ML020640288
| ML020640288 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 02/27/2002 |
| From: | Bergendahl H FirstEnergy Nuclear Operating Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| 2759, TAC MB3280 | |
| Download: ML020640288 (191) | |
Text
{{#Wiki_filter:FENOC Davis-Besse Nuclear Power Station 5501 North State Route 2 S~ Oak Harbor, Ohio 43449-9 760 FirstEnergy Nuclear Operating Company Howard W. Bergendahl 419-321-8588 Vice President-Nuclear Fax: 419-321-8337 License Number NPF-3 Docket Number 50-346 Serial Number 2759 February 27, 2002 United States Nuclear Regulatory Commission Document Control Desk Washington, D. C. 20555-0001
Subject:
Supplemental Information Regarding License Amendment Application to Increase Allowable Power (License Amendment Request No. 00-0006; TAC No. MB3280) Ladies and Gentlemen: On October 12, 2001, the FirstEnergy Nuclear Operating Company (FENOC) submitted an application for an amendment to the Davis-Besse Nuclear Power Station (DBNPS), Unit Number 1, Operating License Number NPF-3, Appendix A Technical Specifications, regarding a proposed increase in allowable power. The proposed amendment (DBNPS Serial Number 2692) would make the necessary TS changes to allow an increase in the authorized rated thermal power from 2772 MWt to 2817 MWt (approximately 1.63%), based on the use of Caldon Inc. Leading Edge Flow Meter (LEFM) CheckPlusTM System instrumentation to improve the accuracy of the feedwater mass flow input to the plant power calorimetric measurement. On January 14, 23, and 28, and February 5, 2002, FENOC received informal requests for additional information (RAI) regarding the license amendment application. Enclosure 1 provides the response to these requests. This supplemental information does not affect the conclusion of the license amendment application that the proposed changes do not involve a significant hazards consideration and do not have an adverse effect on nuclear safety. In order to support the planned operation of the DBNPS at the proposed increased power level following startup from the upcoming Thirteenth Refueling Outage (13RFO), FENOC requests that the NRC staff complete its review and approval of the license amendment application as expeditiously as possible.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Page 2 Should you have any questions or require additional information, please contact Mr. David H. Lockwood, Manager - Regulatory Affairs, at (419) 321-8450. Very truly yours, MKL Enclosures cc: J. E. Dyer, Regional Administrator, NRC Region 1II S. P. Sands, NRC/NRR Project Manager D. J. Shipley, Executive Director, Ohio Emergency Management Agency, State of Ohio (NRC Liaison) C. S. Thomas, NRC Region II, DB-1 Senior Resident Inspector Utility Radiological Safety Board
Docket Number 50-346 License Number NPF-3 Serial Number 2759 SUPPLEMENTAL INFORMATION IN SUPPORT OF THE APPLICATION FOR AMENDMENT TO FACILITY OPERATING LICENSE NPF-3 DAVIS-BESSE NUCLEAR POWER STATION UNIT NUMBER 1 Attached is supplemental information for Davis-Besse Nuclear Power Station (DBNPS), Unit Number 1 Facility Operating License Number NPF-3, License Amendment Request Number 00-0006 (DBNPS Serial Number 2692, dated October 12, 2001). This information, submitted under cover letter Serial Number 2759, includes a response to the January 14, 23, and 28, and February 5, 2002 informal NRC Requests for Additional Information. I, Howard W. Bergendahl, state that (1) I am Vice President - Nuclear of the FirstEnergy Nuclear Operating Company, (2) I am duly authorized to execute and file this certification on behalf of the Toledo Edison Company and The Cleveland Electric Illuminating Company, and (3) the statements set forth herein are true and correct to the best of my knowledge, information and belief. Howard .Br/dla cPrsdn-aer Affirmed and subscribed before me this 27th day of February, 2002 W." N - .HL July
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 1 RESPONSE TO REQUESTS FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST (LAR) 00-0006 FOR DAVIS-BESSE NUCLEAR POWER STATION UNIT NUMBER 1 January 14, 2002 NRC Request for Additional Information Question 1: Overall This submittal provides insufficient information concerning transient analyses evaluation. It does not provide clear conclusions, such as the impact of the power uprate parameters on acceptance criteria and their justification for acceptance. Please provide additional information for the following questions. DBNPS Response to Question 1: The responses to each of the individual questions are provided below. Question 2: Section 3.4.1 NSSS Design Transients Table 3-1 lists the NSSS performance parameters for current design conditions, current operation, once through steam generator (OTSG) 0 and 20 % tube plugging parameters.
- a.
Clarify the intent of OTSG 0 and 20 % tube plugging parameters in this power uprate since the current operation is limited to 8.4 % OTSG tube plugging.
- b.
Clarify which column of the Table 3-1 the parameters values are used to assess the impact of this power uprate. Confirm that the safety analyses values of these parameters are within Technical Specification limits.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 2
- c.
Discuss how section 3.4.1 transients are bounded and provide their bases clearly.
- d.
Provide a copy of FRA-ANP Document No. 18-1149327, "RCS Functional Specifications (DB), Revision 1, May 27, 1993" or send those tables which are appropriate for this section. DBNPS Response to Question 2:
- a.
The intent of evaluating the 0% and 20% tube plugging parameters was to ensure that plant operation at the uprated power was bounded. It was not intended to perform all the required analyses to support 20% tube plugging. However, where it was readily accommodated, 20% tube plugging conditions were conservatively evaluated in lieu of 8.4% tube plugging.
- b.
For the NSSS component evaluations, the most limiting parameters, either those corresponding to 0% plugging or those corresponding to 20% plugging, as appropriate, were evaluated. For example, 20% tube plugging produces the greatest hot leg temperature, whereas 0% tube plugging yields the greatest steam temperature. From a safety analysis perspective, the Table 3-1 values are nominal or best-estimate. The safety analyses model the appropriate average temperature, but the total power (core plus Reactor Coolant Pump heat addition) is increased to account for measurement uncertainty, and a lower Reactor Coolant System (RCS) flow is used to maximize the temperature difference across the core. With the boundary conditions set on the primary side, SG secondary conditions are adjusted to preserve the RCS average temperature. These changes, coupled with the other accident-specific conservatisms, ensure that a conservative analysis is performed, from which the Technical Specification limits are determined. All necessary Technical Specification changes as a result of the proposed power uprate were included in the license amendment application.
- c.
The thermal hydraulic inputs to the primary component structural analyses (including the steam generator) are defined by the RCS Functional Specification design transients. The design transients provide the system and component pressure, temperature, and flow conditions for the normal, upset, emergency, and faulted events. Since the uprate will have a negligible effect on the transient response, the effect of the uprate on the design transients is limited to a change in either the initial or final conditions of the transient. As discussed below, the uprated operating conditions will be bounded by the conditions defined by the design transients.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 3 Primary System Design Transient Conditions The RCS Functional Specification uses the full power Thot and Tcold as either the initial or final points for most of the plant transients (i.e., reactor trip, load rejection, turbine trip, rapid depressurization, loss of flow, power change, and loss of main feedwater transients). Exceptions include plant heatups and cooldowns, which end or start at hot shutdown or 8% power conditions. As shown in Table 3-1, the power uprate increases Thot and decreases Tcold and does not have an appreciable effect on RCS flow. However, the predicted Thrt and Tcold values shown in Table 3-1 for both the 0% and 20% tube plugging cases are bounded by those in the existing RCS Functional Specification. Steam Generator Design Transient Conditions The RCS Functional Specification provides values of steam temperature, steam pressure, feedwater temperature, and steam/feedwater flow for the system transients. Each of these parameters and its impact on OTSG performance is discussed below. The RCS Functional Specification uses a design operational steam temperature of 570 °F. However, the RCS Functional Specification also recognizes that the actual steam generator performance may result in greater temperatures, and uses a maximum steam temperature of approximately 600 °F. Typical operating steam pressures versus steam flow are also identified in the RCS Functional Specification. These range from 885 psia at no-load to 925 psia at 100% load. Feedwater temperature is also shown as a function of steam flow and ranges between 90 IF and approximately 460 °F over the power range. Steam/feedwater flow rates of approximately 6.0 Mlbm/hr per steam generator are defined in the RCS Functional Specification for the full load design condition. This flow rate corresponds to the 570 °F design operational steam temperature. Note that these values were used in the fatigue evaluation of the primary components and were not used as inputs to flow induced vibration (FIV) analyses. The FIV analyses used bounding steam and feedwater flow rates and densities. The power uprate results in an increase in feedwater flow and a small decrease in steam temperature (see Table 3-1). Additional tube plugging results in a further decrease in steam temperature and an increase in feedwater flow. The power uprate feedwater flow at 20% tube plugging is slightly less than the approximately 6 Mlbm/hr design flow shown in the RCS Functional Specification.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 4 While steam temperature decreases with additional tube plugging, the calculated steam temperature at the uprated power and 20% tube plugging is 584.3 'F, which is between the 570 'F and 600 'F values in the RCS Functional Specification. The desired turbine throttle pressure and the pressure losses in the steam line between the steam generator and throttle valve govern steam generator steam pressure. The power uprate and tube plugging do not directly cause a change in steam pressure. Rather, secondary plant performance optimization can cause changes to the turbine throttle pressure. Feedwater temperature will be maintained at its current value and thus will remain within the bounds of the existing fatigue analysis. Injection System Design Transients Design transients also include injection into the RCS/OTSG due to High Pressure Injection (HPI), Auxiliary Feedwater (AFW), pressurizer spray, core flood tank discharge, and normal makeup. The uprate RCS and OTSG temperatures, which are the boundary conditions for these injection transients, are bounded by the temperatures defined in the RCS Functional Specification.
- d.
Framatome-ANP Document No. 18-1149327-01, "RCS Functional Specifications (DB), May 27, 1993," is considered highly proprietary to Framatome-ANP and is not available for placement on the docket. However, arrangements can be made for the NRC to view this document at the Framatome offices in Lynchburg or Roslyn, Virginia. Question 3: Section 3.10.1 LOCA Related Analyses
- a.
Please confirm that the generically approved LOCA analyses methodologies currently used for Davis-Besse LOCA analyses continue to apply specifically to this plant by providing a statement that LOCA analyses and its vendor have ongoing processes which assure that LOCA analysis input values for peak cladding temperature-sensitive parameters bound the as-operated plant values for those parameters.
- b.
What are the calculated LBLOCA and SBLOCA results, per 10 CFR 50.46(b), for Davis Besse at the uprated power?
- c.
Discuss the design of the Davis-Besse ECCS switchover from the injection mode to the ECCS sump recirculation mode. What was the decay heat source assumed in the design of
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 5 the ECCS switchover from the injection mode to the ECCS sump recirculation mode for the present power? Does this assumed heat source change for the uprated power? Is the timing of the switchover affected? Please explain.
- d.
Boric Acid Accumulation 10 CFR 50.46(b)(5) establishes long-term cooling requirements following a LOCA. One aspect of long-term cooling following a LOCA accident is to ensure boric acid accumulation will not prevent core cooling by applying an acceptable evaluation model (EM) to analysis of boric acid accumulation and to determination of the time available for switchover to hot leg injection. If you have not reanalyzed these topics in support of your power uprate request and you have documented application of a staff-approved EM to these topics, then please provide references to this documentation. If you have reanalyzed these topics in support of your power uprate request or you not have a staff-approved EM, then please provide a complete description of your methodology. DBNPS Response to Question 3:
- a.
Framatome-ANP performs Loss-of-Coolant Accident (LOCA) analyses for each new fuel design that is supplied for fuel reloads at the DBNPS. Prior to completing those analyses an Analytical Input Summary (AIS) is prepared to identify the key input parameters that are used in the analysis and the rationale for the values used in the analyses. Peak clad temperature (PCT) sensitive plant parameters such as Core Flood Tank (CFT) initial parameters, pumped Emergency Core Cooling System (ECCS) injection flows, core power level, Reactor Protection System (RPS) trip setpoints, equipment time delays, and containment cooling parameters are included in the AIS. The DBNPS monitors and informs Framatome-ANP of any plant changes for these parameters. Framatome-ANP uses these inputs to calculate the Large Break LOCA (LBLOCA) and Small Break LOCA (SBLOCA) analyses in accordance with the NRC-approved BWNT LOCA Evaluation Model (BAW-10192P-A). Framatome-ANP considers the variations in radial and axial core power peaks, and the initial fuel pin stored energy, and determines the allowed linear heat rate (LHR) limit as a function of core elevation and time in life to ensure that the PCTs are not underpredicted. For SBLOCAs, the spectrum of break sizes and locations are performed using the limiting pumped ECCS injection capacities and CFT parameters given in the AIS. The limiting results from the LBLOCA and SBLOCA analyses are reported to the DBNPS. The summary report also refers to the AIS and gives a list of the key input parameters used in the analyses. The maximum LHR limits are used in the core power distribution analyses to define the acceptable ranges of operation for the plant. The combination of the LOCA AIS and LOCA summary reports provide a common understanding of the inputs and results that serve as a basis for any required input or reanalysis effort that may be needed as a result of a key parameter change. The DBNPS
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 6 contacts Framatome-ANP to discuss any plant changes that may necessitate new LOCA analyzes. The process may best be illustrated through the use of an example. In late 2000, the DBNPS Makeup (MU)/HPI system engineer identified that the sequential HPI flow tests were indicating slight loss of flow margin to the requirements in each subsequent test. The DBNPS requested Framatome-ANP to perform the necessary SBLOCA analyses to justify a 1.5 % decrease in the HPI head flow used in the SBLOCA analyses. The necessary analyses were completed to support a revision to the HPI test acceptance criteria. The new PCTs were summarized in a letter to FirstEnergy and also in a letter to the NRC.
- b.
The existing LBLOCA and SBLOCA analyses for the DBNPS were analyzed at an error adjusted core power level of 3025.32 MWt, which significantly bounds the requested Appendix K-related power uprate. Because the LOCA analyses were performed in anticipation of a larger power uprate, no new analyses were needed to support the Appendix K uprate. The LBLOCA PCT was calculated for the Mark-B10K assembly to be 2104 'F at beginning of life, 9.536-ft, at a LHR of 15.5 kW/ft, and including a 2 'F penalty for the Batch 15E M5TM structural assembly. The SBLOCA PCT is 1440 'F, which is for the HPI line break with the 1.5 percent reduction in the HPI head flow curve and includes a 12 'F penalty for the Batch 15E M5TM structural assembly.
- c.
At the DBNPS, manual operator action is required to make the ECCS switchover from injection from the Borated Water Storage Tank (BWST) to recirculation from the containment emergency sump. This action is triggered when the BWST level reaches a setpoint during the transient. The level setpoint is chosen to allow the operators adequate time to complete the transfer while maintaining adequate NPSH for the ECCS pumps. The break size of the largest LOCA is sufficient to depressurize the RCS to containment pressure within roughly 20 seconds. The makeup control valves go wide open and the HPI and Low Pressure Injection (LPI) pumps actuate from the low RCS pressure setpoint. The containment pressure increases from the RCS blowdown, causing the spray actuation setpoint to be reached, thereby actuating the containment spray system (CSS) pumps. The BWST draining rate from the makeup, HPI, LPI, and the CSS pumps is maximized by the low RCS pressure. The requested power uprate will incrementally increase the residual core decay heat observed at the time of sump switchover for the limiting LBLOCA. This power level change will not alter the minimum time in the transient that sump switchover occurs, nor will it shorten the time required to complete the transfer. This time is controlled by the BWST inventory and pumped injection flow rates. The minimum time that sump switchover will occur is between 25 and 50 minutes from the initiation of the transient for the LBLOCA, and is dependent upon the ECCS equipment available and the initial BWST liquid inventory.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 7 As the break size decreases, the RCS pressure becomes less responsive to the break energy discharge and more responsive to the residual core decay heat. The ECCS flow from the BWST is reduced because of the higher RCS pressure. The activation of CSS and LPI pumps is delayed and the timing of ECCS switchover becomes more extended. The reduced pumped ECCS flow rates for the smaller LOCA provides additional time for the sump transfer actions. The slightly higher core power may also delay the transfer time by a small amount by keeping RCS pressure marginally higher and reducing the ECCS flow rates. More time is available for the operators to complete the transfer from injection mode to recirculation from the containment emergency sump. Therefore, the small increase in core decay heat will not adversely affect the switchover time or decay heat system requirements at that time.
- d.
The DBNPS provided details regarding its boric acid precipitation control (BPC) methodology in a request for an exemption from 10 CFR 50 Appendix K (DBNPS Serial No. 2633 dated March 15, 2000). This exemption was in support of a BPC modification that was implemented in the spring of 2000 during the Twelfth Refueling Outage (12RFO). Calculations in support of the BPC modification were performed by Framatome-ANP and were based on an initial power level of 102% of 2772 MWt. The exemption was granted by the NRC (TAC No. MA7831) on May 5, 2000 (DBNPS Log No. 5659). Since the power level used in the BPC analysis envelopes the requested power uprate, no additional calculations were required. Question 4: Section 3.10.3 Transient Analyses In the submittal, it is stated that cycle 14 (the next cycle) is loaded with two different fuels: Mark-B 10 and Mark-B 10K. This makes the cycle 14 a mixed core. Please provide qualitative and quantitative technical justification demonstrating that the Fuel Centerline Temperature and DNBR limits (as per section 4.2 and 4.4 of the Standard Review Plan, respectively) are still met at the increased power uprate. In addition, since these transients result in changes to the reactor coolant system and faster reactivity insertion rates, please provide the results of the re-analyses, including primary and secondary system pressures, and the magnitude of increased reactivity rates (if any), for the following sub-sections of the submittal:
- a.
3.10.3.1 Uncontrolled Control Rod Assembly Group Withdrawal from a Subcritical Condition (Startup Accident).
- b.
3.10.3.2 Uncontrolled Control Rod Assembly Group Withdrawal at Power Accident.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 8
- c.
3.10.3.3 Control Rod Assembly Misalignment.
- d.
3.10.3.16 Control Rod Assembly (CRA) Ejection Accident. DBNPS Response to Question 4: The centerline fuel melt limit is determined for each fuel rod design contained in the core for a given cycle as part of the reload licensing analyses. In the case of the DBNPS Cycle 14 core, centerline fuel melt limit calculations will be determined for the U0 2 and the gadolinia fuel using the TACO3 (BAW-10162P-A) and GDTACO (BAW-10184P-A) codes. The respective centerline fuel melt limit behavior for the fuel designs is determined based on a rod power envelope. The impact of the power uprate will be reflected in changes to the absolute linear heat rate predicted for the fuel rods in each fuel design. In light of the relatively small power uprate condition for Cycle 14, the current rod power envelopes are expected to have adequate power margin to accommodate the anticipated rod power changes. If that is the case, the centerline fuel melt limits applicable for Cycle 13 will be applied to Cycle 14 for the same rod design. If the current rod power envelopes do not bound the anticipated rod power changes, then new centerline fuel melt limit assessments are performed. With respect to the Departure from Nucleate Boiling (DNB) Ratio (DNBR), please refer to the response to Question 1.a below. In this response, a description of the mixed core DNB analysis method as well as the DBNPS-specific DNB transition core penalty for the fuel designs is provided. There is no mixed core penalty for DBNPS Cycle 14. There are four designs included in the Cycle 14 core: Mark-B8A (a single Mark-B8A fuel assembly, similar to the Mark-B10 design, will be located in the center core location), Mark-B10, Mark-B 1 OK, and Mark-B 12 designs. These fuel assemblies are hydraulically similar in the core heated region. There is, however, a slight hydraulic difference in the lower end fitting, due to the implementation of the fine mesh debris resistant lower end fitting in the Mark-B 10K and Mark-B 12 designs. The other differences between the designs is that the Mark-B 10K and Mark-B12 assemblies contain the M5TM fuel cladding and a slightly larger diameter fuel pellet. The Mark-B 10 and Mark-B 1 OK fuel types are also included in the current fuel cycle, as described in the Cycle 13 Reload Report, BAW-2368. With full RCS flow, the analyses are not particularly sensitive to small physical differences between these fuel designs because the outside clad dimension is the same between the designs, as is the length of the assembly and the pin pitch. There are no changes to the primary coolant system with respect to the transient response for the accident in question. The key parameters for these analyses are not the initial conditions from which the transient is initiated, but the change imposed by the specific accident. Therefore, the critical parameters for these accidents are the moderator coefficient, the Doppler coefficient, and the reactivity addition rate. Although the reactivity parameters may change from cycle to cycle, the values used in each of the analyses are evaluated for the new fuel cycle to confirm that
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 9 the analyses reported in the Updated Safety Analysis Report (USAR) remain bounding. The fuel assembly differences, like typical cycle-to-cycle variations, do not cause the cycle-specific reactivity parameters to exceed the limits of the USAR analyses. With respect to the fuel pellet design, the subject analyses contain sufficient conservatism, via the use of a point kinetics solution, to accommodate small differences to the fuel pellet design. As a result, no new analyses are necessary due to the implementation of the Mark-B 10K and Mark-B12 fuel designs. Question 5: In sub-section 3.10.3.4, Moderator Dilution Accident, it is stated that "conservative reactivity parameters and dilution flow rates are modeled to ensure a bounding calculation." Please provide a list (or a table) of reactivity parameters and flow rates being referred to here, and all the bounding calculations that were performed to demonstrate the conservatism stated in this section. DBNPS Response to Question 5: The dilution flow rates used in the moderator dilution accident analyses described in USAR Section 15.2.4, Makeup and Purification System Malfunction, were 70 gpm, 100 gpm, and 500 gpm. The maximum reactivity insertion rate for a dilution accident is proportional to the initial coolant concentration divided by the inverse boron worth. The USAR analysis was based on an initial critical boron concentration of 1407 ppm and an inverse boron worth of 100 ppm/%Ak/k, which yields an insertion factor of 14.07 %Ak/k. Calculations performed for the power uprate (Cycle 14) indicate that there is a small increase in these parameters compared to the Cycle 13 core. The power uprate calculations showed that the initial critical boron concentration increases from 2207 to 2268 ppm, while the inverse boron worth increases from 171 to 174 ppm/%Ak/k. The insertion factor for the power uprate (Cycle 14) is slightly larger than the Cycle 13 value, 13.03 verses 12.91 %Ak/k, respectively. However, because the USAR analyses are more reactive than the cycle-specific conditions, the maximum reactivity change associated with a given dilution rate would also be higher than the cycle-specific calculation. Therefore, the USAR analyses remain bounding. This evaluation is performed for each new fuel cycle. Question 6: Since this is a mixed core, please describe the impact of the mixed core penalty and its affect on all the transients and accidents analyses results. Also, demonstrate that all the LOCA and non transients accidents were analyzed with the most limiting fuel. DBNPS Response to Question 6: A discussion of the characteristics of the fuel designs to be implemented during the proposed power uprate is described in the response to Question 1.a. below. The response to
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 10 Question 11.a provides the supporting evidence to conclude that the fuel assemblies have compatible hydraulic characteristics. Linear heat rate (LHR) limits are considered separately for each fuel assembly design to ensure that the requirements of 10 CFR 50.46 are met. Therefore, the limiting fuel type is determined by comparison of the LOCA analyses and evaluations performed for each assembly type. The current DBNPS LOCA analyses show that the fuel assembly design with the highest PCT is the Mark-B10K, with an analyzed PCT of 2102 'F. The DBNPS LOCA Evaluation Model (EM) analyses for the Mark-B 10 (and earlier fuel assembly designs that are hydraulically similar), Mark-B 10K and Mark-B 12 fuel assemblies each model a full core of the desired fuel assembly to provide LHR limits specifically for that assembly. These three fuel assemblies are hydraulically similar in the core heated region. There is a slight hydraulic difference in the lower end fitting, due to the implementation of the fine mesh debris resistant lower end fitting in the Mark-B 10K and Mark-B 12 designs. Thus, in addition to the LOCA EM analyses, the effect of the Mark-B 10K and Mark-B 12 debris resistant lower end fittings was specifically evaluated in a mixed-core scenario with the Mark-B 10 fuel. Analyses demonstrated that the lower end fitting did not result in sufficient flow differences to necessitate a LOCA mixed-core penalty for the current DBNPS fuel assembly designs. Finally, the four Batch 15E Mark-B 10K structural assemblies are different than the other Batch 15 assemblies, in that they have the two uppermost intermediate spacer grids fabricated from M5TM material. These grids have a slightly higher resistance that tends to divert flow from the Batch 15E assemblies into the adjacent fuel assemblies. Thus, in addition to the LOCA EM analyses, the effect of the Mark-B 10K and Mark-B 12 debris resistant lower end fittings was specifically evaluated in a mixed-core scenario with the Mark-B 10 fuel. Thus mixed-core analyses were performed that determined a 2 'F penalty for LBLOCA and a 12 'F penalty for SBLOCA for application to these Batch 15E assemblies. Therefore, the limiting PCT for DBNPS Cycle 14 is 2104 'F considering the Batch 15E M5TM structural assemblies. If further assembly design changes are implemented in future cycles, the potential for additional mixed-core penalties will be evaluated and any resulting penalties will be applied to the LOCA LHR limits or PCTs prior to use in the core power distribution analyses. A specific mixed core penalty is not applied to the system response for the non-LOCA transients because the key system parameters, i.e., Doppler coefficient, moderator coefficient, and reactivity insertion rates are not affected by the power uprate. With respect to the fuel pellet design differences, the non-LOCA accident analyses utilize a point kinetics solution that is sufficiently conservative to address small deviations to the fuel pellet design. This "generic" system response is used in conjunction with the specific fuel design parameters to determine the limiting design-specific DNBR and Centerline Fuel Melt responses, thus ensuring that the non-LOCA accidents are analyzed with the most limiting fuel.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 11 Question 7: Section 3.10.3.4 Makeup and Purification System Malfunction (Moderator Dilution) Accident In this analysis, it is stated that the trip setpoint will be determined by the "ultimate power level." Please clarify whether this approach would cause the trip setpoints to be set lower. DBNPS Response to Question 7: The nuclear overpower reactor trip setpoint used in the current accident analyses for the DBNPS is 112% of 2772 MWt, or 3104.64 MWt. Since no system response calculations were performed for the reactivity events with the power uprate, the maximum allowed overpower level must be preserved, i.e., 3104.64 MWt. Expressed in terms of the new rated thermal power, the revised overpower trip setpoint must be reduced proportionally to 3104.64/2817, or 110.2%. This ensures that the analyses presented in the USAR would bound the power uprate when implemented. For the power uprate, the DBNPS Technical Specification high flux trip setpoint Allowable Value is also being reduced. The methodology for defining the Technical Specification setpoint is outlined in BAW-10179P-A, "Safety Criteria and Methodology for Acceptable Cycle Reload Analysis," with the exception that the heat balance error is being reduced from 2% to 0.37% because of the implementation of the Caldon LEFM CheckPlusTM instrumentation. The new Technical Specification trip setpoint Allowable Value is 104.9% RTP. Question 8: Section 3.10.3.5 Loss of Forced Reactor Coolant Flow (Partial, Complete, and Single Reactor Coolant Pump Locked Rotor) Accident In this analysis, it is stated that this analysis is performed for each new reload, a specific evaluation is not performed for the power uprate condition. This is not acceptable. Perform a new analysis and provide their results for the most limiting case using the power uprate parameters and justify how you meet the acceptance criteria. DBNPS Response to Question 8: The intent of the subject statement was to note that the specific DNBR response is addressed as part of the cycle-specific reload, while the RCS response, i.e., power, temperature, pressure, and flow rate, for each event are addressed generically in this report. This approach is viable because the system response and the DNB response are performed in separate calculations. The system response to the loss of coolant flow events generate the transient core exit pressure, core inlet temperature, core inlet flow rate, and core power values. The analyses are performed at the
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 12 minimum design flow rate versus the minimum DNB flow rate to ensure a conservative pressure and temperature prediction. The core inlet flow is normalized and will not be affected by the proposed power uprate. The core power response is also normalized since the initial core power level in the calculation accounts for the heat balance uncertainty. Because the system response calculation already conservatively accounts for the heat balance error and therefore bounds the power uprate, no new system analysis is specifically required for the proposed power uprate. The parameters from the system analysis are provided as input to the DNB calculation. The DNB calculation is performed for each new fuel reload to confirm that the DNB acceptance criterion is not violated. The DNB analysis accounts for the fuel design, the appropriate core power level and peaking factors. A scoping calculation was performed for the proposed power uprate and is reported in Section 3.13.2 of Enclosure 1 Attachment 3 of the DBNPS license amendment application. These analyses confirmed that the uprated core will meet all required thermal-hydraulic core protection requirements. The licensing (DNB) calculations for the power uprate are incorporated into the Cycle 14-specific analyses, and will be used in subsequent cycles. Question 9: Section 3.10.3.15 Steam Generator Tube Rupture (SGTR) Accident
- a.
Discuss whether sufficient margin to overfill of the steam generators exists with a constant leak rate of 435 gpm prior to operators take control of the auxiliary flow rate.
- b.
In this analysis, it is stated that the leak rate calculation for the SGTR analysis is independent of power level based on the analytical method used. Confirm that with power uprate the RCS pressure remains the same. If the RCS pressure is higher than the current analysis, justify your current analysis results or you may require a new analysis.
- c.
Confirm that the reactor coolant activity restrictions are consistent with the current TS requirements with the power uprate. DBNPS Response to Question 9:
- a.
Prior to a reactor trip, the Integrated Control System (ICS) will throttle Main Feedwater (MFW) to the affected OTSG to maintain a constant water level in the steam generator. Following a reactor trip, the ICS reduces MFW flow to both OTSGs to maintain level at the low level control setpoint, while also compensating for the leakage flow to the affected OTSG. At 435 gpm, the leakage rate is insufficient to remove core decay heat, even when combined with the cooling capability of the HPI system. Thus, steaming of both OTSGs is necessary to ensure sufficient decay heat removal. Once diagnosed as an SGTR, the reactor operators are instructed to steam both OTSGs to reduce the RCS temperature. Steaming of
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 13 the OTSGs continues until the RCS temperature is reduced to a value that is less than the saturation temperature corresponding to the lowest set pressure for the Main Steam Safety Valves (MSSVs). During this phase of the event, the leakage rate is insufficient to cause the affected OTSG level to increase above the ICS control point. At approximately 34 minutes after event initiation, the reactor operators, having reduced the RCS temperature to the desired value, take action to isolate the affected OTSG. The water level of the affected OTSG at this time in the transient is less than or equal to the ICS level control point. Thus, adequate margin exists to overfilling the affected OTSG. Should MFW not be available, the Auxiliary Feedwater (AFW) Level Control System acts to control the AFW flow rate to maintain a constant level in the OTSGs. The transient progression will remain the same as if the MFW were available. Again, adequate margin exists to overfilling the affected OTSG.
- b.
The current nominal RCS operating pressure of 2155 psig at the hot leg tap remains unchanged for the power uprate. Therefore, the SGTR leakage rate remains the same.
- c.
The system response and the offsite dose consequence are performed in separate calculations. Section 3.10.3.15 of Enclosure 1 Attachment 3 of the DBNPS license amendment application specifically relates to the system response for the single tube SGTR event. The radiological consequences for all accidents are addressed in Section 3.12.2 of Attachment 3 of the DBNPS license amendment application. The radiological accident analyses are based on 102% of 2772 MWt. Thus, the power uprate, in combination with more accurate measurement of the thermal power level, yields the same maximum thermal power that is currently the basis for source term that is used to assess the accident analyses. Consequently, the current source term and radiological analyses will remain applicable for the requested power uprate. Question 10: Section 3.13 Nuclear Fuel Related Issues
- a.
The future cores of Davis-Besse will include Mark-B10, Mark-B 10K, and Mark-B 12 fuel designs. Is the Mark-B 12 fuel design approved by the staff? Recently, the staff approved a topical report of Mark-B 11 fuel assembly design (BAW-10229P-A), and there are plant specific analyses required for using the Mark-B 11 fuel design. Please explain the relationship among between Mark-B 11 and Mark-B 12 fuel designs.
- b.
Demonstrate that the structural compatibility will exist for a mixed core of Mark-B 10, Mark-B 10K, and Mark-B12 under hydraulic, seismic, and LOCA loads.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 14 DBNPS Response to Question 10:
- a.
