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The Alvin W. Vogtle Electric Generating Plant, also known as Plant Vogtle (/ˈvɡəl/),[4] is a 2 unit nuclear power plant located in Burke County, near Waynesboro, Georgia, in the southeastern United States. It is named after a former Alabama Power and Southern Company board chairman, Alvin Vogtle.

Plant Vogtle
Vogtle NPP.jpg
Official nameAlvin W. Vogtle Electric Generating Plant
CountryUnited States
LocationBurke County, Georgia
Coordinates33°8′36″N 81°45′38″W / 33.14333°N 81.76056°W / 33.14333; -81.76056Coordinates: 33°8′36″N 81°45′38″W / 33.14333°N 81.76056°W / 33.14333; -81.76056
StatusOperational
Construction beganUnit 1–2: August 1, 1976
Unit 3: March 12, 2013
Unit 4: November 19, 2013
Commission dateUnit 1: June 1, 1987
Unit 2: May 20, 1989
Unit 3: May 2021 (planned)
Unit 4: May 2022 (planned)
Construction costUnits 1–2: $8.87 billion (1989 USD)[1]
($16 billion in 2018 dollars[2]) Units 3–4: $25 billion (estimated)[3]
Owner(s)Georgia Power (45.7%)
OPC (30%)
MEAG (22.7%)
Dalton Utilities (1.6%)
Operator(s)Southern Nuclear
Nuclear power station
Reactor typePWR
Reactor supplierWestinghouse
Cooling towers2 × Natural Draft
(for Units 1–2)
2 × Natural Draft
(under construction)
Cooling sourceSavannah River
Thermal capacity2 × 3626 MWth
Power generation
Units operational1 × 1150 MW
1 × 1152 MW
Make and model2 × WH 4-loop (DRYAMB)
Units cancelled2 × 1113 MW
Units under const.2 × 1117 MW AP1000
Nameplate capacity2302 MW
Capacity factor95.09% (2017)
91.25% (lifetime)
Annual net output19,176 GWh (2017)
External links
WebsitePlant Vogtle
CommonsRelated media on Commons

Each unit has a Westinghouse pressurized water reactor (PWR), with a General Electric steam turbine and electric generator. Units 1 and 2 were completed in 1987 and 1989, respectively. Each unit has a gross electricity generation capacity of 1,215 MW, for a combined capacity of 2,430 MW.[5] The twin natural-draft cooling towers are 548 ft (167 m) tall and provide cooling to the plant's main condensers. Four smaller mechanical draft cooling towers provide nuclear service cooling water (NSCW) to safety and auxiliary non-safety components, as well as remove the decay heat from the reactor when the plant is offline. One natural-draft tower and two NSCW towers serve each unit. In 2009, the Nuclear Regulatory Commission (NRC) renewed the licenses for both units for an additional 20 years[6] to 1/16/2047 for Unit 1,[7] and 2/9/2049 for Unit 2.[8][9] During Vogtle's first two units construction, capital investment required jumped from an estimated $660 million to $8.87 billion.[1] ($16 billion in 2018 dollars[2])

Two additional units utilizing Westinghouse AP1000 reactors are under construction.[10] Natural-draft type cooling towers were also selected, and the two new cooling towers are nearly 600 ft (180 m) tall. The units have suffered several delays and cost overruns. The certified construction & capital costs incurred by Georgia Power for these two new units were originally $14 billion, according to the Seventeenth Semi-annual Vogtle Construction Monitoring Report in 2017.[11] This last report blames the latest increase of costs on the contractor not completing work as scheduled. Another complicating factor in the construction process is the bankruptcy of Westinghouse in 2017.[12] In 2018 costs were estimated to be about $25 billion.[3] Upon completion of Units 3 and 4, Vogtle will become the largest nuclear power station in the United States.[13]

Reactor dataEdit

The Vogtle Electric Generating Plant has two operational reactors with two additional units under construction.

