Kingsnorth power station

Kingsnorth
Kingsnorth Power Station Viewed from the west in October 2007
Country	England
Location	Hoo St Werburgh Kent
Coordinates	51.418947°N 0.602702°E / 51.418947; 0.602702
Commission date	1973
Decommission date	2012
Operators	Central Electricity Generating Board (1973–1990) PowerGen (1990–2002) E.ON UK (2002–2012)
Thermal power station
Primary fuel	Coal
Secondary fuel	Oil-fired
Tertiary fuel	Biofuel
External links
Commons	Related media on Commons
grid reference TQ809721

Kingsnorth was a dual-fired coal and oil power station on the Hoo Peninsula at Medway in Kent, South East England. The four-unit station was operated by energy firm E.ON UK, and had a generating capacity of 2000 megawatts. It was capable of operating on either coal or oil though in practice oil was used only as a secondary fuel or for startup. It was also capable of co-firing biofuel, up to a maximum of 10% of the station's fuel mix. A replacement power station, also coal-fired, was considered by owners E.ON, but plans were abandoned. The proposed replacement attracted substantial public protests and criticism, including the 2008 Camp for Climate Action.

History

Built on the site of the former World War I airship base RNAS Kingsnorth, Kingsnorth power station was constructed between 1963 and 1973 by the Central Electricity Generating Board (CEGB). From 1975 to the early 1980s, Kingsnorth was linked to the London power grid by HVDC Kingsnorth, one of the few examples of high-voltage direct current transmission then in use.

Eric Varley the Secretary of State for Energy officially opened Kingsnorth Power Station on 18 April 1975. On the evening of 2 January 2010, a fire broke out in one of the pump rooms of the power station. The fire was put out by fifteen fire engines and five specialist units, though the building was badly damaged and had to be shut down.

Specification

Civil engineering

Site area: 400 acres (162 hectares)

Turbine hall: 954 ft x 135 ft; height 110 ft (290.7 m x 41.2m; height 33.5m)

Boiler house each: 370 ft x 165 ft; height 234 ft (112.7 m x 50.3m height 71.3m)

Auxiliary Gas Turbine House: 180 ft x 90 ft; height 48 ft (55.4 m x 27.7m; height 14.8 m)

400 kV substation: 700 ft x 434 ft; height 70 ft (213.3m x132.2 m; height 21.3m)

132 kV substation: 296 ft x 82 ft; height 50 ft (90.2 m x 25 m; height 15.3 m)

Chimney: 4 x 23 ft dia (4x7 m dia) flues

Height: 650 ft (198m)

Windshield dia.: at base: 86 ft (26.2m)

Windshield dia.: at top: 64.7 ft (19.7m)

Circulating water pump house: 200 ft x 126 ft; height 32 ft (60.9 m x 38.4m; height 9.8m)

Main turbines

The main turbines were of the five cylinder tandem compound design with steam inlet conditions of 538 degC and 2,300 p.s.i.g. with an exhaust condition of 1.1 in Hg. Each turbine had a maximum continuous rating of 500 MW with an additional overload capacity of 26.5 MW for three, one-hour periods per day at a slightly reduced efficiency. The cylinder arrangement consisted of a single flow High Pressure, a double flow Intermediate Pressure and three double flow Low Pressure cylinders. The three LP cylinders exhausted through six outlets into an under slung axial flow condenser. All cylinders were of double shell construction and the rotors were stiff and solidly coupled with a thrust bearing sited between HP and IP cylinders. Four HP throttle valves and four IP interceptor valves were mounted directly onto their respective cylinders. The HP rotor consisted of a solid forged rotor with eight stages of continually shrouded vortex blading. Each flow of the double flow solid forged IP rotor had seven stages of similar blading. For development purposes some of the L.P. rotors were solid forged and others were of welded construction, each flow carried six stages of blading. Unique arch braced cover banding was used as shrouding and this negated the need for lacing wires between the blades. The final stage blades were 37 inches long on a base diameter of 60 inches. Stellite erosion shields were fitted to the inlet edges of the moving blades of the last two stages of each L.P. flow. Steam was tapped off the main turbine for use in the regenerative feed heaters and for driving the turbine driven steam feed pump. No. 7 HP heaters and the turbine driven feed pump were supplied with steam from the HP cylinder exhaust (cold reheat steam) at 592 p.s.i.g. Tapping points on the feed pump turbine supplied bled steam to No's 6 and 5 HP. heaters. The exhaust steam from the feed pump turbine was taken to the IP/LP cross under pipe. Bled steam was tapped off the LP turbine before the second stage for the deaerator, before the 3rd stage for the No. 3 direct contact heater, before the 4th stage for the No. 2 direct contact heater and before the 5th stage for the No. 1 direct contact heater.

