ML110100312

Attachment 2, Vol. 1, to SBK-L-10185, Seabrook Station Response to Request for Additional Information NextEra Energy Seabrook License Renewal Environmental Report, References Requested for Docketing at the Seabrook Station Environmental Sit

ML110100312
Person / Time
Site:	Seabrook
Issue date:	11/23/2010
From:	NextEra Energy Seabrook
To:	Office of Nuclear Reactor Regulation
References
SBK-L-10185
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Appendix B December 6, 2006 USEPA Comment Letter to FPL UNITED STATES ENVIRONMENTAL PROTECTION AGENCY 9h ,, REGION11 CONGRESS STREET, SUITE 1100 BOSTON, MASSACHUSETTS 02114-2023December 6, 2006 .Mr. James Peschel Regulatory Programs Manager FPL Energy Seabrook Station P.O. Box 300 Seabrook, NH 03874 RE: Seabrook Station, National Pollutant Discharge Elimination System Permit No.NH0020338, Proposal for Information Collection

Dear Mr. Peschel:

FPL Energy Seabrook, LLC (Permittee, Seabrook) submitted a Proposal for Information Collection (PIC), dated May 4, 2006, for the Seabrook Station (Station) located in Seabrook, New Hampshire, pursuant to requirements under the Phase II Regulations promulgated by U.S. Environmental Protection Agency (EPA) under Section 316(b) of the Clean Water Act (Phase II Rule). EPA- Region I has reviewed this report and provides suggestions and comments included in this letter.Based on EPA-Region I's review, the PIC provides insufficient information to support the Comprehensive Demonstration Study (CDS). Additional information is needed (regarding previous biological studies) to fully evaluate the validity of the statements and conclusions made in regard to compliance with rule requirements for Impingement Mortality and Entrainment (IM&E) reductions.

EPA-Region I requires that all comments in this letter are incorporated into the data collection, analysis, and presentation aspects ofthe CDS. Please be advised that failure to act in accordance with EPA's comments puts the Permittee at risk for not having acceptable data for permit reissuance.

These comments are outlined below and organized by the Sections identified in the document.3.2 Source Water Physical Data The source water description included in this section of the PIC is very brief, cursory, and provides very little information not already discussed in earlier sections (i.e., location of the CWIS). Given that the PIC does not include a plan to do any further biological sampling and the Permittee is attempting to demonstrate that they are in full compliance with required IM&E reductions, more information on the physical nature of the source waterbody is necessary in order to make determinations on the validity of the reduction calculations and compliance conclusions.e l1 -7 341 Internet Address (URL) 9 http:/Awww.epa.gov/regionl RecycledlRecyciable -Puinted with Vegetable Oil Based Inks on Recycled Paper (Minimum 30% Poatconsumer)

4.1 Applicable

Performance Standards Seabrook plans to claim IM&E reduction credits based on deviations from a baseline configuration (shoreline intake with traveling screens).

These deviations are:* offshore intake* velocity caps* reductions in flow volume due to withdrawing cooler offshore water as compared to withdrawing water from an onshore location

• re-circulation of some discharge water back into the intakeThese credits are quantified in the PIC from comparisons with IM&E at the Pilgrim Station, which has a shoreline intake on allegedly the same waterbody (calculations in Appendices A, B and C). Such a comparison is allowed by the Phase II Rule, specifically, "...the calculation baseline could be estimated by evaluating existing data from a facility nearby without impingement and/or entrainment control technology (if relevant) or by evaluating the abundance of organisms in the source waterbody in the vicinity of the intake structure that may be susceptible to impingement and/or entrainment." However, the Phase II Rule further requires, "If you propose to use existing data, you must demonstrate the extent to which the data are representative of current conditions and that the data were collected using appropriate quality assurance/quality control, procedures." Data were presented in the PIC to establish the appropriateness of the comparison between these facilities, but information was lacking on the source(s) of these data, how the samples were collected, quality assurance/quality control (QA/QC)procedures, or how the data might be representative of current conditions.

A complete complement of this type of information would allow a determination of the validity of the comparison, calculations, and conclusions made from these data.

Examples of required information (to evaluate the validity of comparisons between the sites) include: sampling methods used in collection of existing data, QA/QC procedures applied during the process, the relationship of existing data to current conditions (e.g., age of data and, if necessary, relationship to community structure documented in more recent studies), and any other useful information regarding the physical and ecological similarities between the waters in the vicinity of the intake for the Seabrook and Pilgrim facilities.

In addition, the baseline reduction credits that Seabrook cites (indicating that the facility is already compliant in IM&E reductions) are at the lower limit of the mandated performance range (i.e., 80% reduction for IM and 60% reduction for E). Given that no information is provided to establish the appropriateness or validity of the data used in these calculations, no estimates of error or confidence intervals are given for the reduction estimates, and that no additional biological studies are planned, more information should be provided in the Comprehensive Demonstration Study (CDS) to support these assertions before any determinations of compliance can be made. The appendices that detail the calculations (Appendix A, B and C) do not completely address these concerns.Page 2 of 6 Furthermore, EPA has not yet determined what limits within the performance ranges are potentially achievable at Seabrook Station. In the preamble to the Phase II Regulations,EPA indicates that many facilities can and have achieved a percent reduction in the"higher end of the range" and that "[i]n specifying a range, EPA anticipates that facilitieswill select the most cost-effective technologies or operational measures to achieve the performance level (within the stated range) based on conditions found at their site, and that Directors will review the facility's application to ensure that appropriate alternatives were considered" (emphasis added). 69 Fed. Reg. 41600 (July 9, 2004).4.2 Existing Technology, Operational, and/or Restoration Methods Flow Reduction Due to Recirculation During the winter months, a portion of the heated cooling water is recirculated to the transition structure to prevent subcooling.

Subcooling occurs when cold cooling waterpassing through the condensers reduces the steam condensate temperature to a point where additional heat is required to bring the temperature back up to generate steam when it is returned to the boiler. This results in an overall loss in generating efficiency when the intake water temperature is excessively cold. Since the cooling water pumps are single speed, subcooling is prevented by recirculating a portion of the condenser effluent to the transition structure.

The result is a reduction in intake flow volume equal to the volume of recirculated water.The Phase II Regulations dictate that the Station must reduce impingement mortality by 80 to 95 percent, and reduce entrainment by 60 to 90 percent, of the facility's"calculation baseline." 40 C.F.R. § 125.94(b).

The PIC indicates that the recirculation of cooling water discharge is an operational measure, already being implemented at Seabrook Station, that reduces IM&E and that the facility's calculation baseline should be based on an estimate of the IM&E that would occur without this measure.EPA must disagree.

The calculation baseline for Seabrook Station must be based onimpingement mortality and entrainment levels that reflect this existing operational step.The calculation baseline is defined in 40 C.F.R. § 125.93 as

"...an estimate of impingement mortality and entrainment that would occur at your site assuming that...[,among other things,] the baseline practices, procedures, and structural configuration are those that your facility would maintain in the absence of any structural or operational controls, including flow or velocity reductions, implemented in whole or in part for the purposes of reducing impingement mortality and entrainment." The above-mentioned recirculation of heated condenser water is a baseline operational practice that the Station has historically implemented for power plant operational reasons (to prevent subcooling) and not for the purpose (or partial purpose of) reducing impingement mortality and entrainment.

As a result, the Permittee may not consider the reduction in flow by recirculation in the calculation of baseline flow.Page 3 of 6 EPA does, however, acknowledge that a reduced volume of cooling water is withdrawn due to the colder water at the offshore location of the intakes compared to an inshorelocation and that this difference can be taken into account when calculating baseline.

Differences Due to Intake Water Temperatures The volume of flow recirculation varies as the surface water temperature and cooling requirements vary. When the intake water temperature drops below the threshold of 46-47 OF, recirculation begins and typically occurs from mid to late November to mid to late May. A baseline configuration (shoreline intake) would experience similar periods ofreduced cooling water flow demand due to subcooling and, because there is an economicincentive to do so, would also have similar recirculation measures in the cooling system design.' So, when comparing to a baseline configuration, the flow volume reduction associated with the difference between the two should be based on the much less pronounced difference in inlet temperatures between these two locations during the colder months.In fact, while the average maximum monthly intake temperature for the baseline intake is 6.6 OF higher than for the existing submerged inlet, the baseline intake temperature is only 1.1 OF lower during the coldest month; thus, the baseline intake would actually experience a period of slightly higher recirculation rates during the very coldest part of the year. Since the difference in temperature is inverted at the coldest period, gradually increasing from mid winter to mid summer, and is most pronounced when no recirculation occurs, theoverall difference in recirculation between the existing configuration and baseline configuration is much smaller than the 16.4% maximum and 7.4% overall reduction cited in the PIC. This needs to be clarified in the CDS.During the summer, the PIC estimated that the baseline intake maximum monthlyaverage intake temperature would be 62 °F as opposed to the value of 55.4 OF at the existing submerged offshore location.

The PIC analysis in Section A-i assumes that theexisting calculated maximum effluent temperature of 94.4 OF, based on a change in temperature or "delta-T" (AT) of 39 OF and an intake temperature of 55.4 OF, would be the equivalent permit limit for a system using the shoreline intake. Using this assumption, the PIC estimated the AT limit would be 32.4 OF, resulting in a design flow that would need to be 8.1% higher. This analysis assumes that the baseline system would also employ single speed pumps and, therefore, the increased flow volume needed at the baseline intake during the summer would apply year-round.This assumption may have some validity, since single speed pumps were common at the time of initial plant construction.

However, depending on the basis for the existingNPDES permit AT limit of 39 OF, the calculated baseline AT limit of 32.4 'F may be 1 Recirculation is not the only means of achieving flow reduction to prevent subcooling; variable speed pumps provide an alternative to recirculation with similar results in terms of intake flow volume reduction and would be accompanied by reduced pumping energy requirements.

Page 4 of 6 lower than what would have been applied. Since the 39 °F AT limit is based on a 316(a)variance and a higher than 94.4 'F maximum effluent temperature may have been applied, then the 8.1% reduction may not be a valid estimate of the difference between the existing and baseline intake. In the CDS, the facility needs to clarify the assumptions used to estimate an 8.1% reduction.

4.3 Proposed

Technology, Operational, and/or Restoration Measures Appendix D of the PIC provides a summary of available impingement and entrainment reduction technologies initially evaluated for consideration.

The PIC assumes that the intake technologies would be used in conjunction with the existing submerged intake.

One important aspect of the submerged intake that affects the technology selection, is the stress placed on fish as they pass through the intake tunnel system. Fish are exposed to rapid changes in pressure that occur after they enter the intake and quickly descend to a depth of 160 ft, then travel laterally for about an hour to a depth of 240 ft, and then quickly rise back to the surface. The PIC asserts that this results in significant mortality even before fish encounter the traveling screens. It is probably a reasonable assumption that such rapid changes in pressure would result in significant fish mortality.

