 The tubes, mounted horizontally, went from one end of the shell to the other, and were attached to the sides by tube plates. Intermediate supports along the tube runs kept them from sagging. The ends of the tubes came through drilled holes in the plates and were sealed there. There were two separate tube plates at the inlet end and two at the outlet end of each condenser. Surrounding the exterior of each tube plate and bolted onto the shell was a water box, consisting of a steel semi-cylindrical casing, vvhich channeled the cooling water flow into and out of the tubes. The water boxes, tube plates and sealed tube ends formed a contained pathway for the cooling water to travel through the condenser shell insuring that it did not mix with the steam. The twin set of water flow paths (divided water boxes) allowed one set to be closed for servicing while the other functioned at reduced turbine output.

The cooling water flowed through the tubes in a single pass, a design which required much lTIOre cooling water flow than the more common two-pass type. 135 Steam from the turbine exhausts flowed down past the feed water heater shells and into baffling that prevented damage to the tubes from direct steam impingement. After leaving the baffling at reduced velocity, the steam flowed around the outside of the water-cooled tubes. Contact with the tubes condensed the steam forming water droplets that fell to the bottom of the shells. The collection point in each condenser was a hot well from which the Condensate and Feed water systems drew their supply. Condenser tubes inevitably needed replacement due to wear and corrosion. During tube renewal the old tubes were withdrawn and new tubes inserted though the removable arched panels in the west outer wall adjacent to the units.136 In the original installation most of the tubes were Admiralty Brass, an alloy of brass, zinc and tin. 137 There vvere also some stainless steel tubes in areas where there was a risk of damage from steam impingement and ammonia attack. Maintenance costs of the brass tubes were high due to stress corrosion cracking and the first tube replacement occurred in 1977.138 By 1986 all the tubes were again replaced in a series of repair episodes with a stainless steel alloy called Trent Sea-Cure. 139 Though the new tubes had enhanced resistance to biofouling, they proved vulnerable to vibration cracking which required additional supportS. 140

Circulating water to condense the exhaust steam was pumped from the river and arrived at the west side of the Turbine Building at the 12-foot elevation via four 66-inch-diameter carbon-steel pipes. 141 Two pipes rose up through the floor slab adjacent to each condenser. 142

Each pipe supplied one half of the condenser by a flexible connection to a water box. 143 The circulating water pumps in the Screenwell House (HAER No. CT-185 A) could not pump vvater all the way from the river intake level of -15 ft to the tops of the condenser tubes at 35.5 ft when starting up. 144 They were augmented by a vacuum priming system including two

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 15)

vacuum priming pumps on the Turbine Building ground floor and vacuum priming tanks attached to each of the four water boxes. 145 Once the condensers were filled and the flow started, the priming pumps were not needed for that purpose. After exiting the condenser tubes and outlet water box, cooling water was piped out in four carbon-steel pipes of similar construction to those connected to the inlet water boxes. 146 The pipes carried the water about 23 feet to a concrete discharge tunnel running next to the east wall of the turbine building, directly under the auxiliary bay.147 The tunnel was 12 feet wide by 15 feet high; an even larger tunnel was built next to it with a shared wall to accommodate the discharge requirements of the never-built second reactor. 148

In addition to allowing the condensed steam to be recycled as feed water, the condensers provided the important benefit of vacuum. When condensed in a closed space, steam rapidly loses volume producing a vacuum. This allowed the steam flowing through the low-pressure turbines to do work considerably below 14.7 1 bs atmospheric pressure. 149 The Connecticut Yankee condensers produced a vacuum of up to 1.9 in. Hg absolute (28.1 inches of mercury). * The additional use of steam below 14.7 psig in the turbines provided a large portion of their total outpUt. 150 While the vacuum-forming process was naturally the result of condensation, air build-up would have negated the level of vacuum in a short time. Two priming and two main two-stage air ejector units on the second level mezzanine were the primary units used to start and maintain the vacuum. 151 Steam from the main steam manifold was piped into the ejectors and flowed through velocity-increasing venturi nozzles in communication with the condensers. The high speed steam flow in effect, "dragged" the air out of the condensers. 152 The discharged condenser air was sent to the atmosphere by the primary vent stack located northwest of Reactor Containment. A radiation monitor was located in the stack to detect air contaminated by radioactive steam resulting from a steam generator tube leak 153 The air ejectors could also aid in reactor decay heat removal by blowing steam into the atmosphere if the high pressure steam dump system was not available. 154 In addition to its job of topping off the condensers, the vacuum priming system also removed air from supply piping, water boxes, and tubes before startup. The system remained on during turbine run to remove collected air in the tubes and water boxes. 155 Condenser vacuum control was critical to plant efficiency. The levels in each unit had to match closely or the turbines would be un-evenly loaded. A rise in back pressure to 24.5 in. 'would lead to an emergency shut down. 156

The condensers provided an important safety function. In the event of a turbine trip and reactor trip, steam could be bypassed directly from the steam header to the condensers by the high pressure steam dump system. 157

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 16)

Condensate and Feed water Pumping

The condensed steam (condensate) was the main source of feed water for the steam generators. The collection points were the hot wells which constituted the lower two feet of the condenser shell, and normally held 33,000 gallons. Two condensate pumps on the Turbine Building ground floor removed water from the hot wells and started it on its route to Reactor Containment. 158 These were 6200-gpm, 1500-hp AC induction-motor-driven vertical pumps with suction and pressure stages.

They pulled at condenser vacuum and output at 350 psi. The feed water first passed through the condenser air ejectors to condense their exhaust. 159 It then flowed through two parallel trains of five low-pressure feed water heaters described below (heating steam taken from low-pressure turbines) to the steam generator feed pumps on the main floor of the auxiliary bay. Most exhaust steam used in the feed water system heaters drained into the main condenser, but there were still losses requiring replenishment. The "make-up feed" was drawn from two wells south of the plant. 160 and stored in the 100,000-gal. demineralized "vater tank near Reactor Containment (TK-25-I A). This tank fed directly into the condenser hot wells in the event it received a low level signal. 161 The inside piping diameters in this system varied from 30 inches at the hot wells to 16 inches through the feed water heaters leading to 18-inch suctions for the feed pumps. Leaks from steam generator or condenser tubes could pollute the feed water leading to damage. 162 The original design included two demineralizers on the ground floor of the auxiliary bay that were used to treat well water prior to use in the plant systems. Later in the plant's operating history truck mounted units proved to be a better option. Provision for adding corrosion inhibitors to feed water also existed in the auxiliary bay. After leaving the condensate feed pumps, the condensate water flow was considered part of the feed water system. 163

The system had the important role of providing a contiguous heat sink ( absorber) of reactor generator heat. 164 The two steam generator feed water pumps were horizontal 960-gallons per minute (gpm), 4500 hp induction- motor-driven centrifugal units. The feed water left the pumps at 1100 psi and went through a last high-pressure stage of heating noted below. The two lines fed an I8-inch header in the Turbine Building from which a separate I2-inch feed line was routed to each steam generator in Reactor Containment. 165 Each of condensate and feed water pump took half the station load. All had to be operated to pump the 7.6 million gallons per hour (gph) required under fullload. 166

Auxiliary Feed Water System-Terry Turbine Building

To ensure a continuous un-interruptible supply of feedwater if the main Feedwater system was not functional, Connecticut Yankee had an Auxiliary Feedwater System supplied from

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 17)

the Terry Turbine building. The facility was named after two Terry Turbine driven auxiliary feed pumps. 167 The Terry turbine was developed by the Terry Steam Turbine Company of Hartford, CT early in the 20th century, 168 and became a favored prime mover in the power industry for driving fans and boiler feed pumps due to its ruggedness, relatively high efficiency and high speed. 169 The single forged turbine wheel had multiple semi-circular "buckets" machined directly in the forging and reversing chambers in the surrounding casing. Steam was admitted directly into the buckets causing them to move from the impact. Steam "vas then turned 180 degrees and re-admitted to the blades several times until most of the energy was gone. The unit had very large clearances between the turbine wheel buckets and the reversing chambers for reliability and could even continue to operate if the steam supply turned to water. 170

The pumps were 450-gpm multi-stage centrifugal types which supplied their own lubrication, shaft sealing, and cooling, independent of plant systems. The Terry turbines were the only rotative steam powered auxiliaries in the plant. Even if all plant electric power and backup diesel generators were lost, the Terry turbines could continue to provide pumping power from steam produced by decay heat from the reactor.

The atmospheric dump valves were located at the Terry Turbine enclosure. When a rapid shutdown of the unit was necessary, equipment operators would dash out the east door of the turbine hall, down the outside stairs, across the roof of the service building to the Terry Turbine enclosure to manually open the atmospheric dump valves to vent steam away from the turbine. 171

An auxiliary feed water system, with two pumps operated by steam turbines, was located in the nearby Terry Turbine Building (Figures 1 and 8). These units were driven by steam from the steam generators and provided feed water to the steam governors removing heat from the reactor when main feed pumps were not functioning. Main feed water air-operated regulating valves controlled the flow of water to the steam generators and maintained their level. 172 The valves in the feed water system automatically opened on turbine trip to reduce reactor coolant temperatures. 173 If their control air failed they would close automatically to prevent overfeeding which could overfill steam generators, resulting in ineffective moisture removal and blade damage and missile ejection caused by excess water. 174

It was well established by the middle of the 19th century that preheating the water goin~ into a boiler with waste heat gases saved the amount of fuel required to raise steam. l7 The regenerative (extraction) system was developed cl915 in which steam was bled of the turbine between blade-row pressure stages to heat the feed water. 176 Although there was a net loss of steam for power production, overall system efficiency was increased, in part due to the

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 18)

reduction in steam entry into the condensers. l77 The combination of reheating between turbines and regenerative feed heating improved the overall station efficiency even more.

In the Connecticut Yankee regenerative system, there were six stages of heating. l78 This process was split between six pairs of feed water heaters in different locations in the main and auxiliary sections of the Turbine Building, forming two separate trains. 179 The feed water heaters were pressure vessels filled with a tube bundle. Feed water forced through the tubes was heated by condensing a flow of steam passing through the vessel. 180 All the feed heating steam was bled from six extraction points (stages) between the blade rows in the lower casings of the turbines. The heating process began at the condensers and continued in the direction of Reactor Containment. However, the heaters were numbered according to their steam extraction location (blade row) in the turbines which was in reverse order to the feed flOW. 181 Heaters Nos. 6-2 were technically part of the condensate system flow path. 182

Each heater train was designated IA or IB from its respective source of feed water, the IA and IB condenser hot wells. 183 The first portion of feed water heating (stage 6 and 5) occurred in four low-pressure units mounted two each in the necks of the condensers on a west/east axis. The reason for this location is undocumented but was apparently the-standard location in Westinghouse plants. 184 Two units (6A and SA) received steam from the 6th-and 5th-stage extraction points on low-pressure turbine 1 A. The 6B and SB units received steam from the same points on low-pressure turbine IB.185 The feed water emerged from the first group of heaters, flowed on either side of the turbine pedestal, and was piped up through the operating floor to the second group of low pressure heaters (4A and 3A, 4B and 3B), mounted on that floor along the east and west walls. 186 The A heaters were on the east side and the B heaters on the west. Each set received steam from the 4th- and 3rd stage extraction points of its respective low-pressure turbine. The last portion of low pressure heating occurred on the auxiliary bay mezzanine, where Heaters 2A and 2B were floor mounted under the main steam manifold. They received steam from the exhaust of the high pressure turbine. 187 At this point, the feed water was routed down to the steam generator feed pumps on the ground floor. These forced the water through the high-pressure, final stage of feed heating, in high-pressure heaters 1 A and 1 B also on the auxiliary bay mezzanine. These received steam from the first extraction stage of the high-pressure turbine. 188

Since the feed water heaters 1 and 2 were downstream of the feed water pumps in the heat cycle, they were technically considered part of the feed water system. Feed water was kept from boiling by the high pressure in the line. 189 In total, as the feed water traveled from the hot well to the last heater outlet it had gained between 260-330°F of heating. 190 The water in an extraction feed heating system is a considerable reservoir of heat energy. If the turbine were to trip, there was a risk of high temperature water flowing back into the turbines and then turning to steam (flashing) as its pressure dropped, causing an over speed. 191 To prevent

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 19)

that, most of the heaters had balance-type check valves or electrically-activated non-return valves. The condensate produced by the heat exchange in the feed water heaters was collected by a drain system and returned to the feed flOW. 192 Water from the high pressure heaters flowed through to the high pressure drain tank. This source provided about 30 percent of the feed flow to the steam generators. 193 The low pressure heaters drained back through the shells to the condenser hot wells. 194 The feed water heaters were originally piped with the same type of Admiralty Brass tubes as the condensers. Copper shedding into the feed flow led to the complete replacement with stainless tubes. 195 As in the moisture separator re­heaters, plant builders had to provide clearance for the tubes to be withdrawn from one end of each shell for service. In the case of the condenser mounted heaters, removable panels in the west outer wall of the building were used to provide clearance for tube withdrawal from IA heaters. The IB heater tubes were pulled into the auxiliary bay. 196

Electrical Generation

The south end of the IB low-pressure turbine shaft was directly connected by coupling bolts to a 667 mega volt ampere (mva) synchronous alternator (generator).c It had a revolving-field design, which evolved in the late nineteenth century from the original revolving-armature dc generators. 197 The main elements were the armature (stationary windings) known as the stator and the field (rotating magnets) known as the rotor. In basic terms, electrical energy was produced in the armature windings when an interrupted magnetic field was passed through them by the rotating field. 198 As the rotor turned, the electro-magnets produced a moving field that extended out into the stator windings producing a voltage by electromagnetic induction. Since each magnet pole was of opposite polarity to its neighbor the induced voltage was intermittent. 199 The voltage produced in the stator windings rose and fell in a sine wave called an alternation. Since the rotor had four magnetic poles it produced two cycles (hertz) per revolution?OO At 1800 rpm, it gave an alternating-current frequency off 60 cycles per second (cps). Synchronous machines are designed to operate in cyclic phase with all the generating equipment supplying the grid.201 When operators in the control room connected the unit to the power grid, they used a synchroscope to ensure that the output was in phase with the rest of the system. Failure to do that could lead to explosive destruction of the generator, requiring automatic safety relays to protect from operator error.

': Kilovolt amperes (kva) and megavolt amperes (mva) are ratings for electrical equipment based on potential capacity and are higher than the watts measurements used since the nineteenth century. Volt ampere ratings are affected by power factor, the electrical efficiency of a circuit expressed as the ratio of actual power to apparent power. When noted with the power factor figure they provide an accurate picture of the real capacity of the electrical equipment (Dawes 1928: 158).