Type: Tandem compound design.

No of cylinders: Five

1x single flow High Pressure

1x double flow Intermediate Pressure

3x double flow Low Pressure

Speed: 3,000 r.p.m.

Turbine heat rate: 7,540 BThU / Kwh (7,955 J / Kwh)

Steam pressure at ESV.: 2,300 p.s.i.g. (159.6 bar)

Steam Flow at ESV. 3,500,000 lbs / hr.

Steam temperature at ESV.: 538 deg C

Steam pressure at IV.: 590 p.s.i.g (40.0 bar).

Steam Flow at IV.: 2,900,000 lbs / hr.

Steam temperature at IV.: 538 deg C

Feed heating system and feed pumps

Seven main stages of regenerative feed heating were provided. These consisted of three separate direct contact low-pressure heaters, a deaerator, and two parallel lines each of three stages of high-pressure heaters. Each stage consisted of two head down indirect or non-contact heaters. These six H.P. heaters were arranged in two parallel banks to give a final feed temperature of 254 °C. All H.P. heater drains were cascaded through flash boxes, the No. 5A and 5B heater drains being cascaded from flash boxes to either the deaerator or the main turbine condenser. Several earlier stages of condensate and feed heating was provided by the generator coolers and the gland steam vent condenser. Circulation of condensate and feed water through the various stages of feed heating was provided by three 50 per cent duty two-stage extraction pumps, two 100 per cent duty glandless deaerator lift pumps and one 100 per cent duty main turbine driven boiler feed pump with two 50 per cent duty starting and standby electrically driven boiler feed pumps. Surge and make up capacity was provided on a station basis by two 1,500,000 gallon reserve feed water tanks.

The feed pumps took their suctions from the deaerator and discharged directly through the H.P. heaters into the boiler feed lines. The pumps were tandem units with a slow speed suction stage and a separate high-speed pressure stage coupled through an epicyclical gearbox. Each unit had an automatic microwire suction strainer supplemented by a magnetic filter section to remove any particles which may have passed the microwire 0.008 inch mesh. The main feed pump turbine oil system and gland steam system were integrated with those of the main turbine. The suction stage pump was a single stage horizontal spindle type, driven at 2,850 r.p.m. via a reduction gearbox. The pressure stage pump was a four-stage unit with floating metallic ring glands, directly coupled to the feed pump turbine and driven at 4,150 r.p.m. The main pump was designed to deliver 3,905,000 lb/hr at 2,900 p.s.i.g. The turbine was rated at 16,970 b.h.p. with inlet steam condition of 592 p.s.i.g, and 343 °C and a steam flow of 423,580 lb/hr and thus could not meet boiler feed demand until the unit was at 50 per cent of its maximum continuous rating, that was 250 megawatts.

Starting and standby pumps were of similar design to the main feed pumps but were driven by 9,000 b.h.p. motors with the suction stage directly driven by the motor at 980 r.p.m. and the pressure stage pumps through an epicyclical gearbox at 5,500 r.p.m. The drive motors were 11 kV slip-ring induction motors with a liquid resistor speed control device giving speed variation down to 70 per cent of full load speed.

Number of L.P. heaters: Four, including a deaerator

Type: Direct Contact

Number of HP heaters: Six ( two banks of three)

Final feed temperature: 254 °C

Main Feed Pumps

Main feed pump flow: 3,905,000 lbs / hr (1,403,482 kg / hr)

Feed pressure: 2,900 p.s.i.g. (200 bar)

Number: One per unit steam turbine driven

Steam turbine: GEC Erith

Rating: 16,970 b.h.p.