As such, alltechnology improvements located downstream of the intake tunnel (e.g., Conventional Traveling Screens with a Fish Return System, Modified Traveling Screens, and Angled Screens) are correctly considered as being potentially ineffective, as many fish will havealready been killed prior to reaching the transition structure.

The PIC's conclusion that cylindrical wedgewire screens would cost approximately

$8 million is similar to EPA estimates.

And while feasible, the screens would pose a significant risk for loss of flow due to plugging of the intake with debris if an airburst system was not included.

While the intake location results in a generally lower risk ofhigh debris loading compared to a shoreline intake, the relative inaccessibility of the screens increases the difficulty of executing corrective actions in a timely manner. Thus, an airburst system is probably a necessary safety feature.

However, the PIC cost estimate for an airburst system of $24 to $100 million appears to be high. A more detailed cost review of the airburst system must be provided in the CDS.

EPA agrees that the two flow reduction measures (adding variable frequency drive's and increased flow recirculation) should be evaluated further as having a potential for added flow reduction.

4.4 Costs

for Compliance The PIC refers to Appendix A of the Phase II rule and notes that zero costs were estimated for Seabrook.

The PIC also cites the preamble language explaining the zerocost facilities, "...some entries in Appendix A have NA indicated for the EPA assumed design intake flow in column 2. These are facilities for which EPA projected that they would already meet otherwise applicable performance standards based on existing technologies and measures. EPA projected zero compliance costs for these facilities....These facilities should use

$0 as their value for the costs considered by EPA for a like Page 5 of 6 facility in establishing the applicable performance standard." (69 FR 41646). The PIC asserts that this language suggests that Seabrook Station already meets the applicable performance standards based on existing installed technologies and operational measures.However, although zero compliance costs were estimated for Seabrook Station as part of the national-level costing for the Phase II regulation, this value should not be used as an indicator of compliance on a facility-specific basis. Rather, the rule requires that thefacility "demonstrate" compliance through one of the five compliance alternatives (40 CFR 125.94(a)).

5.0 Ecological

Studies and Historical Impingement Mortality and Entrainment StudiesThe summary of IM&E studies, which are the basis of the IM&E reduction credit calculations, provide no information on methodology, QA/QC procedures, or relevance of the data to current conditions.

This information must be provided for compliance to be evaluated.

7.0 Sampling

Plans Seabrook Station believes it is in compliance for IM& E reductions, and therefore has not planned any additional sampling.

As stated above, the appropriateness of this conclusion cannot be evaluated with the information provided in this PIC. Further verification monitoring may be required to support the facility's belief that it is in compliance with Phase II performance standards.

If you have any questions concerning this letter, please contact Phil Colarusso of my staff at (617) 918-1506 or Sharon DeMeo at (617) 918-1995.Sincerely, Melville P. Cotd, Chief Ocean and Coastal Protection Unit Office of Ecosystem Protection cc: Phil Colarusso, EPA-Region ISharon DeMeo, EPA-Region I Jeffrey Andrews, NHDES Mike Johnson, NMFS Page 6 of 6 Appendix C March and Nyquist 1976 Model Test Report for Seabrook Intake Structures EXPERIMENTAL STUJD! OF INTAKE STRUCTURES PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE SEABROOK STATION, UNITS 1 AND 2 FORYANKEE ATOMIC ELECTRIC COMPANY Patrick A. March Roger G. Nyquist George E. Hecker, Director ALDEN RESEARCH LABORATORIES WORCESTER POLYTECHNIC INSTITUTE HOLDEN, MASSACHUSETTS 01520 November, 1976 Printed at ARL -November, 1976 TABLE OF CONTENTS Page No.ABSTRACT 1 INTRODUCTION 3 DESCRIPTION OF PROTOTYPE 3 SCALING CRITERIA 4 General Remarks 4 Froude Scaling Criterion 5 Euler Scaling Criterion 5 DESCRIPTION OF TEST FACILITIES AND MODELS 7 Introduction 7 Sectional Model 7 Overall Model 8 EXPERIMENTAL PROCEDURE 9 Sectional Model -Flow Pattern Tests 9 Overall Model -Flow Pattern Tests 10 Overall Model -Velocity Profile During Backflushing 10 Overall Model -Head Loss Tests 11Analytic Evaluation of Guard Bar Design 13 TEST RESULTS. 14 Sectional Model -Flow Pattern Tests 14 Sectional Model -Velocity Measurements 14 Overall Model -Flow Pattern Tests 15 Overall Model -Velocity Profile During Backflushing 16 Overall Model -Head Loss Tests 16 Analysis of Potential for Flow-Induced Vibrations of Guard Bars 17

SUMMARY

AND CONCLUSIONS 18 Summary of Results 18 Conclusions 19 REFERENCES 20 FIGURES ABSTRACT Hydraulic model tests were conducted to provide information necessary for evaluating alternative designs for Seabrook Station's intake structures.

Sectional models constructed to a scale ratio of 1: 35.2 were used to determine vertical flow patterns and velocities in the vicinity of individual intake struc-tures, An overall model facility was used to determine loss coefficients and to determine horizontal flow patterns in the vicinity of an array of three intake structures.

Seabrook Alternative A and Alternative C intake designs were tested in the overall model.For an ambient current of 0.2 kt and a water depth of 60 ft, the Alternative A intake withdrew from the bottom 35 ft of the approaching fluid, and for an ambient current of 0.4 kt, the intake withdrew from the bottom 25 ft of the approaching fluid. At a water depth of 30 ft, the Alternative A intake with-drew from the entire depth for 0. 2 kt ambient current and from the bottom 25 ft for the 0.4 kt ambient current. For zero ambient current at both water depths, the Alternative A intake withdrew from the entire depth.At water depths of 30 ft and 60 ft, the velocity profiles at the upstream face of the Alternative A intake were relatively uniform and generally less than 1 ft/sec for ambient currents of 0, 0. 2, and 0.4 kt. Downstream velocity profiles were skewed for ambient currents of 0.2 and 0. 4 kt, and the maximum measured velocity was about 1. 3 ft/sec.At the 60 ft water depth, velocities upstream from the Alternative A intake dropped to the ambient current values within one-half intake diameter for both the 0.2 and 0.4 kt ambient currents.No significant interference between intakes was observed for the Alternative A intakes at a water depth of 60 ft and ambient currents of 0.2 kt S, 0.4 kt S, 0.2 kt S-65 0 W, and 0,4 kt S-65 0 W. For all of the ambient currents tested, each intake appeared to operate independently from the other intakes. Each in-take's range of influence was limited horizontally to about one intake diameter 2 on either side of the intake periphery for the 0.2 kt S and the 0.2 kt S-65°W ambient currents, and to about one-half intake diameter to either side for the 0.4 kt S and the 0.4 kt S-65°W ambient currents.

Similar results were also obtained for the Alternative C intakes, The average intaking (normal flow) loss coefficient was 0. 35 for Alternative A and 3,7 for Alternative C. The average backflushing (reverse flow) loss coefficient was 1, 04 for Alternative A and 2.5 for Alternative C.Because of the low, relatively uniform entrance velocities, minimal inter-ference between intakes, and low losses during normal intaking operation and backflushing operation, the Alternative A intake design was recommended.

3 INTRODUCTION Cooling water for the Public Service Company of New Hampshire's Seabrook Station will be withdrawn from the Atlantic Ocean through three velocity-cap intake struc-tures and discharged through a multiple port diffuser.

During normal operation, water is withdrawn through the intake structures and discharged through the dif-fuser nozzles. During backflushing operation, water is taken into the circulating water system through the discharge structures and discharged through the intake structures for the purpose of reducing biological fouling in the intake tunnel.Knowledge of the head losses associated with the intake structures during normal operation and backflushing operation is important for sizing the pumps in the cir-culating water system, calculating normal plant circulating water flow and tempera-ture rise, and predicting backflushing transients.

Information on the flow patternsand velocities in the vicinity of the intake structures is required to help evaluate the potential for entrainment of marine organisms.

The primary objective of this study was to provide the loss coefficient, flow pattern, and velocity information necessary for evaluating the intake structure designs. A sectional model was used to determine vertical flow patterns and velocities in the vicinity of an individual intake. An overall model was used to determine loss co-efficients and to determine horizontal flow patterns in the vicinity of the three intake structures.

DESCRIPTION OF PROTOTYPE The Seabrook Station will have two nuclear-powered generating units with a com-bined net generating capability of 2300 MWe. For this study, the total plant flow rate was estimated at 1822 ft 3/sec, and the design velocity at the face of each intake was 0.9 ft/sec. The estimated maximum plant flow rate during backflushing opera-tion was also 1822 ft 3/sec, and the estimated typical plant flow rate during back-flushing operation was approximately one-half the maximum flow rate. Subsequent calculations, based in part on the results of this study, predict a maximum plant flow rate of 1897 ft 3/sec (including service water) during normal operation and backflushing operation.

Actual flow rates in the circulating water system during backflushing will vary, depending on the power level and transients during flow reversal.

4 With the present design for the intake portion of the circulating water system, the, three intake structures will be spaced 110 ft apart along the same line. Riser shafts of 9 ft in diameter will connect the intake structures to a 19 ft inside diameter tunnel extending about 17,000 ft (or 13,500 ft, depending on the site selected) to the cir-culating water pumphouse.

Two sites have been proposed for the intake structures.

The "offshore" site, shown in Figure 1, is located about two miles offshore from Hampton Beach, New Hampshire, in approximately 60 ft of water. The "onshore" site is located about one mile offshore from Hampton Beach in approximately 30 ft of water. The original intake design, Alternative A, is shown in Figure 2. Another intake design, Alternative C, is shown in Figure 2. The Alternative C intakes were designed for the purpose of in-creasing the thermal dilution at the onshore location during backflushing operation (Nyquist, et al., 1976). The intake structure for Niagra Mohawk Power Corporation's Nine Mile Point Station, shown in Figure 4, was also included in this study for com-parison purposes.SCALING CRITERIA General RemarksAlthough the model size should be maintained as large as practicable to minimize viscous scale effects, other factors, such as costs, availability of materials, and capacity of existing facilities, must also be considered in determining the geo-metric scale ratio. For this study, a model to prototype scale ratio of 1: 35.2 wasselected, This was the largest scale ratio which allowed adaptation of existing ARL facilities for the study and modeling of the riser tunnel with a standard pipe size.In any physical model study, the choice of a scaling criterion for relating model results to prototype conditions is determined by the relative magnitudes of forceswhich control the phenomena under consideration.

In this study, Froude scaling was used for determining and interpreting velocities and flow patterns.

Euler scaling was used for the head loss tests. These scaling criteria are described in more detail in the following sections.