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING ( Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 20)

The conductors for magnetizing the poles were laid in deep slots cut into the rotor spindle. This form was pioneered by C. L. Brown for high-speed turbine driven generators in the early twentieth century.202 To resist the centrifugal force acting to throw out the windings, they were held in place by retainer rings. The rotor was supported in oil-pressure bearings of the same type as the turbines and was in the same oil supply 100p?03 The stator body was fabricated of individual punched-out rings of silicon steel. The silicon content gave the laminations high magnetic permeability, reduced reluctance (resistance)204 and concentrated the field magnetic flux in the windings. Slots were formed in the inner circumference of the rings to receive the copper conductors. The laminations were individually insulated, then stacked and pressed forming a hollow core?05 Insulated through-bolts running from end to end ensured structural integrity. The laminated form of construction in which each component was insulated from its neighbor reduced the production of eddy currents which caused electrical losses. 206 The core was mechanically locked into the stator inner frame with key bars set into dovetails on the outer surface of the core.207 Working in the early twentieth century, B. G. Lamme, Chief Engineer of Westinghouse, made many of the improvements to the wiring form of turbine generators incorporated into the Connecticut Yankee armature?08 There were three separate winding coils running the length of the stator giving three-phase power. They divided the stator circle equally giving 120 degree separation of their alternations. 209 There were two insulated copper bars laid in each longitudinal trough formed by the lined- up slots. Each bar was made up of a number of insulated copper conductors formed in a spiral pattern. Insulation of each component of the conductors from adjacent components was critical to prevent destructive Short circuits and electrical phenomena such as coronas. 210 The electrical discharge from coronas constituted an electrical loss and produced ozone which could attack the insulation.211 The coils had Thermalastic mica and resin insulation, introduced by Westinghouse in 1949, which had good resistance to ozone attack.212 In addition to the insulation requirements, the conductors had to withstand structural displacement. They were held in place by wedges and springs to resist the powerful electromotive forces at work. At the ends of the core, the bars were joined by connection rings which completed the coils and oriented them in their respective phases. By connecting the bars in each coil in series, the voltages induced in each added Up.213 The electrical power "vas taken off with a grounded wye (Y) connection214 eliminating the need to take out six leads (two for each phase). Instead, one lead came off each phase, with a neutral attaching to all three. 215

The current flow in the conductors produced heat which had to be drawn off to prevent a drop in outpUt.216 The generator utilized pressurized hydrogen gas at over 60 psi passing through the stator and rotor for cooling. This cooling method came into use in the mid 1930s?17 Hydrogen gas was supplied from outdoor banks of cylinders. To ensure complete coverage by the gas, a blower fan was shaft mounted near the coupling at the turbine end. This forced the gas into four hydrogen coolers where the gas gave up its heat to a flow of

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 21)

\vater from the service water system. Hydrogen then flowed through the rotor and stator. Field windings in the rotor were ported to ensure gas flow. Vent plates between the stator laminations promoted even cooling. Heating of the generator leads, bushings and connectors was prevented by hydrogen streams.218 Because the generator's outer housing was under gas pressure, special gland seals were needed at each end of the casing at the shaft penetrations using oil under pressure. 219These prevented hydrogen from exiting and creating an explosive mixture with the air in the Turbine Building. Any hydrogen left in the casing when opened for repair could also combine with incoming air and cause an explosion. Carbon dioxide was used to purge the hydro~en before maintenance, and to purge air in the machine before hydrogen was introduced. 20

Most direct-current generators produce their own field magnetizing current. Synchronous alternating -current machines must have an outside source of this DC excitation current. The SOO-volt DC to excite the rotating field came from a separate ACIDC rotating rectifier exciter mounted on an extension shaft coupled to the south end of the generator shaft. Utilizing an AC exciter generator and rectifying the current to DC (instead of a direct DC exciter) allowed a simpler and more reliable unit without pickup brushes. The exciter conductors \vere ventilated by air which gave up its heat in an air cooler connected to the service water system?21 The exciter received its excitation current from a small permanent magnet DC generator (pmg) on the end of the exciter shaft.222 A bored hole in the rotor shaft provided a route for wires from the exciter to the field magnet conductors.223 In addition to producing the magnetizing current, the exciter system controlled generator output voltage during start­up. The critical device for this purpose was the solid-state voltage regulator which controlled the output of the pmg.224 Varying the current going into the rotor with the voltage regulator directly affected the voltage produced by the generator. Once the generator was up to speed and synchronized with the system electrical grid by operators in the control room, the output was controlled by interaction among the system loads, the turbine governor and control circuitry in the regulator.225 The generator produced 19,000 volts at 22,000 amps. Prior to the low-pressure rotor replacement, the average output was 605 mw. The improved performance with the new rotors boosted that to 612 mw. 226

The generator output was directed out of the south end of the Turbine Building through an isolated-phase bus duct system.227Each phase was contained in a separate metal enclosure. A fan forced air through the ducts to draw off resistance heated air. The air was cooled in heat exchangers fed by the service water system.228 The bus was split, connecting to two outdoor number-designated transformers in the 12R Switchyard at the south end of the building. 229

The 319 Transformer was the step-up device to raise the voltage to the system grid's 345 kilovolts (kv). This high voltage allowed transmission for long distances economically since it allowed small copper conductors to carry power at lower current. The heart of the transformer unit was the laminated silicon steel core with primary ( entrance) and secondary

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 22)

( exit) windings. The core had separately insulated windings for each of the three phases.23o

The high amperage/low voltage output of the generator produced high voltage/low amperage current in the secondary windings via electromagnetic induction. The laminated construction of the cores served the same purpose as that of the generator stator; the reduction of wasteful eddy currents. The core and windings were secured inside an aluminum oil tank. 231 Heat produced by the current flow was drawn off by the oil around the windings. Heated oil was continuously pumped into tubed heat exchanger units attached to the outer casing and cooled by fans. As the load on the station increased and oil temperatures rose, the fans came on automatically to maintain the full rating (power capacity) of the transformers. Current was taken out of the tank by three wires with insulated oil-tight bushings and sent via the 320 Line to the 14B 345 kv Switchyard, at the southeast end of the plant site, for distribution to the system grid. 232 The output voltage could be adjusted (though not under load) with a tap changer hand wheel which changed the ratio of primary to secondary wiring. 233 There were no isolating breakers or switches between the main generator and the 319 Transformer. When de-energized it could be isolated from the 320 line to main 14B Switchyard by motor­operated disconnect (MOD) switches, which could also be manually cranked open/closed?34 'Vhen under load, the 319 unit was switched by gas-quenched power circuit breakers (PCBs) in the 14B yard. 235 Between the transformer and MODs were the lightning arresters?36

The 19,000 KV generator output was also sent to the 309 step down transformer. It was of similar construction to the 319 unit, and produced a lower voltage of 4.16 KV for supplying the reactor coolant pumps.237 A series of primary and backup protective relays in the control room prevented damage to the reactor, turbines and generator from electrical problems. The relays could be activated by faults in either the turbine power into the generator, generator output, or the distribution grid. 238 Faults in the system such as grounds in the generator, leads, and transformers automatically activated relays in the switchyard to protect the grid. The exciter would have also tripped dropping the generator output. Relays protected against two conditions which could lead to over speeding of the generator turbine: loss of field and reverse current.239 Some of the protective relays had time delays if a too rapid shutdown could endanger other equipment up or downstream of the fault.

Other anomalies such as loss of service water for cooling the hydrogen system, low bearing or seal oil, and loss of exciter cooling air would either trigger alarms to warn operators to make manual adjustments or the relays could initiate an automatic shutdown ifwarranted?40

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 23)

Connecticut Yankee Atomic Power Company 1966-1974: 8.12-1,2; Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964a-b, 1964d-e [drawings].

Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964f[drawings]; HH Robertson/Asia Pacific Group 2003, Simpson 1970: 192

Connecticut Yankee Atomic Power Company 1987b: 5; Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964f drawings].

Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964-1992 [drawings].

Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964-1967, 1964-1980b [drawings].

Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964-197 6 [drawings].

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 57, page 1.

Ibid 3.

de Belidor 1737-1753 3. 360.

MacNaughton 1967: 340-343.

11 Connecticut Yankee Atomic Power Company 1998: 1.2-12: 1987-1993. Chapter 16,

page 22.

12 Connecticut Yankee Atomic Power Company 1987-1993: Chapter 16, page 22.

13 Ibid: Chapter 16, page 46.

14 Ibid: Chapter 19, page 16.

15 Ibid: page 17.

16 Ibid: Chapter 22, page 46.

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18

19

20

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26

27

28

29

30

31

32

33

34

35

HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 24)

Ibid: 16, page 13.

Ibid: page 33.

Ibid: Chapter 16, page 5.

Connecticut Yankee Atomic Power Company 1966-1974: 8.1-1.

Ibid: 8.1-4; Connecticut Yankee Atomic Power Company 1998a [drawings].

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 17, page I.

Ibid: 3

Connecticut Yankee Atomic Power Company 1966-1974: 8.1-1.

Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964-197 6 [drawings].

Ibid:8.2-1;Connecticut Yankee Atomic Power Company c.1972: 12, 1998: 1.2-11.

MacNaughton 1967: 513.

Connecticut Yankee Atomic Power Company 1998:1.2-11; Gray 1917: 14.

Morgan 1950: 9.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 22, page 1.

Church 1935: 9.

Morgan 1950: 8.

Church 1953: 10.

Sinton 1966: 112.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 22, page 42.

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37

38

39

40

41

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43

44

45

46

47

48

49

50

51

52

53

54

HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 25)

Ibid: chapter 22, page 42.

Connecticut Yankee Atomic Power Company 1966-1974: 8.2-1.

Ibid: 8.2-2.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 22, page 43.

Ibid.

Ibid: Chapter 22, page 6.

Connecticut Yankee Atomic Power Company 1966-1974: 8.2-2.

Clark 2004.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 23, page 3.

Ibid: Chapter 23, page 4.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 23, page 3; MacNaughton 1967: 507.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 23, page 18.

Connecticut Yankee Atomic Power Company 1966-1974: 8.2-2.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 23, page 38.

Ibid: Chapter 23, page 22.

Ibid: Chapter 22, page 18.

Ibid.

Ibid: page 18.

Ibid.

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57

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69

70

71

72

73

74

HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING ( Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 26)

Ibid: Chapter 22, page 19, MacNaughton 1967: 509.

MacNaughton 1967: 476.

Ibid: 477, Richardson: 191): 5.

Ibid: 475.

Morgan 1950: 10.

Hossli 1969: 105.

Morgan 1950: 10.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 22, page 13.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 22, page 22.

Ibid.

Ibid. Chapter 22, pages 83-84.

Ibid. Chapter 22, page 34.

Ibid. Chapter 22, page 32.

MacNaughton 1967: 487.

Ibid. Chapter 27, page 3.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 27, page 5.

Ibid. Chapter 27, page 7.

Ibid. Chapter 27, page 1.

Bourne 1846: 229, Knight 11205

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 22, page 38.

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING ( Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 27)

Ibid: Lafoon 1950: 28.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 26, page 1.

Ibid. Chapter 26, page 1.

Ibid. Chapter 26, pages 38-43.

Connecticut Yankee Atomic Power Company / Stone & Webster Engineering Corp. 1964-1992 sheet 1 [drawings].

Connecticut Yankee Atomic Power Company 1986-1989: NEO.3 Rev. 6, p. 30f21 (Nov 21,1986): 1987-1993: Chapter 22, page 98.

Connecticut Yankee Atomic Power Company 1987-1991: Chapter 23, page 7.

Meyer 1905: 63.

Engineering 1926: 285. Jackson 1952: 55.

Connecticut Yankee Atomic Power Company 1966-1974: 8.2-1,3.

Ibid: 8.2-3:Connecticut Yankee Atomic Power Co. 1987-1993:Chapter 24, page 1

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 24, page 1.

Ibid: Chapter 24, page 1.

Ibid: Chapter 24, page 1.

Connecticut Yankee Atomic Power Company 1966-1974: 8.2-3.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 24, page 11; Sinton 1986: 110.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 24, page 13.

Ibid: page 36.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 24, pages 34-38.

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95

96

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98

99

100

101

102

103

104

105

106

107

108

109

110

114.

111

HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 28)

Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1967, [drawings].

Ibid 1987-1993: Chapter 24. page 35.

Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1967, [drawings].

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 22, page 34.

Ibid: page 35.

Ibid.

Ibid: page 5.

Connecticut Yankee Atomic Power Company c. 1972: 12.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 24, page 36.

Clark 2003.

Hossli 1969: 103.

Sinton 1966: 113.

Connecticut Yankee Atomic Power Company c. 1972: 13.

Hossli 1969: 101.

Stinton 1966: 112.

Hossli 1969: 108.

Connecticut Yankee Atomic Power Company 1986-1989: Doc 86-94, 9/17/87, page

Sinton 1966: 110.

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113

114

115

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117

118

114.

119

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123

124

125

126

127

128

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 29)

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 27, page 1.

Power 1982: 345.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 22, page 47.

Ibid: 47.

Connecticut Yankee Atomic Power Company 1986-1989: Plant Design Change Record 886, Rev. 0, 5/29/87, page 7.2-4.

Clark 2003.

Connecticut Yankee Atomic Power Company 1986-1989: Doc 86-94,9117/87, page

Ibid.

Kraftwerk Union AG 1986: 4.

Connecticut Yankee Atomic Power Company 1986-1989: GDA-PDCR886-002.

Ibid: Plant Design Change Record 886, Rev 0, 5/29/87, page 7.2-1.

Ibid: 7.3-3.

Kraftwerk Union AG 1986: 24.

Connecticut Yankee Atomic Power Company 1986-1989: Memo PSE-CE-87-683.

Connecticut Yankee Atomic Power Company 1983-1987: Memo, W.D. Barton to G.F. Veredonee and P.D. Watson, 12/6/83, page 2.

Connecticut Yankee Atomic Power Company 1986-1989: Plant Design Change Record 886, Rev. 0,5/29/87, page 7.2-1.

Connecticut Yankee Atomic Power Company 1987b:1.

Ibid: 3.

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142

143

144

145

146

147

HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 30)

Hossli 1969: 110.

Main 1893: 224.

Connecticut Yankee Atomic Power Company 1987-1993: Charter 41, page 12. Westinghouse Electric Corporation 1964 [drawings].

Connecticut Yankee Atomic Power Company c. 1972: 13.

Ibid: chapter 41, pages 12,23: MacNaughton 1967: 541.

Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964e [ drawings].

Brass.org 2003: 1.

Northeast Utilities 1985: 2.

Ibid: Northeast Utilities 1986: Connecticut Yankee Atomic Power Company 1987-1993: chapter 18, page 11.

Ibid. chapter 41, page 24.

Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1968 [drawings].

Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1992, Section AA [drawings].

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 41, page 24.

Ibid: Chapter 42, page 1.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 42, page 3.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 41, page 28.

Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1968, Sheet 1 [ drawings].

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149

150

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158

159

160

161

162

163

164

165

166

HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 31)

Ibid: Connecticut Yankee Atomic Power Company 1987-1993: Chapter 41, page 28.

MacNaughton 1967: 533.

Morgan 1950: 14.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 28, page 1.

Ibid: Chapter 28, page 3.

Connecticut Yankee Atomic Power Company 1966-1974: 8.4-2.

Ibid: Chapter 28, page 8.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 42, page 1.

Ibid: Chapter 18, page 28.

Ibid: Chapter 17: page 2.

Ibid.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 28, page 13.

Connecticut Yankee Atomic Power Company 1966-1974: 8.7-1.

Ibid: 8.3-2.

Kinsman 2001: 1.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 20, page 2.

Ibid: Chapter 19, page 1.

Connecticut Yankee Atomic Power Company 1998: Fig. 10.4-5, Sheet 9.

Ibid: Chapter 19, page 8.

167 Connecticut Yankee Atomic Power Company 1987-1995. Chapter 21, page 1.

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 32)

168 American Society of Mechanical Engineers 1920: 40.

169 MacNaughton 1950: 493.

170 Connecticut Yankee Atomic Power Company 1987-1995. Chapter 21, page 13.

171

172

173

174

175

176

177

178

179

180

181

182

183

184

185

186

187

Personal Communication-Gerald Loftus - May 2010

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 19, page 18.

Connecticut Yankee Atomic Power Company 1966-1974: 8.3-6.

Clark 2004.

Clark 1889: 275.

Parsons 1939: 183.