The Mark-BlOK and Mark-B12 fuel assemblies are an upgrade of the Mark-BlO fuel assembly design. The Mark-B10K design includes 0.430 inch diameter M5TM fuel rod cladding, a debris-filter lower end fitting assembly, and optimized U0 2 and gadolinia fuel rod designs, which allow for increased uranium loading. Four Mark-B 1 OK fuel assemblies, designated "M5TM structural assemblies", are also in operation at the DBNPS. These assemblies utilize M5TM guide tubes in addition to the two uppermost intermediate spacer grids fabricated with M5 TM. The Mark-B12 design is essentially the same as the Mark-B10 design, except all the Mark-B 12 fuel rods and guide tubes are fabricated from M5TM material. The Mark-B12 design also utilizes a 6 leaf cruciform spring, which is an evolutionary optimization of the 8 leaf spring design used on the Mark-B 10 and Mark-B 1 OK. The Mark-B8A is an earlier design that includes a coil hold down spring and a skirted lower end grid. Small differences in fuel assembly and fuel rod lengths also distinguish the four designs. Future plans are to introduce M5TM spacer grids on a batch basis as allowed by the NRC approval of BAW-10227P-A (Reference 1). These designs were implemented in accordance to the criteria specified in 10 CFR 50.59. The Mark-B8A and Mark-B10 product upgrades do not fall in the category requiring NRC approval, as outlined in BAW-10179P-A (Reference 2). The structural evaluations were performed in accordance with the NRC approved topical reports BAW-10133P-A (Reference 3), BAW-10227P-A and BAW-10179P-A to demonstrate the structural compatibility of Mark-B8A, Mark-B10, Mark-B10K and Mark-B12 designs. The documentation of conformance to Standard Review Plan 4.2 (Reference 4), which considers the structural evaluations, is filed with each unique plant application. The Mark-B 11 fuel assembly design, which was approved by the NRC per BAW-10229P-A (Reference 5), incorporates a reduced rod diameter (0.416 inch), flow mixing features on five of six intermediate spacer grid assemblies, and a revised spacer grid restraint system to distribute loads to lower as well as upper end fittings. The Mark-B 11 batch fuel assembly design also incorporates M5TM fuel rods and the 6 leaf spring design. Future plans are to introduce M5TM guide tubes and spacer grids on a batch basis as allowed by the NRC approval of BAW-10227P-A.
- b.
The Mark-B 10K and Mark-B12 fuel assemblies have been evaluated for normal operating and faulted conditions per BAW-10179P-A. It was shown that the Mark-B10K and Mark-B12 assemblies are dynamically similar to the Mark-B8A and Mark-B 10 fuel assembly structures. The natural frequency changes due to the M5TM structural effects are shown to be less than 5%. The rod diameters are identical, and therefore the difference in clad stiffness is attributed to the small differences between the elastic modulus of the Zircaloy-4 and M5TM material. The change in frequency is negligible and satisfies the NUREG-0800, Standard Review Plan 4.2, Appendix A, Section B.3 (Reference 4)
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 15 requirements for uncertainty allowances (less than 15%). No factor needs to be applied on resultant faulted condition loads calculated for the Mark-B8A and Mark-B 10 fuel assemblies. Therefore, the lateral loads for seismic and LOCA events remain unchanged, and the subsequent fuel assembly component structural margins remain acceptable. The net hydraulic lift force on the Mark-B10K and Mark-B12 assemblies were assessed at both full core and mixed core conditions per BAW-10179P-A. Implication of these changes in fuel assembly hydraulic lift forces was evaluated for normal operation and faulted conditions. For all conditions, positive margins are maintained and the structural compatibility is shown. Fuel assembly pressure drop differences due to the debris filter lower end fitting were also considered in the fuel assembly flow-induced vibration assessment. The effects were shown to be small. Previous Mark-B tests and operational experience and performance remain applicable. References
- 1.
BAW-10227P-A, "Evaluation of Advanced Cladding and Structural Material (M5TM) in PWR Reactor Fuel," February 2000.
- 2.
BAW-10179P-A, Revision 4, "Safety Criteria and Methodology for Acceptable Cycle Reload Analyses," August 2001.
- 3.
BAW-10133P-A, Revision 1, "Mark-C Fuel Assembly LOCA-Seismic Analyses," June 1986.
- 4.
Standard Review Plan, Section 4.2, "Fuel System Design," NUREG-0800, Revision 2, US Nuclear Regulatory Commission, July 1981.
- 5.
BAW-10229P-A, "Mark-B 11 Fuel Assembly Design Topical Report," September 1997. Question 11: Section 3.13.2 Core Thermal-Hydraulic Design
- a.
It appears that cycle 14 has a mixed loading of Mark-B 10 and Mark-B 1 OK fuel assemblies. Describe the difference between these two fuel assemblies and their approved status. Provide available data to support the statement that fuel assemblies in the cycle 14 core have compatible hydraulic characteristics.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 16
- b.
Provide detailed justification that the BWC CHF correlation is still valid for Mark-B 10 and Mark-B 10K including all available data bases to support the approved BWC CHF correlation. Also, describe the mixed core CHF calculation method for cycle 14 operation. DBNPS Response to Question 11:
- a.
Fuel Assembly Design Differences The planned DBNPS Cycle 14 core configuration is predominately composed of the Mark-Bi0, Mark-BlOK, and Mark-B12 fuel assembly designs. All three fuel assembly designs have the following hardware similarities that influence the core hydraulics: two inconel end spacer grids, six Zircaloy-4 intermediate spacer grids, and upper end fitting with a cruciform fuel assembly holddown spring. The Mark-B8A and Mark-B 10 fuel assembly designs contains fuel rods utilizing Zircaloy-4 cladding and end caps. The rod design also uses a long lower end cap that extends from the top of the lower end fitting up into the lower end spacer grid as a debris-resistant feature. Should debris be captured at the lower spacer grid plane, the debris would be mechanically acting upon the solid end cap region. The Mark-B 1 OK fuel assembly design contains fuel rods utilizing the low corrosion M5TM cladding and end caps. The design also introduces the TrapperTM debris resistant lower end fitting. Instead of relying on capturing debris at the lower end spacer grid, like the Mark-B10 fuel assembly design, the Mark-B 10K is designed to capture debris within the TrapperTM lower end fitting using a filter plate. As a result of eliminating the need for a long lower end cap, the fuel stack length was increased by approximately 2.3 inches. The Mark-B 12 fuel assembly design has incorporated further improvements beyond the Mark-B 10K such as: M5TM control rod guide tubes for reduced corrosion, a Zircaloy-4 instrument guide tube with a tapered roll (MONOBLOCTM feature) at the top, and replacement of the 8-leaf cruciform fuel assembly holddown spring with a 6-leaf cruciform spring to reduce fuel assembly compressive forces that could contribute to fuel assembly bowing. The Mark-B 12 fuel assembly is hydraulically identical to the Mark-B 10K fuel assembly design.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 17 Fuel Assembly Design Approval Status The approved status of the fuel designs planned for the DBNPS core is based on the combined effect of NRC review of the major analysis tools supporting the fuel designs and the regular Annual Update Meetings held between Framatome and the NRC. Framatome ANP's methodology topical report, BAW-10179P-A (Reference 1), identifies the tools and methods used to support the DBNPS cores. The BWC CHF correlation (Reference 2) and the LYNXT code (Reference 3) have been reviewed and approved for application to the Mark-B 15x15 fuel designs at the DBNPS. Framatome ANP's 30-year Mark-B fuel design developmental effort has produced numerous design improvements that have been implemented at the B&W-designed 177 fuel assembly plants. These design improvements are based on engineering analyses and supplemented, where necessary, with design testing that utilize the approved reload licensing methodology and criteria specified in BAW-10179P-A and its references. The design improvements have also been acknowledged in the respective Reload Reports for each cycle and have been shared with the NRC during the Annual Update Meetings. Fuel Assembly Hydraulic Compatibility All four fuel assembly designs, Mark-B8A, Mark-B10, Mark-B1OK, and Mark-B12 use the same intermediate spacer grid designs. As a result, there is a consistent hardware-related hydraulic resistance within the active fuel region of the DBNPS Cycle 14 core. The hydraulic characteristics of the Mark-B 10 fuel assembly design were obtained from a full-scale flow test performed at the Alliance Research Center in the Control Rod Drive Line flow facility at reactor operating temperatures, pressures, and flow rates. This characterization provided pressure drops that yielded hardware form loss coefficients that have been used in engineering analyses. The centrally located Mark-B8A fuel assembly, with a skirted lower end grid and helical hold down spring, is hydraulically similar to the Mark-B 10 fuel assembly design. The hydraulically significant change for the Mark-B 1 OK fuel assembly design is the TrapperTM lower end fitting. Hydraulic tests of the TrapperM were performed in Framatome's MCTP loop facility located in Le Creusot, France. Theses tests used a short prototype fuel assembly test section that modeled the lower region of the production fuel assembly design - lower support grid pad, lower end fitting, lower end grid, fuel rod segments and instrument/guide tube segments. These tests also provided pressure drops from which lower end fitting form loss coefficients were derived. Fuel assembly hydraulic compatibility in the DBNPS core was demonstrated by showing that all design criteria are satisfied in the potential transition core configurations. This
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 18 included examining the impact of core flow redistributions on DNBR predictions, hydraulic lift forces, and mechanical issues such as flow-induced vibration concerns. The LYNXT code was used to model the DBNPS transition cores. For DNBR predictions, a one-pass transition one-eighth core model containing 64 channels was used. With the limiting fuel assembly located in the center of the core, channels 1 through 36 represented the subchannels within the limiting fuel assembly. Channels 37 through 64 individually represented the remaining fuel assembly locations within the core. Transition core configurations were selected that examined different fuel designs as the limiting fuel assembly. The remainder of the core was modeled in a manner to bound the potential lateral crossflow out of the limiting fuel assembly, thereby, providing conservative minimum DNBR predictions. The minimum DNBR predictions for these transition core configurations were compared to minimum DNBR predictions based on a full core of a single fuel assembly design, in this case, a full core of Mark-B10 fuel assemblies. The DNBR record of analysis is typically based on a full core of one fuel design and the transition core penalty, relative to the full core assumption, is explicitly applied against available DNB margin. In the case of the DBNPS, a transition core penalty can be applied against the retained DNB margin of the Thermal Design Limit for the Statistical Core Design methodology described in Reference 4. As discussed in Section 5.1 of Reference 4, the DNBR margin identified between the Thermal Design Limit and the Statistical Design Limit can be used to offset effects not treated in the Statistical Design Limit development such as transition core effects. DNBR predictions for the various configurations were performed at statepoint conditions that define the pressure-temperature safety limits and the Safety Limit Maximum Allowable Peaking Limits (MAPs). These conditions yielded minimum DNBRs at or near the Thermal Design Limit. Additional DNB predictions were obtained for the limiting Condition HI transient as well as the Operating Limit Maximum Allowable Peaking Limits (MAPs). The minimum DNBR prediction differences between the transition core configurations and the full core configuration were tabulated for the steady-state statepoints and the transient conditions. The DNB transition core penalty is defined as the maximum DNBR difference, where the transition core had the lesser DNBR prediction, for these operating conditions. For DBNPS Cycle 14, Framatome concluded there was no transition core DNB penalty for the Mark-B 1 OK and Mark-B 12 fuel assembly designs even though the TrapperTM end fittings had a higher flow resistance than the end fittings for the Mark-B 10 fuel assemblies. This conclusion was attributed to the lower average linear heat rate for the Mark-B 10K and
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 19 Mark-B 12 fuel designs with the longer fuel stack length that offsets the DNBR disadvantage of the flow diversion away from the TrapperM lower end fittings. It was also concluded that no transition penalty was necessary for the Mark-B 10 fuel because a limiting Mark-B 10 fuel assembly received more flow during the transition core configurations than during a full core Mark-B10 configuration. Similarly, no transition core penalty was necessary for the Mark-B8A fuel assembly. The LYNXT code was also used to examine the predicted fuel assembly hydraulic lift forces and lateral crossflow velocities. LYNXT models for these studies contained 29 channels where each channel represented a fuel assembly of the one-eighth core. Again, core configurations were selected that bounded the hydraulic conditions for each fuel assembly design. Adequate fuel assembly holddown capability and acceptable lateral crossflow velocities were predicted for all fuel designs in the Cycle 14 core. As the DBNPS core proceeds toward becoming a full core of Mark-B12 fuel assemblies, the results of these conservative transition core analyses should remain applicable.
- b.
BWC CHF Correlation Applicability The BWC CHF correlation, Reference 2, was developed and approved for the Mark-B series zircaloy intermediate spacer grid design. Over the last 20 years the grid design has only incurred insignificant changes that do not influence the application of the BWC CHF correlation. As a result, no additional CHF data has been obtained for the grid. The only data base for the Mark-B series application of BWC is contained in Reference 2. The approval for the use of the BWC CHF correlation with the LYNXT code is documented in the LYNXT Safety Evaluation Report in Reference 3. Since there have been no significant design changes in the grid since the CHF tests and the calculational tool, LYNXT, has been approved for providing BWC CHIF predictions, the BWC correlation remains valid for the Mark-B8A, Mark-B 10, Mark-B 10K, and Mark-B 12 fuel assembly designs in reload licensing analyses. Mixed Core CHF Calculation Method The transition core Critical Heat Flux (CHF) calculation method is described in the response to Question 11 a. References
- 1.
BAW-10179P-A, Revision 4, "Safety Criteria and Methodology for Acceptable Cycle Reload Analyses," August 2001.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 20
- 2.
BAW-10143P-A, "BWC Correlation of Critical Heat Flux," April 1985.
- 3.
BAW-10156-A, Revision 1, "LYNXT Core Transient Thermal-Hydraulic Program," August 1993.
- 4.
BAW-10187P-A, "Statistical Core Design for B&W-Designed 177FA Plants," March 1994. Januar 23, 2002 NRC Request for Additional Information Question 1: Provide the grid stability analysis performed in May 2000 for power uprate. DBNPS Response to Question 1: The requested report is provided in Enclosure 2. Question 2: The submittal does not say specifically that no changes to the station blackout coping and mitigation analysis are required due to the 1.63 percent power uprate. Please specify and give the details if any changes would affect the SBO coping capability and mitigation analysis due to the 1.63 percent power uprate. DBNPS Response to Question 2: No changes to the station blackout coping and mitigation analysis are required due to the proposed power uprate. January 28, 2002 NRC Request for Additional Information In Section 3.1, Approach of Safety Analysis, of Attachment 3 of the Enclosure 1 to the licensee's Amendment Application submittal (Reference), the licensee stated that, generally, no new analytical techniques were used to support the power uprate project. However, for OTSG tubes, the integrity of the tubes, virgin, sleeved or stabilized were re-assessed using the latest techniques.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 21 In Section 3.6.7.2, Attachment 3 of Enclosure I to the Amendment Application, the licensee discussed the OTSG flow-induced vibration of the steam generator tubes. The licensee made the following note: "The following discussion is specific to hardware supplied by B&W/FTI. A review of FIV analysis for plugs and stabilizers supplied by ABB/CE is ongoing and will be completed prior to implementation of the proposed power uprate." In view of the above, the staff requests the following information: (a) It is not clear why a separate analysis is being performed by the licensee for plugs and stabilizers supplied by ABB/CE. State whether the method of analysis is the same as that used for hardware supplied by B&W/FTI. Describe the differences if any. Provide the results of analysis for the hardware supplied by ABB/CE. (b) For B&W/FTI hardware, the licensee stated that the uprate "design" flow rate (and the corresponding flow velocity) was 2% greater than the previous FIV analyzed condition. Therefore, the forcing function on the tubes in the OTSG due to fluid flow increases approximately 4% during full power operation. The licensee further stated that, because the qualification analyses were performed through a span of over 19 years, there were differences in the methodology, the computer codes and the input parameters used that resulted in slightly different results even for the identical hardware. In order for the staff to complete its review of this latest technique and the resulting impact on the functional integrity of the steam generator tubes due to power uprate, the staff requests that the licensee submit the B&W/FTI reassessment report for staff review. The staff expects that the report will address the details of the FIV analyses such as, tubes subjected to two-phase flow, vortex shedding, fluid-elastic instability loadings, and turbulence-induced vibrations, and the input parameters used and their justifications, such as stability constant and viscous damping values. DBNPS Response: (a) Framatome ANP was originally contracted to evaluate the structural integrity of the B&W OTSG for the Caldon power uprate. One task of this project was to evaluate the B&W/Framatome stabilizers installed in the OTSG for the FIV considerations associated with the Caldon power uprate. This evaluation was performed by assessing the FIV margins associated with each stabilizer design determined from previous FIV analysis and making adjustments to these results in order to obtain the FIV margins associated with the Caldon power uprate. These previous analyses have been performed over the last nineteen years. Since there have been changes in the Connors' constant value over this time period, the FIV margins associated with the original FIV analysis were adjusted to reflect the latest
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 22 Connors constant value determined from recent testing. This evaluation was completed and documented. The DBNPS was made aware that this evaluation did not consider the installed ABB/CE stabilizers. At that time, Framatome ANP was unable to evaluate the ABB/CE stabilizer since critical design information for this stabilizer was not available. The ABB/CE design inputs were subsequently made available to Framatome ANP in order to evaluate the stabilizer for the Caldon power uprate. The FIV techniques and methodologies performed for the ABB/CE stabilizer design were identical to what had been performed in the original FIV analysis and in the Caldon FIV evaluation of the B&W/Framatome stabilizer designs. The FIV analysis of the ABB/CE stabilizer was documented in a separate calculation. This stabilizer design was determined to not have an adequate stability margin for the power uprate conditions. Thus, these stabilizers will be replaced in the upcoming Thirteenth Refueling Outage (13RFO). (b) The original FIV analyses of the OTSG virgin tube and the B&W/Framatome stabilizer designs address the damping associated with two phase flows, vortex shedding, fluid-elastic instability loadings, and turbulence-induced vibrations. These documents are considered highly proprietary to Framatome-ANP and are not available for placement on the docket. However, arrangements can be made for the NRC to view these documents at the Framatome offices in Lynchburg or Roslyn, Virginia. February 5, 2002 NRC Request for Additional Information Question 1: Stress Corrosion Cracking of Reactor Internals Increased power is expected to increase the corrosion rates and speed up degradation of reactor internals. Identify the plant programs that are in place to periodically inspect reactor internals and discuss whether these programs are adequate to manage the projected increase of reactor internals degradation due to stress corrosion cracking (SCC) and primary water stress corrosion cracking (PWSCC).
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 23 DBNPS Response to Question 1: As shown in Table 3-1 of Enclosure 1 Attachment 3 of the DBNPS license amendment application, the proposed power uprate increases Thot by 0.4 - 1.3 TF. The general corrosion rate of RV internals materials (mainly austenitic stainless steels and some nickel-based alloys) is negligible in PWRs and is not considered as a current or potential internals degradation mechanism. An increase of 1.3 TF will not affect the general corrosion rate. Irradiation-assisted stress corrosion cracking (IASCC), stress corrosion cracking (SCC), stress relaxation (SR), and irradiation embrittlement (IE) are the major reactor vessel internals degradation mechanisms identified by license renewal efforts. An increase in temperature usually accelerates these degradations. However, in the temperature range of interest (Thot 606.1 - 607.4 TF), the current understanding of the above mentioned degradations does not indicate any abrupt changes in the aging mechanism or kinetics. An increase of 1.3 TF is not expected to cause significant or detectable acceleration in degradation. Currently, these issues are addressed by an industry Issues Task Group (ITG) managed by EPRI. The B&WOG also developed a detailed six-year program (1998-2003) to address these issues. In late 2000, the B&WOG completed a formal review of both B&WOG and industry ongoing activities and future plans and established a goal of readying the B&WOG for an inspection of the RV internals and baffle bolts at a B&WOG plant sometime after 2013. PWSCC is a mechanism that affects Alloy 600 components and their welds in the RCS, such as the Alloy 600 CRDM nozzles and the associated J-groove welds. Alloy 600 and its welds have not been used in the RV internals of B&WOG plants. Question 2: Flow Assisted Cracking (FAC) Since the effects of FAC on degradation of carbon steel components are plant specific, the licensee needs to provide a predictive analysis methodology which must include the values of the parameters affecting FAC, such as velocity, and temperature before and after the power uprate (PU) and the corresponding changes in components wear rates due to FAC. (1) Indicate the degree of compliance with NRC Generic Letter 89-08, "Erosion/Corrosion in Piping." This letter requires that an effective program be implemented to maintain structural integrity of high-energy carbon steel systems. Describe how was this program modified to account for PU. If the computer code used in predicting wall thinning by FAC in this program is a generic code (e.g., CHECWORKS), specify it. However, if the code is plant specific provide its description. (2) Identify the predicted change of wear rates calculated by the revised code for the components most susceptible to FAC.
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Attachment Page 24 (3) Will the PU have significant effect on FAC in balance of plant (BOP) components? What is the value of the change in FAC wear rates? DBNPS Response to Question 2: The DBNPS described its programs addressing the concerns raised in NRC Generic Letter 89-08 in a July 14, 1989 letter to the NRC (DBNPS Serial No. 1679). These programs remain in place. As stated in Section 4.1.3 of Enclosure 1 Attachment 3 of the DBNPS license amendment application, Flow-Accelerated Corrosion (FAC) in the piping systems at the DBNPS is modeled using the CHECWORKS computer program. A new plant heat balance was generated for the proposed power uprate to predict pressure, temperature, mass flow rate, and enthalpy through the secondary plant piping systems. Based upon the new heat balance data, the power uprate is expected to have only a minor effect on wall thinning due to FAC in the balance of plant systems. The DBNPS plans to rerun the CHECWORKS model within 90 days of startup from 13RFO utilizing actual plant heat balance data. The results will be factored into future inspection/pipe replacement plans consistent with the current Corrosion/Erosion Monitoring and Analysis Program (CEMAP).
Docket Number 50-346 License Number NPF-3 Serial Number 2759 Grid Stability Study (162 pages attached)
GE Energy Services Davis-Besse Stability Study for FirstEnergy Corporation Final Report May 2000 Power Systems Energy Consulting General Electric International, Inc. One River Road Schenectady, New York 12345 USA GE Energy Services
GE Energy Services FirstEnergy Corporation Davis-Besse Stability Study FINAL REPORT Principle Contributors: Kara Clark Robert Laffen MAY 2000 Power Systems Energy Consulting General Electric International, Inc. One River Road Schenectady, New York 12345
GE Energy Services LEGAL NOTICE This report was prepared by General Electric International Inc.'s Power Systems Energy Consulting Department (PSEC) as an account of work sponsored by FirstEnergy Corporation (FirstEnergy). Neither FirstEnergy, nor General Electric International Inc., nor any person acting on behalf of any:
- 1.
Makes any warranty or representation, expressed or implied, with respect to the use of any information contained in this report, or that the use of any information, apparatus, method, or process disclosed in the report may not infringe privately owned rights; or
- 2.
Assumes any liabilities with respect to the use of or for damage resulting from the use of any information, apparatus, method, or process disclosed in this report.
GE Energy Services TABLE OF CONTENTS
- 1.
INTRODUCTION_
- 2.
STUDY APPROACI. 2 2.1 Benchmark System Conditions................................................................................................... 2 2.2 Uprated Davis-Besse Plant Scenarios................................................................... 6 2.3 Perform ance Criteria......................................................................................................................... 9 2.4 Contingency List................................................................................................................................ 9
- 3.
POWER FLOW ANALYSIS.......... .. 12 3.1 Pre-contingency Violations....................................................................................................... 12 3.1.1 Benchmark System................................................................................................................ 12 3.1.2 1033MW Davis-Besse Plant Uprate............................................................................... 13 3.2 Post-contingency Violations........................................................................................................ 13 3.2.1 Benchmark System............................................................................................................... 13 3.2.2 1033MW Davis-Besse Plant Uprate............................................................................... 14
- 4.
STABILITY ANALYSIS. 4.1 1033MW Davis-Besse Plant Uprate.......................................................................................... 15
- 5.
CONCLUSIONS AND RECOMMENDATIONS........ 17 Appendix A. Davis-Besse Plant Dynamic Models A-1 Appendix B. Power Flow Analysis Contingency List. Appendix C. Power Flow Post-Contingency One-line Diagrams. C-1 Appendix D. Stability Analysis Results-- D-1
Z GE Energy Services
- 1. INTRODUCTION FirstEnergy Corporation requested that PSEC perform a transient stability study of the Davis-Besse nuclear power plant for two reasons. First, an updated stability study was desired - the most recent study was several years ago.
Second, a turbine-generator uprate is under consideration. Davis-Besse currently has a maximum gross power output of 942MW, a rating of 1069MVA, and a nominal power factor of 0.88. The power plant design is based on industry standards and regulatory guidelines. The layout includes two electrically independent 345kV sources of off-site power (OSP) for the start-up transformers. The two 345kV circuits are fed from the Davis-Besse 345kV transmission yard. The transmission yard consists of a five-breaker ring with three transmission line exits, two station service busses and one generator position. For this study, a 10% increase in gross power output was assumed for the uprate. Therefore, an increase in both the rating (1 120MVA) and power factor (0.92) were used to increase the power output to 1033MW. The change in power factor also reduced the unit's reactive power capability from approximately 500MVAr to 433MVAr. It is possible to replace the 67MVAr of generator reactive capability with another reactive power source. Such a var source could be either static (mechanically switched capacitors (MSC)) or dynamic (static compensator (STATCOM), static var compensator (SVC), or synchronous condenser) or a combination. The needs of the system will dictate size, location, and type of source. For this study, the impact of a 67MVAr STATCOM on stability performance was investigated. This study evaluated the steady-state and transient performance of the FirstEnergy system with both the existing Davis-Besse power level and the uprated power level. A variety of disturbance scenarios were analyzed, including single transmission line outages, single generating unit outages, double transmission line outages, and combined transmission line and generating unit outages. Both power flow and stability analyses were performed. The power flow analysis identified branch (e.g., transmission line or transformer) loading and bus voltage violations under both normal and contingency (i.e., outage) operating conditions. The stability analysis evaluated both first swing stability and system damping. Section 2 of this report describes the study approach in detail. Sections 3 and 4 describe the results of the power flow and stability analyses, respectively. Section 5 presents the study conclusions and recommendations. I
GE Energy Services
- 2. STUDY APPROACH This study used a relative approach to determine the impact of a possible Davis Besse station (DBS) uprate on the performance of the FirstEnergy power system.
First, system performance with the current plant output (942MW) was determined in order to establish the benchmark, and then system performance with the power uprate (1033MW) was determined and compared to the benchmark. This relative approach removed any ambiguities as to the actual impact of a possible plant uprate since existing criteria violations were identified. The following sections describe the benchmark system conditions, current and uprated Davis-Besse plant models, as well as the performance criteria and contingency list. 2.1 Benchmark System Conditions The 1999 summer peak power flow database provided by FirstEnergy was modified to represent the Davis-Besse plant in more detail and to represent a year 2000 load condition in FirstEnergy's service territory. Specifically, the following changes were made:
- The Davis-Besse generator model was moved from the 345kV bus to a new 25kV bus, and a 980MVA generator step-up (GSU) transformer with an impedance of 0.14pu was added between the two buses. The generator gross output is 942MW.
" The 25/13.8kV generator auxiliary transformer, which serves the auxiliary load under normal operating conditions, was modeled as a 69MVA transformer with a 0.063pu impedance (on 26MVA). The auxiliary load in the Davis-Besse plant was represented by a detailed model as shown in Figure 2-1. " Start-up transformers 1 and 2 were modeled as 65MVA transformers with impedances of 0.094pu and 0.093pu (on 39MVA), respectively. These transformers were connected between the Davis-Besse 345kV bus and two new 13.8kV buses. The auxiliary load is transferred from the generator auxiliary transformer to the start-up transformers under fault scenarios that trip the Davis-Besse unit. 2
GE Energy Services To simulate a year 2000 load condition in the FirstEnergy service territory, the real and reactive power loads in zones 202, 203, 205, and 241 were increased by 3.63%. A corresponding increase in power output at several large generating plants outside ECAR (Shawnee, JA Fitzpatrick, Susquehanna, Browns Ferry) supplies this load. A one-line diagram of the bulk system illustrating the benchmark pre-contingency power flow results is shown in Figure 2-2. Additional changes were made to the dynamic data to better match the information provided by GE Generator Engineering. Those changes included:. The representation of the Davis-Besse exciter was changed from an exac3 model to an exac3a model to better represent the maximum field current limiting function in an Alterrex exciter. The dynamic load model represents real power loads as constant current and reactive power loads as constant impedance. Block diagrams of the dynamic models used to represent the Davis-Besse plant are included in Appendix A. 3
tl 6 -- I 1 tj '.4
- 4.
-4 -4. lb lb C,, I-' lb 1 lb -4 '-4 ,I. I Ill in lb I0 lb 0 lb (Il
Nzw GE Energy Services 1 1 6364 -270 0 30 1.00C 346 0 4? 0
- 25. 003 0303.4 0.6.6 6 207 0
1.0 22021 2303 30 SH~234 T. Jý C A6 60 26 1.60 03MIW f 3900.22606 220736 00 C, -7. 4? I 1..18 2-750 1.017 -~47 14 C N 0 K44 0-? 7 0.- +/-d I m o.n 02STUW .0 S C. 44 . E 63.1 600k 170-0 0.965 i 0233607 21096 .0 76 Of. 4701 C 7 67 7 T 22201 M W.
- a.
22117IL 04066000 22202
- 1.
C 4, 10 N 1.016* 04mam0 AAAA 221911 C OnlKY G6 1.0500 1010 23.11 4 ild. 600 -6 0.104 0661 99 f t 10 0.960 o C 5u.,;E+/- 6. II .!.r 60, Figure 2-2. Benchmark Power Flow Results (Davis-B esse Output = 942MW). 5 4S3= 2 I.2 TX T 1, 7 28807. 1.022
GE Energy Services 2.2 Uprated Davis-Besse Plant Scenarios The assumed plant uprate would increase power output by about 91MW (from 942MW to 1033MW) and reduce the unit's reactive power capability by about 67MVAr (from 500MVAr to 433MVAr). The benchmark power flow was modified to reflect the above changes. One-line diagrams illustrating the power flow results for the Davis-Besse station and the FirstEnergy bulk power system are shown in Figures 2-3 and 2-4, respectively. The uprate includes a rating increase, and therefore changes the dynamic model of the Davis-Besse generator. A block diagram of this model is also included in Appendix A. 6
TIHI ---. F. F
GE Energy services -13 C ! ~~-C 34"0s' -,3*4,SO,. tl *.~ i356 707 227 22022 04AVONS D o .s8 -20 222 f° 1.02 r-03 1.2 03LDO 1.1o 222 22I2 ,.0,2SUM:
- .; /
1 F I.... I,,*, o,, / I.,-*0 98,' P l 1:* * ",--LO I/ t 21330"/ I AAA I..*,* l iF
- 17 20,Z, 0.97-9I 287,o,-
21 CC 0.. ,,=I 1 / ~ ~ ~ ~ ~ ~ ~ 10 .C%.1.1 x1 (V 2'" 1 I*' S'* J l" I1 .005 4 03 TL 7 _tI .ls O 1Il~ ~,,1. /1 v
- .o
--,-.1-..r,/ 4*
- 1*
,*, =1,
- 2. 4V
'RI ,I. ~ 260 ,0* 2207 21t r?$9t
- J:*l r ~~ 91 0 UP' r
1 °o0,* 1 E, C -1 " ft H P~re 2-4. r./pr~te Power Flo* Rc# (D1.00Ot5t= 03M
0 GE Energy Services 2.3 Performance Criteria For the power flow analysis, different thermal, or branch loading, performance criteria were used for normal operation ard for contingency operation. Under normal conditions, acceptable branch loadings are less than 100% of the normal continuous summer rating (Rate 1 in the power flow). Under contingency conditions, acceptable branch loadings are less than 100% of the long-term emergency (LTE) summer rating (Rate 2 in the power flow). Similarly, different voltage performance criteria were used for normal and contingency operation. Under normal conditions, acceptable voltages are greater than 0.95pu and less than 1.05pu, while under contingency conditions, acceptable voltages are greater than 0.90pu and less than 1.05pu. Impacts due to the uprate will be identified as follows: "* Thermal violations that did not occur in the benchmark system. "* Thermal violations that exceed the benchmark system by at least 3%. "* Voltage violations that did not occur in the benchmark system. "* Voltage violations that exceed the benchmark system by at least 1%. "* Changes in voltage that exceed 10%. The monitored zone consisted of the zones 5 (PN BULK), 202 (OE), 203 (TE), 204 (CEI), 219 (DECO), 241 (CEI-CPP), 251 (AEP-OP) and 888 (new zone for DBS) in the power flow. 2.4 Contingency List The contingency list focused on major 345kV outages in the Davis-Besse area, including fault scenarios that result in the outage of a single transmission line, two transmission lines, or one line and one generating unit. Both Davis-Besse and far end faults were analyzed, as well as both primary clearing and back-up clearing for stuck phases on independent pole breakers. Table 2-1 shows the list of 14 contingencies used for the stability analysis, with fault clearing times as provided by FirstEnergy. For the power flow analysis, the list was reduced to 10 by eliminating duplication - i.e., contingencies 1 and 4 are different in the stability analysis but identical in the power flow analysis. The power flow analysis evaluated contingencies 1-3, 7 10, and 12-14. For all generating unit contingencies, an inertial redispatch was performed. A complete listing and description of the power flow contingencies is included in Appendix B. 9
0 GE Energy Services Table 2-1 Contingency List for Davis-Besse Grid Stability Study CaeFault Type and Location Fault Clearing................. .Type Name Voltage Element From Bus Clear Time To Bus Clear Time 1 3* on line 03DAV-BES 345 kV 22021 345kV line 03DAV-BE 22021 4.5 cy (B.34561,34562) 03BAY SH 22025 4.5 cy (P,34542,34544) 8 3on line 03DAV-BE 345 kV 22021 345kV line 03DAV-BE 22021 4.5 cy (P,34563.34564) 03LEMOYN 22026 4.5 cy (P,34501,34502) 3 # on line 03DAV-BE 345 kV 22021 345kV line 03DAV-BE 22021 4.5 cy (P,34562.34564) 02BEAVER 21330 4.5 cy (P, 115, 88) 4 3# on line 03BAY SH 345 kV 22025 345kV line 03DAV-BE 22021 22.5 cy (B.34561, 34562) 03BAY SH 22025 4.5 cy (P,34542,34544) 5 3f on line 03LEMOYN 345 kV 22026 345kV line 03DAV-BE 22021 22.5 cy (13,34563, 34564) 03EMOYN 22026 4.5 cy (P,34501,34502) 3 on line 02BEAVER 345 kV 21330 345kV line 03DAV-BE 22021 22.5 cy (B,34562, 34564) 02BEAVER 21330 4.5 cy (, 115, 88) 3ý on line 03DAV-BE 345 kV 22021 345kV line 03DAV-BE 22021 4.5 ey (P,34561,34562) 03BAY SH 22025 4.5 cy (P,34542,34544) X MW generator 4.5 cy (P, 34560) 1-B GEN 170 aux load transfer 4.5 cy 3o in CB 03DA OLtV-BE* 34.5 kV 2021 345kV line 03D1AV-E 201 '45y(P35) 03LEMOYN 22026 4.5 cy (P,34501,3452 S34564 345kV line 12 cy (FB,34562) 02BEAVER 21330 12 cy (B,i115, 88) 9 3VlIV on line 03DAV-BE 345 kV 22021 345kV line 03DAV-BE 22021 4.5 cy (P,34561) 03BAY SH 22025 4.5 ey (i1,34542,354) If 34562 fails 345kV line 12 cy (B,34564) 02BEAVPR 21330 12 cy (B, If15, 88) 10 none X MW generator 03DAV-BE 22021 (34560,34561) D-B GEN 17ý0 Aux load transfer 11 3ý in GSU 03DAV-BE 345 kV 22021 X MW generator 03DAV-BE 22021 4 cy (P,34560,34561) D-B GEN 170 aux load transfer 4 cy 12 3t in OSU 19ENFPP 345 kV 28766 1 10 MW 19ENFPP 28766 4cy(P) 19FERMi2 28861 generator 13 none 345kV line, 03BAY S" 22025 (34541,34542) 19MON12 28761 345kV line 03LEMOYN 22026 (34505,34506) 19MAJTC 28754 14 I on 2 lines 03LEMOYN 345 kV 22026 345kV line 03BAY SH 22025 4.5 cy (P,34540,34544) 05FOSTOR 22606 4.5 cy (P) near Lemoyne BYSHFOST 345 kV 22605 345kV line 03LEMOYN 22026 4.5 cy (P,34504,34506) 05FOSTOR 22606 4.5 cy (P) 10
GE Energy Services Notes:
- 1. Table of bus names in load flow Substation Name Number Davis-Besse 345kV 03DAV-BE 22021 Bay Shore 345kV 03BAY SH 22025 Lemoyne 345kV 03LEMOYN 22026 Beaver 345kV 02BEAVER 21330 Monroe 345kV 19MON12 28761 Majestic 345kV 19MAJTC 28754 Fostoria 345kV 05FOSTOR 22606 Fermi 345kV 19ENFPP 28766 Fermi 22kV 19FERMI2 28861
- 2. P = primary clearing, B = backup clearing, F = failure to trip, D = direct transfer trip, cy = cycles
- 3. Circuit breaker identification number
- 4. Davis Besse-Lemoyne 345kV line is out-of-service pre-contingency (circuit breakers 34563 and 34564 are open).