5 Frooude Scaling Criterion The dominant forces determining flow patterns in the vicinity of the intake structures are inertial and gravitational forces. The Froude number, IF, which represents the ratio of these forces, is given by the expression F =v/1- (1)where V is a characteristic velocity, L is a characteristic length, and g is the acceleration of gravity.The Froude scaling criterion requires thatIF'= F (2)m p where the subscripts m and p refer to model and prototype, respectively.

Because the acceleration of gravity-is almost exactly equal in model and prototype, Equations (1) and (2) can be combined and simplified:

V L 1/2 1/2= -35.93(3)p p Other relevant scale ratios can be determined in a similar manner.Euler Scaling Criterion Because of the complex intake geometries and the relatively abrupt changes in shape, the major internal losses come from the dissipation of energy in turbulence created by shape, rather than from viscous shear at flow boundaries.

The Euler number, lE, indicates the relative importance of inertial and pressure forces, and equality of the Euler numbers for model and prototype is necessary and sufficient for proper flow similarity.

6 The Euler number, IE, can be expressed as E = V/V 7 (4)where V is a characteristic velocity, AP is a characteristic differential pressure, and p is the fluid density, The Euler scaling criterion requires that E =E .(5)m p The densities of the working fluids are almost equal in model and prototype, and Equations (4) and (5) can be combined and simplified into the expression AP Ah V 2 m _ m _ m(6)p p V p In Equation (6), the head loss Ah has been substituted for the equivalent pressure loss AP, A loss coefficient, K, is defined as the ratio of head loss Ah to velocity head V 2/2g: K -(7)V 2/Zg Equations (6) and (7), therefore, indicate that the loss coefficients are equal in the model and the prototype if the Euler numbers are equal.

The principal requirement for equal Euler numbers is that viscous effects must be negligibly small compared to inertial effects. The Reynolds number, R, which represents the ratio of inertial to viscous forces, can be defined as Vd R =V (8)where d is a characteristic length and v is the kinematic viscosity of the working fluid. Previous research shows that viscous effects are often negligible and the requirements of the Euler scaling criterion are satisfied for Reynolds numbers larger than about 105 (McNown, 1968).

7 DESCRIPTION OF TEST FACILITIES AND MODELS Introduction A sectional model and an overall model were constructed for this research.

The sectional model, consisting of half an intake structure placed against the glass side-wall of a flume, was used to determine the "elevation view" streak lines in the vicinity of a single intake structure and the velocities across the upstream and downstream faces of the structure.

The overall model, which included three complete intake structures, was used to determine "plan view" -streak lines, velocity distribution at the intake face during reverse flow, and head loss coefficients for normal operation and reverse flow operation.

These models are described in detail in the following sections.Sectional Model Sectional models of the Alternative A intake structure (Figure 2) and the Nine Mile Point intake structure (Figure 4) were fabricated from transparent acrylic plastic (PMMA) to a uniform geometric scale of 1: 35.2. The sectional models were tested individually in a flume which measured 4 ft wide by 4 ft deep by 32 ft long. The test facility is shown schematically in Figure 5.Each sectional model was mounted against the transparent sidewall of the flume.A centrifugal pump was used to withdraw water through the sectional intake, and the flow rate through the intake was measured with a calibrated orifice plate and an air-water differential manometer.

Another centrifugal pump was used for cir-culating water through the flume to provide the ambient current. Flow rate through the flume was measured with an orifice plate and an air-water differential manometer.

Water depth was controlled by draining or filling the flume to the proper depth as measured with a staff gage.Streak lines in the vicinity of the intake were determined by sketching and photo-graphing isokinetic dye releases.

A sample dye trace is shown in Figure 6. A Thermo-Systems, Inc. Series 1050 hot film anemometer was used for velocity measure-ments in the vicinity of the intake.

8 Overall Model Models of the three Alternative A intakes and the three Alternative C intakes were fabricated from transparent acrylic plastic (PMMA) to a uniform geometric scale of 1: 35,2. Each group of three intakes was tested in an elevated tank which measured 20 ft wide by 2 ft deep by 30 ft long. The test facility is shown schematically in Figure 7.The riser for the center intake was placed in a fixed location, and the risers for the other two intakes could be moved to an additional location.

Orientations corresponding to prototype ocean currents from North to South (S current) and from North-65 0 East to South-65 0 West (S-650W current) were provided in the model. An axial flow pump supplied water for providing ambient currents in the model. Flow rate through this supply line was measured with an orifice plate and an air-water differential mano-meter. Two rows of perforated plates were used to produce a uniform velocity dis-tribution across the tank. An adjustable weir located at the downstream end of the model was used to control water depth, as measured with a staff gage.For normal intaking operation, water drained by gravity through the three intakes and into the sump. For backflushing operation, water was pumped to the intakes through a branch line from the ambient current supply line. Metering sections in the lines connected to the three intakes were constructed with pressure taps at one diameter and one-half diameter on each side of the orifice plates. These metering sections were calibrated for both flow directions and were used to measure flow rate from each intake during normal operation and to each intake during backflushing op eration.A probe which discharged dye from multiple ports, as shown in Figure 6, and a dye probe with a single release port were used for determining the streak lines in the vicinity of each intake structure.

Multiple exposure photographs of drogues (i.e., small surface floats with subsurface vanes at varying depths) were used to verify the uniformity in speed and direction of the ambient current. The velocity profile at the face of the center intake was measured during backflushing operation using the hot-film anemometer, 9 Piezometer taps, placed at the locations shown in Figure 8 along the riser. for the center intake, and air-water manometers were used to determine the head losses for the center intake structure during normal operation and backflushing operation.

A calibrated elbow meter and an air-water differential manometer were used to determine the flow rate to or from the center intake during head loss tests.EXPERIMENTAL PROCEDURE Sectional Model -Flow Pattern Tests The water level in the test facility was adjusted to the correct depth. The flume recirculating pump was turned on, and the control valve in the recirculating line was adjusted to produce a manometer reading corresponding to the approximate ambient current desired. A drogue with vanes located at mid-depth was timed over a known distance in order to determine ambient current speed, and final adjustments in the ambient current speed were made with the control valve. The intake pump was switched on, and the control valve in the intake line was adjusted to produce*a manometer reading corresponding to the correct flow rate through the intake.Dye was discharged at numerous locations in the vicinity of the intake structure, and the dye patterns were sketched and photographed.

Streak lines were deter-mined in this manner for each sectional intake at ambient currents of 0, 0. 2, and0.4 kt. The Seabrook Alternative A intake was tested at water depths of 30 ft and 60 ft and a flow rate of. 607 ft 3/sec (i.e., plant flow rate of 1822 ft 3/sec). The Nine Mile Point intake was tested at a water depth of 26. 5 ft and a plant flow rate of 600 ft 3/sec.For another series of tests with the Alternative A intake, the intake flow rate and water level were adjusted to correspond to a plant flow rate of 1822 ft 3/sec and a water depth of 60 ft. The hot-film velocity probe was positionedat the centerline height of the intake. Velocities were measured as a function of distance upstream from the intake for ambient currents of 0.2 and 0.4 kt, 10 Overall Model -Flow Pattern Tests For the intaking mode tests, the ambient current supply pump was switched on, the supply valve and bypass valve were adjusted to produce a manometer reading cor-responding to the approximate ambient current, and the water level was adjusted to the correct depth. Drogues were timed over a known distance in order to determine ambient current speed, and final adjustments were made with the supply valve. The valves in the intake riser lines were adjusted to produce manometer readings corres-ponding to a prototype flow rate of 607 ft 3/sec for each intake (plant flow rate of 1822 ft 3/sec).Dye was discharged at numerous locations in the vicinity of the intake structure, and the dye patterns were sketched and photographed.

Streak lines were deter-mined in this manner for the Alternative A intakes and the Alternative C intakes at ambient currents of 0.2ktS, 0.4kt S, 0.2 ktS-65 0 W, and 0.4kt S-65°W. The Alternative A intakes were tested at a water depth of 60 ft, and the Alternative C intakes were tested at a water depth of 30 ft.For the backflushing mode tests, ambient current and water level were adjusted according to the procedure described above. The valves were adjusted to provide flow out of the intakes, and dye was injected into the riser pipes just upstream from the intakes. Dye patterns from the Alternative A intakes were observed for estimated plant flow rates of 869 ft 3/sec (100% power level), 684 ft 3/sec (6 3% power level), and 535 ft 3/sec (33% power level) at ambient currents of 0.2 kt S and 0.4 kt S. Dye pat-terns from the Alternative C intakes were observed and photographed for the same range of flow rates and ambient currents.

The Alternative A intakes were tested at a water depth of 60 ft and the Alternative C intakes were tested at a water depth of 30 ft.Overall Model -Velocity Profile During Backflushing The valves were adjusted for backflushing operation.

With the Alternative A center intake in place, a water depth of 60 ft, and no ambient current in the model, the flow rate out of the center intake was adjusted to 607 ft 3/sec (plant flow rate of 1822 ft 3/sec). Velocity measurements were taken vertically across the face of the intake using a hot-film anemometer.

A dye probe was used to determine the direction of flow.

11 The hot-film probe was also positioned

0. 5 ft (prototype) below the bottom of the intake roof, and voltages corresponding to the exit velocities were recorded on a strip-chart recorder as the flow rate to the intake was varied. Chart records were analyzed using a graphical spectrum analysis technique to determine frequency of velocity fluctuations as a function of velocity in the riser pipe.Overall Model -Head Loss Tests For the intaking mode tests and the backflushing mode tests, the water level was maintained at a prototype depth of 60 ft for the Alternative A intake and 30 ft for the Alternative C intake. The flow rate into (or out of) the center intake was varied to produce a range of Reynolds numbers. For each flow rate, the differential head across the elbow meter, the manometer reading for each group of piezometers along the riser shaft, the manometer reading from the tank piezometers, and the water temperature were recorded.Riser pipe Reynolds numbers were computed from the measured flow rates by using Equation (8). Head loss measurements were converted into intaking loss co-efficients (KI) using Equation (7), with riser pipe velocity head as the reference velocity head. The expression used for computing intaking loss coefficients was derived by writing the Bernoulli equation between points A and B on the diagram in Figure 8, as shown below.Definitions:

VA = velocity of water surface at point A hA = piezometric head at point A VB = riser pipe velocity at point B hB = piezometric head at point B AhI = head loss between A and B Ah I KI VB 2/2g Assumptions:

VA = 0 Tank (ocean) floor is the datum for measuring piezometric heads.

12Bernoulli equation:

VA 2 V 2 A 4- B +h + Ah 2g A 2g B I Ah 1 h A -h -VB2/2g Ah h A -hB -VB2/2g KI -___ -___ _____ (9)VB2 /2g .VB 2/2g VB /2The piezometric head at point B, hB, was determined by extrapolating the hydraulic grade line obtained from the riser pipe piezometers.