Engineering 1926: 285; Lorenzi 1952: 13.6.

Connecticut Yankee Atomic Power Company CY APC a c.1972: 14.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 20, page 1.

Ibid: page 2.

Connecticut Yankee Atomic Power Company 1966-1974: 8.1-4.

Ibid: 1987-1993: Chapter 20, page 2.

Connecticut Yankee Atomic Power Company /Stone & Webster Engineering Corp. 1964-1980b [ drawings].

Clark 2004.

Connecticut Yankee Atomic Power Company 1998D, 1998C [drawings].

Connecticut Yankee Atomic Power Company/ Stone & Webster Engineering Corp. 1964-1993. Connecticut Yankee Atomic Power Company 1987-1991: Chapter 20, page 4.

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189

190

191

192

193

194

195

196

197

198

199

200

201

202

203

204

205

HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING ( Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 33)

Connecticut Yankee Atomic Power Company/ Stone & Webster Engineering Corp. 1998b [drawings].

Lorenzi 1952: 19-1.

Connecticut Yankee Atomic Power Company 1966-1974: Fig 8.2-2.

Ibid: 8.1-4.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 20, page 1.

Ibid: 7.

Ibid: 8.

Connecticut Yankee Atomic Power Company n.d.: 50 of 57.

Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964e, 1964-1980b [drawings].

Thompson 1890: 602.

Navpers: 1950: 131.

Bureau of Naval Personnel 1960: 217.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 4, page 104, Gray 1917: 195.

Thompson 1900: 659.

Bowers 1983: 69.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 61, page 13.

Dawes 1937: 11250.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 61, page 7.

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206

207

208

209

210

211

212

213

214

215

216

217

218

219

220

221

222

223

224

225

Ibid.

Ibid: 8.

HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 34)

Passer 1953: 265.

Bureau of Naval Personne11960: 223.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 61, page 9.

Dawes 1928: 443.

Westinghouse 2001: 1.

Bureau of Naval Personnel1960: 221.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 61, page 7.

Bureau of Naval Personne11960: 223.

Lafoon 1950: 25.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 32, p.lO.

Ibid: Chapter 61, page 9.

Ibid: 12.

Ibid: 63.

Ibid: 50.

Ibid: 16.

Ibid: 18.

Ibid: 19.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 22, page 16.

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227

228

229

230

231

232

233

234

235

236

237

238

239

240

HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 35)

Connecticut Yankee Atomic Power Company 1987a: SE-28.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 47, page 2.

Ibid: Chapter 47, page 3.

Ibid: Chapter 62, page 1.

Bureau of Naval Personnel 1960: 235.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 61, page 40.

Ibid: Chapter 62, page 1.

Ibid: Chapter 61, p. 40.

Ibid: Chapter 62, page 3.

Ibid: page 12.

Connecticut Yankee Atomic Power Company 1966-1974: 9.2-1.

Connecticut Yankee Atomic Power Company 1987-1993: Chapter 61, page 39.

Ibid: page 48.

Ibid: pages 56, 58.

Ibid: page 65.

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 39)

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 40)

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 43)

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 49)

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APPENDIX A

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BASIC IMPULSE PRINCIPLE

HIGHER EFFICIENCY IMPULSE PRINCIPLE

SCHEMATIC DIAGRAMS OF IMPULSE AND REACTION TURBINE PRINCIPLES (base images: Church 1935)

The basic principal of an impulse turbine wheel may be visualized as a jet of water directed against a flat plate which is moved back by the steady pressure on it. To have a continuous action a succession of plates would have to be struck by the jet. In the steam turbine these are the blades attached to the rotating turbine wheel. In fact, a cup-shaped surface is much more efficient at utilizing the energy in the fluid, so the blades are twisted. The twist causes the steam to leave the blades at an angle of 180 degrees which increases the propulsive force 100 percent. The reaction turbine wheel is analogous to a rocket engine or spinning lawn sprinkler. In a rocket, a jet of combustion products ejected out of a nozzle causes the motor to move in the opposite direction in an equal reaction. In the lawn sprinkler the water leaving the arm at a right angle creates the thrust. In the reaction steam turbine the action is more complex. The steam traveling from the fixed guide blades to the moving blades is turned twice and incorporates an impulsive component. The critical shape of the blading causes the steam to expand and speed up as it leaves the moving blades creating the reaction force on the rotating blade wheel (Church 1935: 113).

The impulse or Rateau stage consisted of one row of nozzles and one row of moving blades. As steam passed through the nozzles, it accelerated until its velocity in the direction of

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 50)

rotation was about twice that of the moving blade. The moving blade absorbed this impulse and transferred it to the rotor in the form of kinetic energy. Steam pressure decreased as it passed through the nozzle, and then remained practically constant as it passed through the rotating blades, dropping only enough to maintain the forward flow of the steam. The velocity of the steam increased as it passed through the nozzle and decreased as it passed through the blades and performed work on the rotor. Ideally, the velocity of the steam exiting the blades was the same as that of the steam entering the nozzles.

INNER CASING

ROTOR MOVING FIXED AND MOVING FIXED AND MOVING BLADES BLADES BLADES IMPULSE 1ST REACTION STAGE 2ND REACTION STAGE STAGE

ROTOR

5 MORE REACTION STAGES

SCHEMATIC DIAGRAM OF HIGH-PRESSURE TURBINE BLADE STAGING (base image: Connecticut Yankee Atomic Power Company 1987-1993: Chapter 22, page 79).

The seven reaction stages consisted of alternating rows of stationary and rotating blades that were practically identical in design and function. Each stage had one row of fixed blades and one row of moving blades. Blades on both rows were shaped so that the area between two adjacent blades of the same row formed a nozzle. Steam pressure dropped progressively as it passed through both stationary and rotating blading. The expansion of the steam in the fixed blading served only to give it the velocity necessary to enter the moving blading. Further steam expansion in the moving blading created a reaction force which worked on the moving blading. Steam velocity was sufficient to allow the steam to escape from the moving blading and enter the next row of fixed blading. Thus, velocity rose and then dropped completely in each stage. The pressure drop for a reaction stage is much less than that of an impulse stage. A reaction turbine is moved by three main forces. The reaction force produced on the moving blades as the steam increases in velocity as it expands through the nozzle-shaped spaces between the blades, the reaction force produced on the moving blades when the steam

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HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING (Connecticut Yankee Nuclear Power Plant, Turbine Building)

HAER No. CT - 185 C (Page 51)

changes direction and the impulse of the steam impinging upon the blades. Each set of reaction blades utilized an additional expansion of the steam, and the rows got larger in diameter as the steam gained volume in its flow through the turbine (Connecticut Yankee Atomic Power Company 1987 & 1993: Chapter 22, pages 13-14).

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WRITTEN HISTORICAL AND DESCRIPTIVE DATA

HAER CT-185-CHAER CT-185-C

ADDENDUM TO:HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING(Connecticut Yankee Nuclear Power Plant, Turbine Building)362 Injun Hollow RoadHaddamMiddlesex CountyConnecticut

HISTORIC AMERICAN ENGINEERING RECORDNational Park Service

U.S. Department of the Interior1849 C Street NW

Washington, DC 20240-0001

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ADDENDUM TO HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING

(Connecticut Yankee Nuclear Power Plant, Turbine Building) HAER No. CT - 185 C

(Page 47)

HISTORIC AMERICAN ENGINEERING RECORD HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING

(Connecticut Yankee Nuclear Power Plant,Turbine Building) (INCLUDES TERRY TURBINE BUILDING - HAER No. CT-185-E)

This report is an addendum to a 46-page report previously transmitted to the Library of Congress in 2010. Location: 362 Hollow Road Haddam Middlesex County Connecticut U.S. Geological Survey Haddam & Deep River Quadrangles UTM Coordinates 18.708748.4595057 Dates of Construction: 1964-1966 Major modifications: c. l978 (concrete sumps in Auxiliary Bay) 1979-1982 (waste treatment facilities) 1986-1987 (low-pressure turbine replacement). Engineers: Westinghouse Electric Company (turbines, generator, related equipment), Stone &

Webster Engineering Corporation (foundations and superstructure), Utility Power Corporation and Kraftwerk Union AG (replacement low-pressure turbine rotors).

Present Owners: Connecticut Yankee Atomic Power Company (CYAPCO) 362 Injun Hollow Road,

Haddam Neck CT 06424-3022 Present Use: The Haddam Neck Nuclear Power Plant was one of the earliest commercial scale

nuclear power stations in the United States, and was eligible for the National Register of Historic Places. The Turbine Building was one of the two most significant structures at the complex. Its function was to generate electricity using steam generated in the reactor. Equipment design was typical of contemporary choices in nuclear-fueled turbines and generators, and had turbine and condenser problems common to plants of this vintage.

Project Information: CYAPCO ceased electrical generation at the Haddam Neck plant in 1997 and

initiated decommissioning operations in 1998, subject to authority of the Nuclear Regulatory Commission (NRC). NRC authority brought the project under the purview of federal acts and regulation protecting significant cultural resources from adverse project effects.i This documentation was requested by the Connecticut State Historic Preservation Office to mitigate the effects of demolishing a historic power generating facility.

i National Historic Preservation Act of 1966 (PL 89-655), the National Environmental Policy Act of 1969 (PL 91-190), the Archaeological and Historical Preservation Act (PL 93-291), Executive Order 11593, Procedures for the Protection of Historic and Cultural Properties (36 CFR Part 800).

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ADDENDUM TO HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING

(Connecticut Yankee Nuclear Power Plant, Turbine Building) HAER No. CT - 185 C

(Page 48)

Project Manager and Historian - Michael S. Raber Raber Associates 81 Dayton Road, P.O. Box 46 South Glastonbury, CT 06073 (860) 633-9026 Nuclear, Steam and Electric Power Historian Gerald Weinstein 40 West 77th Street, Apt. 17b New York, NY 10024 (212) 431-6100 Industrial Archaeologist - Robert Stewart Historical Technologies 1230 Copper Hill Road West Suffield, CT 06093 (860) 668-2928

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ADDENDUM TO HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING

(Connecticut Yankee Nuclear Power Plant, Turbine Building) HAER No. CT - 185 C

(Page 49)

Building Description Like most structures at the Haddam Neck Nuclear Power Plant, the Turbine Building was oriented on a northwest-southeast axis with the northwest end "called north" on plant drawings. Framed in welded and bolted steel with columns forming 20 and 25-foot-wide bays, the building was structurally continuous with the Service Building and Control Room and housed the turbines and generator which rested on a reinforced concrete pedestal. There were two Turbine Building sections, each with metal roofs; the gable-end 122-foot-high, 106-by-268-foot main building, and a flat-roofed, 38-foot high, 27-foot wide auxiliary bay running along the southeast side of the main building. The auxiliary bay was 240 feet long on the ground floor and 268 feet long above (Figures 1-6).1 Enameled fluted aluminum siding sheathed all auxiliary bay exterior walls, and most of the north, east, and west walls of the main building. Except at the main building north end, where expansion for a second nuclear unit was originally planned, the exterior siding and metal roof panels were insulated using (in many places) Galbestos, the original asbestos insulated zinc coated steel panel2.ii The publicly-visible west and south sides presented more finished appearances. A 94-foot-high facade of glazed brown brick covered the south wall to the roof line and wrapped around the west facade almost to the first column line, with the same brick continuing along the rest of the west and north sides as a 4.5-foot-high base. North of the high brick face on the west side, paired 2.5-foot-wide vertical plastic strips flanked insulated aluminum panels on alternating exterior columns, providing natural interior light and dividing most of the west facade into five exterior bays. The northernmost of these bays was hidden by the west facade of the adjacent Administration Building and was blank except for a personnel door. The remaining four bays, 45 or 50 feet wide, were each distinguished by an 8-foot-high, 30.5 or 35-foot-wide arched louvered aluminum panel, which mirrored the two, somewhat larger arched sections on the west side of the Administration Building. As discussed below, the second and third arched panels from the south were removable to allow for condenser tube replacement, and a 20-by-9.5-foot area of removable wall panels above the southernmost of the removable arched sections allowed for withdrawal of certain feed water heater tubes (Figures 3-5, 9-10). Additional natural light was admitted by strips of bronze colored-plastic windows along the wall/roof junctions of the east and west sides, by vertical plastic panels in the pediments under the gable ends, and by a 107 -foot-long strip of 4.5-foot-high aluminum-sash windows along the east side of the operating floor. The east, north, and south exterior walls were otherwise almost blank, penetrated by one man door each at the north and south ground levels, a rolling steel garage door on the south side, and a man door on the east side of the operating floor which accessed the roof of the auxiliary bay. Eleven transverse gravity roof ventilators at 25-foot-centers topped the main Turbine Building exterior (Figures 3-6). Substructure and turbine-generator pedestal components were completed in 1964, during the earliest phases of plant construction. Beneath the condensers described below as part of the plant heat cycle, steel and concrete circulating water intakes and discharges were installed to depths reaching elevation -6 feet. The ground floor concrete slab over these features was poured at the typical plant ground elevation of 21.5 feet, and supported steel superstructure columns. The reinforced-concrete pedestal had footings

ii Profiled metal sheeting with asbestos felt on both sides coated with either bitumen or polyester resin.

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ADDENDUM TO HADDAM NECK NUCLEAR POWER PLANT, TURBINE BUILDING

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below the ground floor and extended to the operating floor elevation of 59.5 feet. The pedestal consisted of large columns and 10-foot-deep beams, with open construction allowing for placement of condensers and auxiliary equipment within the pedestal. Bottle-shaped in plan, the pedestal was widest under the low-pressure turbines.3 The operating floor elevation was presumably dictated by approximate 31-foot height of the condenser tops above the circulating water pipe entries.4 Four openings in the operating floor level allowed for the insetting of the three turbine casings and generator (Figures 2, 6, 11). The perimeter columns of the main Turbine Building superstructure were largest up to the 94.8-foot elevation where they formed a shelf to support bridge crane rails. Smaller-section columns were attached to the outer portions of the perimeter columns to support the upper wall section and roof girders (Figure 9). Surrounding the turbine-generator pedestal, but structurally independent from it, were the steel-framed mezzanine (el. 37.5 feet) and re-heater (el. 47.5 feet) levels, which contained most of the auxiliary equipment systems dedicated to turbine operation. The mezzanine level continued across the auxiliary bay.5 An electrically-powered Manning, Maxwell and Moore Company bridge crane traversed the entire length of the main building, supported on crane rails reaching an elevation of 98.25 feet. The main hook capacity was 125 tons. There was also an auxiliary 20-ton hook (Figures 6-7). Components could be brought up to the various levels by the crane through a large hoist way opening through the floors at the southwest corner.6 Trolley beams mounted on the steel framing of the mezzanine and re-heater levels facilitated withdrawal of moisture separator re-heater, condenser, and feed water heater tubes for repairs. The main ventilation system comprised natural and forced-air flow from the louvers along the base of the west wall and out through vents in the roof.7 The natural flow relied on the stack effect of rising warm air.8 Fans also supplied forced air flow. For heating, air warmed by radiation from equipment was collected by fans and directed down to lower levels. Several steam-supplied unit heaters were used for additional space heating. Secondary Systems Equipment The major equipment in the Turbine Building served two main functions; conversion of steam to electrical energy, and condensation of steam for feed water return to the steam generators in Reactor Containment. These operations were controlled to maintain the overall plant heat balance as well as to supply power to the grid and portions of the plant. Most equipment critical to the heat balance was located in the Turbine Building. A variety of secondary systems supplied and regulated water and air for these functions, often controlled by a wide range of control valves. Housed on the ground floor primarily in the Auxiliary Bay, secondary systems included the compressors, receivers, filters, and driers of the Control Air System, the intake filters, compressors, moisture separators, and receiver for the Service Air System, and components of the Water Treatment System. The flow of steam, gases, and water through the turbine building was controlled by on/off and volume control (throttling) valves. These valve types, operated by threaded spindles, were in use before the Industrial Revolution.9 For simple shut-off service, gate valves blocked the flow with a sliding wedge. For volume control, globe valves with circular discs pressing on circular seats were preferred. To insure flow in the correct direction, non-return valves were used, also a very old design. Pressure-reducing valves enabled low pressure devices to take steam from the main supply without damage.10