- 5. 345kV breaker (34562) is equipped with independent pole operation (IPO).
11
GE Energy Services
- 3. POWER FLOW ANALYSIS The purpose of this power flow analysis was to determine the impact a possible Davis-Besse plant uprate on the FirstEnergy system by comparing the relative performance of the system with and without the uprate. There are two basic conditions under which the transmission system must operate: normal, or all-lines in; and single or double contingency conditions. Both were examined.
The analysis was performed using GEII-PSEC's PSLF program. For pre contingency solutions, transformer tap and phase shifting transformer angle movement were allowed. For post-contingency solutions, no motion or switching was allowed. The branch loading performance was compared against appropriate criteria; i.e., normal continuous rating for pre-contingency loading, and long-term emergency rating (LTE) for post-contingency loading. Similarly, the voltage performance was compared to an acceptable normal operating range of 0.95 pu to 1.05 pu, and an acceptable contingency operating range of 0.90 pu to 1.05 pu. 3.1 Pre-contingency Violations Pre-contingency criteria violations for both the benchmark system and the uprated Davis-Besse plant system are summarized in the following sections. 3.1.1 Benchmark System Under normal system operating conditions without the uprate, the loading on four branches exceeds their normal continuous rating. A complete list of the benchmark pre-contingency overloads is shown in Table 3-1. The first column shows the overload in pu of normal rating (rate 1 in the load flow), the second column shows the affected branch, and the third column shows the nominal voltage level of that branch. A dual entry in the third column indicates that the overloaded branch is a transformer. The fourth, fifth and sixth columns show the real power flow, reactive power flow, and current flow, respectively. The seventh column shows the MVA flow (pu overload times MVA rating), and the final column shows the normal MVA rating. No pre-contingency voltage violations were observed in the benchmark system. 12
GE Energy Services Table 3-1 Benchmark Pre-Contingency Branch Loading Violations 1.02 02DALE-05W CANT 138 -177 -28 791 179 185 1.05 041VY-041VYQ14 36/138 -69 -11 1210 70 72 1.07 04NRTHFL-04NFLDQ4 36/138 -49 -7 844 49 49 1.02 05REEDUR-05TORREY 138 -188 -11 813 188 191 3.1.2 1033MW Davis-Besse Plant Uprate Under normal system operating conditions with the uprate (1033MW), no additional branch overloads were observed. In addition, no pre-contingency voltage violations were observed with the Davis-Besse uprate. 3.2 Post-contingency Violations Ten contingencies were analyzed to investigate the impact of the uprated Davis Besse plant on the FirstEnergy system. A description of each contingency is included in Appendix B. Appendix C contains one-line diagrams of the FirstEnergy .system, illustrating the power flow results for all contingencies, with and without the uprate. Post-contingency criteria violations for both the benchmark system and the uprated Davis-Besse plant study system are summarized in the following sections. 3.2.1 Benchmark System Without the uprate, loadings on two transformers exceed their LTE ratings. A complete list of the benchmark post-contingency overloads is shown in Table 3-2. The first column identifies the contingency that results in the most severe overload on a given branch, the second column shows the pre-contingency loading in pu of normal rating (rate 1 in the load flow), the third column shows the post contingency loading in pu of LTE rating (rate 2 in the load flow), the fourth column shows the affected branch, and the fifth column shows the nominal voltage level of that branch. A dual entry in the fifth column indicates that the overloaded branch is a transformer. The sixth, seventh, and eighth columns show the post contingency real power flow, reactive power flow, and current flow, respectively. The ninth column shows the MVA flow (pu post-contingency loading times MVA rating) and the final column shows the LTE MVA rating. No post-contingency voltage violations were observed in the benchmark system. 13
GE Energy Services Table 3-2 Benchmark Post-Contingency Branch Loading Violations 1 1.06 1.06 02MASURY-02MASURY 138/69 68 19 71 71 67 3 1.03 1.04 02SHNROK-02SHINRO 138/69 67 17 69 69 .67 Key to Contingencies: 1: Loss of Davis Besse-Bayshore 345kV Line 3: Loss of Davis Besse Beaver 345kV Line 3.2.2 1033MW Davis.Besse Plant Uprate With the uprate, no additional branch loading or bus voltage violations were observed under post-contingency conditions. 14
"GE Energy Services
- 4. STABILITY ANALYSIS The stability analysis was designed to evaluate the impact of the possible Davis Besse plant uprate by focusing on the relative performance of the uprated system in comparison to the existing system. The baseline performance was established by the results of stability simulations with the current level of Davis-Besse power output (942 MW) for the combined 1999/2000 summer peak load conditions (1999 load condition modified to represent year 2000 load in FirstEnergy territory). The relative performance of the Davis-Besse uprate (1033 MW) was then compared to these benchmarks. Another series of stability simulations was performed at the uprated power level with a 67MVAr STATCOM (static compensator) at Davis Besse to replace the dynamic var capability lost in the uprate. The performance of this system was compared to both benchmark system performance and the performance of the system with the uprate alone.
4.1 1033MW Davis-Besse Plant Uprate A summary of system performance with and without the uprate and with and without the STATCOM is shown in Table 4-1. A complete set of system variables is plotted for each contingency and shown in Appendix D. These plots show the system performance with the uprate (1033MW) and the STATCOM as a solid line, the system performance of the uprate (1033MW) alone with a dotted line, and the baseline system (942MW) with a dash-dot line. Under the 1999/2000 summer peak load condition, the system response for twelve of fourteen contingencies was first-swing stable with well-damped oscillations for all three Davis-Besse scenarios. System response to contingency 4 varied, and all systems were unstable in response to contingency 8. Contingency 4 is a three-phase fault at the Bayshore 345kV bus, cleared by tripping the Bayshore breakers at 4.5 cycles and the Davis-Besse breakers at 22.5 cycles. For this event, the existing system response is stable but neither of the uprated system responses are stable. Contingency 8 is a three-phase fault in Davis Besse circuit breaker 34564, cleared by tripping the Davis Besse-Lemoyne 345kV line in 4.5 cycles and the Davis Besse-Beaver 345kV line in 12 cycles. For this event, all three system responses are unstable. 15
"GE Energy Services Table 4-1 Transient Stability Analysis Results Et (Oupu =. 94NNS (Oupu =603NN)(upt 03W Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Unstable Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Unstable Stable & Damped Stable & Damped Stable & Damped Unstable Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Unstable Stable & Damped Stable & Damped Stable & Damped Unstable Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped Stable & Damped 16 1 2 3 4 5 6 7 8 9 10 11 12 13 14
GE Energy Services
- 5. CONCLUSIONS AND RECOMMENDATIONS FirstEnergy Corporation requested that PSEC perform a transient stability study of the Davis-Besse nuclear power plant for two reasons. First, an update of the latest stability study was desired.
Second, a turbine-generator uprate is under consideration. For this study, a 10% increase in gross power output was assumed for the uprate. Therefore, an increase in both the rating (1 120MVA) and power factor (0.92) were used to increase the power output to 1033MW. The change in power factor also reduced the unit's reactive power capability from approximately 500MVAr to 433MVAr. It is possible to replace the 67MVAr of generator reactive capability with another reactive power source. Such a var source could be either static (mechanically switched capacitors (MSC)) or dynamic (static compensator (STATCOM), static var compensator (SVC), or synchronous condenser) or a combination. The needs of the system will dictate size, location, and type of source. For this study, the impact of a 67MVAr STATCOM on stability performance was investigated. This study evaluated the steady-state and transient performance of the FirstEnergy system with both the existing Davis-Besse power level and the uprated power level. A variety of disturbance scenarios were analyzed, including single transmission line outages, single generating unit outages, double transmission line outages, and combined transmission line and generating unit outages. Both power flow and stability analyses were performed. The power flow analysis identified branch (e.g., transmission line or transformer) loading and bus voltage violations under both normal and contingency (i.e., outage) operating conditions. The stability analysis evaluated both first swing stability and system damping. Both analyses used a relative performance approach to determine the impact of the plant uprate on the FirstEnergy power system. First, system performance with the current plant output (942 MW) was determined in order to establish the benchmark, and then system performance with the uprate (1033MW) was determined and compared to the benchmark. The power flow results described in Section 3 show that two lines and two transformers exceed their ratings for the benchmark system under normal system conditions. No additional overloads were observed with the Davis-Besse plant uprated to 1033MW. No pre-contingency voltage violations were observed with either level of Davis-Besse plant output. 17
GE Energy Services The post-contingency power flow analysis showed two transformer overloads in the benchmark system. No post-contingency voltage violations were observed in the benchmark system. No additional branch overloads or voltage violations were observed with the Davis-Besse uprate to 1033MW. Thus, the power flow analysis indicates that the uprate results in no additional overloads or voltage violations. The stability analysis compared the performance of the Davis-Besse uprate (1033MW) to benchmark system performance (942MW). Another series of stability simulations was performed at the uprated power level with a 67MVAr STATCOM at Davis-Besse to replace the dynamic var capability lost in the uprate. The performance of this system was compared to both the benchmark system performance and the performance of the system with the uprate alone. The stability analysis showed that under the 199912000 summer peak load condition, the system response for twelve of fourteen contingencies is first-swing stable with well-damped oscillations for all three Davis-Besse scenarios. - System response to contingency 4 varied, and all systems were unstable in response to contingency 8. Contingency 4 is a three-phase fault at the Bayshore 345kV bus, cleared by tripping the Bayshore breakers at 4.5 cycles and the Davis-Besse breakers at 22.5 cycles. For this event, the existing system response is stable but neither of the uprated system responses are stable. Contingency 8 is a three-phase fault in Davis Besse circuit breaker-34564, cleared by tripping the Davis Besse-Lemoyne 345kV line in 4.5 cycles and the Davis Besse-Beaver 345kV line in 12 cycles. For this event, all three system responses are unstable. Improved system stability may be achieved by the application of a shorter breaker/relay operating time or a larger dynamic reactive power source. While this study used a STATCOM to supply vars, other types of equipment are also potentially suited to this application, such as an SVC or synchronous condenser to supply dynamic var support or mechanically switched capacitors to supply steady state support. If the Davis-Besse uprate occurs, additional analysis is recommended to determine methods to improve system stability for the above contingencies. 18
Vff GE Energy Services Appendix A Davis-Besse Plant Dynamic Models A-1
0 GE Energy Services Davis-Besse Plant Model with Power Output = 942MW A-2
- q-axis not shown ***
12 09:45:23 1999 1.7900 0.3650 0.2800 1.6800 0.5750 0.2800 0.2150 0.0044 7.3000 0.0320 0.4100 0.0550 0.0907 genrou s12 h d rcomp xcomp accel 700 DB GEN 25.0 1 0.4120 3.4300 0.0000 0.0000 0.0000 0.0000 Thu Aug id lpd lppd lq ipq lppq Ii ra tpdo tppdo tpqo tppqo sl
0 Vs vamax EcE 1 I+STC Ka I e fd 1+sTb +s~a + so Si S2 S Fex Vref vf Vamin Vtn (KliEtx+Vs+Vref-Etx-Vf) Vfemax = KfaKli Vemax = (Vfemax-Kdlfd)/(Se+Ke) Vemin = Vlv/Fex Ke Kclfd/Ve + Sn Vn l+sTf efd n S4 Thu Aug 12 09:45:26 1999 exac3a 70U DB GEN 25.0 1 tr 0.0000 efdn 0.8610 tb 0.0000 kc 0.1300 tc 0.0000 kd 1.0500 ka 46.2500 ke 1.0000 ta 0.0130 vlv 0.5900 vamax 1.0000 el 5.0800 vamin -0.9500 sel 0.3330 te 4.8500 e2 6.7800 klv 0.2600 se2 2.7500 3r 6.1700 kll 0.5900 kf 0.0720 kfa 0.0500 tf 1.0000 kn 0.0500
Pmechhp dbl 2 7 + + Ph Pref w K1÷ sT2 )-' l l
- 1 I
1 1 'EEDhp SOnS3$S5 ++ Pmechlp + ++P1 Thu Aug 12 09:45:29 1999 ieeegl 700 DB GEN 25.0 1 k 20.0000 k4 0.0000 pgv2 0.0000 ti 0.0500 t6 0.0000 gv3 0.0000 t2 0.0000 S 0.0000 pv3 0.0000 t3 0.050 0 73 -0 gv4 0.0000 so0.0000 t7 0.0000 p44 0.0000 uc -10.0000 k7 0.0000 gv5 0.0000 pmax 1.0000 k8 0.0000 pgv5 0.0000 pmin 0.0000 db1 0.0000 gv6 0.0000 t4 0.5000 eps 0.0000 pgv6 0.0000 l 0.3300 dK2 0.0000 Th 0.0000 199 0.0000 t5 10.0000 pkl 0.0000 k3 0.6700 k2 0.0000
"W/ GE Energy Services Davis-Besse Plant Model with Power Output = 1033MW A-3
Efd+ Se q-axis not shown *** Thu Aug 12 09:45:52 1999 id lpd lppd lq lpq ippq 11 ra tpdo tppdo tpqo tppqo sl 1.8760 0.3830 0.2930 1.7610 0.6030 0.2930 0.2250 0.0046 7.3000 0.0320 0.4100 0.0550 0.0907 genrou s12 h d rcomp xcomp accel 700 DB GEN 25.0 1 0.4120 3.4300 0.0000 0.0000 0.0000 0.0000
S Vs so I Si Vref Vf (KliEtx+Vs+Vref-Etx-Vf) Vfemax = KfaKlj Vemax = (Vfemax-KdIfd) / (Se+Ke) Vemin = Vlv/Fex S4 Thu Aug 12 09:45:55 1999 tr tb tc ka ta vamax vamin te klv kr kf tf kn 0.0000 0.0000 0.0000 46.2500 0.0130 1.0000 -0.9500 4.8500 0.2600 6.1700 0.0720 1.0000 0.0500 exac3a efdn kc kd ke vlv el sel e2 se2 kll kf a 700 DB GEN 25.0 1 0.8610 0.1300 1.0500 1.0000 0.5900 5.0800 0.3330 6.7800 2.7500 0.5900 0.0500 Vamax Vamin S2 Efd
dl 0 -+ + + Pmechhp S* + + y Ph Pref 1K3 I ('+sTi) j ,) UC_ l*T'ns5l+T 1P1 +-T2 PV P Thu Aug 12 09:45:57 1999 ieeegl 700 DB GEN 25.0 1 k 20.0000 k4 0.0000 pgv2 0.0000 ts 0.0500 tn 0.0000 gv3 0.0000 t2 0.0000 k5 0.0000 pgv3 0.0000 t3 0.0500 k6 0.0000 gv4 0.0000 uo0 i0.0000 t7 0.0000 pgv4 0.0000 uc -10.0000 k7 0.0000 gv5 0.0000 pmax 1.0000 k8 0.0000 pgv5 0.0000 pmin 0.0000 dbl 0.0000 gv6 0.0000 t4 0.5000 eps 0.0000 pgv6 0.0000 k+ 0.3300 db2 0.0000 k2 0.0000 gvM 0.0000 t5 10.0000 pgvl 0.0000 k3 0.6700 gv2 0.0000 ,EEDhp
f GE Energy Services Appendix B Power Flow Analysis Contingency List 1 22021-22025, "1" Trip Davis Besse-Bayshore 345kV Line 2 22021-22026, "1" Trip Davis Besse-Lemoyne 345kV Line 3 22021-21330, "1" Trip Davis Besse-Beaver 345kV Line 7 22021-22025, "1" Trip Davis Besse-Bayshore 345kV Line 700, "1" Trip Davis-Besse Unit, Redispatch, 22021-700, "1" Trip Davis-Besse GSU Transfer Auxiliary Loads 22021-22026, "1" Davis Besse-Lemoyne 345kV Line Out-of-service Pre-contingency 8 22021-22026, "1" Trip Davis Besse-Lemoyne 345kV Line, 22021-21330, "1" Trip Davis Besse-Beaver 345kV Line 9 22021-22025, "1" Trip Davis Besse-Bayshore 345kV Line, 22021-21330, "1" Trip Davis Besse-Beaver 345kV Line 10 700, "1" Trip Davis-Besse Unit, Redispatch, 22021-700, "1" Trip Davis-Besse GSU, Transfer Auxiliary Loads 12 28861, "2" Trip Fermi Unit, Redispatch, 28766-28861, "1" Trip Fermi GSU 13 22025-28761, "1" Trip Bayshore-Monroe 345kV Line, 22026-28754, "1" Trip Lemoyne-Majestic 345kV Line 14 22025-22605, "1" Trip Bayshore-Fostoria 345kV Line, 22605-22606, "1" 22026-22606, "1" Trip Lemoyne-Fostoria 345kV Line B-1
GE Energy Services Appendix C Power Flow Post-Contingency One-line Diagrams 1 345kV Drawing, Benchmark with Davis-Besse Plant Output = 942MW 2 DBS Drawing, Benchmark with Davis-Besse Plant Output = 942MW 3 345kV Drawing, Uprate with Davis-Besse Plant Output = 1033MW 4 DBS Drawing, Uprate with Davis-Besse Plant Output = 1033MW C-1
1W GE Energy Services 345kV Network Drawing Benchmark with Davis-Besse Plant Output=942MW Post-Contingency Power Flow Results C-2
Loss of Davis Besse-Bayshore 345kv Line All Lines In Pre-Contingency Existing Davis-Besse Plant (942MW) DSGE O 3 B42J 70 ~ 0.39 1 22022 Jill~3 1 3000 D Vt 1.025 +i 03LEHMN41 22U02 -1w I t 1. F 03DAYS 2102 19)4N012 28761 192 19WAYNE
- 2 8 807a, A-0.7J 3240W F=nT GWSS 07UTIT. 220SW On 00 34563 TIM 02 ______ 1.019 708 707 34564 007 021MVER 4 41 0.983 21330
.00.0 Av A At A.RLIL t 1 0.9"4 00 0li 21600 C~ I (VIMn 3."023WAVE 4 4 414 1.09 21S90OC -0 tV tt Coj O4AVOK tt t t1 AAA 0.986 NIY 22192
- e.,s t1 40.965 0
0 03 t t 4 47 A '0 AVN#9 tw Cl 4 M 10 C ~t 14 0.9641 R (-I rn LCv to M FOX 44 44i 444 tt 0.172 0. 75 0. S In K f 0.960 11.064 o!1004 02C Q 1.448
- 1. 41 io oA/
~ Un, 0W5OSOSTOR I 1.003 031n"A 44 22606 1 22073 011% 00 M '10 (- 0 inf I in t on 4403NS8TAR' 1.003 t* t I .p 22074 in C 102GA.LION t14 0_993 i 21360 CD o44I SN-TD T o TO 02STAR. _ 28827 0 1.024 1 in355 21 101~3 CD 44 041 3AILLM 1 m;.- Y LO 22027 CD 1.0061 0.175 D.! 7S A30 I rn~v C 19MIFFP t 4 1.025 Ohio central
- 1. D0Soa~
28766 1 19FERM2 QA0.993 VV Vv 04300N2PE 28861 21.84 D.s .10Coventry' 22200 t S n 0.988012 -2 22603 0 -Y o 10D o9wST r117 i 1.019 t 4 22201 ~t t A 28830 r-.nCD t 28762 1.!43 04M4RDIN t
- 0. So, V! 7S Marysville r-.10. 4 I,
SW Lima t1 1 28754 .1 0ni Quakr 'rp J,, Oldrid On 22a203 M' 0A c FIOO M 41" o O&SAS= 099 4N f ~ 11 22ame91i 1.0 T A 'Mno isVO I 4 4 11 04,1,5 1.00 =AI~ A" 1.5 M~ Mi tn 0 in oIo.0 o' rt .. 7
- 0. IS V(
I I
Loss of Davis Besse-Lemoyne 345kv Line All Lines In Pre-Contingency Existing Davis-Besse Plant (942MW) DB GEN G191421 700 _g4 J4!560 1 1 2F -3_0 1.000 -34561 W~' L L~ 704 3462 03 IYH 1 .990 2:2022 I i 22021 0 3RAY 520fH 1.021 03LEMON 22025 22026 Mo M Im M (V M M1 11 r I190MOt12 t t 1.042 W 28761 m 1.q40 X. 1m 41 /V A A L0-OV OS A 0FOSTOR 14 t4 0.9O3TA .9 14 22606 22073 c-', t-rM 03013?3.P 0.996 0.0 -22074 r, AA m W E, 0212(S _0.987 I 28817, 19528PPt 28766 28830 288073. CW Mfl mmnm m. 0.175 C.7 .!7 -0 mY 440 T U 03ALLER m 441 12s 2; 22027 0 1.000 I 0.075 *.! 7S AAMm0 'M A#A AA 11.024 Ohi~o Central Can 1.143 28861 21.84 Coenr 2200311 tfOS0.~ M4 ft094.74 IX'I t~ t oBA LA 0.96 Quaker Tp 22603i 34563 1 34564 0;0 TRlO 02 Aý 1.026 708 TRNt 01 1.026 _ 707 Af 0i0 Vt 102 353.9 2.995 O2dEAVER 21330 0 it : 2CARLZL 41 0.975 22600
- 0. 0 NS C9 O4AVC8 t t t 0Mm 22192 t
0.967 NO 0 co @t t 14 p 0.l it D0 N CY tANl .A io samis In C) 7 N Ili O6* C FOXc 411 11 t tft Ai
- t~.
I tm3.mV c 01-TO tS. a, 41 44 41
- 0. 7"s 0.41I. 7 Chamoberlin
- 3. tA T k a., 1 a.-IS Asi V\\
V 'V _________ in 7 m t 0 0 0.985 AA 02BEAVER 11 4 4~ 101 21590 -7 t AýA 0.987 0.9 11 kjo I 41 0.962 in 04PASTLK 10.2993 2219-100 0.1 s 11I M (v - A A~ 04PZRRY 22191 CC. PERRY 0264 1.052 101 23.14 0 -5 0 ft t s 1ý I~c to to4 m 0 / 1.00z Ltabula 100mm f ~ CASC S10 UU Z~t ,u s@w~45.ds IV 21 I.... CC 0.04. Ooo-%.Lmy.. 345kV 14iZ..
- 1)
U0WS PERRY GRS OUPT 126I 0:7W "t?~ 0 0 Lanna
Loss of Davis Besse-Beaver 345kv Line All Lines In Pre-Contingency Existing Davis-Besse Plant (942Mw) 038AY~~TR 02C _A 1.2.027~yz 4 1.1 2 56 ~2 it 8761 LI-1.A 11h' i19B3ISTNS 28817 19flWPP 28766 19ONS'm Z8330 28807.. 0 v Mal I 22026 0, O 66
- 1. 48 1.044
('J N 0 5FOSMRP III t 1.005 03WM 1.0 = 22606 22073 LD 00 0000'6 0r0 %D -0 6 Lfl fnrm I 0~ 3USM=. 1.006 t t 0.64 2207 )2 3 0 020ALION1 0.993 LA7 21260 J I 2o
- 0Io, T1 t
I4 03ALLEN t 22027 1.7 t41.025 Ohio Central 1.00a 281 21.84 So 6 Coventry 222006 -?oC' IOIVMA y tf tO0E Lna t At t 0.989 0. 7S C. 60 22603 M~ 0c 44 ~1.019 t 19M06134ft t
- 1.
CD mc'6 m Tn CV' 22201 (V 44 4T Robisoni Park t
- 0. so06.! 75 Marysville C', 44 SW Lima
=0 w 719LUU III lit 4 1 1.013 28750 1.018 04f1NL?,I m1 N 22203 N466C -.S0 7S 29MAJ3TC 44 1.017 A ~~28754 01-0 "6m m 010 167 Placid 41 7 1 Quaker Tap 4, Madrid )I Oneida Jet 02MMJVER 0.95~ 02ChARLIL t14 0.953 C0 00C 21600 -m N (
- 6. of 02BFAVERI 414
.R6 C' ~21590(q I 0? o wol .-m 1 T in ?I06tA 04x10 t fii tm
- t 4
- 0.
0.963 4 ~ 0.954AA Al4 C'
- 0.
0 1 31 !60
- 0. 91 0 UW t ft 4I 60A AVON # 9 111
/ 0Is6To600CD 110 L C AA 1 016 to. 0I to LO Lni ?Y 60 -A fn1 229 p C' 0.17 0.6 a' 1 6 .D76 00Han QDm m 44
- 4 CD (
- 0. 7S 6.17 7S O4PERX 10.9 22191 A.
60 2 19 _40 -o.s
- I 0
o 21 1 4b3'o.d0 taw.wk Raoift -I 995 4 ~0.. ~ ~ ~ 1 lS0 ~Coventry 1 Wkridns 1-DERn USc amZ 40997 OunZ) I.~ Y., JIJ l1 ""b I .1 0..So 311kV 4 1290M MAR aft" 0n. 120So0 W I .952
Loss of Davis Besse-Bayshore 345kV Lines &DE Unit Davis Besse-Lemoyne 345kv Line Out Pre-Contingency Existing Davis-Besse Plant (942MW) 25.00 033YS20 704 03SKYSHO0.983 22022 I 1 0o3BAY SM ftt 22025c r, - 29M01012 f1 1 1.041 28761 LO M z .4 226 M r I 19ENSflOS 28817 0 1.022
- .!Is 0 75 AM A AA 28766 901 19BNS:
l98X13W -M I 19mm7N 288075.. c4n mr mmI mmII in II 0.! S 0. S7 0.! 7S A E8 GEN 700I 34560 201 34561 34562 34563 1 34564 TRU( 02 ~ 0.951 708 707 th' 3211.0 1.016 03LEMOYN %0 N I 10 10 014D 10' 1 009 22073 03USTAR=, 0.991 22074 us 9-79 5510I 0 03A~LXXN 22027 ~1 010 'p 0.9 19FER~a2 AA0.993 28861 2 1.0:84o eta Civenry 1 ~ ~ .16
- 0.
os40097 24 2260 muumsr mli 1 0--mm2 m o 28762 4 VM-Robjoon Park 1 M Marysville .r 4 SW Limsa I II 19LJUW 114 w r~ mn 1.010 10 mn mcy us Placid Quaker Tap 0.989 02MEVER 02CAJOL 216 2STAR I21355~'a S claf tonN Samm 04JUI3NZE 22200 r m0 21330
- 0.
.so.*60 Mir-AAAM XL~ t 1 0.948 oi si 00 219EIVER,- 44 IN
- 0.
0 AA 21590m 50 ~02 fm 0 i I I 0 AY 'M 04V2 t t t t A 4A 0.958 a0In 22192 075 140.95D0 t 414 A k AVON #9 11 110 -mo us 4 t t4 0.948 0 0 1010 v-~I liv 2-m G N. IS n Alc A A it (501110 N 0 N 0 22201 7~ Wl r, I eg 0 ~7 S 7s .10 M I~ I i II SITI ii Chamberlin nna M mts N' 71 0 -1,0 ft 0.943 04EhSTL 1097 22197M06156 ots T in-dA/WA t If== "IC J, 0 L0 t t 4 .037 2.81 4 Ash 0 utabula 0.992 Z1..7~I. ~. ~.,.-..- ICoventry o3cnI A"l4O Is 15 '14.414 1991 I 2244MOw JImao GR W"T 1205W 31r. 0ctt" .1 OR 44 1 0.989 06 0 (GALZO( I 14 0 21360 OD! Inu M_ ma CYi( W M
- 2.
2 t1 I 22203 01 Wo 19M10=4 1.011.4, 0 sO4PER.X 28754 Wj 10 -MAAAA 22191 TI T I 101 Madrid Oneida Jot 03DAV-BE t t til t tI 22022
Loss of DE-Lemoyne & DB-Beaver 345kv Lines All Lines In Pre-Contingency Existing Davis~-Besse Plant (942MW) __202 27 2 3 -30 MCYIM CY -- N 11HP 0J -Io t Cb 704 03SLAYSICO TTO41
- 0. 987 22022 vw.20
-8 TIO ~03RAY SH tit 1.022 22025 l98w212 t t 1.042 28761 0 to 1.008
- 1. 46 I
1oo Mr I t ~a -ý A_ OS 0FOSTO;R 41 0,22606 Cy; 00 C)iý.l Oto C L CrtC ri C -1 mm Q 2 Nt r 02GALZOE !198STNS ~21360 28817 N .6 CO U1rý ICC'IC 7Tl 19ENFPP tf1 1.024 S CA 28.6
- 1.
S3 o o Cat a 19FERM02~ 0.99ij!40NP 286 21.84 Coventry 1 22200 -D -CW COA f t05E LDnM I ft f tt 0.984 L,0 CO2 22603 M 0Lr , 7, M1 1.o1 t 4 19=034 f t ft 1.48 VC MO InC 22201 CO CO 0Robison ParkLA r ff444; 0.7010 0 C Marysvill __SW fAt 10128754 ou -I 5 0 %0 A CV; nA 7T-119 .01 OC 4maoo Auke &a0 Ad854r MID
- 2887, 346 0
345643 0 .0 220212
- 1. 032 03DAV-DE0 0.994 02BrAVER 0.955 21330
- 0.
00 0.0 02CARLZL t 4 0.951 w-Ol 21600 2EV i i C.. 21590Cq 00 M -f nCO 01, -m -m LA t 04AuVOK t f W sMV\\ 0.961 fT 22192
- 0. 175 t
0.953AA CO 0
- 0. 04 tOCN fft44 A\\
AVoxI 4q tL.= 04~ 000 1 t~* 03LE0OYt 22026 .994 %DlC to W~ t COF II 42 A h 001 0 C4 t) G39ThP 22073 03NSTAR 0.994 22074 Wn 86 -m 03ALLEN fti gi ft 02STAR= 21355 CO C001 K1.toi 0 Kw? I. ~o Coventry Tukn X INCRM 30C CASS 01*97 S=ZZl) uRADOM Ory io IQ/ 124b 1 0
- 1.