For the backflushing tests, riser pipe Reynolds numbers were computed from the measured flow rates by using Equation (8). Head loss measurements were converted into backflushing loss coefficients (KD) using Equation (7), with riser pipe velocity head as the reference velocity head, The expression used for computing backflushing loss coefficients was derived by writing the Bernoulli equation between points B and A on the diagram in Figure 8, as shown below.Definitions:

VB = riser pipe velocity at point B hB = piezometric head at point B VA = velocity of water surface at point A hA = piezometric head at point A KD = AhD/VB 2/2g Assumptions:

VA = 0 Tank (ocean) floor is the datum for measuring pie zometric heads.

13 Bernoulli equation: B + h A + h + Ah 2g B 2 g A D VB 2-+ h h Ah 2g B A D AhD VB2/2g + hB -hA KD _- _ A(10)VB 2/2g VB 2/2 g The piezometric head at point B, h was determined by extrapolating the hydraulic grade line obtained from the riser pipe piezometers.

Analytical Evaluation of Guard Bar Design In addition to the experimental work described above, an analytical evaluation of the potential for flow-induced vibrations with the proposed guard bar design was also conducted.

Guard bar failures due to flow-induced vibrations have been well-documented in the research literature (James and Katakura, 1971; Crandall et al. , 1975).For this study, circular steel guard bars measuring 1-1/2 in diameter by 84 in long were assumed, in accordance with the recommended guard bar design given in UE&C Drawing No. 303-02. A range of possible first mode natural frequencies, depending on end constraints, was determined from standard beam vibration formulas (Den Hartog, 1956). A mass correction was added for vibration in sea water. Vortex shedding frequency was computed as a function of approach velo-city, using an assumed Strouhal number of 0.21 (Hoerner, 1965) for the proposed guard bar section.

14 TEST RESULTS Sectional Model -Flow Pattern TestsStreak lines for the Alternative A intake structure at the offshore site (water depth of 60 ft) with ambient currents of 0, 0.2, and 0, 4 kt are presented in Figures 9, 10, and 11, respectively.

For zero ambient current, the intake withdrew water uniformly from the surrounding fluid. For an ambient current of 0.Z kt, the intake withdrew from the bottom 35 ft of the approaching fluid, and for an ambient current of 0.4 kt, the intake withdrew from the bottom 25 ft of the approaching fluid. With the 0.4 kt ambient cur-rent, a region of flow separation at the downstream end of the intake roof was observed, Streak lines for the Alternative A intake structure at the onshore site (water depth of 30 ft) with ambient currents of 0, 0.2, and 0.4 kt are presented in Figures 12, 13, and 14, respectively.

These streak line results are similar to the results obtained for the offshore site. The intake withdrew from the entire depth for 0 and 0.2 kt ambient current and from the bottom 25 ft for the 0.4 kt ambient current.Streak lines for the Nine Mile Point intake structure for ambient currents of 0, 0. 2, and 0.4 kt are presented inFigures 15, 16, and 17, respectively.

This intake with-drew from the entire depth for ambient currents of 0 and 0.2 kt and from the bottom 20 ft for the 0.4 kt ambient current. The streak line results indicate the presence of considerably larger vertical velocity gradients for the Nine Mile Point intake compared to the Seabrook Alternative A intake. Flow separation at the roof on the upstream and the downstream ends was observed for each of the ambient currents.Sectional Model -Velocity Measurements Velocity profiles across the upstream and downstream faces of the Alternative A intake at the offshore site with ambient currents of 0, 0.2, and 0.4 kt are presented in Figure 18. For zero ambient current, the upstream and downstream velocity profiles were uniform and about equal. For the 0.2 and 0.4 kt ambient currents, the velocity pro-files at the upstream face remained uniform while the velocity profiles at the downstream face became more skewed, with the highest velocities occurring near the center and the bottom of the intake face. Similar velocity profiles were obtained for the Alternative A intake at the onshore site with ambient currents of 0, 0.2, and 0.4 kt, as shown in Figure 19.

15 Velocity profiles for the Nine Mile Point intake structure are shown in Figure 20, Velocity profiles at both the upstream and the downstream faces of the intake were skewed for all ambient currents tested, including zero ambient current. The lower velocities measured near the intake roof and the higher velocities measured near the intake floor indicate the influence of the observed flow separation at the roof and the steeper pressure gradient at the bottom of the intake face on the velocity profiles.The decrease in centerline velocity with increasing distance upstream from the Alternative A intake structure (offshore site) is shown in Figure 21. The measured velocities dropped to the ambient current value within one-half of an intake diameter upstream from the intake face for both the 0. 2 and the 0. 4 kt ambient currents.Overall Model- Flow Pattern Tests Plan-view streak lines for the Alternative A intake structures (offshore location, 60 ft water depth) with ambient currents of 0.2 kt S, 0.4 kt S, 0.2 kt S-65 0 W, and 0.4 kt S-65 0 W are presented in Figures 22, 23, 24, and 25, respectively.

No significant interference between intakes was observed.

For all of the ambient currents tested, each intake appeared to operate independently from the other intakes. Each intake's range of influence was limited to about one intake diameter on either side of the intake periphery for the 0. 2 kt S and the 0.2 kt S-65OW ambient currents, and to about one-half intake diameter to either side for the 0.4 kt S and 0.4 kt S-65OW ambient currents.At all ambient currents tested, a small region of stagnant flow was observed behind each intake.Plan-view streak lines for the Alternative C intake structures (onshore location, 30 ft water depth) with ambient currents of 0.2 kt S, 0.4 kt S, 0.2 kt S-65 0 W, and 0.4 kt S-65OW are shown in Figures 26, 27, 28, and 29. These streak line results are similar to the results obtained for the Alternative A intake, indicating that the internal geometry changes and the decreased water depth did not significantly modify the flow patterns in the vicinity of the intake structures.

During backflushing tests with dye injection, pulsations were observed in the flow out of the Alternative A intakes. The Alternative C intakes produced steady, well-defined jets. No substantial interference between intakes was observed during back-flushing for either intake design.

16 Overall Model -Velocity Profile During Backflushing Figure 30 shows the velocity profile measured in the model for the Alternative A intake during backflushing for a plant flow rate of 1822 ft 3/sec. At the intake periphery, the flow separation extended vertically across half of the intake face.Because of the entrainment produced by the discharge jet, the velocities into the intake during backflushing were actually slightly higher than velocities into the intake during normal operation.

The maximum velocity in the discharge jet was about 7 ft/sec.The measured frequencies of velocity fluctuations are shown as a function of riser velocity in Figure 31. Much of the scatter in this data can be attributed to the approximate nature of the graphical spectrum analysis.

The periodic fluctuations were apparently related to vortex shedding associated with unstable flow separa-tion at the junction of the riser tunnel and the intake floor. A dimensionless frequency parameter, the Strouhal number (S), can be defined as S = f d/V where f is frequency, V is velocity, and d is a characteristic length. The data from themodel can be used to determine a Strouhal number of 0.68, based on the riser dia-meter. There is a paucity of data relating Strouhal number to Reynolds number at high Reynolds numbers. If this S = 0.68 is applicable to the prototype, the range of expected frequencies for velocity fluctuations during backflushing would be from 0.2 Hz to 0. 7 Hz, depending on power level. These frequencies are outside of the range of expected natural frequencies for the guard bars, but the potential for exciting a structural resonance may exist, Overall Model -Head Loss Tests Intaking loss coefficients (KI) for the Alternative A and Alternative C intakes, com-puted according to Equation (9), are plotted as a function of riser tunnel Reynolds number in Figure 32. The average intaking loss coefficient was 0. 35 for Alternative A and 3.7 for Alternative C.Backflushing loss coefficients (KD) for the Alternative A and Alternative C intakes, computed according to Equation (10), are also plotted as a function of riser tunnel Reynolds number in Figure 32. The stronger Reynolds number dependence of the 17 backflushing loss coefficient for the Alternative C intake design is attributed to the increased importance of friction losses compared to form losses in the smoothly curved transition sections.

The average backflushing loss coefficient was 1..04 for Alternative A and 2.5 for Alternative C.The large intaking and backflushing loss coefficients for the Alternative C design are associated with thehigh velocity jets created at the internal restrictions.

The low backflushing loss coefficient for the Alternative A design and the previously presented information on velocity profile during backflushing indicate that the flow is decelerated in the intake and part of the velocity head in the riser tunnel is recovered as pressure head. The low total energy loss for the Alternative A structure represents the energy associated with a discharge jet at a velocity of less than 7 ft/sec plus some small additional losses due to friction and entrainment.

Using the loss coefficient data presented above and Equations 9 and 10, prototype head losses can be computed for typical operating conditions:

Plant Flow Rate Intake Design Operating Mode (ft 3/sec) Head Loss (ft)A Intaking (normal flow) 1897 0.5 C Intaking (normal flow) 1897 5.7 A Backflushing (reverse flow) 949 0.4 C Backflushing (reverse flow) 949 1.0 Analysis of Potential for Flow-Induced Vibrations of Guard Bars In Figure 33, estimated guard bar vortex shedding frequency is plotted as a function of approach velocity, and a range of calculated natural frequency values for the guard bars is also indicated.

The design intake velocity of 0.9 ft/sec, the maximum measured velocity of 6.9 ft/sec during backflushing for Alternative A, and the esti-mated maximum velocity of 7.2 ft/sec during backflushing for Alternative C correspond to vortex shedding frequencies which fall outside of the range of expected natural fre-quencies for the guard bars. Consequently, flow-induced vibrations are not expected to occur with the present guard bar design.

18

SUMMARY

AND CONCLUSIONS Summary of Results Sectional models constructed to a scale ratio of 1: 35.2 were used to determine vertical flow patterns and velocities in the vicinity of individual intake structures.

The Seabrook Alternative A intake design was compared with Niagra Mohawk Power Corporation's Nine Mile Point intake. An overall model facility was used to deter-mine loss coefficients and to determine horizontal flow patterns in the vicinity of an array of three intake structures, Seabrook Alternative A and Alternative C intake designs were tested in the overall model. An analytical investigation was also conducted to determine the potential for flow-induced guard bar vibrations.