Inlet Steam pressure: 512 psig

Inlet steam temperature: 343 deg C

Steam flow: 423,580 lbs/hr

Pumps: Sultzer

Type: Two stage

Suction stage: Single stage horizontal spindle type

Speed: 2,850 R.P.M.

Pressure stage: Four stage unit

Speed: 4,150 R.P.M.

Reduction Gearbox: Epicyclical

Gear Ratio: 1.0 / 1.45

Flow: 3,905.000 lb/hr (1,403482 kg / hr)

Discharge Pressure: 2,900 psig

Starting and standby feed pumps

Flow: 1 ,952,500 lbs / hr (430,066 kg / h r)

Type of drive: 11 kV variable speed motor

Design rating: 9,000 bhp

Maximum motor speed: 980 r.p.m.

Maximum pump speed: 5,550 r.p.m.

Condenser

The condenser adopted was of the under slung single shell, single pass axial type. The condenser ran the whole length of the L.P. turbine with four separate single passes, two at the top and two at the bottom, circulating water passed through each in opposite directions. Each pass had its own water box and compensating bellows. The tubes were 1 inch in diameter and 60 feet long of 70/30 aluminium brass, and expanded into double tube plates at each end. Fifteen sagging plates were provided along the length of the span. 17,336 1-inch diameter tubes were installed with an additional 1,710 1.125 inch diameter tubes in the air-cooling section. Three 50 per cent duty Nash Hytor air extraction pumps were provided with an additional quick start exhauster.

Type: Under-slung axial flow with four single passes

Condenser back pressure: 1.1 in Hg abs.

Number of tubes: 19,046

Length of tubes: 60 ft (18.3 m)

Main generators

Each 3,000 r.p.m. two-pole generator was rated at 500 Megawatt with a power factor of 0.85, but they also provided a continuous over-load output of 526.5 MW with increased hydrogen pressure. The rotor and stator cores were cooled by hydrogen at a normal pressure of 60 p.s.i.g. with the stator windings water-cooled. Excitation was supplied from a self-excited, pilot alternator and a main exciter-alternator with a solid-state rectifier. The voltage of the generator output was 23.5 kV, this was passed to a 600 MVA transformer which stepped up the voltage to 400 kV for direct connection, through high voltage circuit breakers, to the grid system.

Maximum continuous rating: 500 MW at 0.85 power factor

Speed: 3,000 r.p.m.

No of Phases: Three

Output Frequency: 50 Hz.

Stator voltage: 23.5 kV

Stator cooling medium: Water and Hydrogen

Rotor cooling medium: Hydrogen at 60 p.s.i.g. (4.1 bar)

No of Poles: Two

Exciters: AC. Pilot with AC / DC. solid state rectifier

Main exciter output: 2,940 amps 520 volts D.C.

Circulating water system

Water for cooling the turbine condensers was drawn from the River Medway; it entered the station through two 11 ft 3 in square concrete pressure culverts. These were screened by double-entry rotary drum screens to retain any large particles of foreign matter. Four concrete volute cooling water pumps impelled water to the units cooling systems. All water extracted from the river was returned via two culverts of similar size to the inlets passing over a stone weir to Damhead Creek. The whole system was approximately two miles in length. The discharge culverts had vacuum-breaking valves to cushion any surges caused in the event of an emergency shutdown of the cooling water pumps. Two auxiliary pumps were provided for dewatering the inlet culvert and to give auxiliary cooling services when the main units were shut down. All ferrous-based plant in contact with seawater and the unloading jetty structures was provided with cathodic protection to combat seawater corrosion.