O0 Wn-10.Y & V"o. 245V I.I.o 2240M enas GOSS W . 120M Nw t I 0.950 I II b e 1 i CO -1 m 0.90) sOO LA 3100 o0 n ft 4 -a C \\OL Itn I' f I t 5 AA ~ 22191 1.ý 00 C PEMY an A 1.039 101 22.86 0 t t Ash CO stabula 14011.,~ 14 54S.ft 3.
Loss of DE-Bayshore & DB-Beaver 345kv Lines All Lines In Pre-Contingency Existing Davis-Besse Plant (942MW) 34S67 0017 I 3DA700 0.0 1-00 0 356 7i rO~aAY £30 ___ V1.026 0 0L3IY 22025 22026 In ID 7'DA 0-I 4A4 Ln
- I~
t o 195012 II 1.044 21I 1.0 M 28761 CD io 1.441 c, A / AAA A*A OSPOSTOP. 1.1004 03NTAP 1 .006 I22606 t, in (Y 22073 r4 03 30ST m= 1.004 T ft o 22074 35 M 02GALION t 0.9392 7-21360 0 0.009 6'80SU 74 n 0 IOD 1c 2STAR _ 28817 1-I t0:LN AAAA 13DOPPP f 14 1.025 Ohio Central Ca 287661.4 198ERM=12 0.993 1 wi 04JUooIPE 28861 21.84 Covntr 22200
- 0. 60 0.Coent0 o
4 t t OSE LDO tI 1ffi 0.989 0.0175 2 22603 CD 1-0M 11 M 7 S-Mr Ln ~ ~ ~ ~ H fttt 1 0 28830 028762 1900410ARDX -In~t~Z .22201 In Robison Park tl. 02.175 MaryavilleL,1 M 551WL70a 19WAPla 1.0d 28754 .0' 4NA 288a7(r 2a2203idid Onia TRK 02 04A__ 1.025 ~708 WRN 01 2___ .025 _ 707 77.Jo 00
- 1. 025 1.008 21330
- 0. 00 0.
Is*
- 0.
3402BEXVZR t4 J17 22590e M - alt 5n ain M n S0 22192 oncV 0.75 f ft 414 onAVON#9f 0.086 Ol o 110 N4 f Dl i I t 3t o r,
- r.
N~ (In Fox t 14 4 4 ft VI 1,1"7 1 0 .175 0
- 0. 7S W A Af InaW ft ft t 0__.~
094-; Mo0n to 1.27-
- O M~l
- L~n (N Cy~
(4n I ft M I" 6(1 I 0.17S '~ 0.1.1 IV A AIA A A 22197 Co F-O. so
- s.
0 Cy t t = -0 0 M Chamberlin N - A A of M ko tA W mi N to N 0 t t t t 2' 1 0.995 0.1 7S .4. 1 V\\ 22291 1.100 M PERRY GN 1.040 1010 22.88 Ln 0 t t Aghtabula "Inw" 10" AW 12 1441127 U" 0.9 0.963 Old 0.952 dvb 91 I... Of S-S"Ohose 4 US--a.. 34SkV 24... 0-p.Wk QOOOýi ZIO-1c COOgOOo, Fý V_ I Coventry III kins 04EASTLX 10.990
I I I Loss of Davis Besse Unit All Lines In Pre-Contingency Existing Davis-Besse Plant (942MW) Dfl GEN~ 0 q4560 34563 2.00 343.870 12 .00. O3LmK 01 0..996 704 34S6 3464 70 0o, 0A fn 1 Cy 2.~ C4I 21 t i 4941 t 1.09TL 28761 M 1~s. i +/-.96 aI CD (Vh in ý 4W 1~~ t;OTO 0.989 03WtAP 44~ 266 0, 22073 C-(I CD n Ini r-Icv r-Mv N 14 O3kSTpR-0.993 t~ 0 22074 O2QALION tw 1in9 721360-, 0 19BUSTU -C Iin A 2SA 28817. 1.022 M -f 2 13550 m444 foTTTIt4 03ALLEN t CY Cj. Cy ~ ss 22027
- 0. 997!
0.17S 0.175 A A A4 19qwwP t 4 2.023 .0 26766, ~, Ohio Central 19F~MM2A 0.993 VV 1A' 04J~MUPE 28861 21.84 Coventry 22200 0.3 itn .9 N5LG I (V Iv vtv C-i t 0E = i 1 tt0.9,78 4 75 F,. 2 22603 0 -to in 0 1.01 or t t -19M(0 28830 It T 28762 04HARDIN Cit L,,n 22201 inc 44 4R.obison ParkI .500.17S Marysville ~ .r 701 3 n' in 00 to 19~1r 9LUW I4Mf 19WAYNE T 17 M1 T 1.010 270101 0nU 288 0 7,D M mW o 22203 CY 0 ko 1 N47 Mj-2 Quaker Tap Madrid Oneida Jct 02MAVERT 0.969 213300.' 0.3 00 AA 02CARIOL t 0.960 c0L4C01 21600 T2EV1 4 4 -cv 21590M ow tf t~ t~~l 0.956AA M E
- 0. of Sft 11 6A in 1otn Saj-is 0
00 cv-oIOM CO Fox 0,1 I S A 0c U1 r-co r AI 7il20 0-;
- 4) S 4.i 44 1 Ln 01 M w T 11 21 CD 0 cm N M CV M T
14 14 t t 04PERRY 22191 /IV A h A 1' PERRY GN A A 1.042 T 101 22.91 N to 0 to t t t Ash LDin AVON #9 ft t 110 M to ft C00 mlfit in 71 75 0. ISv A A nA C 0.950 04EASTLX 221,97' in C\\1 2- 0. so 0.99a to 0 Y t r. I Coventry I o kin 199 0, MX NO= UC SE (1007 SXVZSI [REncm 31 j 10 110,0 -
- 1
-a -1T 110S 2 9 - D i 0 45.41. ~.Wk a 0. I r-a Uý1. C., FSLý ftý_
Loss of Fermi Unit All Lines In Pre-Contingency Existing Davis-Besse Plant (942MW) VS GEN '700 -294ý O&3-'14 2 220221 Q3 0 30100 +34563 I34564 TANO02 ____ 1.020 708 TRN 01 1.020 707 t* 12 03BAY SHCf 1.022
- 03.
22025 19MNl12 fIt 1.042 co 0 28761 LA CD .441 2.4 0 L AAA 05FOSOSTOR 4!4 t 22606 ~ D CDf 4 !198DJSTNS47 28817 I 0OL 29EN4PPP 287665 (V V AT 197EMw 288 01t 28830 1a N CD I Lp Mv m3 -1W m 43m M 0.! 75 0.!17S C! 7S Quaker 0.999 102CALICNO t T4 0 21360 LA 0'r I 1.021 J 1 i; t1 j A. A1 1., CY U) r C4 731 I1J -7 44t 0321TAP 22073 03NSTAR 1.002 CD 02 03ALLEN 2 220271. ILA W 1.018 Ohio Central 1 22 90w0993 Vr 61 2i.84 ,Coventry (~41
- CTi, CLla 2
LD 05E L2Oa t 1 fit 0.983 0 2~ 22603 CLN 43 (- 41 1.015 tt t1 4 t &I t Oja133i TV 28=762 l4Lo 1.04 '44Robison Park f
- 0. s0 0. 1 isMarysville C-s KiAiA SK Lima 1
19L 34 0 1.010 28750 1.016 4-9B I,-2 43CD 28754 Mir'- (V1-n? V, apMadrid W one 1.006N 02SEAVEBRVE 21330m M0 02RRI 0.969 1 I 04'. 43I3 430 Cj,\\17 -T3 10, t Sami a C' 4373 73.- Poxo a-U 0I IS 6.1 75 A31 A03A430 Chamberlin 0432U.ND 22203 Ln 43 7 4 4 441 t 1.013 0. 7S .! 73 O4PflP.Y_ 22191 PERRY GN C 0 n3 0.97S ?I AM! 0% U1 I3 t43 04 1'D 3t N' Co I-Y It Anna A MAt 351.8 0.982 ,C4 n 0 In ftp 0.956 73 04PASTLX 091 2 2 2 9 7 T kj
- .!so
- 0. so U-s 0 it 0'
- 101, 23.02 a-t ID
'I 1.002 3 43 4 SUNSUR plw A... 0.n 04,10,7 0*07floý 126-e,MW W=U YIV. 11010. W=7if .e I I 00 4 t .51ýmn N1.1t It, ýt t t .046 hA Ashtabula
I I I I I I Loss of Bayshore-Monroe & Lemoyne-Majestic 345kv Lines All Lines In Pre-Contingency Existing Davis-Besse Plant (942MW) p 34563 34564 700 G 942 ___372 -30 1.OOD 25.00 Eý, TRN limp 71 704 03DAYSHO 41 0.991 22022 1 \\?W 03DAV-BE 1.12S r-i -357 22021 0 ! CVL i -39 0104C T92002 A 1.009 708 TtON 01 1.009 707 T oo 00 ft 1.009 0O3SAY SH tit 1.002 03LEMYoN 22025 I22026j 19M=12 I1.047 28761 oeo 1 is .. 1 DiT ?IV N 0FJ LOWn (V 7 CDl MA OSFOSTOP. 414 t i-0.990 F1 ~~22606.. cio 0It !17 0I-n -a, 02GALZICN f 19WS~wS21360 L n 19BNSTNS 21 n iT~t - L 28817 II 0 1.025 a Mim- 'DT TIT I' 4 0.9is 0.17S -n AF 19ENFPP t.11 1.025 Ohio 28766 .41
- 19FER3412 0.993
( 28861 21.84 I 0. 460 .i 0 V) n I 2 22603 I98NST20I4N 1.018 t4 I 28830 3 ft 1444 Robk
- 0. 50 0.17S Maryxvi.
I SK Lia-
?L0 0 1 11V Th I2 I I I I A-1 CJ. ~vl 1.022 Placid Quaker Tap M 00 03NTA 22073 03NS73U 22074 0.984 03A=L 220: ft
- 0. 992 in 0
27 W 0.996 NMi t, 0 414 02STAR 21355c 349.1 0.994 0 A 02CARLX ft 0.96 0t 0.8 216 300 SDi 71S DD 0n t f 4 0.960 0? iIt ID 0 C COto%0-Central 00S Cant..! fA ' I 4 CD 0.982 0- 75 V 0! s0 0 w 0.7 19XLn C4 4n 28762 1.:0,4HARDIN ft t Ii ison Park AtAc 21.-dn3PSl Ile 4-c 44 F 00 M\\ mOI AAi to 29WUW ti I Chamberlin 28750 1.011 O04InLMI F14 22203 LA 61 -90 0 c-I 44 44 f 1914AJTC I4O 0 1 ~, 4PZRP. 28754 'V o~in ML 22191= (VO -tv 3-A~ ft U Y / PERRY OX 9 101 4,Madrid Oneida et. HA0 tri 61 oD kIo mi t-0.955 lv 2219'7'&-0.0 tv l AA A t t 44* 1.002 CUJ .. 046 13.02 Ashotabula 0...11" K1.oIoEt 1001C, CASZo 111 C01ZY IcRkin JL,* 0 )V 12440 PER -t zwOTOOT. a213 L--fi? 34SXW LLng -M W... ".S MLL" I i. I WS GEN
Loss of Bayshore-Fostoria & Lemoyne-Fostoria 345kv Lines All Lines in Pre-Contingency Existing Davis-Besse Plant (942MW) I C Y: 7 nDý0 TR
- 44
- 41 4,.
704 03BAYSHO0.9 22022 H w LI' 2.02S_ 03BAY SH1.030 22025 1926M02 = 1.045 28762 riLn 1.14k.~ MA 05FOSTOp.__ 44 ~ 22606 CIO 00 C-n fit CY I 2GALICKI 19m~sTLIS21360-K f 2880-b 0.171 D3 Dim 700 _7L! 3Y4560 0 1.000 -346 25.00351 34562 O3DAV-SE 22021 m 0.974 03UTAP 00On 22073 03USTAR 1.005 01 2207J4 NI LII .T; CV m 28817 C. 1.02 -0 -Lnl-h 414 414 1 OtLD I w! n-I~ o207 L 4 ~ .I 7L11 2202 1.00 0.!7S .1.75 ~ ~ ~~ '-I CV..(VM V V m '4 '4Can 19ENFPP I 4 1.026 Ohio Central 28766
- 1. 43 l9F~pM2 A \\0.993 V
V 04JUNIP!E 28861 21.84 1 Coventry I 22200
- 0. $0 0.9601 0A cill
-t 117 lmýv A C, t t OSE Lnm ft f~t 0.9726 5 L 31 22603 I U0 7 LAI 0; M C 0%00 OW 7-n N 7'OL t t 'p. 4 19520nn 4 1.019 f 19=1013 ilf T f
- ..4s 28830 LA n
n 28762 0.4 4UAPMXN t CV (VC:Robison Park
- n.
7s MNarysvilleI ~~~SK L3= 910 22: 1.013 1.- 7 04-LN 44 7IT T H S 0-172M6 C101 28754 (V,% C-ko LA OF Placid V I V Quaker Tap Madrid Oneida Jct
- 1.
021 0.0) 10.i C.47 M0 0 1 Coventry 1111 ii 1000mo~ 000 SC CSK 107 32"21, 0"1ul joy jIM1 ad 1!I~l4 Y"Zuft014lL* &70t1i 340kV U4.. 12004 T uJ0 ISI. 2053WS NET 34563 34564 1.00 TRN 02 1.024 708 ?RN 01 1.024 707 .0 Dto 1.2 353.4 Ln r, LA 21 Oil U.95FAVER 0.984 21330
- 0. do 0.isc A A AOKA LA (Y!
CARLIL 0.97S 0 01 OIN 21600 04 T CY17. 023FAVERI ' 2,03.0 AA 21,590"1 -1 fq (V t t
- r.
LA
- fnIO, 04 0 (4
0 04AVON t t t f 01 %D 22192 M t.
- 0. 7S t 4 0.965 A A r,
L, 20
- 4.!"
0 Ln CY M 0 M Lo M 71 Ln fr, t t 411 a A AVON #9 t t Q.old; 0,0 120 C4 LA M 01ý Lo 1 M t t (V UUMIS co 11 0 A I I t 1 0.965 E, (n CV Laim ID a, to n 3 oo ýIr N (M ir (V M W Ln Ln 0 M Fox
- 411,
ý 1 4 ; t 4 11 1 t t + 0.97S a.. ?S a.,
- 0. 7S +
hA ýA ml I ftit t f 07 in C t Hanna (V Chamberlin (4 n o 0 Cy 00 LOV 0 C aO tf 44 04FIERRY 1.006 V1 VA pmRy GN4 1.051 101. 23.11 U)0 t t Ashtabula ab34$.47-S.tIao. 1 ml 1I Ul 0 A In 210EMU I I ýj M M 0.9461 Id-_
\\N / GE Energy Services Davis-Besse Station Drawing Benchmark with Davis-Besse Plant Output=942MW Post-Contingency Power Flow Results C-3
I I Loss of Davis Besse-Bayshore 345kV Line All Lines In Pre-Contingency n-* =.o; Dav s--m-esse-rL"/antIY t9, 2 ) TM 02 Beaver 708 0.0 -0.0
- wig, 14.06 o
03DAV-SE Sk GR C2 22021 S722 02 0,Lp , 2.-
- -2.41:
728 t I" 09-0.06 710 ~ o0 7211 .1 70.3 0 -1.3. 1 --0.00
- 0. 0o
-0.0.300, 1.019 6 0.05 -0.002 14.0.
- 3.
1 I"_ 044 SLGi F1 0.501 -0. 60 732 SWGOR D1 -0.72 =. 724 -.0.20? 15 72.39 0.400 0.0 8 -0.02 -0.02 1.009 1.044 0.485 4.343 1.044 4.343 MR F6 740 _C. 76 00 -0.85 -0.09 -00 00.00 1.010 0.485 1.000 0.480 SWGR E3 734 0.8 -0. 21-, -0.26 3.06 0.996 0.470 SWGR E2 SWGR F4 739 1;'022 -0.144 -0.02
- 02
-0.01 0.999 0.479 SkGR 73 738 1_-ui -0..44 0-0.s -Z0.23
- 70. 02 0.999 0.480 SV&R F2 0
737 20 -0.22 -0.02 0.998 0.479 700 A Bayshore A Lemoyn' 0 .0 1.000 25.00 A TRN 11lp 704 5
- 7 Vf C4 -
A~ TRN lix 4 70S0 .- 12. 7 V 1.019 14.06 706 1.019 14.06 - 1.03 26.32 V 1.017 (V 14.04 G.n.4 K.etr C a. fl. Ut.-ers I .*b Jz: Lim 2260Wmm ms GWT. 1mu W I I /1trO .d Ate 11 14,17S5 0... Uti.. S K-i T ¸ I
Loss of Davis Besse-Lemoyne 345kV Line All Lines In Pre-Contingency Existing Davis-Besse Plant (942MW) S02 706 Beaver Bayshore 1.030 1 4.283 4 SWGR S6 736 -0.89' 2* -2.00 0.00 -0.06 -. 0. 10 -0.00 1.007 0.483 741 .- 0.002 i-0.00
- 10.
002 -0.0 I1. 044 SWGR F1 A732 0.435 SWGR E4 1. D7 .026 4.16 700 "ino V1 Cd A TR: TMl 11"P 704 52D5 0" .I
- 4. 8.1 >
V 1.019 14.06 TRN iXY 706 N2 4d 1.019 14.06 Lemoyne A K L 1.000 25.01 1.053 Nd 26.32 V 1.017 52 14.04 I I .W 15 of Owi 3&...-L 4*1 5 W Li.. 1 MOM MM 1Wm7. 1205w( (SttU
I I I Loss of Davis Besse-Beaver 345kV Line All Lines In Pre-Contingency Existing Davis-Besse Plant (942MW) TIN 02 Beaver Bayshore Lemoyne .10 -I -0.002 0.0 1..
- 7 Y to
-0.18 o SMRX C2 2202-3 722 CD SStW.R D2 coa -2 74 rN24 725 t t 70 -o [ "0.40 -0. 06 710 1 TW0 - 0,. 19D 0.3.*
- _3*
1.0 1ý -0.
- 4. 2.3.
C4.l2 S.=
- 4.
Z43 721 741 i S.0021. 0.2 10 30.2 \\,V~ 14.06 o.64 "o0.05 0<-.002 1,-0.oo ýZ A4ýe,.o --3.6 z* 1.o,44 Sk Fl 01.502 rn "-'2. 4
- 4'
.w ' "°<h
- 7 --
2 1.029 -0.4 .6k.52 0.494 06 '-',-5. 5 'JO 32 2.----D-- .-. o ýý_2 -5__ 2_.5ý J3/
- 1.
SkrR F.1 4.343 700 25.00
- 3 67 3 1
-3 6 D, L 4). 2.' -0.72/** -'0 "-0. 3 _0. -0o2o 1.0,o 1.0301.044 4.283
- 4. 283 1.009 1.044 4.343 0.485 4.3,3 SWGR E6 SWMR F6 R
IP!i 5 3 TR lim 1.053 ",.9. >'0.89 L0.1 76-'- 74,0.4 704 14 0 -C 6 3 0.981 0.471 TRN lIY 706 (4 1.019 14.06 1.017 N1 14.04 m ""09 umm "mZ won cum (1991 SIRIS 110=~ Sy JM 210 d~b 1 11 L.. Of DOW" SOOOO-I..,. 34SkV Lime 022SOM MMV GRIo 01011. 120000 ?
44 05-lu-u 4.40 -I: Mr 0
- ,MA 4
I (4 ftt P-19 t t I r4 0 C.) V4 Ln M In .4. ~4) m 0 to to 0U 04 in
- n-.
I......... I- .1 .. 1... .;11------------L-- WI WS4 .01 4 W tO ta t ~ t ? tc t t I II S O~ 10 1A LA 0 (41(4~~~ 70( 04 (( Ob 4) 04 0 In In 0 m In 'U 11 .1-I In I t I 213 i1 I I-A t t fý C! g I I Eý-ý I. - c; 14
I I Loss of DB-Lemoyne & DB-Beaver 345kV Lines All Lines In Pre-Contingency Existing Davis-Besse Plant (942MW) K K _-0.06 SICS D2 725 L 1.044 4.343 0.996 0.475 SW=R E2 733 -.0.63,/ 1
- 0. 37
- 0. 04 1.017 0.471 14.03 TUI 02 708 S1.032 14.25 S.
0: SWGR B 710 L-Beaver Bayshore A A 3DAV-3E 2202 TMO 01 I707 2. 14
- 0.
MUt Lemoyno A 1.032 356.1 4.2S ~A! V'OW D3 1.000 700 'zl* 25.00 0002 LOICV TROO limp ______ 704 > L I I 1.019 14.06 V TRIM llY 706 1.019 14.06 1.053 N 26.32 [0 IV 1.017 '4 14.04 1,00 MMM MX MM CMZ (0197 SUJUh 4RU gy jA 16, d I3 I 1 &0'00 Of m-Lq & M-bý S 341w "00. J1340"W maty w09yM. 12MM UT I I innfuaa M.d As. 11 *4m1*rlt e.g.. '-I-," n i
4, hi' .1 .1 I .A.. 1 .#, 1 1 L3 ;C) I I I I
- 4) 0 144 0
'U (A 0 '4
- 0)
.H 0 I a I 3 I I I I i I I I i i -i 1 2
I I Loss of Davis Besse Unit All Lines In Pre-Contingency Exist-------i------------t..-..) n 706 BBeaver Bayshore Lemoyn, f3.3j SW=G C2 --021--0.9 "722
- 343.8
-2.74 MM D2:
- 2.
70'9 "-09 25-0.10 -0.03*170 -13.2 0
- 05 7
10 Cz -24, 7 070 2.00 7- -0.19 I -0.00 0.98, 0.473 7135 _.0. 36 -.039 -. 0.191 2-502 -'0.02 -.. 01
- 0. 979
,.470 sWK E3 734 -'0. S2r --0.5 -0.21 Q) -. 0.26 -. ' 0.0O0 -0.02 0.97S 0.462 733
- 9.
-. 0. 63/-, -.0.71 -0.3 17ý 0.959 0.996 0.461 13.75 741 Sz <*'-0.002 <-0.002 1_0. 00 <o rI. 1 1.021 00G F1 0.490 -0.60 732 flG2 D1 -015 =.72 724 '-0.07 _-0.2 -0.02, .00, o-0.53 0.463 0.67 D.0.32 -0.0.' 1( 02 1..21 S0%R El 4.248 731 -'0. 72/ SWGR D3 -0.2 1 723 -0.20 _ '-0.02 "-.0.08 -0.02 o.986 1.021 0.474 4.248 1.021 4.248 40WGR F6 0740 t -0.7?6 _. 0. 00 -os '-0.09 -0.00 '-0. 00 08 0.'474 SWGR F4 7 2 39 "--01'. H-0.44 -0.02 -0. 23 0.976 0.448 5040 F3 -0 0 738 -0.0'4 .23+ 0.977 0.469 SWG'R F 06 7 37
- -0. 02 1 '0.0 0.51 0.97s 0.468 S6
-2, 1 13.75 .o -3.6 -. 2.6ý 2 S3) S am 1.000 700 25.00 -.3. 6 TRK7 -0 -0 T PM 22 1.000 704 25.00 205 0.0 4 0.99 13.75 0.996 13.75 TRN 12Y 706 00 00 0.996 13.75 19'9 SCU0M V= AX 12117 SUIZ=) I(.WU= My ZLm 1l "1 2 4 0 5 1 Zi ~ y o f 7'J U. 1 00 5 1 U 1.56 1-0.65 1.006 4.195 721 "-0. 05 L0.8 .0.3 1.009 4.195 ~3 6 2254 -3. 6 K K
Loss of Fermi Unit All Lines In Pre-Contingency Existing Davis-Besse Plant (942MW) 1.030 4.293 SOOR 0.405 TM~ 02 708 1.044 4.343 736 -- 0.8,0
- 1.007 0.403 S1GR E4
- 1.
14 Dleaver Rayshore Lemoyne IA L 0 iit t, j ?1 020 .07 700 4i4C IS' N -1.000 2S.00 MAA TOSS lI2" 1.05 70 i ti.- 263 1.019 14.06 TON 11Y 706 1.019 14.04
- 1. 01
'4 14.04 '1 .020 51.8 K H-G-4... U01..t C~..pY 161* ý .,~a d AWq It 1.10,46 1941 120 IUAY GROIS *YVg. =MUW WY M.U0* 3
II I I i I I j Loss of Bayshore-Monroe & Lemoyne-Majestic 345kV Lines All Lines In Pre-Contingency Existing Davis-Bess DT-* 1oAn. -~~~IA .1L J 030 02 708 S.......... 0.0. C
- 0. 0 1.009 13.92 r..................................------.
SWGR C2 S 722 p 2.? ) 2., 1 2.025 721 i 0.05 SWGR 0.485
==~ B 710 L.. 03DAV-aE 22021 TW 01 ?707 1.009 13.92 Beaver Bayshore Lemoyne tt t ft 1.oo0 !2!zý340.1 A 1.000 25.00 1.019 14.06 TRN flY, 706 1.019 14.06 1.053 26.32 C tL V 1.017 N 14.04 K V H "5:0.06
I *. ............ I.......... I - I- ______________ I. 'Is I I i) 0 Cs,) 0 0 .,I 0 0 P1i 0 toi m .r4 N 0 'a 0 0 Nl U -r-t o 4I 0 C.) I a I I1 ES! 'i S...... i i .t I -I................. L.... 1
WW GE Energy Services 345kV Network Drawing Uprate with Davis-Besse Plant Output=1033MW Post-Contingency Power Flow Results C-4
Loss of Davis Besse-Bayshore 345kV Line All Lines In Pr~e-Contingency tjprated Davis-Besse Plant (1033Mw) O 3SAYSHO 22022 I ii 03BAY SH tit 22025 to 00 287651 0-.48 1.468 02n A K 2880~ DB G7N 700 12033 0 330O 1.000 o 3456170 25.00 TRK11 lim------------R 0 1.02 704 I0 34562 34564 707
- 1. @
0.995 00 I 03DAV.-BE 1.022 22021352.6 0w 7 OS .0S26 03EMY 1.004 03 P hP 'I' 22606 ol1 o 22073 F__ 22074 LO60 102G=L N tf1 0.994 -1 19DZ')S2~4S 22360~~7 28817 mm ki2 10SA 00m TIT4 ftt T 03ALLEN' t 4 155G ~1.,11 1.u22027 N .0 0.M1 0.1 7S h70AA 19SEFPP f 4+/- 1.025SCa 28-766 .Ohio Central 19P23=Z2 1.4 0.993 W'032)P 28861 21.84 @coety22200 t t05Z LDM i0. 0.40900017 22603 = 0 0 ft ft 0.98 193f~flm 441.019 t 19 t fIt ft 1 0D0 w7 28762 ~ 04HARD~I M: *.CY M 22201 ft 144 4 9 Robison Park mt,
- 0.
O 0! S 00 nI Nf~ 0.0
- .70Marysville SW Lime 1.1319U t1 INS v
1.01328750 107 04nU.La24 NO 0 V C o 3 22203 Mo -L"n ____LA_ 4 4 4 4 44 -10 M
- 7. S 0.! 75 0.!7 192AJTC I
+ 1.016 AA4AAA28*754 Placid T 7 Quaker Tap Mari Oniajot Coventry ?oeVldns 21590~ 0~0 0 1 m (V0 T t 0 O4AVON ft tft Aý/ 098 ).966 AVON #9 110
- 0. 7S AA 00L
-o6o ft t CYn I 0.966 ft t i WYM006 1 a. 86. Mm TlI, Al atn 0 Saowois M 37 0 ,06 @6 Or m Fox I 14141 0*1 722197 1 (V Chamberlin 14 4 4 t t. i. 22191 T.0 PSERY (a;A 1.051 101 0 23.13 LA0 t t Ash T1 A A t ft t 4 G = 0 0 4 1.007 Ltabula1 12 00.00.70 I 24S.ba 8.o..aq I l@'Ogmem iL0Z 01017 ZUlU) 08 U 31M 10/ man myw,. i@uw m O.ý is 0.! ?S W IVA I Coventry Ill I a-i za-L. cý VSLT
Loss of Davis Besse-Lemoyne 345kv Line All Lines In Pre-Contingency Uprated Davis-Besse Plant (1033MW) 700 -10233 1 2 rn Nin TW '-30p 1.000 0 25.00 L4 414 4 11 1 704 03BAYSHO 0.991 22022 V II 030
- n.
-680 4 4 rO03HJY SH 1.023 03LENOYN 22025 22026 19M1a002 t t 1.042 o c 28761 LI) im64 1.44s 0 03 EC-MA A OS0FOSTOR 0 4f1 0996 22606~ 0, 28817 U)- 288073. 03 A3 19ENFPP Ilj 28766 195 irm4JL Itn I K O 0310 0.- 75 A 44A 34561 34S62 kAV-BE 22021 (4 Ia 1 1 039W_ '22073 34564 040: TRU 02 4A__ 1.028 708 72M 01 1.028 "0 T 1 102 354.8 0.996 023RAVrR 0 02CARLIL 44 21600 0.A 0.976 -d C4 02MVEA1 2159 en fi4 44 3NSTAR= 0.996 j 22074 co "C 2I ('ck LA( 0 IJ CD 02GALION ft ft 0.8 0A 21360 N~ 0E88022192 0 1LA 7 0 05 02STAR f4 0.968 r-inI 1.023 TOM CD 21355~ 010 (VI n 0 414 t I 03A.LLEN ti 0'0 .3 4 o i o 22027 _ t, 1.000 (Al-to. t .t IT -IAVO 1.024 Ohio Central S Cato FERM12 A 0.993 e 0430001PE .1tf 1 28861 21.84 .0 o Coventry 22200 0! r-m o ~i C 4 cIl 055 3'"e 3 Cit -'1J0 ('410 inx 4 4 44 't I j t tOS L M1 t I ti 0.950" 75 0. 75 1.0N f t-ff t 0 .4 '10 ('JD 2.0omwz8 ft fI ftMM3 T____._o___L C Al40 mel cow C' 722201 N' M Mi 0' L ofl0,om ('41Pak0A 0 M 2~'4-- D4 -CD 00 3 6.15v+/-1 4417 4 4 I 4 ft SW Lima + 4hSL MC IN A AA 22297 INW 4ffChafterlin 1.1128750 1.013 04INLA2M tn 22203 r in0 rV I D 0, C4 9MIT 14 44 Ill 2744D4n i 1.013 0.7 .o 04PERRY 28754, 0 M Nu r, rVA 22191 e Placid T1 1t 44 1t PERRY ON 1.053 '13 010 23.16 Tap adrid Oneida Jet 1.0 G t
- 0. Is* 0.260 AA 4 0.989 49
.10 ft 1 -0.967 t t.~ 0.963 110 #.Ila 0 6004 ft t44 (D 1.009. ro 0 1tabula la", m-r Ifl SNC CAST 1197 SO=)I (ftD=W By amJ lot Itb, 21 Iý or 2-1 3'4A.oW. 340ky L_ 12601W rwi CROS wnVH. 1030N46 3M (a Coveootxy Toaldns ft05Sae 1 03,019 I Coventry III I 9 Qua) 1 U-S. Cý ý fta--
Loss of Davis Besse-Beaver 345kV Line All Lines In Pre-Contingency Uprated Davis-Besse Plant (1033Mw) -103335.2 1~~0 -25 0.460 456 287 1 ~ xq~345612 60 70 7I I
- 0. S o a E ~ ~ s s 2 50
.0 0 00- ,W OD: OTO TR 04 1.030603~h 15 2260 TRNr 12 03DYS O 1 099 1ft 252011t .3 in.02 03LUI 2207.01208 2 2 0 2 2 22. 0C2 6R A V R0 . 5 M fo-zn ft ft It0 (A 019 U S 2 2 l q 4
- Iryaville I0i 02W VE 4 22201 03n I!
215090(V V 22606 01 2073 on 7Pa9k ft I. 28t 22 9 03N00A 1.00 Pl i 101 220794 4ncvL L11(0 2it Q9uaker na radri M O eD a 02TeR0.54L '0 0..g 2881 307 1 rq Mo e ty TI-n J~ 10 3 0 v 025 O 21355 C'~ 4 ~ I 34 0
- j5d, 010 moD TT O
TIT0S t?
- 3.
03 LL N t 0 n
III I I Loss of Davis Besse-Bayshore 345kV Lines & DE Unit Davis Besse-Lemoyne 345kV Line Out Pre-Contingency Uprated Davis-Besse Plant (1033MW) 03BAYSN
- 0. 98 m CJ7 7
22022 f09 O 3BAY SH 1.01 22025 cm 19xcu12 t 1.041
- 28761 D~ 01.4 AAA M's 05FOSTC 4 4 2265 CO150 CD'D r-I tm 19BNS28S 4
19ENFPP~ 28766 19DNSn108 C-C 190 mr- ' ~ mi Mtn0-I~, 4 1 11 nmi 0.K
- 50.