The more important results are summarized below: 1, For an ambient current of 0.2 kt and a water depth of 60 ft, the Alternative A intake withdrew from the bottom 35 ft of the approaching fluid, and for an ambient current of 0.4 kt, the intake withdrew from the bottom 25 ft of the approaching fluid. At a water depth of 30 ft, the Alternative A intake with-drew from the entire depth for 0. 2 kt ambient current and from the bottom 25 ft for the 0.4 kt ambient current. For zero ambient current at both water depths, the Alternative A intake withdrew from the entire depth.2. Streak line results indicated the presence of considerably larger vertical velocity gradients for the Nine Mile Point intake compared to the Seabrook Alternative A intake.3. At water depths of 30 ft and 60 ft, the velocity profiles at the up-stream face of the Alternative A intake were relatively uniform and generally less than 1 ft/sec for ambient currents of 0, 0.2, and O,4 kt. Downstream velocity profiles were skewed for ambient currents of 0.2 and 0. 4 kt, and the maximum measured velocity was about 1, 3 ft/sec. Velocity profiles for the Nine Mile Point intake at both the upstream and the downstream faces of the intake were skewed for all ambient currents tested.

19 4. At the 60 ft water depth, velocities upstream from the Alternative A intake dropped to the ambient current valves within one-half intake diameter for both the 0.2 and 0. 4 kt ambient currents.5. No significant interference between intakes was observed for the Alternative A intakes at a water depth of 60 ft and ambient currents of 0.2ktS, 0,4ktS, 0.2ktS-65 0 W, and 0.4ktS-65 0 W. For all of the ambient currents tested, each intake appeared to operate inde-pendently from the other intakes. Each intake's range of influence was limited horizontally to about one intake diameter on either side of the intake periphery for the 0.2 kt S and the 0.2 kt S-65°W ambient currents, and to about one-half intake diameter to either side for the 0.4 kt S and the 0.4 kt S-65OW ambient currents.

Similar results were also obtained for the Alternative C intakes.6. During backflushing operation, a flow separation extended vertically across half of the intake face, and the maximum velocity in the dis--charge jet was about 7 ft/sec.7. The average intaking (normal flow) loss coefficient was 0.35 for Alternative A and 3.7 for Alternative C. The average backflushing (reverse flow) loss coefficient was 1.04 for Alternative A and 2. 5 for Alternative C.8. The analytical investigation indicated that flow-induced vibrations should not occur with the present guard bar design.Conclusions The Alternative A intake design provides low, relatively uniform entrance velocities, minimal interference between intakes, and low losses during normal intaking opera-tion and backflushing operation.

No design changes are considered necessary, and the Alternative A intake design is recommended.

20 REFERENCES

1. Crandall, S. , Vigander, S., and March, P. , "Destructive Vibration of Trashracks due to Fluid-Structure Interaction," ASME Journal of Engineering for Industry, 97, November 1975, pp. 1359-1365.

2. Den Hartog, J., Mechanical Vibrations, New York: McGraw-Hill Book Company, 1956, p. 432.3. Hoerner, S., Fluid-Dynamic Drag, Midland, New Jersey: (published by author), 1965.4. James, E., and Katakura, F., "Oroville.

Intake Vibration Problems," ASCE National Water Resources Engineering Meeting, Phoenix, Arizona, January-11-15, 1971.5. McNown, J., "Mechanics of Manifold Flow," ASME Transactions, December 1968.6. Nyquist, R., Durgin, W., and Hecker, G., "Hydrothermal Studies of Bifurcated Diffuser Nozzles and Thermal Backflushing:

Seabrook Station," ARL Report No. 129-76/M296BF, January, 1976.7. Teyssandier, R., Durgin, W., and Hecker, G., "Hydrothermal Studies of Diffuser Discharge in the Coastal Environment:

Seabrook Station," ARL Report No. 86-74/M252F, August 1974.

FIGURES FIGURE 1 LOCATION OF INTAKE AND DISCHARGE STRUCTURES SEABROOK STATION FIGURE 2 PLAN VIEW 0.6'SECTION A-A 30.5'SEABROOK ALTERNATIVE A INTAKE Alý¶ FIGURE 3 PLAN VIEW 1.2'.' A ECTION A-A-30.5'1.1'° 0000 o 0o °

• o 7.0'" 1 -2.0' 7.0' OCEAN1/2 0000 * -BOTTOM S I SEABROOK ALTERNATIVE C I-NTAKE FIGURE 4 PLAN VIEW A A III /i II NOTE: PROTOTYPE IS SYMMETRICAL ABOUT THIS LINESECTIONAL ELEVATION VIEW A-A NINE MILE POINT INTAKE Aý1 PUMP SCHEMATIC DIAGRAM SEABROOK INTAKE SECTIONAL MODEL_"T c m FIGURE 6 SECTIONAL MODEL (ALTERNATIVE A INTAKE)OVERALL MODEL (ALTERNATIVE C INTAKE)DYE TRACES SHOWING STREAK LINES SEABROOK INTAKE STRUCTURES 0 ADJUSTABLE EXIT WEIR ORI L AMBIENT CURRENT CONTROL VALVEI SCHEMATIC OF OVERALL MODEL m SEABROOK INTAKE STRUCTURES

-4 FIGURE 8 A 3.43'O LOCATION OF PIEZOMETER TAPS IN MODEL FEET LOCATION OF PIEZOMETER TAPSSEABROOK INTAKE STUDY

-OVERALL MODEL FIGURE 9WATER DEPTH 60 FEET AMBIENT CURRENT 0 KNOTS PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)STREAK LINES IN SECTIONAL MODEL SEABROOK ALTERNATIVE A INTAKE jyRJL FIGURE 10-.a*- AMBIENT CURRENT WATER DEPTH 60 FEET AMBIENT CURRENT 0.2 KNOTS PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)

STREAK LINES IN SECTIONAL MODEL SEABROOK ALTERNATIVE A INTAKE Ju- =

FIGURE 11----- AMBIENT CURRENT WATER DEPTH 60 FEET AMBIENT CURRENT 0.4 KNOTS PLANT FLOW RATE 1822 CFS(607 CFS PER INTAKE)STREAK LINES IN SECTIONAL MODEL SEABROOK ALTERNATIVE A INTAKE FIGURE 12 WATER DEPTH 30 FEET AMBIENT CURRENT 0 KNOTS PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)

STREAK LINES IN SECTIONAL MODEL SEABROOK ALTERNATIVE A INTAKE Z/k{ý FIGURE 13 V--- AMBIENT CURRENT WATER DEPTH 30 FEET AMBIENT CURRENT 0.2 KNOTS PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)STREAK LINES IN SECTIONAL MODEL SEABROOK ALTERNATIVE A INTAKE A:~Th[L~

FIGURE 14-AMBIENT CURRENT WATER DEPTH 30 FEET AMBIENT CURRENT 0.4 KNOTS PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)STREAK LINES IN SECTIONAL MODEL SEABROOK ALTERNATIVE A INTAKE~pll~

FIGURE 15 00 ,'0 (00.'.0 a o ,2>0"

• 0." WATER DEPTH 26.5 AMBIENT CURRENT PLANT FLOW RATE FEET 0 KNOTS 600 CFS STREAK LINES IN SECTIONAL MODEL NINE MILE POINT INTAKE FIGURE 16-i AMBIENT CURRENT00.0.WATER DEPTH 26.5 FEET AMBIENT CURRENT 0.2 KNOTS PLANT FLOW RATE 600 CFS STREAK LINES IN SECTIONAL MODEL NINE MILE POINT INTAKE hyrIL FIGURE 17AMBIENT CURRENT 9 oQ,o WATER DEPTH 26.5 AMBIENT CURRENT PLANT FLOW RATE FEET 0.4 KNOTS 600 CFS STREAK LINES IN SECTIONAL MODEL NINE MILE POINT INTAKE SEABROOK INTAKE m-AMBIENT CURRENT PLAN AMBIENT CURRENT AMBIENT CURRENT 0.4 KTS.0I I 0 1 2 0.2 KTS.0 1 0 KTS.21 2 0 1 2 0 KTS.02 KTS. 0.4 KTS.0 2 1 0 2 1 0 FACE VELOCITY (FT/SEC)ELEV.FACE VELOCITY (FT/SEC)PLANT FLOW RATE 1822 CFS(607 CFS PER INTAKE)

NOTE: ". " INDICATES LOCATIONS FOR VELOCITY MEASUREMENTS WATER DEPTH = 60.0 FT.(OFF SHORE LOCATION)

\VELOCITY PROFILES AT INTAKE FACE SECTIONAL MODEL SEABROOK ALTERNATIVE A INTAKE ZT11L 0 SEABROOK INTAKE-AMBIENT CURRENT\*PLAN AMBIENT CURRENT AMBIENT CURRENT 0.2 KTS.0.4 KTS. 0.2 KTS. 0 KTS.0 1 2 0 1 2 0 1 2 0 KTS.0.4 KTS.2 1 0 2 1 0 FACE VELOCITY (FTISEC)

NOTE: "= INDICATES LOCATIONSFOR VELOCITY MEASUREMENTS ELEV.FACE VELOCITY (FT/SEC)PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)WATER DEPTH = 30.0 FT.(ON SHORE LOCATION)VELOCITY PROFILES AT INTAKE FACE SECTIONAL MODEL SEABROOK ALTERNATIVE A INTAKE 0 m zmL NINE MILE POINT INTAKE C mr 0)-AMBIENT CURRENT PLAN AMBIENT CURRENT 0.4 KTS. 0.2 KTS. 0 KTS.0 1 2 0 1 2 0 1 2 FACE VELOCITY (FT/SEC)NOTE: "." INDICATES LOCATIONSFOR VELOCITY MEASUREMENTS WATER DEPTH = 26.5 FT.AMBIENT CURRENT 0 KTS. 0.2 KTS. 0.4 KTS.2 1 0 2 1 0 2 1 0 FACE VELOCITY (FT/SEC)VELOCITY PROFILES AT INTAKE FACE SECTIONAL MODEL (NINE MILE POINT INTAKE)z~L FIGURE 21 1.0-0.4 KNOT (0.68 FT/SEC)OCEAN CURRENT al 0-j Lu D.5-0 II ..~0 5 0 10 5 15 0 20 25 30 DISTANCE UPSTREAM OF INTAKE FACE (FEET)INTAKE APPROACH VELOCITIES SEABROOK ALTERNATIVE A INTAKE 4~IL

-n'1"1A I AMBIENT CURRENT t1 I)>~WATER DEPTH 60 FEET CURRENT MAGNITUDE

0.2 KNOTS

CURRENT DIRECTION S PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)ALTERNATIVE A INTAKE -SEABROOK OVERALL MODEL STREAK LINES -OFFSHORE LOCATION zA1L AMBIENT CURRENT\3/4WATER DEPTH 61) FEET CURRENT MAGNITUDE

0.4 KNOTS

CURRENT DIRECTION S PLANT FLOW RATE 1822' CFS (607 CFS PER INTAKE)ALTERNATIVE A INTAKE -SEABROOK OVERALL MODEL STREAK LINES -OFFSHORE LOCATION'11 C