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There were three main systems actuating plant valves: air, electric, and oil. The choice of actuation was based on the type of valve, the medium being controlled, and the requirements for safety backup redundancy. Many valves were actuated by the 100-psigiii Control Air System, which ran through the plant and had backup receivers to provide emergency activation power even if the system failed.11 The admission of air to the activation mechanism was made by solenoids operated from the control room with several backup electrical systems.12 The air-operated valves were often designed so that if they failed, they would automatically go to the safe position.13 Valves for isolating portions of the systems were generally electric-motor operated with both actuation signals and power coming from un-interruptible supplies which would continue to operated even in an emergency.14 Both classes of valves could be set to operate automatically when signaled by an unsafe condition in the plant.15 In most cases they also had manual overrides and hand wheels for local control. A third type of valve operated by oil pressure was used on the main turbine. These were powered by oil from the bearing-lube system and were actuated by electric solenoids. Redundancy was insured by backup pumps, backup electrical supply to the solenoids and fail-to-safe-position construction.16 Four 24-inch-diameter main steam lines (one from each steam generator) entered the auxiliary bay through the east wall at the 47.5-foot elevation, in line with the main building's re-heater level. The steam lines were constructed of nearly l-inch-thick carbon steel pipe, and hung from ceiling steelwork to allow movement during thermal expansion and contraction.17 As it entered the turbine building the steam was measured by flow detectors on each line. Based on their signals the pressure differential devices automatically regulated the feed flow into the generators and signaled the control room. If the steam flow exceeded the feed flow by more than 20 percent the detectors sent a trip signal to the reactor to protect the steam generators from low water.18 The main steam lines were welded 19 into the south side of the 36-inch-diameter, 1.33-inch-thick manifold suspended from the ceiling on an east/west axis.20 The manifold served as a header from which steam could be taken to run various systems discussed below. In addition to the two turbine supply lines, auxiliary steam pipes went to the re-heater sections of the four moisture separator re-heaters, steam jet air and priming ejectors, turbine gland seal valve, and steam heating system.21 They could send steam directly to the condensers after a reactor trip, removing heat from the Reactor Coolant System and preventing the steam generator safety valves from opening. The High-Pressure Steam Dump System came out of the header with two 12-inch-diameter steam lines. They could send steam directly to the condensers after a reactor trip, removing heat from the Reactor Coolant System and preventing the steam generator safety valves from opening.22 Two valve stations in the turbine building consisting of five valves on each line gave reliability to the critical steam dump function, and provided security against an accidental dump.23 A Low Pressure Steam Dump System prevented turbine overspeed by sending the high pressure turbine exhaust directly to the condensers. It was controlled by four motor operated isolation valves and four motor operated dump valves. The main steam pipes were insulated with asbestos and covered with stainless steel casings. The insulation

iii Steam pressure was stated as pounds per square inch gage (psig) which was the pressure over the nominal atmospheric pressure at sea level of 14.7 pounds per square inch (psi). Pressure over true 0 was known as pounds per square inch absolute (psia).

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minimized the heat losses that inevitably occur when bringing steam to different locations. The design basis of this system was for 985 psig steam pressure at 650°F.24 Two 30-inch-diameter, 1.23-inch-thick main steam pipes were welded to the north side of the manifold and made a large diameter arc west into the turbine building at the 50-foot elevation, from which point they then made another large diameter arc south and formed S bends to rise up through the operating floor.25 The steam pipes terminated at two main stop valves anchored to the floor at the high-pressure end of the turbine. By the time the steam had reached the stop valves, it had lost pressure and heat. Connecticut Yankee documents show the pressure at the valves at around 640 psig, 50 pounds less than that issued by the steam generators; steam temperature at the stop valves was about 490°F, about 11 degrees less than that at the steam generator outlets.26 The steam was described as dry and saturated, meaning it had moisture content under 0.25 percent and a temperature that was the same as that of the water from which it was liberated.27 Steam Turbines The thermal energy to rotating energy conversion device was a Westinghouse/KWU three-casing, tandem compound turbine direct- connected to a Westinghouse generator. The turbine included one high-pressure and two low-pressure units, which was typical of many large power plants from the mid 20th century. The nominal turbine output was (in 1987) approximately 830,198 hp (619,328 KW) with a maximum output of 869,339 (648,527 KW).28 At those loads, the hp turbine was taking 7.463 to 8,558 million pounds of steam per hour. The turbines of the Connecticut Yankee unit were all on a single segmented shaft with a high-pressure element exhausting into twin low-pressure units. This design was known as a tandem- compound arrangement to distinguish it from cross-compound types which had two or three separate turbine shafts.29 Turbines were also typed according to the directional flow of steam through the casing. The Connecticut Yankee units were double-axial flow types, in which the steam entered the center of the casing and flowed outward to each end.30 One advantage of this design was that the thrust on the blades was well balanced which simplified the design of the support bearings.31 The Connecticut Yankee turbines were also categorized by their exhaust arrangements. The steam exhausted each casing from two ports at each end, called quadruple exhaust. The splitting of the exhaust path allowed a greater flow without greatly increasing the size of the casing ends (Figure 12). This was an additional benefit of the double-flow design.32 The steam flow volume dictated the size of the exhaust ports, which in turn dictated the length of the last row of blades in each stage. Blade size is a critical factor in turbines because of centrifugal forces acting to pull the blades out by the roots. Blade length and thus casing size had to be increased as steam pressure dropped and steam volume increased prodigiously during the flow of steam through the turbine.33 The constraint of relatively poor steam conditions from the pressurized water reactor generators on exhaust-port design and blade-tip speed required larger-diameter blading in the last low-pressure stages than were found in fossil-fuel power stations. This limited the rotor speed to 1800 rpm.34 The steam entered the turbine through the two hydraulic, on/off, swinging clapper type stop valves.35

Their main purpose was to provide emergency shut off to prevent turbine over- speed.36 The valves had a built-in safety feature: they were held open by oil pressure but closed by a spring and steam flow, thus

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defaulting to shutdown (trip) in the event of a power supply loss.37 Other malfunction scenarios such as low condenser vacuum or low bearing oil would shut off the steam flow.38 They would also close by solenoid signal if the reactor scrammed.39 The stop valves were sized so that one valve could supply enough steam for 2/3 output with the other valve closed for testing or repair.40 Steam flowed through the stop valves and into four hydraulic plug type governor valves which were welded in pairs to each stop-valve body.41 They were actuated by servomotors linked to the turbine-governing devices as the main method of speed control and emergency shutoff during turbine run.42 Generally the plant ran with three of the valves fully open with governor actuation on the fourth valve.43 High-pressure hydraulic oil for shutoff and governing valves was provided by the main oil pump though the Turbine Control Oil System (TCOS).44 Since the main oil pump was driven directly by the rotor, an AC electric motor pump supplied the system during startup and shutdown.45 The TCOS also supplied low-pressure oil to the governor control block, located in the governor pedestal, which detected speed variations via an oil line pressurized by an impeller on the turbine shaft.46 The variations could be caused by changes in the steam supply and/or the electrical load. The control block magnified variations enough to operate the governor valve-control servomotors.47 Changes in speed or malfunction scenarios generally caused a differential of oil pressure on one side of a relay piston allowing springs to activate the valve servomotors controlling the oil actuators of the valves. In the case of the control valves, as the electrical load on the generator rose and fell, the governor raised or lowered the oil pressure to open and close the fourth valve in small increments, modifying the steam flow to keep the speed at 1800 rpm producing precise 60 cycle electric power.48 The control block also contained an auxiliary governor and malfunction trip devices. For critical over speed protection, a centrifugal weight device on the shaft automatically contacted a trip relay if the speed increased by more than 45 rpm, shutting all the valves.49 The stop and governor valves were also remotely controlled by personnel in the control room to admit and throttle steam admission during startup, synchronizing with the grid, and shutdown.50 The casing for the high-pressure turbine was a fabricated weldment of carbon steel, consisting of upper and lower shells bolted together at machined mating surfaces.51 These surfaces were so precisely finished that no gasketing material was needed; only boiled linseed oil was used as a seal.52 The lower casing was attached to the concrete foundation by lugs and keys to allow movement with expansion and contraction. The casing was insulated with asbestos and clad with sheet metal for a neat appearance.53 A separate sheet metal enclosure covered the stop valves, governor and control valves. Steam leaving each governor valve was sent through a pipe to a sector of the first rows of stationary blades or vanes.54 Two pipes were in the upper casing and two in the lower, serving as nozzles for steam admission to the moving element. The rotative motion was caused by a flow of steam passing through alternate rows of stationary blades blade rings that were doweled into the inside surfaces of the casings and rotating rows attached to a spindle. In the 1884 Parsons design, there were multiple rows of blades. The fixed blades served as nozzles in which the steam expanded and reached the speed of the moving blades. The steam continued to expand in the moving blades, changing its momentum and producing a rotative force via reaction.55 Each blade row utilized an additional expansion of the steam and the rows got larger in diameter as the steam flowed through the turbine.56 Rateau in France and General Electric in the United States brought out a competing design around 1905 using differently-shaped impulse blades: In impulse turbines, steam issuing from the stationary nozzle blades was reduced in pressure and

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(Page 54) increased the velocity. The high velocity steam impinged on the moving blades and was deflected in direction causing rotation by impulsive force.57 By 1907 Westinghouse designers realized that an efficient turbine combined elements of both types.58 An impulse turbine needs fewer rows of blades for the same power output.59 Impulse blading also facilitated steam throttling, and allowed for turbine designs which were more efficient at partial loads.60 These advantages were somewhat negated by the difficulties of sealing the ends of the blades against steam leakage. Combining the benefits of both designs, the Connecticut Yankee hp element had Rateau type impulse blading on the first stage meeting the steam, and seven reaction stages following on each half of the rotor (see Figure 13 for additional information).61

High Pressure Turbine The rotor for the high-pressure turbine section was of solid-forged construction.62 A stub extension shaft was bolted to the governor end to carry the main oil pump, governor impeller and over speed trip weight.63

The forging was made large enough so that the blade mounting discs were created by machining away the surrounding metal. The airfoil-shaped blades were rooted into the discs. The rotating blades resisted ejection from centrifugal force with inverted serrated "Christmas-tree" roots in the impulse section and inverted "T" roots in the reaction section.64 The stationary nozzles and blades were doweled or keyed into the casing to ensure correct position relative to the moving blades. Both moving and stationary elements had shroud or seal strips to limit steam leakage past the ends and provide rigidity (Figure 14).65

At various stages in the steam flow, steam was extracted “bled” to supply auxiliaries described below. In addition, steam exiting the high-pressure turbine was diverted down to the re-heater floor below for reheating and drying before being sent to the low pressure turbines. Shaft penetrations at either end of the casing were leak points.66 Two sets of gland seals attached to the casings and closely surrounding the shaft prevented air from entering the turbine or steam from exiting. These consisted of labyrinth packing in which steam and air moving along the spinning shafts were forced to travel in a zigzag pattern between grooves cut in the shaft and surrounding soft seal rings. At each change in direction there was a loss in velocity.67 Expansion chambers in the glands provided a space for the leaking steam to loose energy.68 High pressure steam from the auxiliary steam header was admitted to a portion of the gland to provide an additional screen against air leakage in during low power operation.69 Once pressure rose in the casing this was not needed. Leakage and sealing steam were drawn from the glands by blowers and condensed in adjacent gland seal condensers.70 A separate Cylinder Heating Steam system supplied steam to the glands to prevent leaks from uneven thermal expansion.71

The entire weight of the rotors and generator were literally floated on a film of oil in a split-shell, spherical babbitted bearing at each end of the turbine and generator casings. In this design, going back to the earliest days of power machinery, a cast-steel pedestal (for the high pressure unit) held a split cylindrical shell around the shaft. Babbitt antifriction metal, a lead and tin alloy patented in 1839, was poured into the shell and finished to very close tolerance with the shaft journals.72 The bottom of the shell rested in a spherical bored seat which allowed the bearing to move and align itself with the shaft.73 The main oil pump forced oil into the bearing, forming a fluid wedge between the metal surfaces. While the double-row flow arrangement provided well balanced loads, a Kingsbury-type thrust bearing was also provided. This design originally pioneered by Westinghouse for supporting the weight of vertical hydraulic turbines, had a collar around the shaft with oil-immersed babbitted pads on either side maintaining very precise shaft position.74 A complex system maintained pressure and flow in the bearings and then cooled and filtered the used oil.75 During turbine start up an auxiliary electric pump pressurized

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the supply lines until sufficient speed was reached for a rotor shaft mounted centrifugal pump to take over. Separate oil lift pumps supplying the bearings lifted the rotors before a turning gear used during shutdowns was started.76 Because loss of oil pressure could lead to a destructive failure, there was an additional electric emergency pump run from the plant's station batteries. Clearance space between the shaft and bearing resulted in continuous flow of oil. Used oil was cooled in shell and tube coolers. Impurities such as water and entrained bearing metal were removed in filters and centrifugal purifiers.77 New and processed circulating oil was stored in two 12,500 gallon tanks in the free-standing oil storage room on the ground floor at the north end of the turbine building.78 The 10,000 gallon main reservoir was at the same level north of the condensers. All the attachment points between high-temperature elements and ambient temperature parts had to allow for relative movement. The very close tolerance between the moving and stationary blades required monitoring. Differential expansion probes measured the relative movement between the rotor and the casing.79 Vibration monitors mounted at each bearing facilitated balancing of the rotors at low speeds. They also indicated problems during run. At the rear end of the high pressure turbine shaft a bolted coupling attached to the mating coupling on the first low-pressure rotor. Steam leaving the high-pressure turbine80 could be diverted directly to the condenser by the Low-Pressure Steam Dump System. This would prevent over-speeding of the turbine during trip scenarios by reducing the low-pressure turbines' input. The safe limit of this over-speed protection function was set at 128 percent of 1800 rpm. Steam Reheating Towards the end of reciprocating steam engine development in the late 19th century, builders experimented with reheating.81 By adding more heat to the steam (re-superheating) between expansion stages they hoped to improve efficiency. Turbine builders first applied reheat cycles to American power stations in the mid 1920s, but the practice remained uncommon until after World War II.82 Steam conditions at the high-pressure end of the Connecticut Yankee turbine were generally adequate for reliability, but once the steam left the high-pressure unit, it was severely degraded. The drop in pressure through the unit from 640 to 195 psig, and in temperature from 490 to 371°F, resulted in partial condensation of the steam.83 When entrained in the steam flow, the resulting 9-10 percent moisture could cause erosion of the low-pressure turbine blades and stress corrosion cracking of rotor parts.84 To reduce this problem, the steam was dried and reheated after leaving the high-pressure turbine.85 The "crossover" exhaust steam86 was directed from the four high-pressure exhaust ports through 29-inch lines to four moisture separator re-heaters (MSRs) mounted on the mezzanine floor adjacent to each side of the low-pressure turbines87 They were 9-foot-diameter, 41-foot-long tubular pressure vessels. Upon entering the MSRs, the exhaust steam passed through demisting screens which trapped the entrained water and drained it away, leaving the steam essentially dry.88 Approximately 265 tons of water was removed every hour and drained to the feed water heating system.89 After passing through the screens, exhaust steam flowed over a tube bundle charged with 690° F steam tapped directly from the steam manifold in the auxiliary bay. Baffles caused the exhaust steam to separate and pass around four groups of tubes.90 The high temperature steam gave up heat to the exhaust adding 90-100° F of re-superheat and brought the steam temperature back up to 461°F, This process consumed 5% of the steam generator flow.91 Plant engineers acknowledged that while, in theory, the thermal benefits were uncertain, the moisture reduction function made them worth their cost and maintenance.92 The reheated dried steam left the MSR units by four pipes which went through the operating floor, to meet over and enter the center of the adjacent low-