S0 VSGI 700 01 F'341.0 1.000 -34561 MA 25.00 04o 34562 3 22021 03LEKMY '5 4I t 0.9839 mit-mmL 00 GALION t 1 0 21360 fn 0 1 h A A .5 toC Is ~ Ald mCYS m 44t t A AC 22073 038ST0 0.991 22074 03AsLLI t 22027 ft t ntIS Ca t4104Ohio Central
- 1. 43 19FERM12A 0.993 V'
4.+ 04JU8IVCPE 28861 21.84 Coety22200 ff05E LIMA I 1 0.977 Vi 141.017 t t t4 1 N41 tiI ft
- 2. 4 C4 a
28762 0.~ 410=3N mmm--m i22201 (IS? -~ mr R)iscn ParksUC
- s.
55.1$ Marysville (C 4 070 LO~ mm19LULU T4IT 44 1.010 28750 1.010 0fSM I 22203C CD iy I19NAJT 1 4r 4 1.011 Placid41 4 4 Quaker Top Madrid Oneida Jct V i Coetykn 6034563 345O64 0:0 TRX 02 AAA 0.951 708 TRN 01 ____0.951 707 .o 328.0 0.989 02BEAVER sO 21330 t-s O2CARLIL t 4 0.948 21600 CD Ln C- 04AVM t t LA 22192 02STARt 0.9 21355.- u C
- ID0 WSC
[I~ e, 8 W LD I A tl t t I ton!'IA 41 Samis 10 C%1 I' Fox + 107 T ag a.J ?s h~ Ml 4 4 4 A IA{ 11 mLn t- - C4Mw wO Mm M OI7 0 c-00 V10 07 T -ICV -C (Vm L 4 t M 44 4 4 t I 6, 7$ 0~.! s Chamberlin T D 30 a m 44 44 1 1t 4.,7 o. 7s 04PERRY /'VýA/' A 22191 1.4 s5 101" k475 t 0 0 NJ in ( O2DEILVE 0 4 4 4 0. mi mict )m 50 4745 s, 0 A t t 4 0.95
- 0.
0.948 = 01 A O4EAS0.948 2970 .0 S.SC M 6m C r,- 4~- m 0.992 C 0 1.037 -C 22.81 44 Ashtabula -11M -S -a Mac .At 57 -XS I~N 51 1-b/s 1s 71 Gsa 02 Davis Bass.-lsaysh. J4SkV 14ma,s. A DO Mat epsa 1254665 .@y 11 24,17,2 32545 9 I i w I,
Loss of DB-Lemoyrie & DB-Beaver 345kV Lines All Lines In Pre-Contingency Uprated Davis-Besse Plant (1033Mw) G3EA1033 700 -6 O3AYS (, f P.02 2S00L6O CV~6. t 1 1.02m, tp I ,n Ln01, 0 2876SD 1 T
- 0.
a-t' -m 425 0.994 V-SEiA 44r- -922 06 -rm 22021 03 SAY SH 1.02 03 E D 03I T A 29W1 1.042L 0.24227 286 414nh AMNS~f 4 SOSO 2 136 tI 0 .9 03TL 22606 .111.1 220273099 mmc 0! to 0-r . M~ 0.175AR 0.99 28 02~ c S0.987 l 9 PEIW21360 0.99 00.aSS 28861 21.84 0o~ y22200 1.T
- 0. 0 00K'T 19 E M 2 2260.9 3
04JUNIa-PE wm In 4 19 V T N1.017 l9 6 i 4ft t LA LA M N Lft-CY Z22201 Robison Park c A. Moa 7 arysville CO aIn l -00gC 10t 0 N 1.012 04flNLA3M 0 Ln N N21 2203A m Ln i Ln -18aci2 36R'1 2*id T -1 '.l~~19A 1).013+/- a.~Cvetyf ~ i AA AAb h~- A~ 2875 1,01 0 i.'I? / -LoNww 4 =-§"-t~ 1450v i40. =40111 PEWy mO" GT00. MI0ND00 on 60J 34563 44 TRN 02 1.034 f 708 TRN 01 1.034 707 T 1 034 00 I 356.7 7.994 022FAVER 21330 tnmr 1CASLZL t 4 0.951 21600 0 0 c-L n 071 04AVCH t U1 r 22192 M f 4 0.953 TIT' 0.0 a-V .0 Sarruis II Ln f
- Fox, 4 4 to a-MU a OM 0 0.1 75 6.! ?$
7S A A Chamberlin 4 41
- t.
7S 7S, 04PERRY 0
- 0.
00 1.0 m-Mo 023EAYE11 4 21590N~ f in it AA 0.961 5715 A~ AVON #9 1 110 0-w nn 0.951 rV c-i D AW i~~~ I-4' i I 0.946i CD M c LA Om ft 04EASTLK 0979 22 .9 0 so a-rn At 7 A m I ft 44 0.995 +' 22191
- 1. 06 V7 FERRY 0w2A5 1.039 010 22.87 4
0A 0 tt Ash 1 05 4 -I tabula W/ 3AR Tw
- 2. 0 2 4 I
I
I I 1 1 Loss of DB-Bayshore & DE-Beaver'345kV Lines All Lines In Pre-Contingency Uprated Davis-Besse Plant (1033MW 3GDa 700 1456 -Si 3 -30 1-0 0 i 0; 34561 S704 34562 03SAYSH0 0.995 101 2202222021 0o3DAY SH tV.2 3SOII __________1.026__ 03JM 2025 i22026 1 1.044 44 61 1140
- 1. 48 R31 A a,/h LO AMMA __
FOSTOR V1 1.005 03NTAP 226D6 7-1(\\l in 22073 10I r, 0' t4 T 01111 Ito r44 03iISTAR 9.4 22074 (I 2 e(30 to 2A14C 0.993 3-21360 D ( 28817 N: in 1. 0 j M Mm 010 w 13 44 111 t 03A.LL T.7
- 0. 70%
.11Ii 2
- 11 1
OAAf 19SENFP f 1.025 Ohio Central 28*766 10 19FSERK2 0.993 VV V 28861 21.84 .0000 fft 05E L=U ft t fit 0.9900c. 2% 22603 0 000 0 ion on.. inqc 198MZS¶U 1 1.019 f 28762xn4 28830 0 C 186 int Robison Park
- 0. so 4.7 Karysville 1 tv A SW Lima 1.03.3 Placid 19U=
28750 0-11 19)Q.JTC 28754
- I.
- 289070 T
M 0'-0ffn MIninoWi 1 n 0.7 75444 o% A AA oin
- 1.
00 07 0 1."00 .05 iN +/-34563 0 34564 1.009 025EAVSE 21330 02CARLIL 21600 M .STZR ti L135S1 0 cI ft ft ~I os 04302019 Coventry 22200 4 7 70 o AA ~22203 4 1 I I"s V .0V Mdi d OIie c Fox to CDI-w13 t tO~ 00-TRiO 02 M~A 1.028 708 TRN 01 1.028 707 fItot 1 t4 0.953 ~ 0 O'IC1 0.046 028EA.VER1 4 1 4# 141 c-t O4AVCH t t 1 A 0.963 22192
- 0. is 0.954AA 0.0 4
16inN a., a A A n Mn A ' AVONI f91t 8ýV 000 0 O C N N110 Ln 00i 010 t t in 00 4 Vt t14 0.952 Win0 LO - ~DI0 ri-010o m (V S MMi003 2.10 0 M0 II N N In 1 Chamberlin ON 00IN 3-3.0' 0 CI I Inn
- 3.
0.ý 7S 0.1 70 04P]MY /VA 22191 PERRY ON 101 Em! -I in 0'11 a% Int in 0.948 042ASTLX 22197 3. I I AA1.040 0 22.89 4 LA30 to -ALA =0.996 tabula 2 2870 Quaker T.ap G-OIOI ZIL ce towf Coventry1 ~ is OIWa M. Swe 22 10.36,"7 1099 Ov 19 1* LOf 301-0Y Ans~.. 01-SOO.. 34SkV Lb.. &.W 1~) 26001W PEM GROW OWFU. 1200)00 0W? Ma..t
w to 0 0 00 0 0 a -Lii-- a 40 -4 (-4 40 40 .n in 40
- 0
4 .4 Do, 00 !G-, 0 C C (0 104 GI
- Cl 0
E$o I hIE Sol-IS- -?A-t 01. UG IIIS >.9 LJ 59-9 >1 NN SL-0 0 61 Sh 1-.. E ~ 1 -Ii 91-. (.4' 0.*C C N N N 01 LI: ý I 4,I-Me I 5r 559-Lh OEIV (4 N 0 '41 a 59-- EE o 8 §15-
- 954, N
S-- I. Ih-. S. es-.. 06-LEI-1S~ g
- a.
E EE 4 4 a 194 e-I- j I I-96-C%1I t~it ZSE l89E ZO 9-ecs-e -- 4 I-i El--- 6E ii-. a CE-. IE-40 U N -4 -'4 U U a. ZbS I IE-tel-l ohE h91-. h-904 4 ~ L I.-- 10 C()
- 0.
44J 4Jb~ ?A4 14
- 1.
000A I i ill 0 I St-0 I 5L U N e >-4 E
- aos, H.
11.1 -el:., ý_ a t e. hs-
Loss of FriUnit All Lines In Pre-Contingency tUprated Davis-Besse Plant (1033MW) 03 GEN 700 G 1033 15 1 330 1.000 3434561 25.00 _x 345:62 03RAYSHO 0.995 2 2 02 2 j V WO3SSE 0313AY SN i 1.024 03LSKOYN 22025 I22026 01 w 1.00a 1.10o j19iM012 11.042 E, m 28761 Mn CD~o 1.#4 AA AA A O 5FOSTOR.4 1.001 O3UTAP 1-005 7= 22606 1,0 M 22073 ft ft 22074_ e ~ 0G.Lo41 0.98 D0 2981(-.IS 4, N,_ CD Wk t LA 02STAR 28817 N T 1.021 Wio:3. 1- 04 t 4 03ALLEN C'4,- CU ko 4 1.11 .012 j22027 6.07S 0.! 71 hAIAA~ 287661.019 Oh~io central 19FEO~a2 0.9.93 IV 28819O 21.84 0.171 2 22603 00o 106ft t~ 1936g04 ftt 28830 01 LA~1 28762 Ln Robison Park o~soo4~ Marysville /v A SW T.ma 4 1.010 CY3. t~ Placid 19WWL 28750 -0S 28754 I-19Wk 'ii 28807w l0t-i m 110L M m-N 0.! 7
- 0.
5 Quaker Tap' 1.006 (At-, m 0 oventry 4 0 N M 1.016 60 4 t ft t 4 11 Mad0d1a 21355 S Ca 04 34563 34564 TRN 02 /Y A_ 1.022 708 180101 1.022 707 To if 352.8 1.007 21330 -o O2CASLZ t 14 0.971 0om01 21600 N '133. 0.0$023FAVER
- 4 1l 1007 21 1
9 OMF CD 04AVM4 t11 t Mt A 0.984 3D 1( 22192 0.1~S M 0.962 A 0 w M
- 0. IS
('N C 30 LA0 !0 oo..S4 0 LA
- 1 tt44 A A AWN #9 if t.0-78
-m -D0' 110 neon ff to so 3U1(IPE Omis
- 10l, U
TIT V PV IS $00.61 7S
- 3.
CDID 003 0n.0 = 1030.7
- 0. 70 Hanna 100 0V'Aa 04EU M tt t 1
.S 22201 T Ln to M -toM 10%0 p Of~ 0 f y int, t M idsa Oct 0.~~0Ii" C.%y A"* 20.o 2O0.ly Is 1999 L-b of3 P.M. Gait 136010 SIM GNUS CfUMY. 120S10 MET Iiq 0.961 ý ko t t Ash tabula
I I I I-7 Loss of Bayshore-Monroe & Lemoyne-Majestic 345kV Lines All Lines in Pre-Contingency Uprated Davis-Besse Plant (1033Mw) ME GEN 700 2-1033 3500 a ~25.00 0 TI 2W TN 01 1.01 I T T 0 (, "I O3SAYSBO0.985 22022 10 2:2503D?.V-BEt -03BAY 831 1 ~ 1.007 03L8300M 222025 19=1312 2.067 28761 0-
- 1. 43 1.4g1 L
/ (VCOV AA\\ OSPOSTR t 0.993 034rTAP 7 22606 0' In 22073 r-
- 04II, 3NSTAR 0.995 1 2 112NI N Ol07 0
0 1 'OMAR 28817 N 0 105 J ncjmo In 0A;f~ f 21355~ 1.11.II22027 -_ 00)
- 0. 998 al
- 4.
5 75 AtAA T~ f 711 MAAA
- 19EN4FPP t 41.025 Oi eta a
I-28766
- 2. 43 Ci eta 8
197SRM3~ 0.93 0JN I ~~~28861 218 II0i91? .#oCoventry220 Il n IV nVq t t f05E LM i 0.984 0.7S 2 22603 CD1 (p 7 i 1.018 28B830
- t.
i in 12.3 .49 .L 09IO l7 M AL I 22201
- , 4N 44 Robison Park
- I*tt
- 0. SO 0. 7S Marysyille r
r, In SW I _0nt 740 %Dl 1-01 91UL 44 4 .1 85 102t~UN 288070 En 0P0 l~ 10 12 ." 04fqL2 In1(IInLI122203 2,0%f (Y E, toNjn ,LA-14 Quaker~~ ~~ La ard Onia. I .. ~1 K.~ol. Cy OL? lo..Coventry ?kics "2004 'v =110 1U (217 ZUIRIRU M 1oCID,, nn () d~ftb "I2 2.00 19 3.y0*.---40. &1.b a US,0 Lia._ 12600) M"0 =ass CT00T. 1205W6 WT0 349.9 011 023FAVER 40.979 21.330 I~ 21600 213 T-r
- 0.
0002BEAVER 4 4 4 41 05 2021590(v -7l 'Al 4 01 04AVOK ft fJ AA 0.982 3, 22192 M to
- 0. 75 0.9963 0.0 W95 V
2219
- 7.
- 0.
0n m .0~ PUY M; 104 A A koi toIA M I
Loss of Bayshore-Fostoria & Lemoyne-Fostoria 345kv Lines All Lines In Pre-Contingency Uprated Davis-Besse Plant (1033MW) )3BA1033O30.90 7151 O3FYSM1. 3 0 10 00 34561 m(0i 19I801 25.000 00Y~ M L MM -m 00-0 34562\\OPOTR .7 ONA
- 202 so P.227 2202
-17 1020M72 ff .96 -4 mco 0 02S TB1 In r,,105 0 P t 0 0C 044A jH tit 1.031~ 03LESY 22025 2202600 ID 1; c.o 1.01 00 M OL tor0 n 1M 12 EOP 1 4 1.0264i5cnrl .0 28766
- m. p
.4 .A 28861 TO 21.84 03n cov .t 2200 0;. 00 0.¶C6N 0
- 0rr, i-Nutr
( it ,T 3SA .0 tt 2 2203 00010 ..n 2001 0 Mor 02GrnO to-0.976 ~ 28830TU o a' 00276 02STAR0 -C N ko 22027o Park.08LA I; I. 1A17 VIlo 00 A A SLA 2' 29WAON0 4 .33270 .1 4lLII 288O7-M At Am A'220 = 0.993 IV 104J1W F Placid 8 ovnty220 Qu 0e 4a 4 ard Oed o 34563 34564 010 790 02 A$A
- 1. 027 708 TIM 01 1.027.
707 x.eoo MAI 010 t~t 1.027 354.2 2.0127 02B.SM 4 4 0.986 21330 030*, CY-WA 21600 ('7 0 1 3
- 0.
06 02REAVER 1 4 44 1.03 2 1 5 9ocm 0~- 07 V 0 0-m M-O4VW t At I I 0.8 0O0 221920.8 rn 1 3 0.967AA W0 0.0 LCV1 NP( 00 c~o CO ko M - 7 A 1 M1 I ff;' A AVON #9 I t 102 0.116 0 00110 tonfi I _____ i4 0.966 o0 rT Nn 0 r= LD1 0D0%00 r-r w00 m-0 03( Fox I W 1 4'tJ4 t 0.17
- 0.
?SOi P0
- m 'D tNtWt-ilý fni A1 00 0
rnIo 0001 (D r, c T N 't I14 44 I t .110. 72 0.i 7S Chamberli.n ('100 00 00W P 4f 011 Manna N (V O4EhSTLK 221972 7Y 0t CD-00 7, In 7,ip0 0.962 A A 1.007 00 Ltabul3. O.. 00~i .p~ 1J ~Ij Coventry 1 7 kizos Im T1 k)U2,1,919 do260090 FOXY O 40WM So Ub.-V.SWi 0W? 4440 PAU"v 04I
"1W GE Energy Services Davis-Besse Station Drawing Uprate with Davis-Besse Plant Output=1033MW Post-Contingency Power Flow Results C-5
7P T02 Beaver Bayshore Lemoyne 708 .. - o
- 0.
0.02 7.222 35 -2 7 42 -1 725 I I 22 t '*it SWRAI -7 74Tl 27 W L79 a 7
- -0 0IF S*RC S=F
- 3. 8 D0.0 <_
721 4 1.86 * "z.0z --o. *7,,0 -054.37 .-0.002 i-O. 00 1 .022 63 0.002
- -.0. 00 oz.
14.2. S.... ~~-o os .C 0 1.0,, SWGR F1 0.501 0
- 0.
732 SWG1 D2 -0
- o.
IS !0 724 -0.0201.02901-0.09 0.494 -06 "5*. 02 1.044 SWSR El 4.343 731 ,08 _ 0.*0 722"M1 D
- 0. a
-0.0200.0 2 -0... 1 02 1.. 03 0 1 0..0 174.03 1.0097 3.485 4.343 SWGR E6 S736 -1.00 -*0. OD -0.00 -0. 06 _.0. -'0, 00 1.007 0.483 SWGR £4 735 -.0.36 -0,0.39 -019 -0.21 -7 -0.02 1.000 0.480 SWMR E3 734 _=-0.52d" -0.58 -- 0.2! 2 -0.26 IS
- 0.
0.R -0.02 0.996 0.470 1.044 4.343 0902 FE 740
- ,O~707*
1.010 SWV2 F4 0.42 739 1 o.2 L-.2 '-0.23 -0.02 -027 0.999 0.479 SkWG F3 - 0.40 738 0.44 '-0.04 -0.23 < -0. 02 01999 SWOR E2 733SR F2 73! -373 -. 0.63 -0.46 90 4
- 0.
2 -0, 371, 737 -0. 1 -0.05 -0. 22 Z 1.017 0.981 '*-0. a02 14.03 0.471 14.030.479 1.019 14.06 TRN2 0CVl 1G0 1.000 700 W 2.500 TRN lIMP 1.0S3 704 WIn r-Ify 26.32 Lix T! -12.7 14.06 V TRN IIY 706 V 1.017 C' 14.04 92 Loss of Davis Besse-Bayshore 345kV Line All Lines In Pre-Contingency &5.6 -_5._5 I -5.8(-) -2. GJ2 -3. 6 /-,A -2. 4 U4
Loss of Davis Besse-Lemoyne 345kV Line All Lines In Pre-Contingency Uprated Davis-Besse Plant (1033MW) ?M8 02 708 -0.0 S-0, 0 1.028 14.19 03DAv-SE S0G C2 22021 I 722 gR D2 -2.71 -2.9 725 S5rR A -.1.9 1 7S~ 709 -0.06 710 S-0.90 7L 0 Ti O -. 0.1 '* -0. 03 1 0707 R C. S = -37 IS- - -0 .0 -.2.' - z*sRcz* -3.87
- ,"+
-1.86 SMGR 26 736 -.0. a9 -1..0O0 -.0.00 0.06 -0.10 1.007 0.483 SICK E4 735 -.0.21 ! -0. 0O. 01 1.000 0.480 51CR S3 734 "0.58 -.0.21 -0.26 -0.06 0.996 0.478 SICK E2 733 -0. 63n 0.1 -0. 37 1 U o.04 0.981 1.017 0.471 14.03 -0.002 <=.002 -0!.002o D> 1 1J 1.044, SWGR F1 0.501 732 SWGR D1 -0.72
- 4.
-0.201 7232 S'T*---. 0210..29 02 0.08 94 1 -0.0 -0.. 02 -0002 1.044 SWG. El 4.343 731 SWGR D3 S-0. 20 -0. 02 S"*0.08
- -0.02 1.009 1.044 0.4.85 4.34.3 1.044 4.343 SVXR F6 740
-0.76 _oOsý -0.09 1-0. 00 < Q-0. 00 t*1.010 0.485 SWIR F4 _ 42 I739 1-0.22 -0.44 -0.02 -0. 23 Z 0.01 0.99 0.479 SW=' F3 G738 -0Ou. 4, -0 - N 0.04 -0. 23 1 0.02 0.999 0.480 4 737
- 0.
6 -0. 1 -0.05 -0.22 Z
- I_0.02 0.598 0.479 1.028 14.19 Beaver Bayshore Lemoyne A
1 D4 1.02r tI0' 354.8 NNf AM -.5.7/ -. 2.5 GSI 2_ 700 Srt
- Oic, oI0; tlIN 1.000 25.00 A
704 WILA c.-. V 7051 -24.819 -12.7 S1.019 14.00 TRN 11Y 704 I T 10fl 7 N 1.019 14.06 1.053 N 26.32 V 1.017 14.04 "-1.56 1.030 4.283 -. 0. 05 --0. 8 -- 0.3 1.030 4.283 --5.;* I I Oý..rl 1.O1.iO. Ill.? Fru p vi WMOM Wad AW 1 14,12:32 It"o Mx MPUJI aJ. 11997 svn my xT lot 101.d 0db 1 31 0 Davi aM 15 Use I... 1M MWU ow vM? 120,W MT
- o' J*
3 6 I I
I I I 708 0.0 1.030 14.21 SWGR C2 .3OAV-BE 722 22021 -2.74 Sw= 02 7-2.41 72 SkGR~~MG A 1.q2 a S'61A 1 '1.41 a ./-.2 0.4.0 -D0.0 76 710 L W 701
- 2.
-WRC 3.7 In"O. 14.21 -.1. 54 1.030 4.283 4 SWGR E6 736 -. 0.890 -t.00 .00 D6
- 0.10 1.007 0.483 SWGR E4 735
-,0.8^ 0.31 -0.3 -0 r. -'.0.21 .0.02 0 - Iý -0.02 2.000 0.480 SWrR E3 734 -0. S2 -.0126 0.906 0.996 0.478 2CR £2 733 -.0. 631 1.017 0.471 14.03 721 -0. 0/\\ -0.0 741 -0.002 L -0002 -a-. 00___ 1.044 SW0R 1 0.501 1 732 D1 -. 0. 2 0.R 724 - 0. 07 7 5.-o ý 1 li, 3_
- 0.
.020 1.2 72.2 0.394 -.0.0 _-0.3* .03_0 -00.0 S0GR El 4.343 731 12 -D. 2 SW D3 ,0.8 -* 0.20 723* '00 0.*3 -0.02 -*.0 4.283 1.009 1.044 0.405 4.343 1.044 4.343 SWGR P6 740 t'-0.16 1 -o 0.85o '-0.09 0.00 0.485 SWGR F4 -0.42 739 1.22 -0. 4445 '-0.02 '-0.23 U0 o.99 0.479 SLOR T3 0.90 738 1 -0.'20 '-0.0 0.2 -0. C2 S0.999 0.480 SGWR F2 0.46 737 _-0. 0S _0.22 ý '1-0.02
- 0.
998 0.479 Loss of Davis Besse-Beaver 345kV Line All Lines In Pre-Contingency Uprated Davis-Besse Plant (1033Mw) 700 "V A A TRN 11" 704 L 705 -24.9 14.06 V 706 1.019 14.06 1.000 25.00
- 1. 0S3
[C l 26.32 In V1 "1.027 14.04 1,,, SM§= 04" ume e,.U i2P7 #van0) (VAX= 20,7 3150/ VI-31 1-. Of 0-i-8-*5ý.. 345k LiaM. 1260U0 IrnY mms4 o05U. 120SMl Wo 4 62 K L1 V TIN 02 Beaver Bayshore Lemoyne ii ti -S. 7 /--\\ -2.Sý 3 4
I I I I I Loss of Davis Besse-Bayshore 345kV Lines & DB Unit Davis Besse-Lemoyne 345kV Line Out Pre-Contingency Uprated Davis-Besse Plant (1033MW) TM 02 , 0.951 13.12 S9WM 02 725 L 'SWGR B S710
- r
{ Beaver Bayshore A, 0L Iit~ Lemoyne A L TRN 11P 1.000 704 25.00 l051 7050 .- 0.951 13.12 TRN IIY 706 0.951 13.12 0.951 K 13.12 I"9
- MM R J C:
(1997 XRZIUI 4RE NY By 00/ i,4 1 73 L Of*ýh 3...U )k.1r 34skV L. &06 On 240 may G*sVm* OWIk. 12WU W.mT I ?N0R 54 OW 11 1447,21 10ff 6404W
- 3 TRN 01 707
-50.4
- j 0.951 13.12 VB GEN1.000 700 25.00
_0.06 0.451 0 {
-- I-- *------v------ 1 -I---.. rt hi; CD Co 0 I
- b,.
0 to 0 to to 0 0 (D hi ti-
I I I ?0 02 708 -.0.0 1.020 14.19 r - -O3DAV-SE 5163RC2 222 722222 L -2. 71f 725 Loss of DB-Bayshore & DE-Beaver 345kV Lines All Lines In Pre-Contingency Uprated Davis-Besse Plant (103ThMW) N1., t t TRU 01 707 -0. 0 1.028 14.19 700 'D 1 704 WIL t-N 71 V 1730 11Y_ 706 Sayshore A Leymoye (0 IN 1.000 25.00 1.003 26.32 V 2.017 14.04 Beaver Q-ar. 91-1~c Cýna M/WM W"~q A-l) d 11 14,29,51 2909 1190 V m S I1)9 ZUZS1 (=U= Sry JKIQ/ 10/.&
- lb
) U Q o *C -IrVh.,.4 0 345kV U-. .Uq
I I I I I TRN 02 708 -'*: S* 13.75 722V-B 722 8MR D2 -2.. 74 2 4. 725 70900 -0.06 710
- 2.
SMR C1 GR F7
- -3.8
-24.8 24.8-1 721 741 "1.55 -0.70 1 -0.002 o0.00 0.996 -. 0.67 -.0._37 1 -0.002 ,0.00 13.75 -. 0.02 I 1 1.021 SRF: 0.490 "-0.60 732 S"GR DI 1-0.15
- Z2772 5.0.02 1.006 05 0.4833
-0.67 732 -0.04 4<0-02 1.021 SW3R El 731 _.0. 8 (02 -0.7 2 .0.3 -0.08 1.008 1.000 _'0.02* 4.195 4.195 0.988 0.474 S0-R E6 736 -.0. 89 -. 1.00.* -- 0. 00 -.0. 07 u.* -0.20 0.0 0.986 0.473 S0R E4 735 -. 0. 36/ "0-0.02 0.979 0.470 S8GR E3 734 -.0.52 -- 0.21 -0.26 -00 -,0.02 0.975 0.468 89GR E2 733 -!0.63 0.959 0.996 0.461 13.75 4.249 SICK D3 723 "-0.02 <0.02 1.021 4.249 1.021 4.249 SCKR F6 740 - 0.76 -0.09 -0. 00 -0.00 0.986 0.474 SM9R F4 739 -0 42 7 9 -0. 22 =-0.44 -0.02 -0. 23 "3-0.01 0.976 0.469 S8R F3 0.40 738 1
- -020 -0. 44
-0.0D4 -0.23 og 1* -0. 02 0.977 0.469 SVMR F2 737 1*-o0.52o 0 0.976 0.468 TRN1 -0 -0 Loss of Davis Besse Unit All Lines In Pre-Contingency Uprated Davis-Besse Plant (1033MW) &A AMA DS GEN 1.000 700 25.00 A, TRN 21HP 1.000 704 25.00 12~x 0.0 Vw S0.996 13.75 TRN 11Y 706 0 0.996 13.75 0.996 0 13.75 Beaver Bayshore Lemoynf' AA 2' 23 -325.7 56 2.5 .997 .43.6 0 1 I-j1909 m IPAR Ue
- f 2199I~,
12*)fl (I*O0 ST
- 10/
J*dl' LI..*0 fol. fol i i i 3 -5. 7 r'ý 2.5 _3. 6 2.4 ý 4) I
I I I Loss of Fermi Unit All Lines In Pre-Contingency Uprated Davis-Besse Plant (1033MW) TiN 02 t70 -0.0 1.022 14.11 7 R C2 22021 7 22 S5MR 02 I -27 .;-2.4' 725 709 i SA O 109 0.40 -0.06 710 4-0.1. 1 0.03 L70 S......C--4.7.. 707 -2. M* R C 1 M R V 7 - 3. 8 9 7. - 0. 0 4 721.F 0.0 721 1741 -2.8 -0. 002 -0.00 -0. 37 1,0. 00 <_ .11 -o.0.66 o<0002 1-0..022 K K Beaver Bayshore Lemoyne 0 0nl 1.000 25.00 1.053 26.32 1.017 14.04 109*9 SON eWH CA= 41107 7IZZI 2==) 4 31 10./ &b 132) L. of paI am11 120*,.W VUnY 0S WTPMT. 120SM NT Iwi R Wed AM 11 14,20l16 1"t 3.11.0. x I ý_l Uýft C..D-, rw V'_ I
Loss of Bayshore-Monroe & Lemoyne-Majestic 345kV Lines All Lines In Pre-Contingency Uprated Davis-Besse Plant (1033MW) SWR C2 F 722
- 2.
1 17 2 41 725 -1,41-.27" 709 -0.40 -0.06 -0.19 1 i 0 ** L* .. 017 04 7.981" 14.03 0.471 I 2* H.Pe~/ 1292 2 7 -3.87 1.009 0.485 . n O (1997 c Zln ) mo WOC BY DIM 0f URY OPUS OUMTW. 10202 K" TRN 02
- 1. 021 13.99 0:
S1401 3 710 L-22021 TR3 01 707 1.014 13.99 AtA 0101 030 21HP 704 ¶W 0 LA 115V 1.019 14.06 V_ TWN 12Y 706 k CY 1.019 14.06 I WIs.AM 554 AsS 12 14,2O23 1. 3.k5. 1 Beaver Bayshore Lemoyne t,t V Q 01 m iJ 1.000 25.00 1.053 N 26.32 V 1.017 NO 14.04 I
L L.ýr-L 'SZ 41 -os ILO I A A t t -7. F. in i -.-I 4 v IV ý`
- `-7
, u7s 0 43 ? v?,'Y 41 b) a -H -4 V 41 P4 tt C; a* 0 0 11 t ýjoo t t t c; t t t t t; t tt tt04 1 -; t3 ytc!t;l 6 8 44 0 'a tý 0
- 4) t t
t t tt 41 (d to -1 m 0 r-4
Iw GE Energy Services Appendix D Stability Analysis Results D-1
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Bayshore 345kV Line Machine Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.2-Davis-Besse, vt -4l 6-Davis-Besse, efd 4-2 0 3000 Davis-Besse, pg. 1000 0l-J -1000-ý 1.03. Davis-Besse, spd 1.00 0.97-i 2000- Davis-Besse, qg. 1500-i 1000 500 0 0 2 4 6 8 10 Time (Seconds) 10o-1 Davis-Besse, ang -4 0 -100--i 0, Bayshore #4, ang 7 -100-Beaver A, ang -50 -10 0-' 0 *Monroe.#1, ang. I. -100--j 0- Fermi #2, ang 1 -1004 0 2 4 6 8 10 Time (Seconds) 07 Sammis #6,.ang. -100 .50 -1O -100-o-0Eastlake #5,. ang -4 .100 J 0-o Perry, ang -5o .l-J -100 0- Homer City, ang -0" -100 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:48:59 chanfiIes/d0_99s_r2_c01.chan page I
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Bayshore 345kV Line Bus Variables: (.J With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.i-Davis-Besse 345, Vpu .,,Monroe l&2 345, Vpu Perry 345, Vpu 1.0" 1.0 1.0 0.9-0.9 0.9 - 0.8 0.8 0.8 0.7 0.7-0.7 0.6 0.6's 0.6 1.1 Bayshore 345, Vpu .1 Monroe 3&4 345, Vpu 1.1 -Carlisle 345, Vpu 1.0-1.0 f 0.9-0.9 0.9 0.8-0.8 -0.8 0.7-o.71 o. 0.6-" 0.6-0.6 ; 1.1-Lemoyne 345, Ypu 1.1-, Majestic 345, Vpu .,_Avon 345, Vpu 1.0-1.0 1.0 0.9 0.9 0.9 0.8 0.8-1 0.8 0.7 0.7
- 07.