Reactor unit Reactor type Capacity (MWe) Construction started Grid connection Commercial operation Shutdown
Net (Summer) Gross
Vogtle-1[14] Westinghouse 4-loop 1150 1229 August 1, 1976 March 27, 1987 June 1, 1987
Vogtle-2[15] Westinghouse 4-loop 1152 1229 August 1, 1976 April 10, 1989 May 20, 1989
Vogtle-3[16] AP1000 1117 1250 March 12, 2013 May 2021 (Projected)[citation needed][17]
Vogtle-4[18] AP1000 1117 1250 November 19, 2013 May 2022 (Projected)[17][citation needed]

Power uprateEdit

In 2008, both reactors were increased in power by 1.7% by an "Appendix K" uprate,[19] also called a Measurement Uncertainty Recapture (MUR) uprate. Measurement uncertainty recapture power uprates are less than 2 percent, and are achieved by implementing enhanced techniques for calculating reactor power. This involves the use of state-of-the-art feedwater flow measurement devices to more precisely measure feedwater flow, which is used to calculate reactor power. More precise measurements reduce the degree of uncertainty in the power level, which is used by analysts to predict the ability of the reactor to be safely shut down under postulated accident conditions.[20] Because the reactor power can now be calculated with much greater accuracy than with the old venturi type measurement, the plant can safely run within a tighter margin of error to its limits. The new flowmeter works by comparing the time it takes ultrasonic sound pulses to travel upstream versus downstream inside the pipe, and uses the time differential to figure the flow rate of the water in the pipe.

The NRC approved Vogtle's License Amendment Request (LAR) in March 2008. The NRC staff determined that Southern Nuclear could safely increase the reactor's power output primarily through more accurate means of measuring feedwater flow. NRC staff also reviewed Southern Nuclear's evaluations showing that the plant's design can handle the increased power level.[21] Unit 1 was uprated during its Spring 2008 refueling outage, and Unit 2 was uprated in the Fall outage of the same year.

Incidents and accidentsEdit

Loss of powerEdit

A loss of electrical power in the plant occurred on March 20, 1990.

At 9:20 a.m., a truck carrying fuel and lubricants in the plant's 230kV switchyard backed into a support column for the feeder line supplying power to the Unit 1-A reserve auxiliary transformer (RAT). At the time, the 1-B RAT was de-energized for maintenance and RAT 1-A was powering both trains of emergency electrical power. The non-emergency electrical trains were being powered by back-feeding from the switchyard through the main step-up transformer to the 1-A and 1-B unit auxiliary transformers (UAT). Additionally, emergency diesel generator (EDG) 1-B was out of service for planned maintenance. After the power loss, EDG 1-A failed to start due to a protective safety trip. The resulting loss of electrical power in the plant's "vital circuits" shut down the residual heat removal (RHR) pump that was cooling the core of Unit 1 (which was nearing the end of a refueling outage) and prevented the backup RHR from activating. Even though Unit 1 was offline at the time, residual heat from the natural decay of the radioactive fuel must be removed to prevent a dangerous rise in core temperature. While the non-safety power was not interrupted, there was no physical connection between the vital and non-vital electrical trains, preventing the vital trains from receiving power from the unaffected path through the UATs.

At 9:40 a.m., the plant operators declared a site area emergency (SAE) per existing procedures which called for an SAE whenever "vital" power is lost for more than 15 minutes. At 9:56 a.m., after trying multiple times to start the 1-A EDG normally, plant operators performed an emergency startup of the EDG by activating the generator's emergency start "break-glass" which bypassed most of the EDG's safeties and forced it to start. The startup was successful. RHR-A was then started using power from EDG-A. With core cooling restored, the SAE was downgraded to an alert at 10:15 a.m. At 11:40 a.m., crews energized RAT 1-B which had been shut down for maintenance, restoring power to the "B" safety electrical train. At 12:57 p.m., the "A" safety train was switched from the EDG to RAT 1-B and the EDG was shut down. With both trains receiving offsite power, the alert was terminated at 1:47 p.m.