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pressure turbine casings (two pipes/casing).93 The condensed heating steam was collected and sent to the feed heating system and helped to maintain system heat balance.94 The MSR's were laid out with clearance for their tubes to be pulled south for repair, using trolley beams mounted from steel building framing.95

Low Pressure Turbines

The two low-pressure turbines were numbered 1A and l B to distinguish them from those in the projected #2 unit. They had separate casings and rotors. Each was split horizontally like the high-pressure unit, and in addition had separate outer and inner sections.96 The inner casings were supported by the outer casings and held the stationary blades. The outer casing formed the exhaust hood which directed the exhaust steam to the condensers. The shape of the hoods was critical to the free flow of the exhaust from the casing.97 During low-steam conditions the rotating blades could act as fans, overheating the exhaust hoods.98 This was controlled with condensate spray manifolds in the hoods. The casings formed the supports for the rotor bearings, which were of similar construction to those on the high-pressure turbine.99

As described below, steam was extracted between stages of the high and low-pressure turbines to heat feed water sent back to the steam generators in Reactor Containment (HAER No. CT-185-B). Steam extraction from the three turbines reduced steam flow to approximately 4.40 million pounds per hour passing into the condensers.100 The low-pressure turbines contributed about 70 percent of the output to the condensers.101 Unlike the high-pressure unit, the low-pressure casings were not insulated.102 Steam entered the units at around 174 psi. As the steam had increased in volume (cubic feet per pound of steam) by about 3 times after leaving the high-pressure turbine, the entry ports of the low- pressure units were larger to accommodate that expansion.103 The exhaust ends had to accommodate a further increase in volume of over 200 times. The larger casings required rotors of a size that exceeded forging capacity, so they were of built-up design. Steel alloy blade mounting discs were expanded by heat, pressed, and shrunk on to the spindle and locked with keys to prevent rotation.104

As originally constructed, there were ten reaction stages on each half of the rotors.105 As the steam flowed through the low-pressure blades it continued to gain in volume so even with four exhaust paths, the last stage of blades had to be 44 inches long to cover the passages. With the increase in volume there was also an increase in steam velocity to over 600 ft. per second.106 Coupled with the increase in moisture content as the temperature dropped, these steam conditions put the last three rows of blades at risk. The ends of their leading edges were protected with strips of Stellite, a hard cobalt based alloy.107 The long blades in the last stages were highly twisted in shape, and subject to torsional and resonance vibrations.108 Metal wedges between the blades helped to stabilize them. "Christmas-tree"-style blade roots were used, similar to those in the high-pressure reaction stages.109 To control moisture, the last blade rows had slots to allow steam to flow directly to the condensers pulling out entrained water. As in the high-pressure turbine, steam was extracted between blade rows to heat feed water. The extraction points at the bottom of the casings were an additional source of moisture removal.110 Each low-pressure casing was mounted directly over and exhausted into a surface condenser described below.

Entry points of the rotor shafts in the casings were sealed with glands similar to those used on the high-pressure turbine. On the low-pressure units, where there was a vacuum at the ends of the casings, the main problem was keeping the exterior air from rushing in.111 Steam was continuously injected into these

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seals to maintain equilibrium.112 The rotors were each about 60 feet long and weighed over 118 tons. The long span between bearings and the weight of the rotors made it imperative that the unit never be stopped for any length of time, or sagging would occur. To avoid this problem when the units were not operating, a motorized turning gear was mounted alongside the 1B turbine (closest to the generator). The gear automatically began rotating the shaft at 1.5 rpm as soon as coast-down was completed.113 During long shutdowns, after the rotors had cooled to ambient temperature, the unit was manually engaged to turn the rotor daily. 114 Low Pressure Turbine Replacement Design and construction of the original Westinghouse low-pressure units had flaws causing reliability problems. These led to refurbishments and reconstructions, and finally to their replacement during the 1987 refueling outage.115 The new low pressure rotors were supplied by the Utility Power Corporation, a subsidiary of the German firm Kraftwerk Union AG (KWU). Their engineers measured the units and utilized original drawings to design the replacements, which were made to metric specifications and required metric tools for maintenance.116 The new units were generally similar to the originals but with impulse blading in the first rows, and eight reaction stages following making nine stages at each end, one less than in the original units.117 The last-stage blade length was the same in as the Westinghouse units, but the last three rows were made free standing. Root designs were changed to "T" slots for the first six rows.118 Though also of built-up construction, the new rotors had advanced engineering, metallurgy and manufacturing making them reliable. The disc bore keyways, an area prone to stress corrosion cracking, were of improved design.119 Mean hours between inspections went up from 60,000 to 100,000.120 The new blade configuration of the rotors required completely new upper and lower inner casings.121 In spite of having one less blade row, the new rotors used the same extraction points as the originals.122 The casings had "crash rings" (strengthened sections) for improved protection against ejected rotor or blade parts due to over speed failure.123 The new inner casings were designed to fit into the original Westinghouse outer casings, avoiding modifications to the turbine-generator pedestal. The hood sprays were improved with outside casing accessibility.124 The heavier replacement rotors made it necessary to increase the capacity of the bearing oil lift system. Improved vibration and differential expansion monitoring probes were installed, and exhaust pressure monitoring probes were added for the first time. 125The two rotors were attached to each other by bolted coupling flanges. As the original bolts had proven to be hard to install and remove, new quick connect types were used on the replacement units.126 The new components were barged up the Connecticut River and then up the discharge canal. Multi-wheeled Halliwell conveyors moved the units across the underground condensing water discharge structure and to the southwest end of the turbine building.127 Parts were then hoisted by the traveling crane through the access opening running through the floors. New calculations were done for the loads on the ground and for staging on the main floor as the units were somewhat heavier than the originals.128 This documentation has not determined how the original components were disposed of, or whether any warranty action was taken on Westinghouse. Generally, the life span of fossil-fuel turbine-generator sets was taken to be a minimum of 20 years.129 The original low-pressure elements of the Connecticut Yankee turbine/generator just reached that milestone.

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Condensation

After the steam finished its work in the turbines, it was condensed back to water and recycled. Two surface condensers (nos. lA and 1B) stood directly below the low-pressure turbines. The condensers were of shell and-tube construction in which cooling water and exhaust steam were not mixed, a standard design evolved from mid-19th -century steamships which needed fresh water for feeding high pressure boilers.130 In principal the Connecticut Yankee condensers simply reversed the heat exchange of the steam generators. Water flowing through tubes cooled and condensed the surrounding steam. At full load, 93,000 gallons per minute (gpm) of water was required for condensation.131

Each condenser was a welded steel tank mounted rigidly on the ground floor and connected to the bottom of its respective low-pressure turbine by a rubber expansion joint. Mounted in each condenser neck, just under the turbine connection were two feed water heater shells. Below them was the condenser tube section containing over 13,000 50-foot-long, 1-inch-diameter tubes.132 The total tube surface area was 350,000 square feet, about three times more than that of the steam generators.133 The tubes, mounted horizontally, went from one end of the shell to the other, and were attached to the sides by tube plates. Intermediate supports along the tube runs kept them from sagging. The ends of the tubes came through drilled holes in the plates and were sealed there. There were two separate tube plates at the inlet end and two at the outlet end of each condenser. Surrounding the exterior of each tube plate and bolted onto the shell was a water box, consisting of a steel semi-cylindrical casing, which channeled the cooling water flow into and out of the tubes. The water boxes, tube plates and sealed tube ends formed a contained pathway for the cooling water to travel through the condenser shell insuring that it did not mix with the steam. The twin set of water flow paths (divided water boxes) allowed one set to be closed for servicing while the other functioned at reduced turbine output.

The cooling water flowed through the tubes in a single pass, a design which required much more cooling water flow than the more common two-pass type.134 Steam from the turbine exhausts flowed down past the feed water heater shells and into baffling that prevented damage to the tubes from direct steam impingement. After leaving the baffling at reduced velocity, the steam flowed around the outside of the water-cooled tubes. Contact with the tubes condensed the steam forming water droplets that fell to the bottom of the shells. The collection point in each condenser was a hot well from which the Condensate and Feed water systems drew their supply. Condenser tubes inevitably needed replacement due to wear, corrosion and leaks. During tube renewal the old tubes were withdrawn and new tubes inserted though the removable arched panels in the west outer wall adjacent to the units.135 In the original installation most of the tubes were Admiralty Brass, an alloy of brass, zinc and tin.136 There were also some stainless steel tubes in areas where there was a risk of damage from steam impingement and ammonia attack. Maintenance costs of the brass tubes were high due to stress corrosion cracking and the first tube replacement occurred in 1977.137 By 1986 all the tubes were again replaced in a series of repair episodes with a stainless steel alloy called Trent Sea-Cure.138 Though the new tubes had enhanced resistance to biofouling, they proved vulnerable to vibration cracking which required additional supports.139

Circulating water to condense the exhaust steam was pumped from the river and arrived at the west side of the Turbine Building at the 12-foot elevation via four 66-inch-diameter concrete encased carbon-steel pipes.140 Two pipes of bare steel rose up through the floor slab adjacent to each condenser.141 Each pipe supplied one half of the condenser by a flexible connection to a water box.142 The circulating water pumps

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in the Screenwell House (HAER No. CT-185 A) could not pump water all the way from the river intake level of -15 ft to the tops of the condenser tubes at 35.5 ft when starting up.143 They were augmented by a vacuum priming system including two vacuum priming pumps on the Turbine Building ground floor and vacuum priming tanks attached to each of the four water boxes.144 Once the condensers were filled and the flow started, the priming pumps were not needed for that purpose. After exiting the condenser tubes and outlet water box, cooling water was piped out in four carbon-steel pipes of similar construction to those connected to the inlet water boxes.145 The pipes carried the water about 23 feet to a concrete discharge tunnel running next to the east wall of the turbine building, directly under the auxiliary bay.146 The tunnel was 12 feet wide by 15 feet high; an even larger tunnel was built next to it with a shared wall to accommodate the discharge requirements of the never-built second reactor.147 In addition to allowing the condensed steam to be recycled as feed water, the condensers provided the important benefit of vacuum. When condensed in a closed space, steam rapidly loses volume producing a vacuum. This allowed the steam flowing through the low-pressure turbines to do work considerably below 14.7 1bs atmospheric pressure.148 The Connecticut Yankee condensers produced a vacuum of up to 1.9 in. Hg absolute (28.1 inches of mercury).iv The additional use of steam below 14.7 psig in the turbines provided a large portion of their total output.149 While the vacuum-forming process was naturally the result of condensation, air build-up would have negated the level of vacuum in a short time. Two priming and two main two-stage air ejector units on the second level mezzanine were the primary units used to start and maintain the vacuum.150 Steam from the main steam manifold was piped into the ejectors and flowed through velocity-increasing venturi nozzles in communication with the condensers. The high speed steam flow in effect, "dragged" the air out of the condensers.151 The discharged condenser air was sent to the atmosphere by the primary vent stack located northwest of Reactor Containment. A radiation monitor was located in the stack to detect air contaminated by radioactive steam resulting from a steam generator tube leak.152 The air ejectors could also aid in reactor decay heat removal by blowing steam into the atmosphere if the high pressure steam dump system was not available.153 In addition to its job of topping off the condensers, the vacuum priming system also removed air from supply piping, water boxes, and tubes before startup. The system remained on during turbine run to remove collected air in the tubes and water boxes.154 Condenser vacuum control was critical to plant efficiency. The levels in each unit had to match closely or the turbines would be un-evenly loaded. A rise in back pressure to 24.5 in. would lead to an emergency shut down.155 The condensers provided an important safety function. In the event of a turbine trip and reactor trip, steam could be bypassed directly from the steam header to the condensers by the high pressure steam dump system.156

iv Steam pressure was measured (English System) in pounds per square inch gage (psig). This meant that the steam gage “0" point was actually the 14.7 pounds per square inch (psi) pressure of the atmosphere at sea level. Vacuum at the exhausts of the lp turbines and condenser was measured backwards from 14.7 psi down to true zero (absolute zero.) Modern dial type vacuum gages were derived from mercury filled tubes similar to barometers. They were graduated in 30 inches of mercury, with every 2 inches equaling one pound of pressure. Thus the condenser vacuum of 1.9" Hg absolute (28.1" of mercury) equaled a pressure of less than a pound over absolute zero (Ripper 1903: 121).