0.6 0.6 -1 0.6 ,1.-. Beaver 345,.Vpu 1.. N Brown 345, Vpu 1.I1 Star 345, Vpu 1.-1.0 1.0 0.9 0.9 0.9 0.8 0.S-j 0.8 0.7 0.7 0.7.i 0"6ý 0.6"] 0.6 I.,- Fostoria 345, Vpu Fermi 345, Vpu. Harding 345, Vpu 1.0 1.0 .o 0.9 0.9 0.9-0.8 0.8-o.8 0.7 0.7 0.
- 00.
0.6-0.6] 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:48:59 chanfilesld0_99s-r2_co0.chan Pave 2
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Bayshore 345kV Line Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate -_Eastlake 138, Vpu 1 1 Beaver 138, Vpu I., Wayne 138, Vpu 1.0
- 1.
0.9 0.9 0.9 0.8-0.8 0.8-4 0.7 0.7-0.7 0.6-0.6-0 1.1-Juniper 138. Vpu 1.1-Bayshore 138, Vpu N Brown 138, Vpu 1.0-1.0 1.0, 00.9.9 0.9-a 0.8-4 0.87 o.8-j 0.7-0.7 0.7 0.6-0.6-0.6 J. 1.1-Avon 138, Vpu 1.1-Lemoyne 138, Ypu "!-E Lima 138, Vpu 1.01.0-.0 -i 1.0 0.9 0.9-0.9 0.8-0.8-0.8 0.7 0.7-0.7 0.6-o4 0.6-j 1.1-Star 138, Vpu 11-Fostoria 138, Vpu 11 Allen 138, Vpu 1.0_ 1.0-1.0 0.94-1 0.9-0.9 0.8-4
- 0.
0.8 0.7-ý 0.7-0.7 0.6-0.6-0.6 1.1-, Carlisle 138, Vpu . 1 Monroe 138, Vpu Galion 138, Vpu 1 1.0-1 0 1.0 0.9 0.9 0.9 0.8 1 0.8 0.8-1 o8 0.7-0.72 0.7 0.6 2 0.6-0.6 0 6 0 2 4 6 8 10 0 2 4 6 8 10 O Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:48:59 chanfiles/d0.99sr2c01.chan Page 3
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Bayshore 345kV Line Motor Variables:..j With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 SWGR A #2, vt 1.- SWGR B #2, vt 0.9.Z0.9 0.8 -0.8 0.7 0.7 0.6r-0.,r 1 0 SWGR A #2, pg SWGRB#2,pg oIo 01o0 -10 -10 207~SWGR A#2, qg 20--SWGR B#2, qg 4 -20 5 SWGR A #2, it 4 3 2* 0 1.0 SWGR A #2, spd 0.99 0.984 0.97 -j 0.96] 0 2 4 6 8 10 Time (Seconds) 0 5 SWGR B #2, it 4-3 2 0 1.00 SWGR B #2, spd 0.99_* 0.98 0.97 0.96 0.95 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:48:59 chanfiies/dO_99sr2_cOj.chan Page 4
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Bayshore 345kV Line Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 SWGR E6, vt .- SWGR E3, vt 1..- SWGR D1, vt .1.0.0 1.0 0.9 0.9. 0.9 0.8 0.8-0.8. 0.7 0.7-0.7 0.6 0.6-. 0.6 1 1 SWGR F6, vt 1.1 SWGR E4, vt 1.1-SWGR F4, vt 1.0-1.0-1.0 0.9 0.9-0.9 0.8 0.8-0.8 0.7-0.7-0.7 0.6-0.61 0.6 1.1 SWGR El, vt 1 -SWGR C2, vt 11 -SWGR F2, vt 1.0 1.0. 1.0 0.9-0.9-0.9 0.8 0.8 0.8 0.7 0.7 0.7 0.6-0.6-0.6-1 1.1 SWGR Fl, vt -SWGR Cl, vt 11 SWGR F3, vt 1.0-1.0-1.0.' 0.9-0.9 0.9r 0.8 0.8 0.8 0.7-0.7-0.7 0.6_1 0.6 0.6 1.1 SWGR E2, vt 11-SWGR D2, vt 1.0
- 1.
0.9-0.9 0.8-0.8 0.7-0.7] 0.6-0.6" 1 I I '! i i. I I i ' 1 ' 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:48:59 chanfies/d0_99sr2_c1.chan Page 5
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Bayshore 345kV Line STATCOM Variables: -. With Uprate & STATCOM 2 I I I 4 6 8 Time (Seconds) 26-APR-2000 14:48.59 chanfiejd09sr2_co1.ch Page 6 O 1.1 1.0 0.9 0.8 0.7 0.6 5 4 a C,, 3 21 0* 0 CIO 150 Iio 110 70 30 -10 -50 0 10 I
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Lemoyne 345kV Line Machine Variables: (_j With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate Davis-Besse, vt 1. 6-Davis-Besse, efd 4 2. 0-30-Davis-Besse, pg 1000 -1000 1.03 Davis-Besse, spd 1.00 0.97 oo0 Davis-Besse, qg. I I 0 2 4 6 8 10 Time (Seconds) o--Davis-Besse, ang -100-i .l0 0- Bayshore #4, ang J "-50 -100-' -. Beaver A, ang -50 2 -4 -100-i o-*Monroe #l, ang. "Oý -4 -1001 0 - Fermi #2, ang -50 -100-0 2 4 6 8 10 Time (Seconds) 0- Sammis #6, ang -50 -100-4 0 Eastlake #5, ang -4 -100-0- A n #9, ang J -100-j 0- Perry, ang I - Homer City, ang - - LUJ-0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:01 chanfiIes/dO_99s_r2_cO2.cban Page I
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Lemoyne 345kV Line Bus Variables: (.) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 11i Davis-Besse 345, Vpu 1..- Monroe l&2 345, Vpu ,-Perry 345, Ypu 1.0-1.0 -7 0.9 0.9-0.9 0.8 0.8-0.8s 0.7-0.7-0.7 0.6-- 0.6-0.6 .1 - Bayshore 345, Ypu .- Monroe 3&4 345, Vpu 1-Carlisle 345, Vpu 1.0 1.0 1.0] 0.9 0.9 0.9 0.8 0.8-1 0.8 0.7-7 0.7 0.7-' 0.7 0.6 0.6 6 Lemoyne 345, Vpu 11 Majestic 345, Vpu 11 Avon 345, Ypu 1.0 0 1 0.9-0.9 0.9 0.8-0.8 0.8 0.7 0.7-4 0.7 0.61 .6-0 .6_ 1.1. Beaver 345, Vpu I., - N Brown 345, Ypu 1-I Star 345, Vpu 1.0-1.0 1.0 0.9 0.9 0.9 o.8-0.8-0.8* 0.7 0.7-- 0.7 0.6 J 0.6--0. 11 Fostoria 345, Vpu 11 Fermi 345, Vpu-Harding 345, Vpu 1.0 1.0 1.0. 0.9-0.9 0.9 0.8-0.8 0.8 0.7 -0.7 0.71 0.6 0.6-0.6 I i i I I ' I ' I I I ' I I I ' 1 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 OTime (Seconds) Time (Seconds) Time (Seconds) .6-APRK-200 14:49:01 cbanfiIes/d0_99sr2c02.cha Page 2
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Lemoyne 345kV Line Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate
- 1. 1-Eastlake 138, Vpu 1.0 --J" 0.9 0.8 0.7-:
0.6 1.1 - Juniper.138, Vpu 1.0-0.9 0.8-+ 0.7 0.6 1. Avon 138, Ypu 1.0 0.9 0.8 0.7 0.6-J 1.1-, Star 138, Vpu 1.0-0.9-T 0.8 0.7 0.6-1 1.1-Carlisle 138, Vpu 1.0-: 0.9 0.8 0.7 0.6. 0 2 4 6 8 10 Time (Seconds) 1.1-, Beaver 138, Vpu 0.6 1.1-Bayshore 138, Ypu 1.0_ 0.9 0.8 0.7 0.6 1..- Lemoyne 138, Ypu 1.0. 0.9 0.8 0.7 0.6 ,. 1_Fostoria 138, Vpu 1.0 ! 0.9* 0.8 0.7 0.6-1.1 -Monroe 138, Vpu 1.0* 0.9 "-I 0.8-0.74 -4 0.6-J 0 2 4 6 8 10 Time (Seconds) 1.1 Wayne 138, Vpu 1.0 0.9 0.8* 0.7-J 4 0.6-1.1 N Brown 138, Ypu 1.0 0.9-] 0.7-0.6 1.1-E Lima.138, Vpu 1.0 0.9 081 0.6J 1 - Allen 138, Vpu 1.0 0.9S 0.8 0.7 0.6 1 1 Galion 138, Vpu 1.0 0.9 0.8 0.7-' "*1 0.6 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:01 chanfies/dO_99sr2_cO2.chan Page 3
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Lemoyne 345kV Line Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (-.) Without Uprate 1.1 SWGR A #2, vt 11 SWGR B #2, vt 1.0-]1.0 0.8 0.7 -0.
- 0.
10.6--J 10o SWGR A #2, pg 10 SWGR B #2, pg 0 0 20 - SWGR A #2, qg ' 5 SWGR A #2, it 4.- j 32 0 1.00 - SWGR A #2, spd 0.99 0.98 0.97 - 0.961 0.95 0 2 4 6 8 10 Time (Seconds) 20 SWGR B #2, qg 01 5 SWGR B #2, it 41 3 24 0-1.00 SWGR B #2, spd 0.99
- /
0.98 0.97-0.96 -*1 0.95 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49.01 chanfiles/d0_99s-r2_c02.chan Page 4
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Lemoyne 345kV Line Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 SWGR E6, vt I1.,-SWGR E3, vt 1..- SWGR D1, vt 1.0-1.0- ', 1.0 .0-0.9 0.9 0.9 0.8 0.8. 0.8 0.7 0.7 0.7. 0.6-0.6 0.6-. l1 SWGRPF6, vt 1.1 SWGR E4, vt 1..- SWGR F4, vt 1.0 1.0-1.0 0.9-0.9-0.9 0.8 0.8 o0.8 0.7-0.7-- 0.7. 0.6-" 0.6-0.6-1.-1 SWGR El, vt 1.1 SWGR C2, vt 1a SWGR F2, vt 1.0 1.0 1.0O 0.9-0.9 0.9 0.8-0.8-0.8 0.7 0.7-0.7 0.6-0.6-0.6A - SWGR Fl, Vt SWGR Cl, Vt 1 1-SWGR F3, vt 1.0 1.0 1.0 0.9-0.9-0.9 0.8-0.8-0.8 0.7-0.7 0.7 0.6-0.6-- 0.6
- 1. 1 SWGR E2, vt SWGR D2, vt 1.0 "
1.0 0.9 0.9 0.8 0.8 0.7 0.7 0.6-0.6-1 ' i'~l~l I l~,!*II 1,
- 1111, 0
2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 STime (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:01 chanfilesld0_99sr2_c02.chan Page 5
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Lemoyne 345kV Line STATCOM Variables: (.) With Uprate & STATCOM 1 -J 1 Ii I 0 2 4 6 8 Time (Seconds) 26-APR-2000 14:49.01 chanfila/dO_99sr2_cO2.Chd 0 1.1 1.0 0.9 0.8 0.7 0.6 5 4 0 3 2 0 C', 150 110 70 30 -10 -50 0 10 Page 6 I V I1 n
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Beaver 345kV Line Machine Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.2-' D 1i-esse, Vt. 1.0 0.9 0.8 6 Davis-Besse, efd 4 0-i "0i 3000- Davis-Besse, pg. 0004 100 ..1000-' 1.03 Davis-Besse, spd 1.00 J 0.97 2000-, Davis-Besse, qg 100o7 Davis-Besse, ang 0 -. _100-I o-, Bayshore #4, ang so-A0~ -100-: 0- Beaver A, ang -4 IO-j -100-1 0. Monroe #1, ang. -JOO -100 ri g 0-,Ferxni #2, ang .so-PO W II 0 2 4 6 8 10 -100- FF _Tý I' I I I' I 0o Sammis #6,.ang. -.1 -100 0- Eastlake #5,. ang "-0 1... 0_, Avon #9, ang -100 0- Perry, ang -10J 01i Homer City, ang t -100-0 2 4 6 8 10 I I I 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 27-APR-2000 09:02:14 chanfiles/d0_99sj2_c03chan 1500 100 0-Page I
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Beaver 345kV Line Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1..,Davis-Besse 345, Vpu - Monroe 1&2 345, Vpu 1..-.Perry 345, Vpu 1.0 1.0 1.0 0.9-0.9i 0.8-0.8 0.8-I 0.7 07.7 0.6 0.6-0.6-i 1.1.Bayshore 345, Vpu .- Monroe 3&4 345, Vpu 1-] Carlisle 345, Vpu 1.0 1.0 .1.0o 0.9 0.9 0.9 0.8 0.8-0.8 0.7 0.7- .7 0.6 0.60 1.1 Lemoyne 345, Ypu .- Majestic 345, Vpu I.,- Avon 345, Ypu 1.0-1.0 1.0 0.9-0.9 0.9 0.8-0.8 0.8 0.7-0.7 "0.7-j 0.6s 0.6 0.6-' 1.1-Beaver 345, Vpu .*N Brown 345, Vpu S 1..1Star 345, Vpu .0. 1.0 1.0 0.9 0.9 0.9-0.8 0.8 0.8-1 0.7-0.61 1-Fostoria 345, Vpu 0.9 0.8 0.7- .u-- I I I 0 2 4 6 8 10 Time (Seconds) 0.6-' Fermi 345, Vpu 1.0 0.9 0.8 0.6 I ' I I 0 2 4 6 8 10 Time (Seconds) 0.6d
- 1. Harding 345, Vpu 1.0 0.9 0.8 0.7 0.6 I '
I I ' l ' 0 2 4 6 8 10 Time (Seconds) Page 2 0 27-APR-2000 09:02:14 chanfiles/d0_99sr2_c03.chan
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Beaver 345kV Line Bus Variables: (__) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 11 Eastlake 138, Vpu !.0 0.9 0.8 0.7 0.6-1 1 Juniper.138, Vpu 1.0 0.9-] 0.8 0.6 1.IjAvon 138, Vpu. 0.9 0.8-* 0.7 0.6-' -* Star 138, Vpu 1.0-0.9 TT 0.8 -j "I 0.7-ý 0.6 1.1-Carlisle 138, Vpu 1.0 0.9 0.8 0.7.7 0.6 2 4 8 0 2 4 6 8 10 Time (Seconds) 1..-. Beaver 138, Vpu 1.0 0.9 0.8 0.6-j t.- Bayshore 138, Vpu 1.0 0.9; 0.8 0.7 0.6" 1.1-Lemoyne 138, Vpu 1.0-0.9 0.8 0.7 0.6
- 1. 1-Fostoria 138, Vpu 1.0 -
0.9 0.8; 0.7 0.6 1.1 Monroe 138., Vpu 1.0 0.9 0.8 "~1 0.7 0.6-' 0 2 4 6 8 10 Time (Seconds) , Wayne 138, Vpu 0.9 0.8-, .1 0.7-1 0.6-j 1.1 N Brown 138, Vpu 1.0 0.9 0.8* 0.7-A 0.6-J 1..- E Lima 138, Vpu 1.0 0.9 0.8 0.7-* 0.6-1.1-Allen 138, Ypu 1.0 0.9 0.8 0.7 0.6 1.1.Galion 138, Vpu. 1.01. 0.9! 0.8 0.7 0.6 i 0 I i 6 I I I I 0 2 4 6 8 10 Time (Seconds) 27-APR-2000 09:02:14 chanfIes/d0_99sr2_c03.char3 Page 3
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Beaver 345kV Line Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 SWGR A #2, vt 1.1 SWGR B #2, vt !1.0 1.0 0.9 0.9 0.8 0.8 0.7 0.7 0.6 0.6F 10o._.SWGR A #2, pg 10 SWGR B #2, pg 0 0- -10 20 -- SWGR A #2, qg 0 -10 20 -,SWGR B #2, qg 0 -20 SWGR A #2, it 4-3 2 0-1.00 - SWGR A #2, spd 0.98 0.99 0.97 - 0.96-* 0.95 4 6 8 10 Time (Seconds) -20 5 ' SWGR B #2, it 3-1 2 k 0 1.00 SWGR B #2, spd 0.98 0.97. 0.96 0.95 -1 0 2 4 6 8 10 Time (Seconds) / 27-APR-2000 09:02.14 chanfiles/dO_99s r2_cO3.chw Page 4 a 1
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Beaver 345kV Line Motor Variables: (.) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate .-, SWGR E6, vt 1.1-SWGRE3, vt L-SWGR D, vt 1.0-1.0-1.0 0.9-0.9-0.9 0.8-0.8-0.8S 0.7] 0.7-0.7 0.6 0.6-4 0.61 11 SWGR F6, vt 1.1-SWGR E4, vt 1-SWGR K4, vt -t 1.0 1.0 1.0 0.9 0.9-0.9 0.8 0.8-- 0.8 0.7 0.7-0.7 0.6 0.6-0.6 1,.,-SWGR El, vt C2, vt
- 1. SWGR F2, vt 1.0-1.0 1.0 0.9-0.9 0.9 0.8 0.8 0.8 0.7-0.7-0.7 0.6-0.6-"
0.6 11-SWGR Fl, vt 1.1-SWGR Cl, vt - SWGR F3, vt 1.011.0 0.9s 0.9 0.9 0.8-0.8-0.8 0.7-0.7 0.7 0.6-0.6 0.6 1.1-SWGR E2, vt 1.1 SWGR D2, vt -4 1.0-1.0 0.9-0.9 0.8-0.8 0.7-0.7 0.6-0.6-" 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 27-APR-2000 09:02:14 chanfiles/d0_99sr2_c03.chan Page 5
3phase, 4.5cycle Fault at Davis-Besse 345kV Bus Trip Davis Besse-Beaver 345kV Line STATCOM Variables: (_) With Uprate & STATCOM 1.1 - 7 150 110 j 70o-, 30 -* -10 -50 I I I 2 4 6 8 Time (Seconds) 27-APR-2000 09:02:14 chanfiles/dO99s-r2c_03.t 0 C F-1.0 0.9 0.8 0.7 0.6 5 0 COO) 4 3 2 1 0 H H 0 S 10 Page 6 7 u
3phase Fault at Bayshore 345kV Bus Trip DB-Bayshore 345kV Line (4.5cy @Bayshore, 22.5cy @DB) Machine Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.2 Davis-Besse, vt D00-Davis-Besse, ang 1.0-" 0ý 0.9] 0.8- -100 6J_ D - esse, efd , Bayshore #4, ang 4-0 3000- Davis-Besse, pg. 2 = 1000- .4-1I 0- Beaver A, ang - ./" -\\ .~- I, O_" Lo-*[ avis-Besse, spd o-Monroe #1, ang "-4 0.97-' 200-i Davis-Besse, qg 1500 1000 0 0I 2 I 6 0 2 4 6 8 10 -100-0- Fermi #2, ang 1 -100j.. lao-.] i Ii 0o Sammis #6, ang. \\ -0i -100-' o-Eastlake #5,. ang .100 0-Avon #9, ang o-
- Perry, IOJ
-Perry, ang... "-i -100-o 0- Homer City, ang 5 0-- -100-0 2 4 6 8 10 I I I 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:04 chanfiIesfd0_99s_r2_c04.chan Page I
3phase Fault at Bayshore 345kV Bus Trip DB-Bayshore 345kV Line (4.5cy @Bayshore, 22.5cy @DB) Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1..--Davis-Besse 345, Vpu ,1-,Monroe l&2 345, Vpu ,-1 Perry 345, Ypu 1..0T 090.9 0.9 o.8 -o 0.80.8
- 0.
0.7 0.6 0.67 0.6 1.1-Bayshore 345, Ypu 1.- Monroe 3&4 345, Vpu 1 -Carlisle 345, Vpu 1.0 0I. 0.9 0.9 0.7-. 0 7J007 o.6
- o.6_J 0.6 1.1-. Lemoyne 345, Ypu 1-Majestic 345, Vpu 1 --,Avon 345, Vpu 0.9-.".
.1. 0.9 0.9 0.8-0.8 0.8 0.7-0.7 o.7 0.6 .o.6- . 0.61 11 -Beaver 345,. Vpu 1..-N Brown 345, Vpu ,'1-..Star345,Vpu 1.0-1 0.9 0.9 .0.9 0.8 0.8][
- 0.
0.7-J 0.7". 0.07 S_ Fos~toria 345., Vpu 1"_Felrni 345, YpU. IHrig35 p 0.9-0.9 -0.9 0.8- .8f o 0.9 0.7£ 0.7-ý 0.7-1 0.6"- 0.6 - 0.6j 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:04 chanfiles/d0_99sr2_C04.cha1 L6.
3phase Fault at Bayshore 345kV Bus Trip DB-Bayshore 345kV Line (4.5cy @Bayshore, 22.5cy @DB) Bus Variables: (..) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1_ Easftake 138, Vpu 0.9--; 0.8 0.7 0.6-: 1-Juniper 138, Vpu 1.0-woo 0.9 0.7-* 0.6 .1 Avon 138, Vpu 1.0 0.9 t 0.8 0.7 0.6 --j - Star 138, Vpu 0.7-1 0.6IA C~arlisle. 138, Vpu 0.7 -- 0.61 ! I j i I I i I " 0 2 4 6 8 10 Time (Seconds) 1.1 Beaver 138,. Vpu 0.9 0.87 0.6-1 1.1 Bayshore 138, Vpu 1.0 0.9 0.8 0.7 ] 0.6-4 1.1 -,Lemoyne 138, Vpu 1.0 0.9-" 0.8-0.7] 0.64
- 1. 1-Fostoria 138, Vpu 1.0-1 0.9-0.8 0.7.
0.61 1 1 Monroe 138., Vpu 1.0* 0.9-0.7-0.6 0 2 4 6 8 10 Time (Seconds) 1 - 1 Wayne 138, Vpu "7t 1.0*I 0.9 0.8 0.7 0.6 N Brown 138, Vpu 0.02 0.7 0.6-i 1 1 ELima 138, Vpu 1.07 0.8 0.7] 0.6 1.1.Gallon 138, Vpu 1.0-. 0.9 0.81 0.7 0.6 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:04 chanfilesd0._99sr2_c04.chan Page 3
3phase Fault at Bayshore 345kV Bus Trip DB-Bayshore 345kV Line (4.5cy @Bayshore, 22.5cy @DB) Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 SWGR A 2, vt I, SWGR B #2, vt
- 1. 0 I 1.0-0.9 A
0.9 0.8 0.8 0.71 0.7 0.6 0.6-1ll1 1 0 SWGR A #2, pg 1oSWGR B #2, pg J 2 0 -7 SWGR A #2, qg 20 SWGR B #2, qg -20 -20* 5 SWGR A ,it 5 SWGR B #2, it 3 .3 2 2 0 0 1 SWGR A #2, spd SWGR B #2, sd 0.98 - 0.98-1 0.7-ý 10.97 Il 0.9 0.97 I-1 I i' i I 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) O6-AIPR-2IX00 14:49:04 chanfilesId0_99s-r2_c4.chan Page 4
3phase Fault at Bayshore 345kV Bus Trip DB-Bayshore 345kV Line (4.5cy @Bayshore, 22.5cy @DB) Motor Variables: (.) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate SWGR D1, v 1.1 -SWGR E6, Vt 1 1..,qSWGR E3, vt 1.I SW RD, vt 1.01 1
- 1.
1.0 0.8 0.8 08.1.90 0.8-. o~s ., *0.8 S 0I0 0.7] .7 7] 0.6 0.6-0.6 1.1-SWGR F6, Vt 1.1 SW*OR E4, vt 1.1-SWGR F4, vt I d Io-' ],, 4.o ]*' ~-" 0.9 0.9-09 o.8I o.8-oLII 0.8-0.8 0.8 0.*7 07 ARM0 0.6-i 0.6I I 1 SWGRF1, vt 11 SWGR C1, vt 11_.SWGRF3, vt 1.0 1" 0.9-0.9-0.9 0.8 0.1-o.8 0.7 0.7 0.7 0.6-I l 0.6 - 0.6-" IlIl 1 1 SWGR E2, vt 1.1 SWGR D2, vt 1.0" 1.0 j'J. 10 0.9-0.9-0 0.8 0.8 0 07 0.7-0 0.6-7 0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:04 chanfiles/dO_99s_r2_cO4.chan Page 5
3phase Fault at Bayshore 345kV Bus Trip DB-Bayshore 345kV Line (4.5cy @Bayshore, 22.5cy @DB) STATCOM Variables: (-) With Uprate & STATCOM 1.1 1.0 0.9 0.8 0.7 0.6 5 7 N 4 3 2 1 0 150 110 70 30 -10 -50 UJ 4 6 Time (Seconds) 26-APR-2000 14:49:04 chanfiles/dO_99s-r2_c04.chan U CIO 0 U F F C,, 0 CO-0 I I 8 10 Page 6 2
3phase Fault at Lemoyne 345kV Bus Trip DB-Lemoyne 345kV Line (4.5cy @Lemoyne, 22.5cy @DB) Machine Variables: (.) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate -. Davis-Besse, vt -.1 1.0. 6-, Davis-Besse, efd 4-2 3000- Davis-Besse, pg. 2 0 00 100 -10600 1 1.03-* Davis-Besse, spd 1.00-0.97--! 20001 Davis-Besse, qg 1000 500 o 2 0 2 4 6 8 to 106-Davis-Besse, ang .100-; 0
- Bayshore #4, ang
-s -500-Beaver A, ang IAl 0-Monroe' #1 ana 0- Fermi #2, ang .50 .1001 I 2 I 4 I 6I 0 2 4 6 8 10 o1 Sammis #6,.ang. 0_1 -0j -J -0oo o-, Eastlake #5,. ang I -100 o-, Avon #9, ang 04
- 0. Perry, aug
-50 °100* 0 Homer City, ang -50 -100 2 i, I, I, 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:06 chanfiIesdO_99s_j2_c05.can 0 Page I 11411ý1_
3phase Fault at Lemoyne 345kV Bus Trip DB-Lemoyne 345kV Line (4.5cy @Lemoyne, 2 2.5cy @DB) Bus Variables: CJ With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.- Davis-Besse 345, Vpu 1.0-
- j.
0.91 o.s8 0.71 0.6 -I Beaver 345,. Vpu 0.9 0.8. 0.74 0.6 j LI - Fostoria 345, Vpu 0.9 0.7--8 0.6 0 2 4 6 8 10 Time (Seconds) Monroe 1&2 345, Vp 1.0 0.9 0.8 0.7* 0.6 1.1 Monroe 3&4 345, Vpt 1.0o 0.9 0.8 0.7-" 0.6-Majestic 345, Vpu 1.0 0.9 0.8 0.7] 0.6-1 1.1-N Brown 345, Ypu 1.0 0.9 0.8 O.7F 0.6* 1,.1 Ferrni 345, Ypu. 1.0 0.9 0 2 4 6 8 10 Time (Seconds) Perry 345, Ypu 0.9 0.8] 0.74 0.6-1 SCarlisle. 345, Vpu 0.9 0.8-1 07 J 0.7-J .1 -, ~Avon 34,Ypu 0.8-* 0.7 0.6 .1-, Star 345, Vpu 1.01 0.9 0.84 0.7-jj1 1..-, Harding 345, Vpu 0.91 0.6 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:.06 chanfile/d0_99s r2_cO5.cha Page 2
3phase Fault at Lemoyne 345kV Bus Trip DB-Lemoyne 345kV Line (4.5cy @Lemoyne, 22.5cy @DB) Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate I.,-Eastlake138, Vpu .1 1-. Beaver.138,. Vpu I., Wayne !38, Vpu -J 1.0 1.0 0.9-- 0.9 0.9 0.8-0.8-0.8 0.7-0.71 0.7] 0.6-0.6-j 0.6-1.1 Juniper 138, Vpu .- Bayshore 138, Ypu 1 -N Brown 138, Vpu 1." 1 1.0 0.9-0.9 0.9 0.8 0.8-0.8 .7.7 0.71 0.6-! 0.6-0.6 1-17 Avon 138, Vpu .I-. Lemoyne 138, Ypu 1.1-E Lima.138, Vpu 1. 0 -. 0 0.9 40.9-0.9 0.8-0.8 0.8 0.7-i 0.7 0.71 0.6-0.6 E*-- Star 138, Vpu 1 1,Fostoria 138, Vpu .,.Allen 138, Vpu .0-i 1.0o 1 0.9-"e 0.9 0.9 0.1 0.8-0.8 0.6-j 0.61 0.6 1.1 Carlisle. 138, Vpu I,- Monroe 138., Vpu I., Galion 138,.Vpu 1.0 - o.- o.0-1.0 0.9 0.9 0.9 0.8 0.8-0.8 0.7 0.7 - 0.7 0.6 0.6-0.6" 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 STim e (Seconds) Tim e (Seconds) Tim e (Seconds) 26-APR-2000 14:49-.06 chanfiles/d0_99s_r2_c05.chan Page 3
3phase Fault at Lemoyne 345kV Bus Trip DB-Lemoyne 345kV Line (4.5cy @Lemoyne, 22.5cy @DB) Motor Variables: (.) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 SWGR A #2, vt 1.0 0.9 0.8 0.7 -* 0.6 1 0 SWGR A #2, pg 7 0 -4 -10 20- SWGR A #2, qg 0 5 -SWGR A#2' it 4 3 I 1.00 SWGR A #2, spd 0.97 0.96 -J 0.95 0 2 4 6 8 10 Time (Seconds) 1.1 SWGR B #2, vt 1.0 0.9 0.8 0.7 B 0.6 10 = SWGR B #2. pg 0 20 SWGR B #2, qg 0.20 -20 __1 5 SWGR B #2, it 4 3-0 1.00o-SWGR B #2, spd 0.98 0.97 0.96 0.95 - 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:06 cbanfiles/do_99sr2_c5.can, Page 4
3phase Fault at Lemoyne 345kV Bus Trip DB-Lemoyne 345kV Line (4.5cy @Lemoyne, 22.5cy @DB) Motor Variables: C_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1-,SWGR E6, vt 0"91 0.1 0.7 0.6A
- 1. 1-SWGR F6, vt 1.01 J 0.9 0.81 0.7 0.6A
.- SWGR El, vt 1.0] 0.9 0.81 0.7 0.61 1.1 *SWGR F, vt 1.0 0.9-0.8 E 0.7] 0.6 1.0-H 0.9-1i. 0.21 4 0.71 0.6 s 0 2 4 6 8 10 Time (Seconds) ._SWGR E3, vt -Jf" 101 0.8 0.7 06.1-SWGR E4, vt 1 -SWGR C2, vt 1.0 0.9 0.8-0.7 0.6 1 1 SWGR.C1, vt -4 1.0 0.9 0.8 0.7] 0.64
- 1. 1-SWGR D2, vt 1.0.