The temperature of the Unit 1 core coolant increased from 90 °F (32 °C) to 136 °F (58 °C) during the 36 minutes required to re-energize the A-side bus. Throughout the event, non-vital power was continuously available to Unit 1 from off-site sources. However, the Vogtle electrical system was not designed to permit easy interconnection of the Unit 1 vital busses to non-vital power or the Unit 2 electrical busses.[22] Since this incident, Plant Vogtle has implemented changes to the plant that allow the non-vital electrical buses to transfer power to the vital buses in this type of scenario.

This electrical fault also affected Unit 2 by causing breakers in the 230kV switchyard to trip, cutting off power to RAT 2-B and vital bus "B." EDG 2-B subsequently started and restored power to the vital bus. At the same time, the electrical disturbance from the falling line striking the ground was detected by protective safeties on the Unit 2 main step-up transformer and a protective relay actuated, opening the transformer's output breaker. This caused a full load rejection to Unit 2, leading to a turbine trip and subsequently, a reactor scram. After Unit 2 tripped, the "B" non-vital electrical train lost power as it attempted to transfer from UAT 2-B (powered by the turbine generator) to the failed RAT 2-B, causing two of the reactor coolant pumps and one of the main feedwater pumps to trip. Despite this, plant cool-down proceeded safely. At 9:03 p.m., the RAT 2-B breakers in the switchyard were reset and offsite power was restored to the vital and non-vital "B" electrical trains, allowing reactor coolant pumps 2 and 4 to be restarted. EDG 2-B was shutdown. It was later determined that the fault disturbance caused by the line falling was not of significant magnitude to trip the protective relay per design and should not have caused Unit 2 to shut down. Further investigation found that current transformers on the main transformer were improperly set. The controls were adjusted to the proper setting. Had the CTs been properly set initially, the Unit 2 would have remained online.

Units 3 and 4Edit

Planning phaseEdit

 
Construction underway at Vogtle, October 2011
Vogtle Unit 3 Condenser B time-lapse video

On August 15, 2006, Southern Nuclear formally applied for an Early Site Permit (ESP) for two additional units. The ESP determined whether the site was appropriate for additional reactors, and this process is separate from the Combined Construction and Operating License (COL) application process.[23] On March 31, 2008, Southern Nuclear announced that it had submitted an application for a COL, a process which would take at least 3 to 4 years.[24] On April 9, 2008, Georgia Power Company reached a contract agreement for two AP1000 reactors designed by Westinghouse; owned by Toshiba. Westinghouse partnered with the Shaw Group (Baton Rouge, LA) and its Stone & Webster division to manage the project with Westinghouse responsible for engineering, design, and overall management, and Shaw responsible for manufacturing the pre-fabricated component modules and managing the on-site construction.[25] The contract represented the first agreement for new nuclear development in the United States since the Three Mile Island accident in 1979, and it received approval from the Georgia Public Service Commission on March 17, 2009.[26][25]

ConstructionEdit

On August 26, 2009, the Nuclear Regulatory Commission (NRC) issued an Early Site Permit and a Limited Work Authorization. Limited construction at the new reactor sites began, with Unit 3 then expected to be operational in 2016, followed by Unit 4 in 2017, pending final issuance of the Combined Construction and Operating License by the NRC.[27][28] These dates have since slipped to 2021 and 2022 for Units 3 and 4, respectively.