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Condensate and Feed water Pumping The condensed steam (condensate) was the main source of feed water for the steam generators. The collection points were the hot wells which constituted the lower two feet of the condenser shell, and normally held 33,000 gallons. Two condensate pumps on the Turbine Building ground floor removed water from the hot wells and started it on its route to Reactor Containment.157 These were 6200-gpm, 1500-hp AC induction-motor-driven vertical pumps with suction and pressure stages. They pulled at condenser vacuum and outputted at 350 psi. The condensate first passed through the condenser air ejectors to condense their exhaust.158 It then flowed through two parallel trains of five low-pressure feed water heaters described below (heating steam from the low-pressure turbines) to the steam generator feed pumps on the main floor of the auxiliary bay. The inside piping diameters in this system varied from 30 inches at the hot wells to 16 inches through the feed water heaters leading to 18-inch suctions for the feed pumps. Most of the steam used in the feed water system heaters drained as water into the main condenser, but there were still losses requiring replenishment. The "make-up feed" was drawn from two wells south of the plant.159 and stored in the 100,000-gal. demineralized water tank near Reactor Containment (TK-25-1 A). This tank fed directly into the condenser hot wells in the event it received a low level signal.160 Leaks from steam generator or condenser tubes could pollute the feed water leading to damage.161 The original design included two demineralizers on the ground floor of the auxiliary bay that were used to treat well water prior to use in the plant systems. Later in the plant's operating history truck mounted units proved to be a better option. Provision for adding corrosion inhibitors to feed water also existed in the auxiliary bay. After leaving the condensate feed pumps, the condensate water flow was considered part of the feed water system.162 In addition to increasing the plant efficiency, the system had the important role of providing a contiguous heat sink (absorber) of reactor heat.163 The two steam generator feed water pumps were horizontal 960-gallons per minute (gpm), 4500 hp induction- motor-driven centrifugal units on the ground floor of the turbine building. The feed water left the pumps at 1100 psi and went through a last high-pressure stage of heating noted below. The two lines fed an 18-inch header in the Turbine Building from which a separate 12-inch feed line was routed to each steam generator in Reactor Containment.164 Each of the condensate and feed water pumps took half the station load. All had to be operated to pump the 7.6 million gallons per hour (gph) required under full load.165 Main feed water air-operated regulating valves controlled the flow of water to the steam generators and maintained their level. 166 If their control air failed they would close automatically to prevent overfeeding of the steam generators which could lead to ineffective moisture removal, blade damage and missile ejection from the turbines caused by excess water. A separate set of feedwater header isolation valves prevented designed leakage in the main valves from reaching and overfeeding the steam generators and also prevented over-pressurization of containment if there was a line break. Many valves in the feedwater system automatically opened on turbine trip to reduce reactor coolant temperatures.167 Auxiliary Feed Water System-Terry Turbine Building To ensure a continuous un-interruptible supply of feedwater if the main Feedwater System was not functional, Connecticut Yankee had an Auxiliary Feedwater System (AFW) supplied from the Terry Turbine Building (HAER CT-185-E), a 40-foot-wide, 43.5-foot-high steel-framed, Galbestos-sided

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structure extending 11 feet west of the Containment Building (Figure 8). The facility was named after two Terry Turbine driven auxiliary feed pumps.168 The units were driven by steam if main feed pumps were not functioning. Even if all electric power and backup diesel generators were lost, the Terry Turbines could continue to continue to cool the reactor from the steam produced by decay heat from the reactor. Unlike fossil fueled station which often had many steam powered auxiliaries, the Terry Turbines were the only steam driven pumps at Connecticut Yankee. The system automatically activated if the circuit breakers on the main pumps tripped, or low water was sensed in two of the steam generators. On account of its important role in RCS heat removal, the AFW was maintained as part of the plant Engineered Safety Systems. The Terry Turbine was developed by the Terry Steam Turbine Company of Hartford, CT early in the 20th Century169 and became a favored prime mover in the power industry for driving fans and boiler feed pumps due to their ruggedness, relatively high efficiency, and high speed.170 The units were driven by steam supplied by the steam generators. They sent feedwater back to the generators to remove heat from the reactor when the main feed pumps were not operating. The single forged turbine wheel had multiple semi-circular buckets (blades) machined directly in the forging, and reversing chambers cast in the surrounding casing. Steam was admitted directly into the buckets causing them to move from the impact. Steam was then turned 180 degrees in the reversing chambers and re-admitted to the buckets and chambers several times until most of the energy was gone. The unit had very large clearances between the turbine wheel and the reversing chambers for reliability and could even continue to operate if the steam turned to water.171 Steam supply was from the #3 and #4 steam generators through the atmospheric steam dump valve supply header. Special throttling control valves with greater reliability than other types were operated by the plant control air system and would automatically open if the system failed. The directly connected pumps were 450-gpm multi-stage centrifugal types which supplied their own lubrication, shaft sealing, and cooling, independent of plant systems. Supply water for the AFW came from the Demineralized Storage Water Tank that was located within a concrete protective shield wall south of the Terry Turbine Building. Protection from freezing was insured by the plant heat trace circuit system. The atmospheric dump valves were located in the Terry Turbine building. When a rapid shutdown of the main turbine was necessary, operators would dash out of the east door of the Turbine Hall, down the outside stairs, across the roof of the service building to the Terry Turbine enclosure to manually open the atmospheric dump valves to vent steam away from the turbine. 172 A third component of the system was a manually operated electric motor driven pump located in a separate enclosure south of the Terry Turbine Building. The 725 gpm pump could supply feedwater when the Condensate and Feedwater systems were manually shut down, and provided a back up source if the main pumps and Terry Turbine pumps were involved in a loss of feed incident.

Feed Heating It was well established by the middle of the 19th century that preheating the water going into a boiler with waste heat gases saved the amount of fuel required to raise steam.173 The regenerative (extraction) system was developed c l915 in which steam was bled out of the turbine between blade-row pressure stages to

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heat the feed water.174 Although there was a net loss of steam for power production, overall system efficiency was increased, in part due to the reduction in steam entry into the condensers.175 The combination of reheating between turbines and regenerative feed heating improved the overall station efficiency even more. In the Connecticut Yankee regenerative system, there were six stages of heating.176 This process was split between six pairs of feed water heaters in different locations in the main and auxiliary sections of the Turbine Building, forming two separate trains.177 The feed water heaters were pressure vessels filled with a tube bundle. Feed water forced through the tubes was heated by condensing a flow of steam passing through the vessel.178 All the feed heating steam was bled from six extraction points (stages) between the blade rows in the lower casings of the turbines. The heating process began at the condensers and continued in the direction of Reactor Containment. However, the heaters were numbered according to their steam extraction location (blade row) in the turbines which was in reverse order to the feed flow.179 Heaters Nos. 6-2 were technically part of the condensate system flow path.180 Each heater train was designated 1A or 1B from its respective source of feed water, the 1A and 1B condenser hot wells.181 The first portion of feed water heating (stage 6 and 5) occurred in four low-pressure units mounted two each in the necks of the condensers on a west/east axis. The reason for this location is undocumented but was apparently the standard location in Westinghouse plants.182 Two units (6A and 5A) received steam from the 6th-and 5th-stage extraction points on low-pressure turbine l A. The 6B and 5B units received steam from the same points on low-pressure turbine 1B.183 The feed water emerged from the first group of heaters, flowed on either side of the turbine pedestal, and was piped up through the operating floor to the second group of low-pressure heaters (4A and 3A, 4B and 3B), mounted on that floor along the east and west walls.184 The A heaters were on the east side and the B heaters on the west. Each set received steam from the 4th and 3rd stage extraction points of its respective low-pressure turbine. The last portion of low pressure heating occurred on the auxiliary bay mezzanine, where Heaters 2A and 2B were floor mounted under the main steam manifold. They received steam from the exhaust of the high-pressure turbine.185 At this point, the feed water was routed down to the steam generator feed pumps on the ground floor. These forced the water through the high-pressure, final stage of feed heating, in high-pressure heaters l A and l B also on the auxiliary bay mezzanine. These received steam from the first extraction stage of the high-pressure turbine.186 Since the number 2 and 1 feed water heaters were downstream of the feed water pumps in the heat cycle, they were technically considered part of the feed water system. Feed water was kept from boiling by the high pressure in the line.187 In total, as the feed water traveled from the hot well to the last heater outlet it had gained between 260-330°F of heating.188 The water in an extraction feed heating system is a considerable reservoir of heat energy. If the turbine were to trip, there was a risk of high temperature water flowing back into the turbines and then turning to steam (flashing) as its pressure dropped, causing an over speed.189 To prevent that, most of the heaters had balance-type check valves or electrically-activated non-return valves. The condensate produced by the heat exchange in the feed water heaters was collected by a drain system and returned to the feed flow.190 The low-pressure heaters drained back through the shells to the condenser hot wells.191 Water from the high-pressure heaters flowed through to the high pressure drain tank. This source provided about 30 percent of the feed flow to the steam generators.192 The feed water heaters were originally piped with the same type of Admiralty Brass tubes as the condensers. Copper shedding into the feed flow led to the complete replacement with stainless

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tubes.193 As in the moisture separator re-heaters, plant builders had to provide clearance for the tubes to be withdrawn from one end of each shell for service. In the case of the condenser mounted heaters, removable panels in the west outer wall of the building were used to provide clearance for tube withdrawal from lA heaters. The lB heater tubes were pulled into the auxiliary bay. 194 Electrical Generation The south end of the 1B low-pressure turbine shaft was directly connected by coupling bolts to a 667 mega volt ampere (mva) synchronous alternator (generator).v The output in kilowatts (in 1987) was nominally 619,328 with a maximum output of 648,527 at 19,000 volts, 22,000 amps. It had a revolving-field design, which evolved in the late nineteenth century from the original revolving-armature dc generators.195 The main elements were the armature (stationary windings) known as the stator and the field (rotating magnets) known as the rotor. In basic terms, electrical energy was produced in the armature windings when an interrupted magnetic field was passed through them by the rotating field.196 As the rotor turned, the electro-magnets produced a moving field that extended out into the stator windings producing a voltage by electromagnetic induction. Since each magnet pole was of opposite polarity to its neighbor the induced voltage was intermittent.197 The voltage produced in the stator windings rose and fell in a sine wave called an alternation. Since the rotor had four magnetic poles it produced two cycles (hertz) per revolution.198 At 1800 rpm, it gave an alternating-current frequency off 60 cycles per second (cps). Synchronous machines are designed to operate in cyclic phase with all the generating equipment supplying the grid.199 When operators in the control room connected the unit to the power grid, they used a synchroscope to ensure that the output was in phase with the rest of the system. Failure to do that could lead to explosive destruction of the generator, requiring automatic safety relays to protect from operator error. The conductors for magnetizing the poles were laid in deep slots cut into the rotor spindle. This form was pioneered by C. E. L. Brown for high-speed turbine driven generators in the early twentieth century.200 To resist the centrifugal force acting to throw out the windings, they were held in place by fabricated retainer rings. The rotor was supported in oil-pressure bearings of the same type as the turbines and was in the same oil supply loop.201 The stator body was fabricated of individual fabricated rings of silicon steel. The silicon content gave the laminations high magnetic permeability, reduced reluctance (resistance)202 and concentrated the field magnetic flux in the windings. Slots were formed in the inner circumference of the rings to receive the copper conductors. The laminations were individually insulated, then stacked and pressed forming a hollow core.203 Insulated through-bolts running from end to end ensured structural integrity. The laminated form of construction in which each component was insulated from its neighbor reduced the production of eddy currents which caused electrical losses.204 The core was mechanically locked into the stator inner frame with key bars set into dovetails on the outer surface of the core.205 Working in the early twentieth century, B. G. Lamme, Chief Engineer of Westinghouse, made many of

v Kilovolt amperes (kva) and megavolt amperes (mva) are ratings for electrical equipment based on potential capacity and are higher than the watts measurements used since the nineteenth century. Volt ampere ratings are affected by power factor, the electrical efficiency of a circuit expressed as the ratio of actual power to apparent power. When noted with the power factor figure they provide an accurate picture of the real capacity of the electrical equipment (Dawes 1928: 158).

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the improvements to the wiring form of turbine generators incorporated into the Connecticut Yankee armature.206 There were three separate winding coils running the length of the stator giving three-phase power. They divided the stator circle equally giving 120 degree separation of their alternations.207 There were two insulated copper bars laid in each longitudinal trough formed by the lined-up slots. Each bar was made up of a number of insulated copper conductors formed in a spiral pattern. Insulation of each component of the conductors from adjacent components was critical to prevent destructive short circuits and electrical phenomena such as coronas.208 The electrical discharge from coronas constituted an electrical loss and produced ozone which could attack the insulation.209 The coils had Thermalastic mica and resin insulation, introduced by Westinghouse in 1949, which had good resistance to ozone attack.210 In addition to the insulation requirements, the conductors had to withstand structural displacement. They were held in place by wedges and springs to resist the powerful electromotive forces at work. At the ends of the core, the bars were joined by connection rings which completed the coils and oriented them in their respective phases. By connecting the bars in each coil in series, the voltages induced in each added up.211 The electrical power was taken off with a grounded wye (Y) connection212 eliminating the need to take out six leads (two for each phase). Instead, one lead came off each phase, with a neutral attaching to all three.213 The current flow in the conductors produced heat which had to be drawn off to prevent a drop in output.214 The generator utilized pressurized hydrogen gas at over 60 psi passing through the stator and rotor for cooling. This cooling method came into use in the mid 1930s.215 Hydrogen gas was supplied from outdoor banks of cylinders. To ensure complete coverage by the gas, a blower fan was shaft mounted near the coupling at the turbine end. This forced the gas into four hydrogen coolers where the gas gave up its heat to a flow of water from the service water system. Hydrogen then flowed through the rotor and stator. Field windings in the rotor were ported to ensure gas flow. Vent plates between the stator laminations promoted even cooling. Heating of the generator leads, bushings and connectors was prevented by hydrogen streams.216 Because the generator's outer casing was under gas pressure, special gland seals were needed at each end of the casing at the shaft penetrations using oil under pressure.217 These prevented hydrogen from exiting and creating an explosive mixture with the air in the Turbine Building. Any hydrogen left in the casing when opened for repair could also combine with incoming air and cause an explosion. Carbon dioxide was used to purge the hydrogen before maintenance, and to purge air in the machine before hydrogen was introduced.218 Most direct-current generators produce their own field magnetizing current. Synchronous alternating-current machines must have an outside source of this DC excitation current. The 500- volt DC to excite the rotating field came from a separate AC/DC rotating rectifier exciter mounted on an extension shaft coupled to the south end of the generator shaft. Utilizing an AC exciter generator and rectifying the current to DC (instead of a direct DC exciter) allowed a simpler and more reliable unit without pickup brushes. The exciter conductors were ventilated by air which gave up its heat in an air cooler connected to the service water system.219 The exciter received its excitation current from a small permanent magnet DC generator (pmg) on the end of the exciter shaft.220 A bored hole in the rotor shaft provided a route for wires from the exciter to the field magnet conductors.221 In addition to producing the magnetizing current, the exciter system controlled generator output voltage during start-up. The critical device for this purpose was the solid-state voltage regulator which controlled the output of the pmg.222 Varying the current going into the rotor with the voltage regulator directly affected the voltage produced by the generator. Once the generator was up to speed and synchronized with the system electrical grid by operators in the control

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room, the output was controlled by interaction among the system loads, the turbine governor and control circuitry in the regulator.223 The generator produced 19,000 volts at 22,000 amps. Prior to the low-pressure rotor replacement, the average output was 605 mw. The improved performance with the new rotors boosted that to 612 mw.224 vi

The generator output was directed out of the south end of the Turbine Building through an isolated-phase bus duct system.225Each phase was contained in a separate metal enclosure. A fan forced air through the ducts to draw off resistance heated air. The air was cooled in heat exchangers fed by the service water system.226 The bus was split, connecting to two outdoor number-designated transformers in the 12R Switchyard at the south end of the building.227 The #319 Transformer was the step-up device to raise the voltage to the system grid's 345 kilovolts (kv). This high voltage allowed transmission for long distances economically since it allowed small copper conductors to carry power at lower current. The heart of the transformer unit was the laminated silicon steel core with primary (entrance) and secondary (exit) windings. The core had separately insulated windings for each of the three phases.228 The high amperage/low voltage output of the generator produced high voltage/low amperage current in the secondary windings via electromagnetic induction. The laminated construction of the cores served the same purpose as that of the generator stator; the reduction of wasteful eddy currents. The core and windings were secured inside an aluminum oil tank.229 Heat produced by the current flow was drawn off by the oil around the windings. Heated oil was continuously pumped into tubed heat exchanger units attached to the outer casing and cooled by fans. As the load on the station increased and oil temperatures rose, the fans came on automatically to maintain the full rating (power capacity) of the transformers. Current was taken out of the tank by three wires with insulated oil-tight bushings and sent via the #320 Line to the 14B 345 kv Switchyard, at the southeast end of the plant site, for distribution to the system grid.230 The output voltage could be adjusted (though not under load) with a tap changer hand wheel on the transformer which changed the ratio of primary to secondary wiring.231 There were no isolating breakers or switches between the main generator and the 319 Transformer. When de-energized it could be isolated from the #320 line to the main 14B Switchyard by motor-operated disconnect (MOD) switches, which could also be manually cranked open/closed.232 When under load, the #319 unit was switched by gas-quenched power circuit breakers in the 14B yard.233 Between the transformer and MODs were the lightning arresters.234

The 19,000 KV generator output was also sent to the #309 step down transformer. It was of similar construction to the #319 unit, and produced a lower voltage of 4.16 KV for supplying the reactor coolant pumps.235 A series of primary and backup protective relays in the control room prevented damage to the reactor, turbines and generator from electrical problems. The relays could be activated by faults in either the turbine power into the generator, generator output, or the distribution grid.236 Faults in the system such as grounds in the generator, leads, and transformers automatically activated relays in the switchyard to protect the grid. The exciter would have also tripped dropping the generator output. Relays protected against two conditions which could lead to over speeding of the generator turbine: loss of field and reverse current.237 Some of the protective relays had time delays if a too rapid shutdown could endanger other equipment up or downstream of the fault.

vi These average figures are lower than the mean and maximums shown above under Turbines.