'-'1 C)ml I AMBIENT CURRENT.A.lýWATER DEPTH 60 FEET CURRENT MAGNITUDE

0.2 KNOTS

CURRENT DIRECTION S-65eW PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)ALTERNATIVE A INTAKE -SEABROOK OVERALL MODEL STREAK LINES -OFFSHORE LOCATION/JL 4 AMBIENT CURRENT WATER DEPTH 60 FEET CURRENT MAGNITUDE

0.4 KNOTS

CURRENT DIRECTION S-65OW PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)ALTERNATIVE A INTAKE -SEABROOK OVERALL STREAK LINES -OFFSHORE LOCATION MODEL m hi~I "1'm 4 AMBIENT CURRENT WATER DEPTH 30 FEET CURRENT MAGNITUDE

0.2 KNOTS

CURRENT DIRECTION S PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)/I!ALTERNATIVE C INTAKE -SEABROOK OVERALL MODEL STREAK LINES -ONSHORE LOCATION 0 AMBIENT CURRENT I WATER DEPTH 30 FEET CURRENT MAGNITUDE

0.4 KNOTS

CURRENT DIRECTION S PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)ALTERNATIVE C INTAKE -SEABROOK OVERALL MODEL STREAK LINES- ONSHORE LOCATION'1lýi 0 0 m cN 4 AMBIENT CURRENT ,4-1ýWATER DEPTH 30 FEET CURRENT MAGNITUDE

0.2 KNOTS

CURRENT DIRECTION S-65 0 W PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)MODEL ALTERNATIVE C INTAKE -SEABROOK OVERALL STREAK LINES -ONSHORE LOCATION AMBIENT CURRENT WATER DEPTH 30 FEET CURRENT MAGNITUDE

0.4 KNOTS

CURRENT DIRECTION S-65 0 W PLANT FLOW RATE 1822 CFS (607 CFS PER INTAKE)ALTERNATIVE C INTAKE -SEABROOK OVERALL MODEL STREAK LINES -ONSHORE LOCATION"11 G)m ni f2L1t FIGURE 30 WATER DEPTH 60.0 FEET AMBIENT VELOCITY 0 KNOTS PLANT FLOW RATE 1822 FT 3/SEC (607 CFS PER INTAKE)VELOCITY PROFILE DURING BACKFLUSHING ALTERNATIVE A INTAKE -OFFSHORE LOCATION FIGURE 31 30 0 20 UJ U.-J UJ 0 0 1-I0 0 2 4 6 8 10 12 14 ACTUAL PIPE VELOCITY IN MODEL (FT/SEC)INTAKE VELOCITY FLUCTUATIONS DURING REVERSE FLOW SEABROOK ALTERNATIVE A INTAKE h%;L FIGURE 32 4.0 I-w 0 U-U-0 (-I LU-J 0 w<LU 3.0 2.0+ A-7: Ii :XT-1IT II.::E:,::... ...1 7j ---l- -- -1.0 0.0 0 100,000 200,000 REYNOLDS NUMBER BASED ON MODEL INTAKE SHAFT DIAMETER 0 ALTERNATIVE C INTAKE 0 ALTERNATIVE C INTAKE U ALTERNATIVE A INTAKE A ALTERNATIVE A INTAKE-NORMAL FLOW-REVERSE FLOW-REVERSE FLOW-NORMAL FLOW LOSS COEFFICIENT DATA 4Rlý FIGURE 33 50 NCLAMPED r,.

RANGE OF NATUI g (CIR CULAR GUARD BARI ,- ... .t.o ............. ....... ..........Lui ` h .... .. .............

........ .. ....0 -10 I I I 0 2 4 6 VELOCITY (FEET/SECOND) 8 10 12 GUARD BAR VORTEX SHEDDING FREQUENCY Appendix D July 31, 2007 USEPA Comment Letter to FPL

• " 'S, UNITED STATES ENVIRONMENTAL PROTECTION AGENCY REGION 11 CONGRESS STREET, SUITE 1100BOSTON, MASSACHUSETTS 02114-2023 CERTIFIED MAIL -RETURN RECEIPT REQUESTED July 31, 2007Mr. Allen L. Legendre Environmental Services Supervisor FPL Energy Seabrook, L.L.C.

Seabrook Station Lafayette Road Seabrook, NH 03874-4213 Re: Supplemental Information Request Pursuant to Section 308 of the Clean Water Act to Supercede Previous Letter dated December 30, 2004 for Seabrook Station NPDES Permit Reissuance

-[NPDES Permit No: NH0020338]

Dear Mr. Legendre:

The United States Environmental Protection Agency's office for the New England Region (EPA or the Region) is sending this letter to clarify and update certain information submission requirements for FPL Energy Seabrook related to the Seabrook Nuclear Power Station's (Seabrook Station or the Station) application for reissuance of its National Pollutant Discharge Elimination System (NPDES) permit (NPDES Permit No.

NH0020338).

The information requirements in question pertain to your facility's cooling water intake structures (CWISs)regulated under section 316(b) of the Clean Water Act (CWA). See 33 U.S.C. § 1326(b).Seabrook Station's NPDES permit authorizes the facility to discharge pollutants into, and wi--draw cooling water from, the Atlantic Ocean. The Station's curre.nt permit expired oh April 1, 2007. The permit was administratively continued, however, because the Station timely applied to EPA for permit reissuance. As a result, Seabrook Station remains subject to the existing permit until EPA issues it a new one.With any NPDES permit reissuance, EPA evaluates a facility's current compliance with applicable standards, including the requirements of CWA § 316(b) governing CWISs. To satisfy§ 316(b), the location, design, construction and capacity of a facility's CWISs must reflect theBest Technology Available (BTA) for minimizing adverse environmental impacts.On December 30, 2004, EPA issued FPL Energy Seabrook an information request letter under CWA § 308 (the December 30, 2004 § 308 Letter). CWA § 308(a), 33 U.S.C. §1318(a), authorizes EPA to require the owner or operator of any point source to make reports and provide information as may reasonably be required to: Toll Free 888-372-7341 Internet Address (URL) a http://www.epa.gov/regionl Recyclecl/Recyclable -Printed with Vegetable Oil Based Inks on Recycled Paper (Minimum 30% Postconsumer)

... carry out the objectives of ... [the CWA], including but not limited to: (1) developing or assisting in the development of any effluent limitation, or other limitation, prohibition

... or standard of performance under [the CWA] ...; (2) determining whether any person is in violation of any such effluent limitation, or otherlimitation, prohibition or effluent standard,.

.or standard of performance; (3)any requirement established under this section; or (4) carrying out section...

1342 ... of [the CWA] ....The December 30, 2004 § 308 Letter required Seabrook Station to submit certain information to EPA by no later than January 7, 2008 for the purpose of developing CWIS limits under CWA

§316(b) for Seabrook Station's permit reissuance.

EPA's Phase II Rule for CWISs under CWA §316(b), 40 C.F.R. Part 125, Subpart J (the Phase II Rule or the Rule), set national performance standards for, and information submission requirements regarding, CWISs at large, existingpower plants.

Because Seabrook Station was subject to the Phase II Rule, EPA's December 30,2004 § 308 Letter required the submission of information consistent with the requirements of theRule. The required information included: 1. a Proposal for Information Collection (PIC) satisfying 40 C.F.R. §125.95(b)(1) by no later than October 7, 2006;2. a Comprehensive Demonstration Study (CDS) satisfying 40 C.F.R. § 125.95 by no laterthan January 7, 2008; and 3. the information required by 40 C.F.R. §§ 122.21 (r)(2), (3) and (5) by no later than January 7, 2008.On January 25, 2007, the United States Court of Appeals for the Second Circuit issued its decision in a law suit challenging the Phase II Rule. See Riverkeeper, Inc. v. EPA, 475 F.3d 83 (2d Cir. 2007). The court struck down certain provisions of the Rule and remanded several others to the Agency for reevaluation.

On March 20, 2007 Benjamin Grumbles, EPA Assistant Administrator for Water, sent a memorandum to EPA's Regional Administrators dictating that the Phase II Rule should be considered suspended because so many of its provisions are affected by the court decision.

In addition, the March 20, 2007, memorandum directed that "[uin the meantime, all permits for Phase II facilities should include conditions under § 316(b) of the Clean Water Act developed on a Best Professional Judgment (BPJ) basis. See 40 C.F.R. §401.14." More recently, on July 9, 2007, EPA formally suspended the Phase II Rule, with the exception of 40 C.F.R. § 125.90(b), by publishing a notice of suspension in the Federal Register.See 72 Fed. Reg. 37107 (July 9, 2007). Under 40 C.F.R. 125.90(b), permitting authorities are directed to establish

§ 316(b) requirements on a BPJ basis for existing facilities not subject to categorical standards contained in EPA regulations. As the Federal Register notice states, the BPJ requirement is consistent with the CWA, case law, and the March 20, 2007 memorandum's direction to do so. See 72 Fed. Reg. at 37108.In light of these developments, the Region is now issuing FPL Energy Seabrook this supplemental information request letter under CWA

§ 308. This letter clarifies and updates, 2 consistent with 40 C.F.R. § 125.90(b), the information submission requirements of the December 30, 2004 § 308 Letter. While the requirements of this letter are similar to those in the December 30, 2004 § 308 Letter, there are some differences.

This new § 308 letter supersedes the December 30, 2004 § 308 Letter and seeks information to assist EPA in developing new CWISlimits under CWA § 316(b) on a BPJ basis, consistent with 40 C.F.R. § 125.90(b).

Please be aware that any failure to comply with the requirements of this § 308 letter could, depending on the circumstances, subject FPL Energy to enforcement action pursuant to § 309 of the CWA, 33 U.S.C. § 1319.Schedule for Information Collection and Submission

1. EPA received the Seabrook Station PIC dated May 4, 2006, pursuant to the December 30, 2004, § 308 letter. EPA reviewed the PIC and sent FPL Energy a letter, dated December 6, 2006, detailing additional information that EPA needed to develop and reissue Seabrook Station's NPDES permit. The information requested in EPA's December 6, 2006, letter is required as part of the response to this § 308 letter to be included in the CWIS Information Document, described in Attachment A.2. As expeditiously as practicable, but not later than January 7, 2008, the Station shall submit a CWIS Information Document that satisfies the specifications detailed in Attachment A to this letter. The purpose of this document will be to:* characterize impingement, impingement-induced mortality, and entrainment by Seabrook Station's CWISs;* describe the operation of the facility's cooling water intake structures;

• evaluate both the existing technologies and operational measures, as well as possible additional technologies and operational measures, as potential components of the BTA under § 316(b); and* establish whether the technologies and/or operational measures already installed, or that the Station proposes to install, at the facility reflect the BTA under CWA §316(b).See Attachment A of this letter detailing the information requirements for the Station's CWIS Information Document.3. The Station shall also submit to EPA by January 7, 2008, the information described in 40 C.F.R. §§ 122.21 (r)(2) and (r)(3), which includes: , Source Water Physical Data" Cooling Water Intake Structure Data With regard to the information that must be submitted under this letter, FPL Energy may assert a business confidentiality claim with respect to part or all of the information submitted to EPA in 3 the manner described at 40 C.F.R. § 2.203(b).