On February 16, 2010, President Barack Obama announced $8.33 billion in federal loan guarantees toward the construction cost,[29] although as of December 2013, Georgia Power had not availed itself of those guarantees, at first awaiting the construction license, and after the construction stop lawsuit outcome. The expected building cost for the two reactors was $14 billion.[30] Georgia power's share was around $6.1 billion, while remaining ownership of the two reactors is split among Oglethorpe Power Corp., the Municipal Electric Authority of Georgia (MEAG Power), and Dalton Utilities.[31]

In February 2012, the NRC approved the construction license of the two proposed AP1000 reactors at Vogtle.[32] NRC Chairman Gregory Jaczko cast the lone dissenting vote on plans to build and operate the two new nuclear power reactors, citing safety concerns stemming from Japan's 2011 Fukushima nuclear disaster, saying, "I cannot support issuing this license as if Fukushima never happened."[33] One week after Southern Company received the license to begin construction, many environmental and anti-nuclear groups sued to stop the expansion project, claiming "public safety and environmental problems since Japan's Fukushima-Daiichi nuclear reactor accident have not been taken into account".[34] On July 11, 2012, the lawsuit was rejected by the Washington D.C. Circuit Court of Appeals.[35]

In February 2013, the project's construction contractor, Shaw, was purchased by Chicago Bridge & Iron Company (CB&I). On March 12, 2013, construction on Unit 3 officially began with the pour of the basemat concrete for the nuclear island.[36] This operation was completed on March 14.[37] During the weekend of June 1, 2013, assembly of the containment vessel began with the bottom head of the vessel being lifted into place on the nuclear island.[38] By June 2013, the construction schedule had been extended by at least 14 months.[39] On November 21, 2013, the basemat pour for Unit 4 was completed.[40]

In February 2014, the Department of Energy approved a $6.5 billion loan guarantee for Southern Company subsidiary Georgia Power and Oglethorpe Power Corp. The Department of Energy initially demanded a credit subsidy fee, but the demand was ultimately dropped given the financial strength of Southern Co. and the Vogtle project.[41][42][43]

Further delays and cost increases were incorporated in a revised schedule in early 2015. As a result of the increased delays and cost overruns, contractor CB&I exited the project and Westinghouse took direct control of the project as contractor and hired construction firm Fluor to replace CB&I/Shaw on-site managing the day-to-day work. Westinghouse purchased certain assets of the former Shaw Group from CB&I to allow the project to go forward. In 2016, Southern Company and Westinghouse added construction firm Bechtel to the project to share construction management responsibilities.[44]

Recent construction milestones include setting the final of the "big six" structural modules for Unit 3 (CA-02 and CA-03, which form the walls of a storage tank that is part of the reactor's passive cooling system). The "big six" modules also include the previously installed CA-01, CA-04, and CA-05 in-containment structural modules, as well as the previously installed CA-20 structural module which forms part of the internal structure of the auxiliary building, containing many of the reactor's support systems. CA-02 and CA-03 were placed within the containment vessel in May 2016. The setting of these modules is a fairly significant milestone and allows other construction activities to commence. In June 2016, the final reactor coolant pump for Unit 3 was received on site. In November 2016, the reactor vessel for Unit 3 was set within the nuclear island. 2017 progress includes the installation of the reactor coolant loop piping and both steam generators at Unit 3. Progress has also been made in the turbine, auxiliary, and annex building. Unit 4 has also seen progress with the installation of the final two "big six" structural modules. Construction of both cooling towers is complete, with each nearly 600 ft (180 m) tall.[citation needed]

Westinghouse bankruptcy 2017Edit

In March 2017, Westinghouse Electric Company filed for Chapter 11 bankruptcy due to losses from its two U.S. nuclear construction projects.[45] The U.S. government has given $8.3 billion of loan guarantees to help finance construction of the Vogtle reactors,[46] and a way forward to completing the plant has been agreed upon.[47] On July 31, 2017 Southern Company division, Southern Nuclear, officially took over construction from Westinghouse and opened a bid for a new construction management contract to manage the day-to-day work on the site. Southern received bids from both Fluor and Bechtel. On August 31, 2017, Southern announced its decision to move forward with Bechtel to be the day-to-day construction manager for the remainder of the project. Bechtel will replace Fluor, who will no longer be involved in the project.[48]