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Other anomalies such as loss of service water for cooling the hydrogen system, low bearing or seal oil, and loss of exciter cooling air would either trigger alarms to warn operators to make manual adjustments or the relays could initiate an automatic shutdown if warranted.238

NOTES 1 Connecticut Yankee Atomic Power Company 1966-1974: 8.12-1,2; Connecticut Yankee Atomic Power

Company. Stone & Webster Engineering Corp. 1964a-b, 1964d-e [drawings]. 2 Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964f [drawings]; HH

Robertson/Asia Pacific Group 2003, Simpson 1970: 192 3 Connecticut Yankee Atomic Power Company 1987b: 5; Connecticut Yankee Atomic Power Company. Stone

& Webster Engineering Corp. 1964f drawings]. 4 Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964-1992 [drawings]. 5 Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964-1967, 1964-1980b

[drawings]. 6 Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964-1976 [drawings]. 7 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 57, page 1. 8 Ibid: page 3. 9 de Belidor 1737-1753, v3: 360. 10 MacNaughton 1967: 340-343. 11 Connecticut Yankee Atomic Power Company 1998: 1.2-12; Connecticut Yankee Atomic Power Company

1987-1995. Chapter 16, page 22. 12 Ibid: page 22. 13 Ibid: page 46. 14 Ibid: page 6. 15 Ibid: page 17. 16 Ibid: page 46. 17 Ibid: Chapter 16, page 13. 18 Ibid: page 33.

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19 Ibid: page 5. 20 Connecticut Yankee Atomic Power Company 1966-1974: 8.1-1. 21 Ibid: 8.1-4; Connecticut Yankee Atomic Power Company 1998a [drawings]. 22 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 17, page I. 23 Ibid: page 3 24 Connecticut Yankee Atomic Power Company 1966-1974: 8.1-1. 25 Connecticut Yankee Atomic Power Company. Stone & Webster Engineering Corp. 1964-1976 [drawings]. 26 Connecticut Yankee Atomic Power Company 1966-1974:8.2-1; Connecticut Yankee Atomic Power Company c.l972:12, 1998: 1.2-11. 27 MacNaughton 1967: 513. 28 Connecticut Yankee Atomic Power Company 1998:1.2-11; Gray 1917: 14. 29 Morgan 1950: 9. 30 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 22, page 1. 31 Church 1935: 9. 32 Morgan 1950: 8. 33 Church 1953:10. 34 Sinton 1966: 112. 35 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 22, page 42. 36 Ibid: page 42. 37 Connecticut Yankee Atomic Power Company 1966-1974: 8.2-1. 38 Ibid: 8.2-2. 39 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 22, page 43. 40 Ibid: page 43 41 Ibid: page 6.

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42 Connecticut Yankee Atomic Power Company 1966-1974: 8.2-2. 43 Clark 2004. 44 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 23, page 3. 45 Ibid: page 4. 46 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 23, page 3; MacNaughton 1967: 507. 47 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 23, page 18. 48 Connecticut Yankee Atomic Power Company 1966-1974: 8.2-2. 49 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 23, page 38. 50 Ibid: page 22. 51 Ibid: Chapter 22, page 18. 52 Ibid: page 18. 53 Ibid: page 18. 54 Ibid: Chapter 22, page 19; MacNaughton 1967: 509. 55 MacNaughton 1967: 476. 56 Ibid. 477; Richardson: 191): 5. 57 MacNaughton 1967: 475. 58 Morgan 1950: 10. 59 Hossli 1969: 105. 60 Morgan 1950: 10. 61 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 22, page 13. 62 Ibid: page 22. 63 Ibid: page 22. 64 Ibid: page 83-84. 65 Ibid: page 34.

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66 Ibid: page 32. 67 MacNaughton 1967: 487. 68 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 27, page 3. 69 Ibid: page 5. 70 Ibid: page 7. 71 Ibid: page 1. 72 Bourne 1846: 229, Knight v1: 205 73 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 22, page 38. 74 Ibid. 39; Lafoon 1950: 28. 75 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 26, page 1. 76 Ibid: page1. 77 Ibid: page 38-43. 78 Connecticut Yankee Atomic Power Company / Stone & Webster Engineering Corp. 1964-1992 sheet 1

[drawings]. 79 Connecticut Yankee Atomic Power Company 1986-1989: NEO.3 Rev. 6, p. 3 of 21 (Nov 21, 1986): 1987-

1993: Chapter 22, page 98. 80 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 23, page 7. 81 Meyer 1905: 63. 82 Engineering 1926: 285; Jackson 1952: 55. 83 Connecticut Yankee Atomic Power Company 1966-1974: 8.2-1,3. 84 Ibid: 8.2-3; Connecticut Yankee Atomic Power Co. 1987-1995: Chapter 24, page 1 85 Ibid: page 1. 86 Ibid: page 1. 87 Ibid: page1. 88 Connecticut Yankee Atomic Power Company 1966-1974: 8.2-3.

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89 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 24, page 11; Sinton 1986: 110. 90 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 24, page 13. 91 Ibid: page 36. 92 Ibid: pages 34-38. 93 Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1967, [drawings]. 94 Ibid; Connecticut Yankee Atomic Power Company 1966-1974: 8.2-3; Connecticut Yankee Atomic Power Company 1987-1995: Chapter 24, page 35. 95 Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1967, [drawings]. 96 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 22, page 34. 97 Ibid: page 35. 98 Ibid: page 35. 99 Ibid: page 5. 100 Connecticut Yankee Atomic Power Company c. 1972: 12. 101 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 24, page 36. 102 Clark 2003. 103 Hossli 1969: 103. 104 Sinton 1966: 113. 105 Connecticut Yankee Atomic Power Company c. 1972: 13. 106 Hossli 1969: 101. 107 Sinton 1966: 112. 108 Hossli 1969: 108. 109 Connecticut Yankee Atomic Power Company 1986-1989: Doc 86-94, 9/17/87, page 114. 110 Sinton 1966: 110. 111 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 27, page 1. 112 Power 1982: 345.

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113 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 22, page 47.

114 Ibid: page 47.

115 Connecticut Yankee Atomic Power Company 1986-1989: Plant Design Change Record 886, Rev. 0, 5/29/87, page 7.2-4.

116 Clark 2003.

117 Connecticut Yankee Atomic Power Company 1986-1989: Doc 86-94, 9/17/87, page 114.

118 Ibid: page 114.

119 Kraftwerk Union AG 1986: 4.

120 Connecticut Yankee Atomic Power Company 1986-1989: GDA-PDCR886-002.

121 Ibid: Plant Design Change Record 886, Rev 0, 5/29/87, page 7.2-1.

122 Ibid: 7.3-3.

123 Kraftwerk Union AG 1986: 24.

124 Connecticut Yankee Atomic Power Company 1986-1989: Memo PSE-CE-87-683.

125 Connecticut Yankee Atomic Power Company 1983-1987: Memo, W.D. Barton to G.F. Veredonee and P.D. Watson, 12/6/83, page 2.

126 Connecticut Yankee Atomic Power Company 1986-1989: Plant Design Change Record 886, Rev. 0, 5/29/87, page 7.2-1.

127 Connecticut Yankee Atomic Power Company 1987b:1.

128 Ibid: 3.

129 Hossli 1969: 110.

130 Main 1893: 224.

131 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 41, page 12.

132 Westinghouse Electric Corporation 1964 [drawings].

133 Connecticut Yankee Atomic Power Company c. 1972: 13.

134 Connecticut Yankee Atomic Power Company 1987-1995: chapter 41, pages 12, 23; MacNaughton 1967: 541.

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135 Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964e [drawings].

136 Brass.org 2003: 1.

137 Northeast Utilities 1985: 2.

138 Ibid; Northeast Utilities 1986; Connecticut Yankee Atomic Power Company 1987-1995: chapter 18, page 11.

139 Ibid: chapter 41, page 24.

140 Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1968 [drawings].

141 Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1992, Section AA [drawings].

142 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 41, page 24.

143 Ibid: Chapter 42, page 1.

144 Ibid: Chapter 42, page 3.

145 Ibid: Chapter 41, page 28.

146 Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1968, Sheet 1 [ drawings].

147 Ibid; Connecticut Yankee Atomic Power Company 1987-1995: Chapter 41, page 28.

148 MacNaughton 1967: 533.

149 Morgan 1950: 14.

150 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 28, page 1.

151 Ibid: page 3.

152 Connecticut Yankee Atomic Power Company 1966-1974: 8.4-2.

153 Ibid; Connecticut Yankee Atomic Power Company 1987-1995: Chapter 28, page 8.

154 Ibid: Chapter 42, page 1.

155 Ibid: Chapter 18, page 28.

156 Ibid: Chapter 17, page 2.

157 Ibid: page 2.

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158 Ibid: Chapter 28, page 13.

159 Connecticut Yankee Atomic Power Company 1966-1974: 8.7-1.

160 Ibid: 8.3-2.

161 Kinsman 2001: 1.

162 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 20, page 2.

163 Ibid; Chapter 19, page 1.

164 Connecticut Yankee Atomic Power Company 1998: Fig. 10.4-5, Sheet 9.

165 Ibid: Connecticut Yankee Atomic Power Company 1987-1995: Chapter 19, page 8.

166 Ibid: page 18.

167 Ibid: page 8

168. Ibid: Chapter 21, page 1.

169. American Society of Mechanical Engineers 1920: 40.

170. MacNaughton 1950: 493.

171 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 21, page 13.

172 Personal Communication-Gerald Loftus - May 2010

173 Clark 1889: 275.

174 Parsons 1939: 183.

175 Engineering 1926; 285; Lorenzi 1952: 13.6.

176 Connecticut Yankee Atomic Power Company CYAPCO a c.1972: 14.

177 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 20, page 1.

178 Ibid: page 2.

179 Connecticut Yankee Atomic Power Company 1966-1974: 8.1-4.

180 Ibid; Connecticut Yankee Atomic Power Company 1987-1995: Chapter 20, page 2.

181 Connecticut Yankee Atomic Power Company /Stone & Webster Engineering Corp. 1964-1980b [ drawings].

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182 Clark 2004. 183 Connecticut Yankee Atomic Power Company 1998D, 1998C [drawings]. 184 Connecticut Yankee Atomic Power Company/ Stone & Webster Engineering Corp. 1964-1993. 185 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 20, page 4. 186 Connecticut Yankee Atomic Power Company/ Stone & Webster Engineering Corp. 1998b [drawings]. 187 Lorenzi 1952: 19-1. 188 Connecticut Yankee Atomic Power Company 1966-1974: Fig 8.2-2. 189 Ibid: 8.1-4. 190 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 20, page 1. 191 Ibid: page 8. 192 Ibid: page 7. 193 Connecticut Yankee Atomic Power Company n.d.: 50 of 57. 194 Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964e, 1964-1980b

[drawings]. 195 Thompson 1890: 602. 196 Bureau of Naval Personnel 1960: 131. 197 Ibid: 217 198 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 4, page 104; Gray 1917: 195. 199 Thompson 1900: 659. 200 Bowers 1983: 69. 201 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 61, page 13. 202 Dawes 1937: 1/250. 203 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 61, page 7. 204 Ibid: page 7.

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205 Ibid: page 8. 206 Passer 1953: 265. 207 Bureau of Naval Personnel 1960: 223. 208 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 61, page 9. 209 Dawes 1928: 443. 210 Westinghouse 2001: 1. 211 Bureau of Naval Personne1 1960: 221. 212 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 61, page 7. 213 Bureau of Naval Personnel 1960: 223. 214 Lafoon 1950: 25. 215 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 32, page l0. 216 Ibid: Chapter 61, page 9. 217 Ibid: page 12. 218 Ibid: page 63. 219 Ibid: page 50. 220 Ibid: page 16. 221 Ibid: page 18. 222 Ibid: page 19. 223 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 22, page 16. 224 Connecticut Yankee Atomic Power Company 1987a: SE-28. 225 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 47, page 2. 226 Ibid: page 3. 227 Ibid: Chapter 62, page 1. 228 Bureau of Naval Personnel 1960: 235.

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229 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 61, page 40.

230 Ibid: Chapter 62, page 1.

231 Ibid: Chapter 61, page 40.

232 Ibid: Chapter 62, page 3.

233 Ibid: page 12.

234 Connecticut Yankee Atomic Power Company 1966-1974: 9.2-1.

235 Connecticut Yankee Atomic Power Company 1987-1995: Chapter 61, page 39.

236 Ibid: page 48.

237 Ibid: pages 56, 58.

238 Ibid: page 65.

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SOURCES OF INFORMATION/BIBLIOGRAPHY

A. Engineering Drawings

Drawings are archived as part of the Connecticut Yankee Atomic Power Company, Haddam Neck Plant Records Collection, Series I, Archives & Special Collections, Thomas J. Dodd Research Center, University of Connecticut Libraries.

Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp.

1964a North Elevation. Turbine Building Area. Nuclear Power Plant - Unit No. 1. No. 16103-14004. [reproduced as HAER No. CT-185, Sheet 1 of 12]

1964b South Elevation. Turbine Building Area. Nuclear Power Plant - Unit No. 1. No. 16103-14005. [reproduced as HAER No. CT-185, Sheet 2 of 12]

1964c Wall Sections. Turbine Building & Auxiliary Bay. Sheets 1 & 2. Nuclear Power Plant - Unit No. 1. No. 16103-14006.

1964d East Elevation. Turbine Building Area. Nuclear Power Plant - Unit No. 1. No. 16103-14044. [reproduced as HAER No. CT-185, Sheet 3 of 12]

1964e West Elevation. Turbine Building Area. Nuclear Power Plant - Unit No. 1. No. 16103-14045. [reproduced as HAER No. CT-185, Sheet 4 of 12]

1964f Arrgt. - Turbine Support Outline. Machine Location-Plan & Sect. Turbine Area-Reheater Level. Nuclear Power Plant - Unit No. 1. No. 16103-27062. [reproduced as HAER No. CT-185, Sheet 5 of 12]

1964-1965 Equipment Handling. Generator Stator & L.P. Rotor. Nuclear Power Plant - Unit No. 1. No. 16103-27017.

1964-1966 Turbine Gen. Dismantling & Lay-Down Arrgt. Nuclear Power Plant - Unit No. 1. No. 16103-27018.

1964-1967 Machine Location-Plan & Sect. Turbine Area-Reheater Level. Nuclear Power Plant - Unit No. 1. No. 16103-27055. [reproduced as HAER No. CT-185, Sheet 8 of 12]

1964-1968 Circulating Water Lines-Sheets 1 & 2. Nuclear Power Plant - Unit No. 1. No. 16103-20085.

1964-1980a Flow Diagram. Misc. Drains - Secondary Plant. Nuclear Power Plant - Unit No. 1. No. 16103-27019.

1964-1980b Machine Location-Plan & Sect. Turbine Area- Mezzanine Level. Nuclear Power Plant - Unit No. 1. No. 16103-27053. [reproduced as HAER No. CT-185, Sheet 7 of 12]

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(Page 78) 1964-1993 Machine Location Plan. Turbine Area - Operating Floor. Nuclear Power Plant - Unit No.