0.9 0.8 0.7 0.6 F-i i I I1 i, i 0 2 4 6 8 10 Time (Seconds) 1*--SWGR D1,.vt o-7 1.0-0.9 0.81 0.7 0.6 11 2SWGR F4 vt 1.0 0.9 0.81 0.73 0.6 1.1 SWGR F2, vt 1.0-" 0.9 0.81 0.7 0.64 1.1-SWGRF3, vt 1.01 0.9 0.8 -" 0.60 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:06 cbanfi1/d0_9sjr2_c05.c1xan 0 Page 5
3phase Fault at Lemoyne 345kV Bus Trip DB-Lemoyne 345kV Line (4.5cy @Lemoyne, 22.5cy @DB) STATCOM Variables: (.) With Uprate & STATCOM 1.0 0.9 0.8 0.7 0.6 5 4 3 2 1 0 150 110 70 30 -10 -50 B I I I 1 1 U 2 4 6 Time (Seconds) 26-APR-2000 14:49:06 chanfiles/dO099s-r2_cO5.chan L) C-, 0 U C-, 0 r,6 8 10 Page 6
3phase Fault at Beaver 345kV Bus Trip DB-Beaver 345kV Line (4.5cy @Beaver, 22.5cy @DB) Machine Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.2 Davis-Besse, vt 1.1-] 1.01 0"9 0.8] 6-Davis-Besse, efd 4 2 0 Davis-Besse, pg 1 0- i -1000-1.03 Davis-Besse, spd 1 1.00 0.97 2=-, Davis-Besse, qg. 1000-2 0-~ 0 2 4 6 8 10 100-, Davis-Besse, ang 0 -J - Bay~shore #4. ang -50 -10o-J 0o. Beaver A, ang -I -100-i 0- Monroe #1, ang. * -100-j o2 Fermi #2, ang -50 I -100-i 0 2 4 6 8 10 o-Sammis #6, ang 4 -100.o 0 -, Eastlake #5, ang -50 -1001 0, Avon #9, ang Perry, ang -0ý -1001 0--0 Homer City, ang 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 27-APR-2000 09:02:16 chanfiles/dO_99s_r2 cO6xca 0 Page 1
Bus 0 2 4 6 8 10 Time (Seconds) 0 2 4 6 8 10 Time (Seconds) ' I I J l 0 2 4 6 8 10 Time (Seconds) 27-APR-2000 09:02:16 chanfils/d0_99s-r2_cO6.chan Page 2 3phase Fault at Beaver 345kV Bus Trip DB-Beaver 345kV Line (4.5cy @Beaver, 22.5cy @DB) Variables: (.J With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate - Davis-Besse 345, Vpu j*Monroe 1&2 345, Vpu Perry 345, Vpu 1.0 1.0 1.0 0.9-0.9-0.9 0.8 0.8-i 0.8 .-4 0.7 0.7-4 0.7 0.6-- 0.6 _, 0.6 1.1-Bayshore 345, Vpu . Monroe 3&4 345, Vpu 1.1 Carlisle. 345, Vpu 0.9 0.9-1 0.9 0.8-0.8-i 0.8 0.7-o.7-0.7 0.6-* 0.6-0.6 1.1, Lemoyne 345, Ypu .- Majestic 345, Vpu 1 1 Avon 345, Vpu 101.0 1.0] 0.9 0.9ý 0.9 0.0.8o.8, 0.8 0.7-0.7-0.7 0"6ý 0.6-0.6 1.1 Beaver 345, Vpu 1.1 N Brown 345, Vpu 1.1 - Star 345, Vpu 1.0-1.0-* - 1.0-" 0.9 0.9-0.9 0.8 -. 0.8 0.7 0.7 0.71 0.6f 0.61 0.6 ,.I Fostoria 345, Vpu o Fermi 345, Vpu 11 Harding 345, Vpu 1.0 0.9 0.9"1 0.9 0.8 0.8t 0.8 0.7j 0.7-0.7 0.6 0.6-1 06
3phase Fault at Beaver 345kV Bus Trip DB-Beaver 345kV Line (4.5cy @Beaver, 22.5cy @DB) Bus Variables: (_J With Uprate & STATCOM,-(...) With Uprate, (.-.) Without Uprate 1. Eastlake 138, Vpu 1.1_Beaver 138, Vpu 1 1 Wayne 138, Vpu 1.0 1.0 0.9 0.9-0.9-+ 0.8 0.8 o 0.7-0.7 0.6-- 0.6-0.6] 1.1-Juniper 138, Vpu 1.1 Bayshore 138, Vpu 1.1-N Brown 138, Vpu 1.0 1.0 1o.0.-. 0.9 0.90. 0.8 0.8 0.8+ 0.7- .71 0 -4 0.6-0.6-0.6-j -,Avon 138, Vpu 1.1 "Iemoyne 138, Vpu E Lima 138, Vpu 1.0-1.0 1.0 0.9-0.9 0.9-0.8-08.8 0.7-0.7 0.7 0.6-0.6 1 -. 1 Star 138, Vpu 1 -Fostoria 138, Vpu .- Allen 138, Ypu. 1.o-. 1.0 1.0 0.9 0.9 0.9-0.8-. 0.8-0.8 0.7 0.7. 0.7: 0.6-0.6-0.6. 1.- Carlisle 138, Vpu 11 Monroe 138, Vpu 1 1.,-Galion 138,.Vpu 1.0-1.0 1.0 0.9-0.9 - 09* 0.8 - 0.8-0.8 0.7-0.7A 0.7H 0.6-1 0.6 0.6 I I I ' I
- j' I
I i ' I 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) " -^rrK-,zuU 09.:02:1 lO¢lanfilestdO_99s_r2_cO6.chan Page 3
3phase Fault at Beaver 345kV Bus Trip DB-Beaver 345kV Line (4.5cy @Beaver, 22.5cy @DB) Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 SWGR A #2, vt 1.1 SWGR B #2, vt 1.0 1.0 0.9 0.9 0.8 0.8 0.7.. 0.7 0.6 -0.6 1 0o SWGR A #2, pg 10 SWGR B #2, pg 0 ---* 20 - SWGR A #2, qg o -20 SWGR A #2, it 0 1.00 SWGR A #2, spd 0.99 0.98 -4 0.97 - 0.95 I I i 0 2 4 6 8 10 Time (Seconds) 0 0 -10 20 SWGR B #2, qg 7 0 -201 5 7 SWGR B #2, it 4--1 2. 1 0 1.00 - SWGR B #2, spd 0.99 0.98 -J 0.97 0.96 0.95 I i 0 2 4 6 8 10 Time (Seconds) 27-APR-2000 09:02:16 chanfiles/dO_99sr2_cO6.chm Page 4
3phase Fault at Beaver 345kV Bus Trip DB-Beaver 345kV Line (4.5cy @Beaver, 22.5cy @DB) Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.- SWGR E6, vt 11-SWGR E3, vt !.1 SWGR D1, vt 1.0-1.-0 1.0 0.9 0.9 0.9 0.8 0.8 0.8 0.7 0.7- -0.7 0.6-; 0.6-- 0.6-] SWGR F6, Vt 1.1-SWGR E4, vt 1.1 SWGR F4, vt 1.0 1.0 1.0 0.9 0.9 0.9 0.8 0.8 0.8 0.7.7 0.7 0.6-- 0.6-0.6-] 1.1 SWGR El, vt 1 -SWGR C2, vt l SWGR F2, vt 1.0 1.0 1.0 0.9 0.9-0.9 0.8 0.8-0.8 0.7 0.7-0.7o 0.6 0.6-0.6 1.1 SWGR Fl, vt SWGR.Cl, Vt 1.1 SWGR F3, vt 1.0 1.0 " 1.01 0.9 0.9 0.9 0.8 0.8 0.8 0.7 0.7-0.74 0.6-0.6-0.6-J 1.1-SWGR E2, vt 1.1-SWGR D2, Vt 1.0-1 1.0.. 0.9-0.9 0.8 0.8 0.7-0.7 0.6_ 0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) "-1-7 ADD "nv, fl'., -&%K"w7:wz:IU CmUfIICwQV-Vw-r,4-CLPDA%= Page 5
3phase Fault at Beaver 345kV Bus Trip DB-Beaver 345kV Line (4.5cy @Beaver, 22.5cy @DB) STATCOM Variables: (,. With Uprate & STATCOM 1.1 1.0 0.9 0.8 0.7 0.6 5 3 2 1 0 Ii *1 150 110 70 30 -10 -4zn U .1 2 4 Time (Seconds) 27-APR-2000 09:02:16 chanfilIes/dO99os_r2_c06.chan 8 0 C.) 0 0 0. --,,1%J 10 Page 6 q 6
3ph, 4.5cy Fault at DB 345kV Bus, Trip DB-Bayshore 345kV Line & DB Unit, Transfer Aux Load DB-Lemoyne 345kV Line Out-Of-Service Pre-contingency Machine Variables: () With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 12_ Davis-Besse, vt 1.01 0.9 0.8 6-Davis-Besse, efd "4
- 2.
0-3ooo Davis-Besse, pg 2W-i 2000-* -4 1000 0 -1000-1 7 .3-,Davis-Besse, spd 1.00 0.97 2000- Davis-Besse, qg .J 1500 1000 500 01 0 2 4 6 8 10 Time (Seconds) 100o. avis-Besse, ang -100
- 0. Bayshore #4, ang
-100-0-4 Beaver A, ang -4 -100-j 0 - Monroe #1, ang. -50 -100]J 0, Fermi #2, ang 1 I1 1 ' 1 I 1' 1 0 2 4 6 8 10 Time (Seconds) 0. Sammis #6, ang -1001 0- Eastlake #5, ang
- 0. Avon #9, ang 1 4
-50", -100-: 0 - Perry, ang 1 -50* -J -I 1 -100o Homer City, ang .100 -J" I I 1 I 1 1 0 2 4 6 8 10 Time (Seconds) Page I 0 27-APR-2000 09:02:18 chanfiles/d1_99sr2_c07 ann
3ph, 4.5cy Fault at DB 345kV Bus, Trip DB-Bayshore 345kV Line & DB Unit, Transfer Aux Load DB-Lemoyne 345kV Line Out-Of-Service Pre-contingency Bus Variables: (.. With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate Davis-Besse 345, Vpu l Monroe l&2 345, Vpu t. Perry 345, Vpu 1.0 1.0 .1.0o 0.9 0.9 0.9-1 0.8 0.8 0.8-i 0.7 0.7 -i 0.7 0.6t o.6i 0.6 1.Bayshore 345, Vpu Monroe 3&4 345, Vpu ICarlisle.345, Vpu 1.0 1.0 1.0 0.9 0.9J 0.9 0.8 0.8-0.8 0.7 0.7-0.7 0.6-0.6-0.6]
- 1. 1 Lemoyne 345, Ypu I-J Majestic 345, Vpu
- Avon 345, Vpu 1.0' 1.0-1.0 0.9 0.9-ý 0.9 0.8 0.8~J 0.8 0.7-] 0.7-j 0.7-_ 0.7 0.6 0.6 1 0.6-i 0.6-i 1.1-Beaver 345, Vpu 1 1 N Brown 345, Ypu Star 345, Vpu
- 0
-1.0 -0.9 0.9-t 0.8o 0.8 0.8 0.7 0.7-0.7 0.6 0.6- ; 0.6 11 -Fostoria 345, Vpu Fermi 345, Ypu. Harding 345, Vpu 1.0 1.0 1.0 0.9-0.9 0.9 0.8 0.8--i 0.8-1 0.71 0.7-i 0.7 0.6 0.6 0.6 _ ' 'I 'i i i i 1 'I'I 1 * [ 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 27-APR-2000 09:02:18 chanfiles/d1_99s-r2_c0".cjan Page 2
3ph, 4.5cy Fault at DB 345kV Bus, Trip DB-Bayshore 345kV Line & DB Unit, Transfer Aux Load DB-Lemoyne 345kV Line Out-Of-Service Pre-contingency Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1 1 Eastlake 138, Vpu 1.0 _ 0.9 0.8 0.7 0.6 1.1 Juniper 138, Vpu 1.0 0.9--T 0.8 0.7-0.6 1.1-Avon 138, Vpu 1.0-I 0.9 0.8-: 0.7 0.6 1.1-Star 138, Vpu 1.0. 0.9-*4 0.8-0.7 0.6 1*1 Carlisle 138, Vpu 0.9 0.8 0.7--i 0.6-i I 0 I 4I i 8 I 1 0 0 2 4 6 8 10 Time (Seconds) 1.1-Beaver 138, Vpu Bayshore 138, Vpu 1.0 0.9 0.8 0.7 0.6
- 1. Lemoyne 138, Ypu 1.0 0.9 0.8S 0.7 0.6 1.1 Fostoria 138, Vpu 1.0 0.9 0.81 0.71 0.6-J
-Monroe 138, Vpu 0.9 -j 0.7* 0.6 I 2i 4 6*I 0 0 2 4 6 8 10 Time (Seconds) U, Wayne 138, Vpu 1.01 0.9 0.87 0.7 1.1 N Brown 138, Ypu 1.0* 0.9_4~ 0.7 0.6 E Lima.138, Vpu 1.0 0.9 0.7-0.6 1.1 - Allen 138, Vpu 1. 0.92 0.8 0.7 0.6 1 Galion 138, Vpu 0.9 0.9 0.7-1 0.6-1 I 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) 27-APR-2000 09:02:18 chanfiles/dl_99sr2_c07.chan 0 Page 3
3ph, 4.5cy Fault at DB 345kV Bus, Trip DB-Bayshore 345kV Line & DB Unit, Transfer Aux Load DB-Lemoyne 345kV Line Out-Of-Service Pre-contingency Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate SWGR A #2, vt 0.9 0.8 0.7 0.61 10 SWGR A #2, pg 0 - -10 20 - SWGR A #2, qg 0 -20 5 SWGR A #2, it 4 3 2 0 1.0 -SWGR A #2, spd 0.99 -* 0.98 0.97 0.96-0.95 0 2 4 6 8 10 1..., SWGR B #2, vt 1.0 0.9 - 0.6 - 1 0 -SWGR B #2, pg 0_ -10 2 0SWGR B#2, qg 0 5 SWGR B #2, it 4 ---. 3-1 2 I-ý- 0-1 1.00 , SWGR B #2, spd 0.98 0.97 - 0.96 0.95 -- 0 2 Time (Seconds) 4 6 Time (Seconds) 27-APR-2000 09:02:18 chanflles/dl_99s-r2_c07.xan Page 4 8 10
3ph, 4.5cy Fault at DB 345kV Bus, Trip DB-Bayshore 345kV Line & DB Unit, Transfer Aux Load DB-Lemoyne 345kV Line Out-Of-Service Pre-contingency Motor Variables: (__ With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 SWGR E6, vt 1.0 0.9 0.8 0.7 0.6f 1.1 SWGR F6, vt 1.0 0.9 0.8 0.7 0.6 1.-- SWGR El, vt 1.0 0.9 0.8 0.7 0.6 1.1-SWGR Fl, vt 1.0 0.9 0.8 0.7 0.6 1 1-SWGR E2, yt 1.0 0.9 0.8 0.7 0.61 0 2 4 6 I i 1 0 2 4 6 8 10 SWGR E3, vt 0.8 0.7-. 0.6 1.1 - SWGR E4, Vt 1.0 0.9 0.8 0.7 0.61 1.1 SWGR C2, vt 1.0 0.9 0.8 0.7 0.6f 1 1 .- SWGRC1,vt 1.0-0.9 0.8 0.7 0.6A 1 1..SWGRD2, vt 1.0-is 0.9 0.8 0.7 0.6 0 2 4 6 8 10 1.1-SWGR Dl, vt 1.0 6 0.9 0.8 0.7 0.6 1.1 -SWGR F4, vt 1.01 0.9 0.8 0.7 0.6 1l-SWGR F2, vt 1.0 0.9 0.8 0.7 0.6 1.1-SWGR.F3, vt 0.9 0.8 0.7 0.6-0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 27-APR-2000 09:02:18 chanfilesldlI _99sr2_cO7.chan 0 Page 5 0.9 L%
3ph, 4.5cy Fault at DB 345kV Bus, Trip DB-Bayshore 345kV Line & DB Unit, Transfer Aux Load DB-Lemoyne 345kV Line Out-Of-Service Pre-contingency STATCOM Variables: (L) With Uprate & STATCOM 1.1 0 rU 1.0 0.9 0.8 0.7 0.6 4 12 0 U' 2 1 0-- C,, 150 110 70 30 -10 -50 Jl I I I I I U 2 4 6 8 10 Time (Seconds) 27-APR-2000 09:02.18 chanfies/dl_99sr2_c07.chan Page 6 J
3phase Fault in Davis-Besse Circuit Breaker 34564 Trip DB-Lemoyne 345kV Line (4.5cy), Trip DB-Beaver 345kV Line (12cy) Machine Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1 _ Davis-Besse, vt i.0 0.9 0.8] j 6-/s-Besse, efd 4-: 2 0-: 3;ooop Davis-Besse, pg -4 2000ý,A-1000- -1000 1.03-, avis-Besse, spd 1.00 0.97-2M-o1 Davis-Besse, qg. 1500-- I II 0 2 4 6 8 10 0-100-1 avis-besse, ang 0 1 -100-1 0o Bayshore #4, ang -i0 -100 o-Beaver A, ang .50 N _100] 0- Monroe #1, ang -50 -Oi -100-s 0 Fermi #2, ang I77TT1 0 2 4 6 8 10 0o Sammis #6, ang -1 -1 -100 o-.Eastlake
- 5,. ang "1 _I
-i5 -1001 0 Avon #9, ang -so -1001 0o Perry, ang 2 -100* 0 Homer City, ang k -501 -100 °'-r-7 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:10 chanfiIes/d0_99sr2_cO8.chan Page 1
3phase Fault in Davis-Besse Circuit Breaker 34564 Trip DB-Lemoyne 345kV Line (4.5cy), Trip DB-Beaver 345kV Line (12cy) Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 11 -Dav* -Besse 345, Vpu I. Monroe 1&2 345, Vpu 1 1 Perry 345, Vpu 1.0-l jLm10 0i-0.9-0.9-0.9 0.8 0.8-0.81 03 0.7-! 0.7 0.6i 00.-6 1.1Bayshore 345, Vpu Monroe 3&4 345, Vpu 1.1 Carlisle 345, Vpu 1.0- ~~1.011. ... 10 0.9-0.9-0.9 0.8-o..8-o.8 0.7 0.7 - -
- 0.
0.7* 0.6 0.6-0.6 1.. Lemoyne 345, Ypu .Majestic 345, Vpu 11 -Avon 345, Vpu 1.0-10* 1.0-. 0.9-" 0.9 0.9 0.8-o.8i o.8 0.7-0.7] 0.7 0.6-1 0.6-i 0.6 1.1 Beaver 345, Vpu 1N Brown 345, Vpu 1.1 Star 345, Vpu 1.0 1.0 0.9 0 0.8.-J..j 0.8 -i. 0.8-0.7 - 0.7 0.7-' 0.6 0.0.6-7 .1.1 - Fostoria 345, Vpu H - Fermi 345, Vpu. Harding 345, Vpu 1.0 1.0 1.0-. 0.9-0.91-0.9 0.8 0.8-0.8 0.7-0.7 0.7 0.6A 0.6-0.6-' 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 STime (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:10 chanfiles/dO_99sr2_c08.chan Page 2
3phase Fault in Davis-Besse Circuit Breaker 34564 Trip DB-Lemoyne 345kV Line (4.5cy), Trip DB-Beaver 345kV Line (12cy) Bus Variables: (__ With Uprate & STATCOM,-(...) With Uprate, (.-.) Without Uprate H-Eastlake 138, Vpu 11 -Beaver 138, Vpu 11Wayne 138, Vpu .4 l~o-*- 1.0-1.o-0 1 0.9-0.9-" 0.9 0.8-0.87 0.8 0.7-0.7-7 0.7 0.6-0.6 -- 0.6-11 -Juniper 138, Vpu I1.,.Bayshore 138, Vpu . N B Own 138, Vpu 1.0-1.0. 1.0 0.9-0.9 0.8-0.8-0.8 0.77 0.7-0.71 0.6-0.6 0.6 1.1 Avon 138, Ypu Lemoyne 138, Ypu 1.1 E Lima 138, Vpu i)or 1.0-1..0, 0.9 0.9 0.9 0.8-0.8-0.8 0.7 0.7-0.7-J 0.6-0.6 0.6 1.1 Star 138, Vpu 1....Fostoria 138, Vpu 1 1.1-Allen 138, Vpu 1.0-J1.0 0.9-1 0.9-0.9 o.s
- o0.8-o.s-0.7 0.7]
0.7-] 0.6-0.6" 0.61' 1.1 Carlisle 138, Vpu Monroe 138, Vpu 11 Galion 138, Vpu 1.0-L.o 1.0 0.9-0.9 0.9-* 0.8 0 , 8 0.8 .7-o0.7 0.7 I-4 0.6__ 0.6-J 0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) '1rv4u., A ';y U~aUc/UYSJc~DnPg /.L/*r*-*14;Y: CU. H]'Icwd0UYvJ_9W'r cU*.(hw Page3
3phase Fault in Davis-Besse Circuit Breaker 34564 Trip DB-Lemoyne 345kV Line (4.5cy), Trip DB-Beaver 345kV Line (12cy) Motor Variables: C._) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1 --SWGR A #2, vt 1.0 0.9 0.7 0.6 -I 10 7 SWGR A #2, pg 20 SWGR A #2, qg -20 5 -1 SWGR A #2, it 3--1 2 1.0 -SWGR A #2, spd 0.99 0.98 0.97 0.96 0.951 0 2 4 6 8 10 Time (Seconds) I.' ,SWGR B #2, vt 0.9 o.8 0.7
- 0.6 -
10 - SWGR B #2, pg -10 20 SWGR B #2, qg 0 -20 5 SWGR B #2, it 4-i 0 1.0_ SWGR B #2, spd 0.998 0.98 0.97 0.96 0.95-0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:10 chanfiIes/dO_99sr2_cO.chan Page 4 a r/
3phase Fault in Davis-Besse Circuit Breaker 34564 Trip DB-Lemoyne 345kV Line (4.5cy), Trip DB-Beaver 345kV Line (12cy) Motor Variables: C_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate SWGR E6, vt 1..-.SWGR E3, vt 10-1 0.9-" 0.8 0.7 1
- 1. SWGR F6, vt 1.0 1 0.9:
0.8 o.7S 0.6-1 'A, 1 - SWGR El, vt 1.0 o.9 0.8 0.7 0.64 .-SW R FF, Vt 0.9 0.8 0.7 0.6 1 1.1 - SWGR E2, yt I ] III 0 2 4 6 8 10 Time (Seconds) 1.0 0.9 0.8-0.7 0.6-" A !.-SWGR E4, vt 087 1.01 0.9-" 0.8 0.7 0.6-1
- 1. 1-SWGR C2, vt 1.0 0.9 0.8 0971 os 0.64 1.1 SWGR C2, vt 1.0 0.9 0.8 0.7-i 0.6 l 1-SWGR D2, vt 1.0 0.9 0,8 0.7 a0.6-j
'[i7iT17 0 2 4 6 8 10 Time (Seconds) 1 --,SWGR D1, vt i.o 0.9 0.8 0.7 0.6 SWGR F4, vt 1.01 0.97 0.87 0.7 0.61 1.1 SWGR F2, vt 1.00"9. 0.1 0.97, 1.1 SWGRF3, vt 1.0 0.91 0.8-] 0.771 0.64 I I I I I I I I 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:10 chnfiles/d0_99s_r2_e08.cban 1.0 0.9 0.8 0.7 0.6-0 Page 5
3phase Fault in Davis-Besse Circuit Breaker 34564 Trip DB-Lemoyne 345kV Line (4.5cy), Trip DB-Beaver 345kV Line (12cy) STATCOM Variables: (.) With Uprate & STATCOM 1.1 1.0 0.9 0.8 0.7 0.6 I' 5 4 3 2 1 0 150 110 70 30 -10 -50 I I I I i i 1 U 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49-.10 chanfiesMd0_99s r2_c08.cha 0 CO 0 U F-0~ 0U Page 6 I
3phasellphase Fault near Davis-Besse 345kV Bus Trip DB-Bayshore Line (4.5cy), Breaker IPO Fails, Trip DB-Beaver Line (12cy) Machine Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.2-Davis-Besse, vt l.2-1.0-6 -- Davis-Besse, efd 4-2- 0 - 3.- Davis-Besse, pg. 2M 100-- 0 -1000-, 1.03-. Davis-Besse, spd 1.00 0.97-J 7 Davis-Besse, qg !.500 1000 500 0-I I 0 2 4 6 8 10 Time (Seconds) 100-i Davis-Besse, ang 0 0
- Bayshore #4, ang
-100-0-. Beaver A, ang -50 -100-I 0-, Monroe #I, ang. -50 0-.Fermni#2, ang -100-- 0 2 4 6 8 10 Time (Seconds) 0-, Sammis #6, ang. -50. i -100-: 0- Eastlake #5,. ang -4 -100-i 0 -Avon #9, ang 1 -50 .100-j
- 0. PeH.ry, anCg
-50 "~1 -100i o* HmerCity, ang 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:12 chanfiles/d0_.99sr2_c09.chan 0 Page I
3phase/lphase Fault near Davis-Besse 345kV Bus Trip DB-Bayshore Line (4.5cy), Breaker IPO Fails, Trip DB-Beaver Line (12cy) Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 Davis-Besse 345, Vpu 1.0 0.9 0.8 0.7 0.6-F 1 1 Bayshore 345, Vpu -4 "1.0 0.9 0.8 0.7 0.6-1.1-Lemoyne 345, Ypu 1.07 0.9 0.8 0.7 0.6 L.-Beaver 345,. Vpu 1.0 0.9 0.8 0.7j 0.6-t J1 -J Fostoria 345, Vpu 1.0 0.9 0.8 0.73 0.6 0 2 4 6 8 10 Time (Seconds) 1.1 Monroe 1&2 345, Vpt 1.0 0.9 0.8 o.7--1 0.6--' Monroe 3&4 345, Vpu 1.0 0.9 0.8 0.7-7 0.6 ,.I Majestic 345, Vpu 1.0 0.9 0.8 -J 0.7 0.6 _J 1.1 N Brown 345, Vpu 1.0 0.9 0.8 0.7-o.6 J 1.1 Fermi 345, Vpu 1.0 0.9 0.871 0.7-J 0.6-8 0 2 4 6 8 10 Time (Seconds) SI-. Pery 345, Vpu 1.0 0.8-4 0.7 0.6-! 1 Carlisle 345, Vpu 1.0-4. 0.9 0.8 0.7 -i 0.6 L. -,Avon 345, Ypu "1.0 0.9 0.8 0.7 0.6A 1.1Star 345, Vpu 1.0 0.9 0.8 0.7-1 0.6-1
- 1Harding 345, Vpu 0.94 0.8-*
o.74 0.6 2 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:12 chanfilesfd099sr2_c09.chan Page 2
3phaseflphase Fault near Davis-Besse 345kV Bus Trip DB-Bayshore Line (4.5cy), Breaker IPO Fails, Trip DB-Beaver Line (12cy) Bus Variables: (_..j With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 Eastlake 138, Vpu 1.1-Beaver 138,-Vpu .1 Wayne 138, Vpu 1.01-1.0 1.0 0.9-1 0.9-0.9 0.8-0.8-0.8 0.7-0.7-- 0.7-' 0.6-0.6-'-j i 1.1-Juniper 138, Vpu 1.1 Bayshore 138, Ypu
- 1.,N Brown 138, Vpu 1.0-1.0 1.0 0.9 0.9.
0.8-0.8 0.8-4 0.7-0.7 0.7H 0.6-j 0.6 0.6 1 Avon 138, Ypu 1.1 Lemoyne 138, Vpu 1 1 E Lima 138, Vpu 7 1 1.0-1.0-1.0 0.9 0.9-0.9 0.8-0.8 0.7-0.7-0.7 0.6 0.6-- 0.6-l 1.1Star 138, Vpu .Fostoria 138, Vpu 1.1-Allen 138, Vpu -1.0 1.0 0.9-- 0.9-0.9 0.8 0.8-0.8-"
- 0. 7 0.7 -
0.7 1 0.6-' 0.6-0.6 1. Carlisle 138, Vpu 1.1 1 Monroe 138, Vpu 1.1 Galion 138, Vpu 1.0i -1.0 .1.0 0.9 0.9 0.9 0.8 0.8 0.8 0.7-1 0.7-0.7 0.6-0.6-0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:12 chanfiles/dO_99sr2_co9.chan ,4 UW~ Page 3
3phaseflphase Fault near Davis-Besse 345kV Bus Trip DB-Bayshore Line (4.5cy), Breaker IPO Fails, Trip DB-Beaver Line (12cy) Motor Variables: () With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 -SWGR A #2, vt 1.o0 -- 0.9 0.8 0.7 0.6-10 SWGR A #2, pg 0 -1i 20 SWGR A #2, qg "-20 5 SWGR A #2, it 4 3 2-0 1.00 SWGR A #2, spd 0.98 0.97-i 0.96-* 0.95 0 2 4 6 8 10 Time (Seconds) 1.1 , SWGR B #2, vt ,-4 0.9 0.8 0.7 0.6 -- 10 SWGR B #2, pg -1 -I 0-7l -10 20 SWGR B #2, qg 0 .20 5 SWGR B #2, it 4 3 2 0-1._ SWGR B #2, spd 0.99 0.98 0.97 H 0.96 0.95 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:12 chanfiles/d0_99sr2 c09.chan Page 4
3phase/lphase Fault near Davis-Besse 345kV Bus Trip DB-Bayshore Line (4.5cy), Breaker IPO Fails, Trip DB-Beaver Line (12cy) Motor Variables: (-) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1-SWGR E6, vt 1.l-SWGR E3, vt l, SWGR D1, vt 1.0-1.0 1.0o 0.9-0.9-0.9 0.8-0.8-0.8 0.7 0.7 0.7 0.6F 0.6 0.6 11 SWGR F6, vt
- 1. 1 SWGR E4, vt 1.1 SWGR F4, vt 1.0 1.0 1.0 0.9-0.9-0.9 0.8-0.8-0.8 0.7-0.7-0.7 0.6 0.6 0.6 1.1.SWGR El, vt 11 SWGR.C2, vt 1 1-SWGR F2, vt 1.0-1.0.
1.0 0.9-0.9-0.9 0.8-0.8-0.8S 0.7-0.7-0.7 0.6£ 0.6 0.6F 1.1 SWGR F1, Vt .,SWGR Cl, vt
- 1. SWGR F3, vt 1.0 1.0-
- 1.
0.9-0.9-0.9 0.8-0.8 0.8 0.7-0.7-0.7 0.6-0.6F 0.6 1.1 SWGR E2,vt 1-SWGR D2, vt 1.0 .1.0 0.9-0.9 0.8 -. 0.8 - 0.7-0.7 0.6 - 0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) Page5 -'O-APRK-2000I 14-49:12 chanfihls/dO_99_r2_cO9han
3phase/lphase Fault near Davis-Besse 345kV Bus Trip DB-Bayshore Line (4.5cy), Breaker IPO Fails, Trip DB-Beaver Line (12cy) STATCOM Variables: (,j With Uprate & STATCOM 1.1 1.0 0.9 0.8 0.7 0.6 5 4 3 2 1 0 13U3-110 i 110 -H 70 30 -10 -50 I I 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:12 chanfImsld099sr2_cO9.dc Page 6 0 Q 0 f-q 0 U.
No Fault Trip Davis-Besse Unit Machine Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 14 Davis-Besse, vt 1.I1
- .O -'
1.0* 0.9 0.8 Davis-Besse, efd 4 7 2 0-* 3.- Davis-Besse, pg. 20 1000 01 -1000 03_Davis-Besse, spd 0.97 M_ Davis-Besse, qg. 1500] 500-4 01 I I 0 2 4 6 8 10 Iooj avis-Besse, ang 0 -100-o Bayshore #4, ang -5 -100-1 Beaver A, ang 0I -100o Monroe #1, ang. ii 0-, Fermi #2, ang .50-1 -100-j 0 2 4 6 8 10 07 Sammis #6,.ang. 4 1 .50-7 -100 o-Eastlake #5,. ang -4 -4 -100-0 - Avon #9, ang -5 -5o10i - .100-9 _ Perry, ang -100 0-, Homer City, ang -lw 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:14 chanfiles/dO_99sr2_1.cIhne 0 Page I
No Fault Trip Davis-Besse Unit Bus Variables: (.. With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1 -1 Davis-Besse 345, Vpu 1 1 -- Monroe 1&2 345, Vpu Perry 345, Vpu 1.0-? 1.0-1.0 0.9 o.9j 0.9H 0.8-0.8-. 0.8s 0.7-0.7-- 0.7-i 0.6 - 0.6-0.6 1.1 Bayshore 345, Vpu 1.1 Monroe 3&4 345, Vpu .I Carlisle. 345, Vpu 1.01.0---. 1.0 0.9-0.9-0.9 0.8 D8 0.8 0.7 0.7 -i 0.7 0-6* 0.6--. 1 _* 1,Lemoyne 345, Vpu 1.1 - Majestic 345, Vpu .1-Avon 345, Vpu 1o-f I0 1.0 0.9-0.9i 0.9-H 0.8-0.8-0.8 0.7-- 0.7 0.7 0.6 0.6-' 0.6-'
- 1. 1 Beaver 345, Vpu
.1-N Brown 345, Vpu lI]Star 345, Vpu 0.9-. 0.9-4 o.9 -4 0.8-70.8-
- 0.
0.7 1.0.7 0.7 0.6 -. 0.6-0.6 J .1 -Fostoria 345, Vpu 1.1 Fermni 345, Vpu I., Harding 345, Vpu 0.. "1 -_1.0_. 0.9-1, 0.9-0.97 0.8" 0.8 0.- 0.7-10. 0.6 0. 6 -J.06 I~~~ ~~ F7 -7 'j 0 2 4 6 8 1 2 4 6 8 10 2 4 6 8 10 D Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49-14 cbanfiIes/d0 99sr2 c10.chan Page 2
No Fault Trip Davis-Besse Unit Bus Variables: (L) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1 Eastlake 138, Vpu ._-Beaver 138, Vpu 1 -Wayne 138, Vpu 1.0o4 1.0 P 0.9 .9-0.9-1 0.8-0.8-0.8-J 0.7 0.7-- 0.7-1 0.6-0.6-0.6* .1 -Juniper 138, Vpu 11 Bayshore 138, Vpu 1*-*N Brown 138, Vpu 1.0-
- 1.
0.9-0.9-1 0.9 0.8-o.8* 0.8 0.7-0.7o 0.7 0.6-' 0.6-J 0.6A 1.1--.Avon 138, Vpu 1.Lemoyne 138, Vpu 1.1-E Lima.138, Vpu -10 1.0-- I.O-- 1.0
- 0.9-0.9 -
0.9-i 0.8-i 0.8-. 0.7-7 0.7 0.7 0.6-0.6-'
- 1. -Star 138, Vpu 1..- Fostoria 138, Vpu 1 -Allen 138, Vpu o.10-o 0.0.9-.9-0.9-.