As of October 2017, recent progress includes completion of a critical 71 hour continuous concrete pour within the Unit 3 containment vessel, installation of the CA-33 floor module within Unit 3, placement of the Unit 4 deaerator within the turbine building, and the setting of the Unit 4 CA-03 module within the containment vessel.[49]

Continuation of construction approved 2017Edit

In November 2017 the Georgia Public Service Commission (GPSC) requested additional documentation following concerns that design blueprints had not been approved by appropriately licensed engineers, which has legal implications. On December 21, 2017, the PSC approved the continuation of construction on Units 3 and 4, with conditions that reduced the costs that can be recovered from ratepayers over the life of the project.[50]

On January 22, 2018, the Unit 3 pressurizer was installed within the containment building. On March 29, 2018, the Unit 4 reactor vessel was placed inside the Unit 4 containment building.[citation needed]

In the February 2018 Vogtle Construction Monitoring Report (VCM), GPSC approved November 2021 and November 2022 as the target in-service dates for Units 3 & 4 respectively. The report notes that the project is being completed on an accelerated schedule and is currently tracking ahead of the 2021 & 2022 in-service target dates.[51]

In August 2018 a $2.3 billion increase in costs was recognised.[52] The total cost, including financing costs, is estimated at about $25 billion.[3] In September 2018, in order to sustain the project, Georgia Power agreed to pay an additional proportion of the costs of the smaller project partners if the cost of completion went beyond $9.2 billion.[53]

On October 5, 2018 the first reactor coolant pump (RCP) was placed in the Unit 3 containment vessel. The RCPs are critical components of the power generation process in pressurized water reactors. The RCPs circulate the high pressure reactor coolant through the primary reactor loop through the reactor core where it absorbs heat from the nuclear fission and on to the steam generators where the steam is produced in the secondary non nuclear loop. A total of eight RCPs will be placed, four per unit.[citation needed] On December 4, 2018 Southern Company announced that the fourth and final reactor coolant pump had been placed for unit 3. Additionally the third ring of the containment vessel was set.

In March 2019 further federal loan guarantees of $3.7 billion were given to the various build partners, taking total federal loan guarantees up to $12 billion. The Georgia Power CEO said the loan guarantees played a key role in reducing financing costs for the build.[54] Also in March 2019, Georgia Power confirmed that the Unit 3 containment cap had been lowered into place and the reactor would be ready to load nuclear fuel in 2020.[55] This was preceded by the containment vessel third ring, as well as reactor coolant pump and polar crane installation in unit 3 during 2018 and 2019. The containment vessel top head was set during a site visit by Secretary of Energy Rick Perry and executives of the plant's owners. Recent progress on unit 4 includes the installation of the final steam generator and pressurizer. Unit 4 is being constructed utilizing lessons learned from Unit 3 and from the failed V.C. Summer project and as a result the order in which some components are being installed has been modified.[citation needed]

Surrounding populationEdit

The Nuclear Regulatory Commission defines two emergency planning zones around nuclear power plants: a plume exposure pathway zone with a radius of 10 miles (16 km), concerned primarily with exposure to, and inhalation of, airborne radioactive contamination, and an ingestion pathway zone of about 50 miles (80 km), concerned primarily with ingestion of food and liquid contaminated by radioactivity.[56]

The 2010 U.S. population within 10 miles (16 km) of Vogtle was 5,845, a decrease of 16.3 percent in a decade, according to an analysis of U.S. Census data for msnbc.com. The 2010 U.S. population within 50 miles (80 km) was 726,640, an increase of 8.8 percent since 2000. Cities within 50 miles include Augusta, GA (26 miles to city center).[57]

Seismic riskEdit

The Nuclear Regulatory Commission's estimate of the risk each year of an earthquake intense enough to cause core damage to either reactor at Vogtle was 1 in 140,845, according to an NRC study published in August 2010.[58][59]

ReferencesEdit

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External linksEdit