Main boiler by International Combustion Ltd

Each boiler house was 370 feet long, 165 feet wide and 234 feet high, and housed two water-tube boilers of the divided furnace, assisted circulation, type. Each boiler was capable of producing 3,550,000 lb of steam per hour at 2,400 p.s.i.g. and 541 deg C at the superheated outlet, with reheat of 2,900,000 lb per hour from 348 to 541 deg C and 590 psig at the reheater outlet, based on a final feed temperature at the economiser inlet of 254 degC. In order to take advantage of the price and availability of coal and oil in the 1960s, each furnace (which was of a fully welded membrane wall construction) was designed to operate on either fuel with a (maximum continuous rating) efficiency on coal of 90 per cent and 89 per cent on oil. For the original oil firing mode, heavy fuel oil with a viscosity of up to Redwood No. 1 6,000 sec was fed into the furnace by 48 burners arranged at the eight corners in vertical banks of six, the bottom bank being arranged in two groups for use in light up. The pulverised fuel burners were interspersed with the three lower banks of oil burners. Seven stages of superheater and two stages of reheater were provided and as the final steam temperatures were only 541 deg C, Austenitic stainless steels were not used. Two all-welded, continuous loop, transverse finned tube economisers were arranged end to end to operate in parallel. Two Howden regenerative air heaters were provided together with two bled steam air heaters located between the forced draught fans and the main air heaters. These bled steam air heaters were to be used for cold start-up and when firing oil.

Two 1,180 hp Forced Draught fans are installed and two 1,565 hp Induced Draught fans were installed, the latter drawing gasses from three Davidson "R" type straight flow mechanical dust collectors via three Sturtevant parallel plate electrostatic precipitators. For coal firing, five International Combustion Lopulco Pressure Mills supplied pulverised coal to the furnace, each mill feeding a horizontal ring of eight tilting burners arranged for a tangential firing configuration from each corner of the divided furnace. The arrangement, coupled with a 15-inch gap at either side of the division wall was designed to balance the combustion conditions in each furnace.

Main boilers: Assisted circulation, single drum, Divided furnace

Maximum continuous rating: 3,550,000 lbs / hr (1,610,250 kg / hr)

Superheater outlet pressure: 2,400 p.s.i.g. (166 bar)

Superheater outlet temperature: 541 deg C

Reheater steam flow: 2,900,000 lbs / hr (1,315,418 kg / hr)

Reheater outlet pressure: 590 p.s.i.g. (40.7 bar)

Reheater inlet temperature: 348 deg C

Reheater outlet temperature: 541 deg C

Economiser water inlet temperature: 254 degC

Drum pressure: 2,590 p.s.i.g. (178 bar)

Ash and dust handling

Ash collected at the bottom of the boilers when in the coal burn regime and was removed after quenching by water sluices. Two crushers were fitted on each boiler to reduce any large ash to a manageable slurry. Dust and grit from the precipitator that cleansed the flue gases was collected in either a wet or dry state and was either discharged to dust hoppers for resale or pumped out as slurry to lagoons on the east side of the station.

Water treatment

Water of high purity was required for use in high pressure boilers. This called for a demineralisation plant of several processes capable of handling one million gallons a day. The water was passed through a cation unit, where the salts were converted into their corresponding acids and then through a scrubber tower for carbon dioxide removal. After passage through an anion unit for acid removal and neutralisation, the water was further "polished" in one of the three mixed-bed units to render it suitable for "make-up" for the feed water systems.

Gas turbines

Four 22.4 MW English Electric gas turbine generators were provided housed in a separate sound proof building. Each powered by two distillate fuelled Rolls Royce 1533 Avon Gas Turbines. The expansion turbines were directly coupled to 28 MVA air-cooled alternators. The alternators supplied the 11 kV unit boards direct and each gas turbine was provided with an 11 kV/415 V transformer to power auxiliaries. The gas turbine auxiliaries could also be supplied by a 62.5 kVA standby diesel driven alternator set. This enabled the station to be started when completely disconnected from the grid system (black start). The gas turbines, which were equipped with automatic synchronising facilities, could be selected to start up automatically if the grid system fell below 49.7 Hz.

Number: Four

Rated output: 22.4 MW

Gas turbine engines: Rolls Royce 1533 Avon

Type of fuel: Gas Oil

Generated voltage: 11 kV

Auxiliary boilers

Two auxiliary boilers capable of producing 45,000 lb per hour of steam at 400 p.s.i.g. at 260 deg C provided soot blowing steam for the main boilers during periods of light load, feed-water deaeration, main boiler steam air heating, fuel oil heating, oil storage tank heating, and heating for the auxiliary buildings.