1. No. 16103-27052. [reproduced as HAER No. CT-185, Sheet 9 of 12] 1964-1992 Machine Location. Turbine Area - Sections. Sheets 1 & 2. Nuclear Power Plant - Unit

No. 1. No. 16103-27056. [reproduced as HAER No. CT-185, Sheets 10-11 of 12] 1964-1997 Machine Location Plan. Turbine Area - Ground Floor. Nuclear Power Plant - Unit No.

1. No. 16103-27054. [reproduced as HAER No. CT-185, Sheet 6 of 12]

1965a Sheets 1 & 2. Misc. Details. Turbine Area. Nuclear Power Plant - Unit No. 1. No. 16103-14035.

1965b Yard Pipe Sup. & Plate Housing. . No. 16103-14038.

Northeast Utilities Service Company. Connecticut Yankee Atomic Power Company. 1978 Location & Details for Concrete Sumps in Turbine Bldg El. 21'-6." Sheets A & B. No.

16103-11014. 1979-1982 Machine Location - Partial Plan. Turbine Bldg. Fl. El. 21'-6.” No. 16103-27080. Connecticut Yankee Atomic Power Company.

1998a Piping & Instrumentation Diagram. Main Steam System. 38" Main Steam Collection Header. Decommissioning Updated Final Safety Analysis Report (UFSAR), Fig. 10.3-1. Sheet 2.

1998b Piping & Instrumentation Diagram. Main Steam System. High Pressure Turbine &

Turbine Main Stop Trip and Governor Valves. UFSAR Fig. 10.3-1. Sheet 3.

1998c Piping & Instrumentation Diagram. Main Steam System. Moisture Separator Reheators. UFSAR Fig. 10.3-1. Sheet 4.

1998d Piping & Instrumentation Diagram. Main Steam System. Low Pressure Turbine “1A”,

Feedwater Heaters No. 5A.& 6A, Main Condenser “1A” and East High Pressure Steam Dump. UFSAR Fig. 10.3-1 Sheet 5.

1998e Piping & Instrumentation Diagram. Main Steam System. Low Pressure Turbine “1B,

Feedwater Heaters No. 5B & 6B, Main Condenser 1B and West High Pressure Steam Dump. UFSAR Fig. 10.3-1. Sheet 6.

1998f Piping & Instrumentation Diagram. Main Steam System. Feedwater Heaters 1A&B,

2A&B, 3A&B, 4A&B, and Low Pressure Steam Dump. UFSAR Fig. 10.3-1 Sheet 7.

1998g Piping & Instrumentation Diagram. Feedwater & Condensate. Condenser “A” and Feedwater Heaters 5A & 6A. UFSAR. Fig. 10.4-5 Sheet 1.

1998h Piping & Instrumentation Diagram. Feedwater & Condensate. Condenser “B” and

Feedwater Heaters 5B & 6B. UFSAR Fig. 10.4-5. Sheet 2.

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Westinghouse Electric Corportation. 1964 Outline Condenser No. E-23-1B. Drawing No. 675J544.

B. Historic Views

A large number of Reactor Containment views are archived as part of the Connecticut Yankee Atomic Power Company, Haddam Neck Plant Records Collection, Series VI, Archives & Special Collections, Thomas J. Dodd Research Center, University of Connecticut Libraries. Major sets of views are noted below:

Connecticut Yankee Atomic Power Company n.d. [roughly chronological color photographs of plant construction and site views, 1964-

1999] on archival CD with file name Haddam Neck Construction.pdf

C. Bibliography and Personal Communications

Babcock & Wilcox 1972 Steam/its generation and use. New York: Babcock & Wilcox.

Bowers, Brian 1982 A History of Electric Light and Power. London: Peter Peregrinus LTD.

Bourne, John 1846 A Treatise on the Steam Engine. London: Longman, Brown, Green, and Longmans.

Brass.org 2003 Effect of Further Alloying Additions. Nov. 11: 2. http:www.brass.org/Pulicat/

pub117sec63.htm.

Bureau of Naval Personnel 1960 Basic Electricity. Navy Training Course. Navpers 10086-A. Washington: USGPO.

Church, Edwin, F. 1935 Steam Turbines. Second Edition. New York: McGraw-Hill Book Company.

Clark, D.K. 1889 The Steam Engine. Half -Vol. 1. London: Blackie & Son.

Clark, Peter (CYAPCO engineer) 2002-2004 Connecticut Yankee Power Plant. Personal electronic communications.

Connecticut Yankee Atomic Power Company (CYAPCO) n.d. Condenser & Feedwater Lesson Handout. Rev. 2a nt64/83111.

1966-1974 Facility Description and Safety Analysis (FDSA) Vol. 1. Topical Report No. NYO-3250-5. Neck Plant, Haddam, Connecticut.

c1972 Technical Data.

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(Page 80) 1983-1987 LP Turbine Instrumentation and Control. Plant Design Change Record (PDCR) 889,

Project Assignment 86-027. Various Reports, Memos, Letters. 1986-1989 LP Turbine Replacement. Plant Design Change Record (PDCR) 886, Project

Assignment 86-027. Various Reports, Memos, Letters.

1987a Electrical Technical Evaluation Connecticut Yankee Low Pressure Turbine Rotor Replacement, in CYAPCO 1986-1989. April 1987.

1987b Civil Structural Safety Evaluation, in CYAPCO 1986-1989. April 1987.

1987-1995 Connecticut Yankee Plant Information Book. 15 vols.

1998 Decommissioning Updated Final Safety Analysis Report (UFSAR). 3 vols. Dawes, Chester L. A

1928 A Course in Electrical Engineering. Alternating Currents. 3rd edition. 2. Vols. New York: McGraw-Hill Book Company.

de Belidor, Bernard F. 1737-1753 Architecture Hydraulique. 2 parts in 4 vols. Paris: Chez Charles-Antoine-Jombert. Engineering (London)

1908 Mitchell Thrust Bearings. 86, December 18: 333. Friday.

1926 50,000 KW Parsons Turbo-Alternator For Chicago. March 5. Gray, Alexander

1917 Principals and Practice of Electrical Engineering. New York: McGraw-Hill Book Company.

HH Robinson Asia/Pacific Group

2003 Welcome to Robinson. http://www.robertson.com.au/content.htm. Hossli, Walter

1969 Steam Turbines. Scientific American. April. Vol. 220. No. 4. Jackson, Robert L.

1952 Reheat Turbines Are Shouldering the Increased Electrical Load. GE Review 55, 6. November.

Johnson, J. F.

1919 The Large Steam Turbine. Transactions of the American Society of Mechanical Engineers 40, 1681: 1097-1118.

Kinsman, Nicole

2001 Moly Does the Job. IMOA Newsletter. July. http://www.imoa.info/newsletter July01.pdf: 1-3.

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Knight, Edward. H. 1877 Knight’s American Mechanical Dictionary. Vol. 1. New York: Hurd and Houghton.

Kraftwerk Union AG 1986 Turbine Missile Analyis for 1800 rpm Nuclear LP-Turbines with 44-inch Last Stage

Blades. KWU/TM/TDM 86/024.

Laffoon,, C.M. 1950 Evolution and Eventualities of A-C Generation. Westinghouse Engineer 10, 1: 20-30.

January.

Lorenzi, Otto de. 1952 Combustion Engineering. New York: Combustion Engineering-Superheater, Inc.

MacNaughton, Edgar. 1967 Elementary Steam Power Engineering. 3rd Edition. New York: John Wiley & Sons, Inc.

Main, T. 1893 The Progress of Marine Engineering. New York: The Trade Publishing Co.

Meyer, Henry C. 1905 Steam Power Plants. 2nd ed. New York: McGraw-Hill Book Co.

Morgan, D. W. R. 1950 Central-Station Steam-Power Generation. Westinghouse Engineer 10, 1: 7-17. January.

Meyer, Henry C. 1905 Steam Power Plants. 2nd ed. New York: McGraw-Hill Book Co.

Northeast Utilities 1985 Meeting notes - June 5, 1985. GMB-85-267. Subject: CY Condenser Waterbox “A”

Retube.

1986 GMB-86-218. Connecticut Yankee Main Condenser Waterbox A (Project Assignment No. 85.024) Project Close Out. April 14, 1986.

Oxford English Dictionary 1989 2nd. Edition. Oxford: Clarendon Press.

Parsons, R. H. 1939 The Early Days of the Power Station Industry. Cambridge: Babcock and Wilcox, Ltd.

Passer, Harold C. 1972 The Electrical Manufacturers 1875-1900

Cambridge: Harvard University Press.

Power 1982 A Century of Power Progress. 100th Anniversary Issue. 1882-1982. Vol.6, No. 4. April.

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Richardson, Alexander 1911 The Evolution of the Parsons Steam Turbine. London: Offices of Engineering.

Ripper, William 1903 Steam. London: Longmans, Green, and Co.

Simpson, Charles 1970 Colourful Cladding. Engineering 209, 5416: 192-3. February 20.

Sinton, Walter 1966 Steam Turbines for Nuclear Power Plants. Westinghouse Engineer 26, 4. July.

Swain, Philip and Arrott, William 1951 Power Handbook. New York: McGraw-Hill Publication.

Snyder, F. L. 1950 The Transformer and How it Grew. Westinghouse Engineer 10,1: 50-61. January.

Thompson, Silvanus, P. 1900 Dynamo-Electric Machinery. New York: American Technical Book Company.

Westinghouse Electric Company 2001 Thermalastic Insulation by Westinghouse Electric Company.

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Figure 1. LOCATION OF TURBINE BUILDING AND TERRY TURBINE BUILDING

AT MAIN PLANT AREA Source: Stone & Webster Drawing No. 10899-FY-1N

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Figure 2. PLAN VIEW OF TURBINE BUILDING Source: Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964f

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Figure 3. WEST ELEVATION OF TURBINE BUILDING Source: Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964c

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Figure 4 - EAST ELEVATION OF TURBINE BUILDING Source: Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964d

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Figure 5. NORTH ELEVATION OF TURBINE BUILDING Source: Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964a

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Figure 6. TURBINE BUILDING LONGITUDINAL SECTIONS (see Figure 2) Source: Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1992

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Figure 7. TURBINE BUILDING TRANSVERSE SECTIONS Source: Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1964-1992

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Figure 8. PLAN AND ELEVATION OF TERRY TURBINE BUILDING Source: Connecticut Yankee Atomic Power Company/Stone & Webster Engineering Corp. 1965b

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Figure 9. VIEW NORTH OF TURBINE BUILDING (CENTER), 345 KV TRANSFORMER (RIGHT CENTER), SCREENWELL HOUSE (LOWER LEFT) REACTOR CONTAINMENT

(RIGHT) AND ADMINISTRATION BUILDING (LEFT CENTER). Source: Connecticut Yankee Atomic Power Co. n.d. [historic views] – Photo. 269.

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Figure 10. VIEW SOUTH OF TURBINE BUILDING (RIGHT CENTER) REACTOR CONTAINMENT (LEFT CENTER) AND ADMINISTRATION BUILDING (RIGHT)

Source: Connecticut Yankee Atomic Power Co. n.d. [historic views] – Photo. 185

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Figure 11. DETAIL VIEW NORTHEAST OF CONSTRUCTION INCLUDING TURBINE BUILDING TURBINE-GENERATOR PEDESTAL (CENTER) AND REACTOR

CONTAINMENT (UPPER CENTER) Source: Connecticut Yankee Atomic Power Co. n.d. [historic views] – Photo. 49

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Figure 12. 1969 VIEW NORTHWEST OF TURBINE BUILDING OPERATING FLOOR AT COMPLETION OF CONSTRUCTION, WITH (LEFT TO RIGHT) HOUSING FOR EXCITERS, GENERATOR, LOW PRESSURE TURBINES AND CROSSOVER PIPES FROM MOISTURE

SEPARATOR REHEATERS AND FROM HIGH PRESSURE TURBINE Source: Connecticut Yankee Atomic Power Co., Photograph Number DPP-0531

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Figure 13. SCHEMATIC DIAGRAM OF HIGH-PRESSURE TURBINE BLADE STAGING (base image: Connecticut Yankee Atomic Power Company 1987-1995: Chapter 22, page 79).

A steam turbine turns heat energy to work by converting the potential energy in the steam into kinetic energy. This process occurs in stationary nozzle blades and moving blades. As the steam enters the nozzle blades it expands and gains speed. The kinetic energy is converted to rotative motion when the steam flows through moving blades in which its momentum is changed in direction or magnitude. As it flows through the blade rows the steam velocity rises and falls while the pressure drops. The basic principal of an impulse turbine wheel (the first section of the high pressure turbine) may be visualized as a jet of water directed against a flat plate that is moved back by the steady pressure on it. To have a continuous action a succession of plates would have to be struck by the jet. In the steam turbine these are the blades attached to the rotating turbine wheel. In fact, a cup-shaped surface is much more efficient at utilizing the energy in the steam. The shape causes the steam to leave the blades at an angle of 180 degrees that increases the propulsive force 100 percent. The reaction turbine wheel (all the following high pressure and low pressure sections) is analogous to a rocket engine or spinning lawn sprinkler. In a rocket, a jet of combustion products ejected out of a nozzle causes the motor to move in the opposite direction in an equal reaction. In the lawn sprinkler the water leaving the arm at a right angle creates the thrust. In the reaction steam turbine the action is more complex. The steam traveling from the fixed guide blades to the moving blades is turned and incorporates an impulsive component. The airfoil shape of the blading causes the steam to expand and speed up as it leaves the moving blades creating the reaction force on the rotating blade wheel.

The impulse (Rateau) stage consisted of one row of nozzles and one row of moving blades. As steam passed through the nozzles, the pressure was reduced and it accelerated until its velocity in the direction of rotation was about twice that of the moving blade. The moving blade changed its direction and produced an impulsive force that was transferred to the rotor in the form of kinetic energy. Steam pressure decreased as it passed through the nozzle, and then remained practically constant as it passed through the rotating blades, dropping only enough to maintain the forward flow of the steam. The velocity of the steam increased as it passed through the nozzle and decreased as it passed through the blades and performed work on the rotor. Ideally, the velocity of the steam exiting the blades was the same as that of the steam entering the nozzles.

The seven reaction stages consisted of alternating rows of stationary and rotating blades that were practically identical in design and function. Each stage had one row of fixed blades and one row of moving blades. Blades on both rows were shaped so that the area between two adjacent blades of the same row formed a nozzle. Steam leaving the stationary blades expanded and gained the velocity necessary to enter the moving blading without impact. Further steam expansion and change indirection in the moving blading created a reaction force which worked to rotate the wheel. Steam velocity was sufficient to allow the steam to escape from the moving blading and enter the next row of fixed blading. Thus, velocity rose and then dropped in each stage. The pressure drop for a reaction stage is much less than that of an impulse stage. A reaction turbine is moved by three main forces. The reaction force produced on the moving blades as the steam increases in velocity as it expands through the nozzle-shaped spaces between the blades, the reaction force produced on the moving blades when the steam changes direction and (to some extent) the impulse of the steam impinging upon the blades. Each row set of reaction blades utilized an additional expansion of the steam, and the rows got larger in diameter as the steam gained volume in its flow through the turbine (Connecticut Yankee Atomic Power Company 1987 & 1993: Chapter 22, pages 13-14; Church 1935: 113; MacNaughton 1967: 476).

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Figure 14. CROSS SECTIONS SHOWING HIGH-PRESSURE TURBINE BLADE ROOTS (base images: Connecticut Yankee Atomic Power Company 1987-1995: Chapter 22, pages 82, 84). 


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