Information covered by such a claim will be disclosed by EPA only to the extent, and by means of the procedures, set forth in 40 CFR Part 2, Subpart B. If no such claim accompanies the information when it is submitted to EPA, it may be made available to the public by EPA without further notice to FPL Energy.

Please note that"effluent data" under 40 C.F.R. § 2.302 may not be regarded as confidential business information.

Please note that to the extent you have already submitted any of the requested information to EPA as part of another submission, it is sufficient for you simply to reference where in the other submission the pertinent information is provided.Please address your information submittals to: Damien Houlihan Office of Ecosystem Protection U.S. EPA Region 1 One Congress Street, Mail Code CIP Boston, MA 02114-2023 EPA looks forward to working with you on your new permit.

If you have any questions concerning the required information requested above, please contact Damien Houlihan at (617)918-1586.Sincerely, Stepp Perkins, Director Office of Ecosystem Protection cc. Harry T. Stewart, NHDES Mark Stein, EPA Sharon DeMeo, EPA David Webster, EPA 4 Attachment A Information Requirements for the Cooling Water Intake Structure Information Document Source Waterbody Flow Provide the delineation of the hydraulic zone of influence for your cooling water intake structure (CWIS).Technology and Biological Assessment Information1. Please provide a detailed description of Seabrook Station's cooling system, including:

a. the cooling water intake structure and related equipment, b. the discharge canal or pipe, c. a cooling process flow diagram depicting the flow of cooling water through the facility, d. all pumps of any type used in the cooling system, e. any equipment for adding disinfectant or biocide to the cooling water, f. any equipment used for chilling the cooling water after it has been heated up in the power plant, and g. design calculations showing the velocity at the entrance to each intake structure atminimum ambient source water surface elevations.

You must also provide a narrative description of the operation of the Station's cooling watersystem, the role of each CWIS in the overall cooling water system, the proportion of the design intake flow of each CWIS that is used in the system, the number of days of the yearthe cooling water system is in operation, and any seasonal changes in the operation of the system. In addition, you must include design and engineering calculations prepared by a qualified professional and relevant data to support your description of your cooling water system.As part of this description, please also identify the age of the equipment and facilitiesinvolved and provide a brief description of all major upgrades and repairs to this equipment accomplished since January 2001.2. Please identify the projected retirement date, if any, of Seabrook Station's existing operation.

3. Please provide a description of the processes employed at Seabrook Station with regard toboiler operation, condenser operation, CWIS operation, and effluent treatment operations (including any chilling or cooling of heated cooling water). To the extent that this information is provided under item No. 1 above, you may simply cross-reference to where in your submission the information is already provided.5

4. Please describe the engineering aspects or considerations pertinent to considering the possible application of the following technologies at Seabrook Station:

a. Mechanical draft or natural draft cooling towers for use in a recirculating (or "closed-cycle") cooling system for the generating unit and service water system at Seabrook Station. The analysis must specify the number of cooling tower cells required based on the facility's heat balance, space requirements, a discussion of the major components that would need to be added, and the major modifications to the facility that would need to be undertaken, to retrofit Seabrook Station with this technology.

b. CWIS screening systems or barrier technology that will minimize entrainment, impingement, and impingement mortality.

Each analysis must include a discussion of the major components that would need to be added, and the major modifications to the facility that would need to be undertaken, to retrofit Seabrook Station with this technology.

c. The use of "grey" water for cooling purposes. Potential sources of grey water include the Seabrook Wastewater Treatment Plant and the Portsmouth Wastewater Treatment Plant.d. The reduction of cooling water flow (i.e., "capacity")

by using variable speed pumps and/or by reducing pumping operations from the current three pump operation.

' Such evaluation shall include consideration of any configuration, and/or additional "stand-by" pumping systems that may be necessary to address any safety concerns.e. Any other technology that you deem worthy of consideration for reducing Seabrook Station's entrainment and/or impingement mortality of aquatic organisms.

5. For each of the technologies evaluated under Item No. 4 above, please provide: a. A detailed explanation of the process changes required to operate and maintain such technologies.

b. An estimate of the most stringent thermal discharge limits that Seabrook Station would be able to comply with utilizing the technology in question.c. An estimate of the most stringent cooling water withdrawal flow limits that the facility would be able to comply with utilizing the technology in question.d. An estimate of the most stringent cooling water intake velocity limits that the facility would be able to comply with utilizing the technology in question.I As you are aware, Seabrook Station's CWIS was originally designed to provide cooling for two reactors. Since only one reactor was built, EPA believes that the capacity of Seabrook's CWIS may be as much as twice that which is necessary to cool the plant.6

e. An estimate of the extent to which (1) impingement, (2) impingement mortality, and (3)entrainment would be reduced at Seabrook Station by utilizing the particular technology.

f To the extent that you believe any of these technologies would be infeasible for implementation at Seabrook Station, provide a detailed explanation for your conclusion in this regard.g. An estimate of the cost for installing and operating each of these technologies.

h. Please describe in detail the non-water quality environmental impacts (including energy, air pollution, noise, public safety), if any, that you have determined will occur from the use of each technology.

6. Please provide all fisheries data collected during entrainment and impingement sampling conducted from 2002 to 2007, including all data collected by Seabrook Station. Specifically, EPA requests the following for each sampling event that was conducted:

a. Number of eggs of each fish species collected;

b. Number of larvae of each fish species collected;

c. Number of fish (juvenile and adult) of each species collected;

d. Duration of sampling event (in hours);e. The location and method of sampling; and f. The ambient water temperature(s) measured during the sampling event.7. Provide the following, based on the data described above in Item No. 6: a. The estimated average number of eggs entrained per calendar month for each species, and the estimated annual total number of eggs entrained for each species, based on Seabrook Station's typical recent water withdrawal rate for each calendar month;b. The estimated average number of larvae entrained per calendar month for each species, and the estimated annual total number of larvae for each species, based on Seabrook Station's typical recent water withdrawal rate for each calendar month;c. The estimated average number of fish (juveniles and adults) of each species impinged per calendar month, and the estimated annual total number of each species impinged, based on Seabrook Station's typical recent operations for each calendar month;d. The estimated number of "adult equivalent" fish of each species lost to entrainment and impingement for each calendar month, and an annual adult equivalent total for each species, based on Seabrook Station's typical recent water withdrawal rate and operations for each calendar month; and e. All assumptions, methods and calculations for each of the above estimates of entrainment and impingement effects.7 Other Information Reciuested

a. Provide the information requested in EPA's December 6, 2006, letter.b. Provide a description of the combination of existing and proposed technologies andoperational measures at Seabrook Station for which Seabrook Station believes the location, design, capacity, and construction reflect the Best Technology Available for minimizing adverse environmental impacts.8 ARCADIS Appendix E Seabrook Station Facility Description Document Seabrook Station FACILITY DESCRIPTION While every atten 1'this vlume, it w4 Facih' escri orlo made to incorporate the latest design and specification revisions into edto be used as a technical manual. Therefore, this Seabrook Station ukd for informational purposes only.

chapter, Overview .........

..................................

5 3"!4.1.'7 8.9! ,11 Energy From The Atom.. ..................................Reactor Control ...............................Station Design ........ ................................

Site Layout ....... .................................

Reactor Coolant System ...... ...........................

Emergency Core Cooling Systems- ECCS ..................

Reactor Auxiliary Systems ...... ..........................

Reactor Containment Building ..............................

Secondary Plant Systems ................................Main Steam and Feedwater Systems ... ................. ....Circulating W ater System ..............

.

..........

Auxiliary Cooling ..............................

Electrical System s ..............................

6 8 9 10 12 14 16 20 22 23 24 26 28 31 32 34 Appendix-Principal Materials

-Containment Design-Construction Photos.....................I ...................-, ...........

TI~6;J

Ceabrook Station is located in Seabrook, New Hampshire on a peninsula slightly higher)than the surrounding salt marsh and estuarine waters. The 900-acre site is two miles inland from the Atlantic Ocean, forty miles north of Boston, Massachusetts and eleven miles south of Portsmouth, New Hampshire.

The Station was designed to be a twin unit 1160 mega-watt nuclear generating station.Unit 2 was cancelled in 1986 at 25% completion.

Unit 1 utilizes a pressurized water reactor design (PWR) developed by Westinghouse Electric Corporation and a turbine generator built by General Electric.7>i f 5 C S eabrook Station uses the nuclear reaction called fission to generate heat. Fission is the splitting of the heavy nucleus, the center of an atom such as uranium, into two or more principal fragments, as well as lighter pieces, such as neutrons. In a nuclear reactor this splitting is induced by the colli-sion of a neutron with a fissionable nucleus.Neutrons are one of the two basic parts of nuclei and, as noted, are released during fission and become available to induce subsequent fission events. A "chain" reaction is initiated which may be sustained under controlled conditions in a nuclear reactor. The fission process takes place entirely within the fuel assemblies which make up the core of the reactor.FISSION PROCESS JAV 4,11 URANIUM ATOM HEAT The principal feature of a nuclear reactor is the release of a large amount of energy from each fission that occurs in the core. On the aver-age, a fission event releases about 200 million electron volts (MEV) of energy.A typical chemical reaction releases about one electron volt-a difference of 200 million.This is why the complete fission of one pound of uranium would release roughly the same amount of energy as the combustion of 6000 barrels of oil or 1000 tons of high-quality coal.

The heat energy generated by fissions in the reactor core must be transferred into the energyof high pressure steam, then into mechanical energy and finally into electricity.

The follow-ing schematic drawing is representative of the major heat transfer processes used in pressurized water reactor (PWR) generating stations, including Seabrook Station.The process may be described by reference to the schematic and the numbered flow loca-tions. Three major fluid or heat transfer cycles are used. The reactor coolant water shown (Labeled A) is a closed cycle loop using water at 2,235 pounds per square inch pressure (psi). The feed water and steam cycle (Labeled B) is also a closed loop operating at up to 1,200 psi. The condenser cooling or circulating water (Labeled C) uses water from the ocean. This is the only fluid stream or system open to the environment.

Heat generated in the reactor core(2) is transferred to the reactor coolant water which is pumped through the reactor vessel(l) to the four steam generators(5) and the connecting pip-ing by four-reactor coolant pumps(3).

The pressurizer(4) maintains the reactor coolant system (also known as the primary system) at a pressure of 2,235 psi to prevent boiling and to keep the coolant in the liquid state. The reactor coolant, at an average temperature of 587 IF flows through the 5000 U-tubes in each of the four steam generators.