Number: Two

Rating: 45,000 lbs / h r (20,430 kg / h r)

Working pressure: 400 p.s.i.g. (27.6 bar)

Final steam temperature: 260 °C

Station electrical supplies

Electrical auxiliary supplies were provided by a three voltage system: two 11 kV station boards supplied by the 132 kV substation via two 50 MVA transformers, and four 11 kV unit boards. The latter could be supplied either from the 30 MVA unit transformers, the 22,4 MW gas turbine, or from the station board inter-connectors. The feed pumps and circulating water pump motors were supplied from the 11 kV boards. A comprehensive system of auxiliary power supply included a safe supplies system for the instrumentation and control equipment,

There were approximately 115 electrical transformers within the power station ranging in size from 1.0 MVA to 660 MVA. Kingsnorth Power station supplied the National Grid system which interconnected other power stations and load centres. The electrical power was generated at 23,500 volts and, for reasons of economy, it was transmitted in the National Grid at much higher voltages. The generators fed transformers which changed the voltage to 400,000 volts and were in turn connected to bus-bars by means of switches which controlled the power. The bus-bars were a means of collecting the output from each generator allowing it to be distributed through various transmission lines carried by pylons across the country on the Super Grid. Other transformers on site switched the voltage from 400,000 to 132,000 volts and fed a further system of bus-bars to which connections via underground cable circuits supplied power to the Medway towns. Both the 400,000 volt and 132,000 volt bus-bars and switches were in covered accommodation at Kingsnorth to prevent airborne pollution of the insulators affecting their electrical efficiency. For the 400,000 volt switchgear, this had meant enclosing an area 700 feet by 440 feet to a height of 75 feet, (an air-space of 23,100,000 cubic feet).

400 kV Plant

Generator transformers: Ratio 23/400 kV

Rating: 600 MVA

Super Grid transformers: Ratio 400/132 kV

Rating: 240 MVA

Switchgear: Rupturing capacity 35,000 MVA

Busbar rating: 4,OOO amps

Overhead: Rating 1,800 MVA per circuit

132 kV Plant

Switchgear: Rupturing capacity3,500 MVA

Busbar rating; 2,000 amps

Underground cables: Rating 120 MVA

11 kV switchgear

Type of circuit breaker: Air break

Breaking capacity: 750 MVA

Current rating: 2,000 amps

3.3 kV switchgear

Type of circuit breaker: Air break

Breaking capacity: 150 MVA

415 volt switchgear

Type of circuit breaker: Air break

Breaking capacity: 31 MVA

Fire protection equipment

Water spray pumps: Diesel driven, centrifugal, auto start

Number: Four

Capacity: 2,100 gpm (132.5 L/s)

Discharge head: 293 ft head (89.31 m head)

Hydrant pumps: Two diesel driven and one electric, centrifugal

Capacity: 1,680 gpm (106 L/s)

Discharge head: 301 ft head (91.74 m head)

Closure

The station closed as a result of the EU's Large Combustion Plant Directive (LCPD), which requires stations that are not equipped with flue-gas desulfurization (FGD) technology to close after 20,000 hours of operation from 1 January 2008 or the end of 2015, whichever comes first. Kingsnorth ceased generation on 17 December 2012, having consumed all its LCPD hours. Demolition of the coal handling plant commenced on Thursday 23 October 2014 with a series of controlled explosions. The station's turbine hall was demolished on 9 July 2015. The final part of the boiler house was demolished by explosion on 27 July 2017. The 650 ft (198m) concrete chimney was demolished by explosives at 10:00 am on 22 March 2018.

Decommissioned Kingsnorth power station, partially demolished

Proposed replacement

As a replacement for the four old Kingsnorth units, in October 2006 E.ON proposed the construction of two new coal-fired units, Kingsnorth Units 5 and 6. They had proposed constructing two new 800 MW supercritical coal-fired power units on the site, to be operational "as early as 2012". E.ON expected the supercritical units to reduce carbon dioxide emissions per unit of electricity by around 20%, as compared to the former subcritical plant. E.ON also said the new units would be "capture ready" to allow the option of retrofitting with carbon capture and storage (CCS). Their environmental statement reads:

CCS will be considered as an option...subject to the process of CCS being allowed by law and incentivised by a suitable framework and technological hurdles for the process being overcome.