0.8-00-o.8-, 0.7-i 0.7-i 0.7 A 0.6-0.6-'o.6 Carlisle 138, Vpu 1.1 Monroe 138, Vpu 1., Galion 138,.Vpu 1.0 o 1.0] 0.9, 0.9 0.9-ý 0.O. 8 i 0.81 0.7 I. 0.7-1 0.7 0.6-= 0.6--- 0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) AALP-j*r%=zUWJ UU=y 1 ICaI[II*U_YYS rz_CjUx= Page3
No Fault Trip Davis-Besse Unit Motor Variables: (_) With Uprate & STATCOM,(...) With Uprate, (.-.) Without Uprate 1.1 SWGR A #2, vt 1.SWGRB#2,vt 1.01.0 0.9 - 0.9 0.8-0.8 0.7 -. 0.7 0.6-0.6-1o SWGR A #2, pg 10 SWGR B #2, pg 0-0 2o fSWGR A #2, qg 20 SWGR B #2, qg 0 0 -] 4 j .J -20 5 SWGR A #2, it 5 SWGR B #2, it 4-- 4.__ 3-_. 3 2-2 1 0" 00 1.00 SWGR A #2, spd L.O SWGR B #2, spd 0.9 -j. 0.991 0.98 0.98 0.97 0.97 0.96 -0.96 0.95 0.95 0 2 4 6 8 10 0 2 4 6 8 10 e (Seconds) Tim e (Seconds) 26-APR-2000 14:49:14 chanfiles/d0 99s r2_el0.chan Page 4
No Fault Trip Davis-Besse Unit Motor Variables: (.) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate .- SWGR E6, vt 1.1 SWGR E3, vt 1.--,SWGR Dl, vt 1.0* 1.0 1.0 0.9m 0.9ý 0.9 0.8-0.8-0.8" 0.7-0.7-0.7-' 0.6 0.6-0.6 1 -SWGR F6, vt - SWGR E4, vt SWGR F4, vt 1.0-4_ 1.0- "0 0.9-0.9-i 0.9-, 0.8 0. 8 0.7-0.7-i o.74 0.6-0.6-' 0.6 1.1-SWGR El, vt 1.1*SWGR C2, vt 11-1 SWGR F2, vt 1.0-f 1.0J-10 0.9-, 0.9-0.9 0.8-0.8-0.8 0.7-0.7-- 0.7-i j 0.6-0.6-06 SWGR F1, vt 1.1-SWGR C1, vt 1.1-SWGR F3, vt 1.0 1.0-t 1.0__ 0.9-0.9+ 0.9 0.8-0.8-o.8-j 0.7-; 0.7-0.7 0.6-1 0.6-- 0.6 SWGRE2,vt 1.1 SWGR D2, vt 1.0-1.0-1 0.9-0.91 01 0.8 -i 0.77-. 0.6-0.6 i ~ ' ~ 'i l I [ I I ' I' , I ' 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 2.O-AU'm-/Mm 14:49):14. chaunnlesfo_99_r2_cIOc*lai Pag 5
No Fault Trip Davis-Besse Unit STATCOM Variables:._ With Uprate & STATCOM 1.1 -i 1.0 I 0.9 0.8 - 0.7 d1 4-7 3 -4 2~~ 0 Il 0 I 4 0 2 4 6 8 1 Time (Seconds) 26-APR-2000 14:49:14 chanflIes/d0_9s_r2_cO.chan 0 C-)2 0.6 0 COD 0 0./ 150 110 70 30 -10 -50 ) Page 6 A*
Machine Variables: 3phase Fault in Davis-Besse GSU Transformer Trip Davis-Besse Unit () With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.2-Davis-Besse, vt 1* -£2. 1.1-1.0 0.9 0.8f 6-Davis-Besse, efd 4 0 3000- Davis-Besse, pg. 2000 1000 0 .1000 1.03-Pavis-Besse, spd 0.97 2ooM-Davis-Besse, qg 1500ý- 0 2 4 6 8 10 Time (Seconds) 1ooj )avis-Besse, ang 0 .1oo-J 0. Bayshore #4, ang 1 -, Beaver A, ang 0- Monroe. #1, ang -loi -50 -100--j o-, Fermi #2, ang -10j i 1 I 1 ! I i I ; I 0 2 4 6 8 10 Time (Seconds) o7 Sammis #6, ang -i -so' -4 -IOO- - Eastlake #5, ang -J - 1 00 J Pey Avon #9, ang 7 -50 -100] 0 - Perry, ang 2 -50 _100] 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:15 chanfiles/d0_99sr2_cl1.chan 0 Page I
3phase Fault in Davis-Besse GSU Transformer Trip Davis-Besse Unit Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1 _Davis-Besse 345, Vpu l 1 Monroe
- l&2 345, Vpu 1.1 Perry 345, Ypu 1.0-1.0 1.0 0.9 0.9-09 0.8-0.8 0.8 0.7-0.7-0.7 0.61 0.6-:
0.6J 1.1-Bayshore 345, Vpu LI Monroe 3&4 345, Vpu 1.1 -,Carlisle 345, Vpu 1.0-1.0 1.0! 0.9-0.9 0.9 0.8-0.8 - 0.8 0.7 .70.7 0.6-. 0.6-0.6-' l.- Lemoyne 345, Vpu 1. Majestic 345, Vpu l1-Avon 345, Vpu 1.0 1.0 1.0 0.9 0.9 0.9 0.8 - 0.8 - 0.8 0.7 0.7-. 0.7 0.6 0.6 0.6 -Beaver 345, Vpu 1.1-N Brown 345, Vpu L Star 345, Vpu 10
- 1.
1.0. 0.9 0.9 0.9 0.8 0.8 0.8A 0.7 0.7 0.7 0.6-1 0.6-0.61 1 1 Fostoria 345, Vpu 1 Fermi 345, Vpu Harding 345, Vpu 1.0 1.0 1.0-i 0.9 0.9 0.9 0.8 0.8_ 0.8 0.7 0.71 0.7 0.61* 0.6-i 0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 STime (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:15 chanfiIes/d0_99sr2_c l.chan Page 2
3phase Fault in Davis-Besse GSU Transformer Trip Davis-Besse Unit Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.Eastlake 138, Vpu 1 1 Beaver 138, Vpu I1.,-Wayne 138, Vpu 1.0-- 1.0 1.0 0.9-0.9 0.9 0.8-0.8 0.8---: 0.7 -
- 0. 7-
- 0. 7 0.6-0.6-0.6 j
-Juniper 138, Vpu .I_ Bayshore 138, Ypu 1.1-N Brown 138, Ypu 1.0-1.0- .0 o9 0.9 0.8-0.8 0.8-1 0.7_- 0.7-0.7 0.6-0.6 0.6 1.1 -Avon 138, Vpu ,.1* Lemoyne 138, Vpu 1.1,E Lima 138, Vpu 1.0l 1.0
- 0.
0.9 0.9 0.8-0.8 0.8 0.7-0.7 0.7 0.6-- 0.6 0.6-] 1.1-Star 138, Vpu 1 1 Fostoria 138, Vpu 1 -Allen 138, Vpu 1.0-1.0-1.0-, 0.9-- 0.9-0.9 0.8-0.8-0.8 0.7 0.7-0.7 0.6-1 0.6-0.6 1.1 Carlisle 138, Vpu 1.1_Monroe. 138, Vppu lGalion 138, Vpu 1.0-1.0 -. 0" 0.9 0.9 0.9" 0.8 0.8-0.8 0.7 o.7-7 0.7 0.6-0.6-0.6A 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:15 chanfiles/dO_99sr2_¢c lthan Page 3
3phase Fault in Davis-Besse GSU Transformer Trip Davis-Besse Unit Variables: () With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 SWGR A #2, vt
- 1.
1 SWGR B #2, vt 1.0 - r 1.o-0
- 0.9 0.9 0.8 0.8 0.7 0.7 0.6 --
0.62 10SWGR A #2, pg 10 SWGR B #2, pg 5 -10 -* - SWGR A #2, qg -4 _SWGR A #2, it 0m -20 5 4 3 2 1-0- 1.00 SWGR A #2, spd 0.97 0.98 0.97 0.9 0-
- 20 -- SWGR B #2, qg
._1 0 -20 5 SWGR B #2, it 4-3 2 0 1.00 SWGR B #2, spd 0.98 0.97.. 0.961 0.95 - 0 2 4 6 8 10 Time (Seconds) 0 2 4 6 Time (Seconds) 26-APR-2000 14:49:15 chanfilesdO_99sr2cI I.chan Motor 0- -10 20-8 10 Page 4 I1--
3phase Fault in Davis-Besse GSU Transformer Trip Davis-Besse Unit Motor Variables: (..) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate - SWGR E6, vt z-SWGR E3, vt SWGR D1, vt 1.0-1.0- r. 0.9 0.9-0.9 0.8-0.8-0.8 0.7 0.71 0.7 0.61 0.6 0.6 1.- SWGR F6, vt 1.1 SWGR E4, vt 1.- 1SWGR F4, vt 1.0 1.0-1.0 0.9 0.9-0.9 0.8 0.8-0.8 0.7 0.7 0.7 0.6 0.6 0.6 1.17 SWGR El, vt 11.- SWGRC2, vt 11 SWGR F2, vt 1.0-T.0 1.0o 0.9 0.9-0.9 0.8-0.8-0.8 0.7-0.7-0.7 0.6-0.6-1 0.6 1.- SWGR F1, vt
- 1. SWGR C1, Vt
- SWGR F3, vt 1.0-1.0-1.0-0.9 0.9-0.9 0.8-0.8-0.8 0.7-0.7-0.7 0.6-0.6 0.6 SWGR E2, vt 1.1 SWGR D2, vt 1.0-1.0- r 0.9 0.9 0.8-0.8 0.7-0.7 0.6-0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 2.6-,qP'-2UUU 14:49:15 chnfIcsfdOe/0_99s12_cII.¢];an Page 5
3phase Fault in Davis-Besse GSU Transformer Trip Davis-Besse Unit STATCOM Variables: (._.) With Uprate & STATCOM 1.1 4 3 in 150 f-1 110 - 70 30i -10 -50 I I I 2 4 6 8 0 Time (Seconds) 26-APR-2000 14:49:15 chanfiles/dO_99sr2_cl.chan 0 H H 0, 1.0 0.9 0.8 0.7 0.6 5 0 Q H* 2 1 0 0 0 U H H 0, 10 Page 6
Machine Variables: (_) 3phase Fault in Fermi GSU Transformer Trip Fermi Unit With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 12.2 Davis-Besse, Vt 1.1 1.0 0.9T 0.8-' 6 - Davis-Besse, efd 4 2 0 3000_ Davis-Besse, pg. 2000 100 -10 00 --i 1.03-, Davis-Besse, spd 0.97 2000 Davis-Besse, qg 1500-i J 1000-1 0-i 0 2 4 6 8 10 Time (Seconds) 100 o Davis-Besse, ang 0- -100-o-Bayshore #4, ang o0 Beaver A, ang -4. A -100 o-*Monroe #1, ang. 4 1 -4 -100 0oFermi #2, ang -4 i 0 2 4 6 8 10 Time (Seconds) 0-. Sammis #6,.ang -50 .100 0- Eastlake #5, ang -50 .100.. 0-7 Avon #9, ang -J -50~ -100-j o_ Perry, ang 2 -4 _1 J -100 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:17 chanfile/dO_99sr2_ci2.chan Page I
- CGO,
3phase Fault in Fermi GSU Transformer Trip Fermi Unit Bus Variables: (.. With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.-.-.Davis-Besse 345, Vpu ,-Monroe l&2 345, Vpu 1.- Perry 345, Vpu 1.0 1.0 1.0 0.9 0.9 0.9 0.8 0.8 0.8 0.7-0.7 0.6-0.6-0.6-J 1.1 Bayshore 345, Vpu Monroe 3&4 345, Vpu I., Carlisle 345, Vpu 1.0 1.0 1.0 0.9 0.9 0.9 0.8 0.8 0.8-1 0.7 0.7 0.7. 0.6-J 0.6-0 1.1 -,Lemoyne 345, Vpu I-, Majestic 345, Vpu .I:Avon 345, Vpu 1.0 1.0 0.9 0.9 0.9 0-.-8 ' 0.0.8.8 0.7 -
- 0.
0 0.6-' 0.6 _ Beaver 345,. Vpu 11-*N Brown 345, Vpu -1 Star 345, Vpu 1.0-! .0 0.9 0.9 0.9H 080.8.8 0.8-1i 0.7-j 0.7 0.7 0-'5 0.6 0.6 11-Fostoria 345, Vpu 1.1-- Fermi 345, Ypu. Harding 345, Vpu 1.0 1.0-
- 1.
0.9
- 0.9 0.9 0.8 0.8-0.8*
07 0.7-0.7 0.6 0.6 0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:17 chanfies/d099szt2_c12.chan Page 2
3phase Fault in Fermi GSU Transformer Trip Fermi Unit Bus Variables: C-) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 Eastlake 138, Vpu 1 1. Beaver 138, Vpu 1.1 Wayne 138, Vpu 1.0-1.0 0.9-0.9-0.9 0.8-0.8-' 0.8 0.7-0.7-0.7 0.6-0.6-- 0.6 1.1 - Juniper 138, Vpu Bayshore 138, Ypu .1 N Brown 138, Vpu 1.0-1.0 1.0 0.9-0.9 0.9 0.8-0.8-0.8 0.7 ' 0.7-1 0.7 -1 0.6-0.6-0.6-a 1.1-Avon 138, Vpu 1.1 Lemoyne 138, Vpu E Lima.138, Vpu 1.0-1.0 .0 0.9-0.9 o.9 0.8-0.8 0.7-- 0.7-0.6-0.6-1 0.6-1 1.1 Star 138, Vpu 1 1 Fostoria 138, Vpu 11 Allen 138, Vpu 1.0-' 1.0 1.0 0.9-7 0.9 0.9 0.8-1 0.8 0.8 o.71 0.7H 0.7 0.6- - 0.6-0.6-1.1-Carlisle. 138, Vpu
- l.
Monroe 138, Vpu 11 Galion 138, Vpu 1.0-1.0-1.o o9*- 0.9 0.9 0.8-7 0.8-0.8 0.7-0.7-0.7] 0.6.- 0.6-0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:17 chanfiles/d0_99s_rc12.ch2an Page 3
3phase Fault in Fermi GSU Transformer Trip Fermi Unit Motor Variables: (.) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 --SWGR A #2, vt ASWGR B #2, vt 1.0 1.0 0.9 0.9 0.8 - 0.8-i 0.7 0.7 0.6 0.6 10 - SWGR A #2, pg 10 SWGR B #2, pg -0j o -0.A ~ 20 SWGR A #2, qg 0 J 5 SWGR A #2, it 4 2 -J I 0 i.oo SWGR A #2, spd 0.99 - 0.98 -* 0.97-0.96% 0.951 0 2 4 6 8 10 Time (Seconds) -10 20 SWGR B #2, qg 0 -4 -20 5 SWGR B #2, it 27 I o, 1.00SWGR B #2, spd 0.98 0.97 0.96 - 0.95 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:17 chanfiles/d099s-r2_c12.han Page 4
3phase Fault in Fermi GSU Transformer Trip Fermi Unit Motor Variables: (.) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate SWGR E6, vt 1 -SWGR E3, vt 1 -SWGR D1, vt 1.0 1.0110 0.9-0.9 0.9 0.8-0.8-0.8-, -l 0.7-0.7-0.7 0.6-0.6-- 0.6 1.1-SWGRF6, vt 1.1-SWGR.E4, vt 1.1 SWGR F4, vt 1.0-
- 1.
1.0 0.92 0.9 0.9 0.8-: 0.8 0.7-0.7-0.7 0.6-0.6-- 0.6 1.1 SWGR El, vt 1 SWGR C2,vt 1 -, SWGR F2, vt -4 -4 1.01(-. 1.01r 1.0 0.9 0.9 0.9 0.8-0.8 0.8-11 0.7-0.7-0.7 60.7 0.6-0.6-' 0.6-' 11-SWGR F1, vt 1.1 SWGR C1, vt 1 SWGR F3, vt 1.- 1.0 1.o 0.9 -7 0.9 -- 0.9 0.8-* o.8 -i o.8 0.7-0.7-07 0.6-0.6-' 0.6-' E1-SWGR E2, vt 1.1-SWGR D2, vt 1.0-1.0 0.9-0.9-9 0.8-' 0.8 0.7-o0.7- ' 0.6-] 0.6 S' I ' ii i
- i i '
i 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) '11 AD nn ff ~l. .rfan UII.SAJI~I 1 a U c U YC~falPg p~ag 5
3phase Fault in Fermi GSU Transformer Trip Fermi Unit STATCOM Variables: __.) With Uprate & STATCOM 1.1 -- 1.0 0.9 0.8 0.7 0.6 5 4+ 3J IJI0 110 70 30 -10 -I0 0 2 4 6 8 Time (Seconds) 26-APR-2000 14:49:17 chanfilesfdO_99s r2_cl2.chan 5-0 CI 2 1 0 I Cd'l 0 EU F CO' 10 Page 6 --JV
No Fault Trip Bayshore-Monroe 345kV Line & Lemoyne-Majestic 345kV Line Machine Variables: (-. With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.2-Davis-Besse, vt 1.1"- 1.0 0.9 0.8 6-Davis-Besse, efd 4-] 2 0-300ooDavis-Besse, pg. 2000 1000~ - 0 -1000-: L.03-Davis-Besse, spd ~1 1.00 0.97 2000-, Davis-Besse, qg. 1500 1000-500-i J4-0 2 4 6 8 10 Time (Seconds) 100 -Davis-Besse, ang 0-= -100-0- Bayshore #4, ang "-J -100-1 o-J Beaver A, ang 1* -I -4 -100
- o. Monroe. #1, ang.
7 1 j -100-i 0 - Fermi #2, ang -i -100 0 2 4 6 8 10 Time (Seconds) 0-, Sammis #6, ang ; -100 o-Eastlake #5, ang J -10 0-i o0- Avon #9, ang -100-o0 Perry, ang -501I -100 i o-Homer City, ang - 10 0 -i 0 I I 6 8 10 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:18 chanfiIesId0_99sr2_c13.chan 0 Page I
No Fault Trip Bayshore-Monroe 345kV Line & Lemoyne-Majestic 345kV Line Bus Variables: C_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate .-- Davis-Besse 345, Vpu 1.- Monroe 1&2 345, Vpu .-, Perry 345, Ypu 1.0 1.o-- 1.0 0.9-0.9--' 0.9-i 0.8-0.8 0.8-' 0.7-0.7- .7 0.6-0.6-. 0.6-' 1.1-Bayshore 345, Vpu Monroe 3&4 345, Vpu C - Carlisle 345, Vpu 1.0 1.0-1.0-0.9 0.9-- 0.9' 0.8 -1 o0.8-0.8 0.7-0.7 0.7-1 0.6-0.6 0.6 .- Lemoyne 345, Vpu 1.1-Majestic 345, Vpu Avon 345, Vpu 0.9-0.9-0.9 0.8-1 0.8 0.8 0.7-0.7-0.72 0.6-' 0.6 -- 0.6 ,.--,Beaver 345,.Vpu 1.1 N Brown 345, Ypu I.,- Star 345, Vpu l.0-1.0 0.9 0.9-4 0.9 0.8-A 0.8-0.8 0.7-0.7" 0.7 -1 J 0.6-: 0.6-0.6 1.1-Fostoria 345, Vpu Fermi 345, Vpu 1.1 Harding 345, Vpu 1.0-, 0.9 0.9H-0.9 0.8 0.8-0.8 .4 -{ 0.7-1 0.7-1 0.7 0.6-0.6 0.6-' I T_ 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 STime (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:18 chanfilesdO_99s r2_cl3.chan Page 2
No Fault Trip Bayshore-Monroe 345kV Line & Lemoyne-Majestic 345kV Line Bus Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 Eastlake 138, Vpu 1.Beaver 138, Vpu 1 1 Wayne 138, Vpu 1.o-] 1.0 - 1.0 0.94 0.9-1 0.9 0.8-0.8-0.8-1 0.7-0.7-i 0.7 0.6-* 0.60.6 - Juniper 138, Vpu - Bayshore 138, Vpu 1.1 N Brown 138, Vpu 1.0-1.o-b I.o 0.9-0.9i 0.9 0.8-0.81 0.7-0.7-, 0.7 0.6-1 0.6-' 0.6
- 1. Avon 138, Vpu 1_ Lemoyne 138, Vpu 1.1 E Lima 138, Vpu 1.0-*
1o-4 1.0o 0.9-, 0.90.9 0.8-0.8* 0.8 0.7-1 0.7-0.7 0.6-0.6-11 Star 138, Vpu 1* - Fostoria 138, Vpu - Allen 138, Vpu 11.0-10 0.9-0.9A-- 0.9] 0.8-, o0.8 0.87 o.'0.7on* 0.7 -i 0.6-: 0.6-11 Carlisle 138, Vpu Monroe 138, Vpu 1 Galion 138, Vpu 1.0 1.0 1.0 0.97 0.9 0.9-J 0.80.8-0.8 0.7 0.7-_ 0.7 0.6-0.6-] 0.6 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) ')e-ADDf1
- 0 lq a~auciuys~
anPg
- vrr-ZbUW 14.4:1a:
c, hannesd0_9n_r2_cI3.chlan Page 3
No Fault Trip Bayshore-Monroe 345kV Line & Lemoyne-Majestic 345kV Line Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1 SWGR A #2, vt 1.1 SWGR B #2, vt 1.0 1.0 0.9 0.0.9 0.8 - 0.8 0.7 0.7 0.6 - 0.6 -* 1 0 -, SWGR A #2, pg 10 SWGR B #2, pg 7"1 0 o-] 4,i 20 - SWGR A #2, qg 0 1 -20 SWGR A #2, it 4 3 2 0 1.. -SWGR A #2, spd 0.99 0.98 j 0.97 0.96 0.95 0 2 4 6 8 10 Time (Seconds) A -10 20 - SWGR B #2, qg -6 5 - SWGR B #2, it 4* 3 2 1 -J 1.00 SWGR B #2, spd 0.99 0.98 0.97 - 0.96 0.95 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:18 chanfiles/d099s-r2 cl3.ch=n Page 4
No Fault Trip Bayshore-Monroe 345kV Line & Lemoyne-Majestic 345kV Line Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 11 SWGR E6, vt SWGR E3, vt 1 1 SWGR D1, vt 0.9-0.9-- 0.9 0.8-0.8-0.8 0.7-: 0.7-0 = J 060.6-0.6 1.1 SWGR F6, vt 1 -SWGR E4, vt 1.1 SWGR F4, vt 1.0-4IO-.- 1.0--L 0.9-4 0.9-1 0.9-, 0.8-0.8-, 08-' 0.7-0.7--] 0.7 0.6-' 0. 0.6 1 -SWGR El, vt SWGR.C2, vt SWGR F2, vt 1.o-*-1.o-F 1.0 1.0-1.0 -1 0.9-0.97 0.9 0.8 0.87
- 0.
0.7-H7 0.6ý 0.6-0.6 J.6 lJ-SWGR Fl, vt 1.1-SWGR Cl, vt 1.1 SWGR F3, vt 0.9* 0.9-i 0.9 0.8 0.8 0.8 o.7-o 0.70. o.0 0.6-. 01.61 1.17 SWGR E2, vt 1.1-SWGR D2,.vt 1.0 -4 N 1.0 0.9 - 0.9 0.8-0.8 0.7 07 0.61 0.62 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) 26-APR-2000 14:49:18 chanfilestd0_99sr2_c13.chan Page 5
No Fault Trip Bayshore-Monroe 345kV Line & Lemoyne-Majestic 345kV Line STATCOM Variables: (L) With Uprate & STATCOM 1.0 0.9 0.8 - 0.7 - 0.6 4 3-i 2 150 110 70 30_ -10 -50 J 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:18 chanfiles/d0_99s-r2_c13.chan Page 6 0 Q C-, 0 F C-, U 0 0 U F F C-,
lphase Fault on 2 Lines near Lemoyne 345kV Bus Trip Bayshore-Fostoria 345kV Line & Lemoyne/Fostoria 345kV Line Machine Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate .2-Davis-Besse, vt l.l-H 1.0 0.9 0.8 6-Davis-Besse, efd 47 2 0-3000, Davis-Besse, pg 2000-ý IW O1 -1000 103-Davis-Besse, spd 1.00 k - 0.97-* Ao Davis-Besse, qg 2-4 1500 1000 500-0 2 4 6 8 10 Time (Seconds) 100- Davis-Besse, ang "1 .J 0- -100-o0- Bayshore #4, ang -IO -5 0 -_ .100-j 0-. Beaver A, ang _j J7 J, I -I00I FeMormi #2, ang. .1 4 i0 -100-i I , !,I 0 2 4 6 8 10 Time (Seconds) 0o 1Sammis #6, ang -s0-- -I00 -100-j 07 Easlake #5, ang 4 -50 -10 0 -i Avon #9, ang -50 -I00-j 0 . Perry, ang -s "-100i 0] Homer City, ang -100--1 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:20 chaniIesfd0._99s_r2_14.chan 0-0 Page I
1phase Fault on 2 Lines near Lemoyne 345kV Bus Trip Bayshore-Fostoria 345kV Line & Lemoyne/Fostoria 345kV Line Bus Variables: (_) With Uprate & STATCOM, (..) With Uprate, (.-.) Without Uprate 1.- Davis-Besse 345, Vpu .-,Monroe.l&2 345, Vpu ., Perry 345, Vpu 1.0 1.0 1.0o 0.9 0.9 -i 0.9-j 0.8-, 0.8-0.8 0.7-0.7-4 0.7 0.6-1 0.6-' 0.6-1 1.1 Bayshore 345, Vpu Monroe 3&4 345, Vpu .I Carlisle. 345, Vpu 0.9 0.9-1 0.9 0.8-0.8 -i 0.8 -J 0.7-0.7-7 0.7 0.6 0.6-.6J 1.1 Lemoyne 345, Ypu
- 1. Majestic 345, Vpu
- 1.
- Avon 345, Vpu 1.0 LT10 -I 0.9 0.9-i 0.8 0.8-7.8-0.7*
0.7-1 0.7 0.6-0.6-0.6 1 Beaver 345, Vpu N Brown 345, Vpu Star 345, Vpu 1.0-1.0. 1.0.. 0.9-0.9. 0.9-'
- 0.
0.8-i 0.8 0.7-1 0.7
- 0.
0.6-1 0.6-' 0.6 1.1 - Fostoria 345, Vpu Fermi 345, Ypu 1 Harding 345, Vpu
- .0 1.0-f.
1.07 0.9 0.9 0.9 0.81 0.8-0.81 0.7 -] 0.7 -i 0.7-i 0.7-I 0.6-- 0.6-- 0.61 0 2 4 6 8 10 Time (Seconds) 0 2 4 6 8 10 Time (Seconds) 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:20 chanfies/d0._99sr2_c14.chan Page 2
lphase Fault on 2 Lines near Lemoyne 345kV Bus Trip Bayshore-Fostoria 345kV Line & Lemoyne/Fostoria 345kV Line Bus Variables: (_. With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1.1*Eastlake 138, Vpu 1.0-* 0.9 0.8 0.7 0.6 1.1 Juniper 138, Vpu 1.0 0.9 0.8 0.7-, 0.6 1l. Avon 138, Ypu 1.0 -.1 0.9-0.8 .m 0.7: 0.6 Star 138, Vpu 1.0-. 0.9-1 0.8 0.7 "0.6 1.1 Carlisle 138, Vpu 1.0-4 0.9 0.87 0.6-0 2 4 6 8 10 Time (Seconds) Beaver 138, Vpu 1.01, 0.9-i ! 0.8-1 0.7-' 0.6 -j
- 1. 1 Bayshore 138, Ypu 1.0 0.94 0.8 0.7H 0.6-i 1.1--,Lemoyne 138, Vpu H
1.0 0.9 0.8 0.72 0.6 J 1 1 Fostoria 138, Vpu 1.0 0.9 0.8 0.7-1 O.6 Monroe 138., Vpu T1 7 7 0.9 0.8-1 0.7 0.6-i 0 2 4 6 8 10 Time (Seconds) 11 Wayne 138, Vpu 1.0--] 0.9-0.7 0.6 1.1-N Brown 138, Vpu 1.0-0.9-j 0.8H 0.7-ý 0.6-i E L~ima 138, Vpu 1.01'*7 0.9i 0.8-t 0.7-H 0.6-1 1.1 Allen 138, Ypu 1.02 0.98 0.8-1 1.0-i 0.79 1 0.6 -7 I I t ' I ' I i 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:20 chanfiles/dO_99s_r2_14.canPe 0 Page 3
1phase Fault on 2 Lines near Lemoyne 345kV Bus Trip Bayshore-Fostoria 345kV Line & Lemoyne/Fostoria 345kV Line Motor Variables: (._j With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate i 1 SWGR A #2, vt 1.0 -I 0-9 0.8-1 0.7 0.6* 1o0 SWGR A #2, pg -4 I o-4 -Io 20 SWGR A #2, qg -0 5 SWGR A #2, it 4-7 3-! 2 1.00 SWGR A #2, spd 0.99 0.98 0.97-7 0.96 1 0.95 0 2 4 6 8 10 Time (Seconds) 1.1 SWGR B #2, vt .4 1.0 0.9 0.8 0.7 -- * -J 0.6 10 SWGR B #2, pg -4 -0 20 _ SWGR B #2, qg "-1 0 -20 5 SWGR B #2, it 4 3-21j 0--J 1.00 SWGR B #2, spd 0.99 --- 0.98 - 0.97 4 0.96 0.95 0 2 4 6 8 10 Time (Seconds) 26-APR-2000 14:49:20 chanfiles/d0_99sr2_14.cha Page 4
lphase Fault on 2 Lines near Lemoyne 345kV Bus Trip Bayshore-Fostoria 345kV Line & Lemoyne/Fostoria 345kV Line Motor Variables: (_) With Uprate & STATCOM, (...) With Uprate, (.-.) Without Uprate 1 -..SWGR E6, vt 1.1 SWGR E3, vt SWGR D1, vt 1.01 - 1.0 1.0 0.9 0.9 0.9 -f 0.8-0.8-0.8 0.7-0.7 0.7] 0.6-0.6-0.6 1.1 SWGR F6, vt 1.1 SWGR E4, vt 1.--SWGR F4, vt 1.0-1.0 1.0 .9o 0.9 0.9 0.8-o.s8 0.8 0.7-0.7-' 0.7"i 0.6-' 0.6-; 0.6 ._SWGR El, vt 1.1 SWGR C2, vt 1 t SWGR F2, vt 1.0 1.0 1.0 0.9-0.9 0.90 0.8-0.8-0.8 0.7-0.7" 0.7-j 0.6-; 0.6-0.6-i 1.1-- SWGR F1, vt .-. SWGR Cl, vt 1 SWGRF3, vt 1.0 1.0 1.0 0.9 0.9 0.9 08.8,8 0.8 071 0.7-i 0.71 0.6 0.6 j0.6 1.1 SWGR E2, vt 1-SWGR D2, vt 1.0 1.0 f 0.9 0.9 0.80.8 0.7-0.74i 0.6.] 0.6*. S ' I I t ' I i ' [ I I ' i 1 0 2 4 6 8 10 0 2 4 6 8 10 0 2 4 6 8 10 Time (Seconds) Time (Seconds) Time (Seconds) o 4v "W4W_4 r-&*r. j
lphase Fault on 2 Lines near Lemoyne 345kV Bus Trip Bayshore-Fostoria 345kV Line & Lemoyne/Fostoria 345kV Line STATCOM Variables: U With Uprate & STATCOM 1.1-1.0 0.9 0.8 0.6 5 3 0 2 1 0 150 110 70 30 -10 -50 .I I 0 2 4 6 8 Time (Seconds) 26-APR-2000 14:49:20 chanfiles/dO_99s-r2_c14.chan Page 6 O C,, 0 U. )
Docket Number 50-346 License Number NPF-3 Serial Number 2759 COMMITMENT LIST THE FOLLOWING LIST IDENTIFIES THOSE ACTIONS COMMITTED TO BY THE DAVIS-BESSE NUCLEAR POWER STATION (DBNPS) IN THIS DOCUMENT. ANY OTHER ACTIONS DISCUSSED IN THE SUBMITTAL REPRESENT INTENDED OR PLANNED ACTIONS BY THE DBNPS. THEY ARE DESCRIBED ONLY FOR INFORMATION AND ARE NOT REGULATORY COMMITMENTS. PLEASE NOTIFY THE MANAGER - REGULATORY AFFAIRS (419-321-8450) AT THE DBNPS OF ANY QUESTIONS REGARDING THIS DOCUMENT OR ANY ASSOCIATED REGULATORY COMMITMENTS. COMMITMENTS DUE DATE
- 1. The FIV analysis of the ABB/CE stabilizer was documented in a separate calculation. This stabilizer design was determined to not have an adequate stability margin for the power uprate conditions. Thus, these stabilizers will be replaced in the upcoming Thirteenth Refueling Outage (13RFO).
- 2. The DBNPS plans to rerun the CHECWORKS model within 90 days of startup from 13RFO utilizing actual plant heat balance data. The results will be factored into future inspection/pipe replacement plans consistent with the current Corrosion/Erosion Monitoring and Analysis Program (CEMAP).
- 1. By the end of 13RFO.
- 2. Within 90 days of startup from 13RFO.}}