On 31 March 2008 E.ON announced that the proposed station would be used in a bid for the Government's CCS competition. In addition E.ON proposed that the planning decision should be delayed until after the Government has completed its consultation on CCS.

The proposed station came under much criticism from groups including:

• Christian Aid who note that the emissions from the plant will be over 10 times the annual emissions from Rwanda
• Greenpeace
• The Royal Society
• The Royal Society for the Protection of Birds
• World Development Movement.
• The WWF
• The CPRE

Climate scientist and head of the NASA Goddard Institute for Space Studies James E. Hansen condemned the building of new coal power stations stating: In the face of such threats [from climate change] it is madness to propose a new generation of power plants based on burning coal, which is the dirtiest and most polluting of all the fossil fuels. We need a moratorium on the construction of coal-fired power plants and we must phase out the existing ones within two decades He is however more accepting of coal with CCS stating that Coal could still be a long-term energy source for power plants, if the carbon dioxide is captured and sequestered underground. Greenpeace is sceptical that CCS technology is viable.

On 30 June 2008 it was announced that Kingsnorth project had proceeded to the next stage of the competition (prequalification) with three other competitors. But in March 2009, Ed Miliband said that he was postponing a decision on Kingsnorth, and in the following month the E.ON chief executive said that "Without commercial carbon capture, [the proposed station was] 'game over'". On 7 October 2009 E.ON postponed the replacement until at least 2016, before 20 October 2010 when it was announced that the proposal had been shelved.

Protests

Greenpeace - October 2007

Six Greenpeace protesters were arrested for breaking into the power station, climbing the station's chimney, painting the word Gordon on the chimney and causing an estimated £30,000 damage. They had been planning to write "Gordon, bin it", but had stopped when served with a High Court injunction. At their subsequent trial they admitted trying to shut the station down but argued that they were legally justified because they were trying to prevent climate change from causing greater damage to property elsewhere around the world. Evidence was heard from David Cameron's environment adviser Zac Goldsmith, and an Inuit leader from Greenland, both saying that climate change was already seriously affecting life around the world. The six were acquitted after arguing that they were legally justified in their actions to prevent climate change from causing greater damage to property around the world. It was the first case where preventing property damage caused by climate change has been used as part of a "lawful excuse" defence in court.

In December 2008 Greenpeace received a letter from the Crown Prosecution Service revealing that the Attorney-General was close to referring the case of the Kingsnorth Six to the Court of Appeal in an effort to remove the defence of 'lawful excuse' from activists. Also in December the New York Times listed the acquittal in its annual list of the most influential ideas that will change our lives

Climate Camp - August 2008

The 2008 Camp for Climate Action was held near the power station and 50 people were arrested trying to break into the site. Some of the tactics used by police during the demonstration have been the subject of complaints, a judicial review, and mainstream media criticism.

Occupation - October 2008

On 29 October 2008, Greenpeace activists occupied part of the power station after accessing the site using boats including the Rainbow Warrior. There was an hour-long stand-off with security staff before they boarded the plant's jetty and demonstrated while others set up camp on a concrete island owned by E.ON. Protesters projected campaign messages on the building, and then on a bulldozer brought in by the company to block the image, until the early hours of the following morning when they were served with a high court injunction.

Taken off-line for four hours - November 2008

On 28 November 2008 a lone protester entered the plant undetected and shut down unit 2, one of the station's 500 MW turbines, leaving a message reading "no new coal". The turbine was offline for four hours.

Greenpeace - June 2009

On 22 June 2009, ten Greenpeace activists boarded a fully loaded coal delivery ship bound for Kingsnorth.

See also

• Damhead Creek power station

External links

• Kingsnorth Muse - History and pictures - History of the station with pictures and features covering 40 or so years.
• Kingsnorth power station - General information on Kingsnorth Power Station, including references to the Nature Reserve, one of the few of its kind in the region.
• No new coal - a lobby group opposing the replacement planned by E.ON