Heat is transferred through the thin tubes of insonel to the feedwater on the out-side of the tubes. The steam side of thesteam generators (also called the secondary side) operates at a pressure of 1000 psi. At this pressure and the t6mperature of 545 IF the feedwater boils producing steam.The steam, produced at the rate of 15 million pounds per hour, flows from the steam genera-tors(5) through valves to the turbine(6).

The Seabrook Station turbine design uses onehigh-pressure unit and three low-pressure units connected on a single shaft to the generator(7).

A

7. Generator 8. Step-Up Transformer

9. Condensate

& Feed Pumps 10. Condenser 11. Circulating Ocean Water The steam entering the turbine at 990 psi and 545 OF exhausts from the low pressure tur-bines into the condenser(1

0) at an absolute pressure measured as two inches of mercury (about 1 psi absolute) and a temperature of 100 0 F. At this point, all the energy which can be usefully recovered from the steam has been converted to mechanical energy in spinning the turbine. The steam is condensed(1

0) to the liquid state and pumped(9) through a series offeedwater heaters back into the steam generators.

Condensing the steam back to feedwater requires removing heat. This is done by pumping ocean water(1 1) through titanium tubes in the condenser(1 0). Steam condenses on the out-side of the tubes as its latent heat of condensation is transferred to the circulating water.

The temperature of the circulating water is raised 34 OF in the process.The electrical output of the unit leaves the generator(7), is raised in voltage by the step-up transformer(8) and transmitted at 345,000 Volts to the New England transmission grid.7 .E ach fission of a fuel atom produces an average of two additional neutrons.

Maintenance of a stable chain reaction and power level requires that the excess number of neutrons be con-trolled. Two control processes are used to capture by absorption a portion of the excessneutrons. Moveable control rod assemblies composed of silver, indium, and cadmium clad in stainless steel are inserted in 57 of the 193 fuel assemblies.

The amount of insertion is adjusted by the control rod drive mechanisms in response to signals from the reactor control system.The further into the core the control rod assemblies are inserted, the more neutron absorption will occur and the lower the power level will be. Full insertion of all the control rods shuts down the reactor. Control rods are primarily used to start-up and shutdown the reactor.During full power operation, the control rods are usually fully withdrawn from the core.The second control method is based upon the neutron-absorbing property of boron. Boron in the form of boric acid is dissolved in the reactor coolant water so that the desired con-centration of boron is present in the water and therefore present throughout the reactor core as the coolant flows up through the fuel assemblies.

Early in a core cycle after new fuel has been loaded in the reactor, the number of neutrons to be controlled is higher than late in a core's life when other neutron absorbing fission products are present. Therefore, after refuel-ing the boron concentration is highest. As fuel burnup occurs, the concentration is decreased towards 0 ppm by the end of the core life. Boric acid is the primary means of control during full power operation.

Since boric acid would attack ordinary carbon steel,piping and equipment in contact with the reactor coolant water are made of stainless steel.ýNRUI UtMR AM OmPM.Wentinghouss 17 X 17 FUEL ASSEMY%wsznghomm NUCLEAR~ REACTOR 8

I~A rhe design of Seabrook Station has been determined by the summation of many regula-1tory requirements and management objectives.

The most important objective of the owners and regulators is a unit which operates safely with a minimum risk to the public and the operators.

Environmental protection is the second paramount objective.

The third goal is efficient and reliable operation over an extended period to minimize energy cost.

A philosophy, often referred to as 'safety in depth,' has been practiced at Seabrook Station.Three levels of challenge to the station's safety are presumed for design and analysis pur-poses. In performing this analysis it must be remembered that as long as there is water in the reactor vessel, the core will be cooled and public risk is minimal. All safety features are designed to ensure the core has water around it at all times.Level One -Prevent accidents through plant design by using high quality standards, redundancy, testing and inspection of equipment.

-Anticipate operating transients or operating errors by providing protective devices and systems, using conservative design practices and built-in safety margins, and by using redundant detection and actuation devices.Level Three -Postulate occurrences of extremely unlikely circumstances by hypothe-sizing severe accidents and incorporating safety systems to handle the resulting situations.

The specific requirements upon which design and construction are based are listed in the Updated Final Safety Analysis Report. Since so many of the station's facilities and such a large percentage of its cost result from safety and environmental protection commitments, the principal design criteria are listed below. Individual systems and structures are described on the following pages. The artist's drawing on the center pages is useful in locating specific plant components.

SAFETY DE.SIGN CR HITERIA P Seismic design based on a ground acceleration of .25g& 300 mph tornado advancing at 60 mph#. Ability to shut down the reactor safely from outside the control room&.Physical and electrical separation of redundant components

• Protection from flood waters 20.6 feet above mean sea level e' Protection from aircraft and wind-driven objects 4 Protection against dynamic effects from ruptured pipes o0 Piping supports designed as ASME code components

0; Fire protection based on arbitrary fire A. No permanent facilities constructed in the salt marsh 9

Trhe U.S. Nuclear Regulatory Commission (NRC) requires nuclear station owners to have legal control of the land around the station out to a distance called the exclusion bound-ary. At Seabrook Station, the radius of the exclusion boundary is 3000 feet from each reactor. In addition to the 730 acres defined by the exclusion radius, the site includes 170 acres outside the circle. Approximately 500 acres are considered wetlands and have not been infringed upon by the project. The site is underlain with competent granite bedrock upon which all the major structures are founded. The finished grade of 20 feet above mean sea level was selected to place the facilities above the highest wave run up calculated to result from an ocean storm having a probability of occurring only once in 10,000 years.At the center of the site are the permanent structures of the station. They occupy about 50 upland acres as shown in the site drawing. A security fence encloses Unit 1 as required by the NRC security regulations.

The Station had been arranged with Unit 2 to be a twin of Unit 1. Unit 2 was cancelled by the Joint Owners at about 25% completion.

Many Unit 2 building shells remain on plant property outside the Protected Area fence., t" i NEW j, .XEIEH k AMPTOW,- ; Atlanti KI HMPT N', wEAST~,__'" ' SO UIH "-.. ..KN ... SITE ENVIRONS" ,A 2-mile radius W--.. ....P"x: o. B 5-mile radius* ...... ,..\C 10-mile radius' map to the left shows the towns in the; " vicinity of Seabrook Station. The 1 0-mile M a eradius, circle C, encompasses the towns Masschuetts in the emergency planning for the station 4A STATION STRUCTURES 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Containment Building Turbine Building Administration Building Diesel Generating Building Control Building Waste Process Building Tank Farm Primary Auxiliary Building Fuel Storage Building Cooling Tower Security Building Switchyard Transformer Area Condensate Storage Tank Demineralized Water Tanks Maintenance BuildingCirculating Water Pump House Service Water Pump House Rad Water Storage Building Intake Structure Discharge Structure 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 Chlorination Building Seawall General Office Building Training Center Science & Nature Center Fuel Oil Storage Tank Fire House Pump and Tanks Operation's Support Building 345 Kv Termination Area Warehouse No. T Warehouse No. 2 Warehouse No. 3 Equipment Maintenance Shop Siren Maintenance Fire ProtectionPipe Shop Hi-Rise Office Building General and Specialty Training Dept.Weld Shop Electrical Shop 11 T he reactor coolant system (RCS), also called the primary coolant system, consists of four similar heat transfer loops connected in parallel to the reactor pressure vessel. Each loop contains a reactor coolant pump, steam generator and associated piping and valves. In addi-tion, the system includes a pressurizer, pressurizer relief tank, pressurizer relief and safety valves, interconnecting piping, pipe Supports and instrumentation necessary for operational control. All the above components are located in the containment building.

Collectively, this equipment is often referred to as the nuclear steam supply system (NSSS).During operation, the RCS transfers the heat generated in the core to the steam generators where steam is produced to drive the turbine generator. Demineralized water to which boricacid has been added is pumped through the RCS at a flow rate and temperature consistent with achieving the required heat transfer and core cooling. The water also acts as a neutron moderator and reflector by slowing down the neutrons so they can effectively cause more fissions.The RCS pressure bouncla'y provides a barrier against the release of radioactivity generated within the reactor, and is designed to ensure a high degree of iniegrity throughout the life of the plant.RCS pressure is controlled by the use of the pressurizer, where water and steam are main-tained in equilibrium by electrical heaters and water sp;rays. Steam can be formed (by the heaters) or condensed (by the pressurizer spray) to minimize pressure variations due to contraction and expansion of the reactor coolant. Spring-loaded safety valves and power-operated relief valves mounted on the pressurizer provide steam discharge to the pressurizer relief tank.12 REACTOR COOLANT SYSTEM FLOW DIAGRAM MODEIL F STEAM GENERATOR 13 rcE, ýG EM RE 7ý_ T CO0 JNG E evere accidents have been hypothesized in the "safety-in-depth" planning and design 3process for Seabrook Station. Although not expected to occur, these events provide yard-sticks to measure the effectiveness of the engineered safeguards for the station, some of which are represented by the emergency core cooling system (ECCS). Analysis shows that as long as water is in contact with the reactor core, severe fuel damage (fuel or clad melt) willbe avoided and public risk minimized.

The ECCS ensures that water can be kept around the core under all the specified conditions.

Equipment is provided to respond to a wide range of loss of coolant conditions.

To replace water lost if a small leak develops in the reactor coolant system, a high-pressure pump with a relatively small capacity is required.

At the other end of the leakage, or pipe break spec-trum, a large break would quickly reduce the RCS pressure.

The ECCS in this situation is able to replace a large quantity of coolant at a low pressure.

The components of the ECCS are arranged in two safety trains that are physically and electrically separate, designed towithstand earthquakes, protected from missiles and storms and operable following powerfailures. Some of the ECCS components also serve functions in other systems. For example the residual heat removal pumps serve as low pressure safety injection pumps as well as in their residual heat removal function.

The diagram on the next page shows how equipment is utilized in the ECCS.The design of the ECCS is based on using redundant sets of equipment and upon detecting coolant leakage by diverse types of instruments.

A loss of water in the reactor coolant sys-tem can be recognized by falling water level in the pressurizer, reduced pressure in the system and increased make up flow. Independent of the reactor coolant system instrumenta-tion, rising water in the containment sump or increasing humidity are conditions giving warning of a potential problem. The design of the ECCS equipment trains ensures that thesame source of power is used to supply the instruments, valves and pumps in a train.ECCS COMPONENT NUMBER CAPACITY PRESSURE Centrifugal charging pump 2 150-550 gpm 2700-675 psi Safety injection pump 2 425-650 gpm 1650-1100 psi Residual heat removal pumps 2 3000-4500 gpm 600-180 psi-(passive) 4 850 cu. ft. 700 psi-r N. --%

ajflc.tffOtn ca4~Ta~t *~ A NSPAYI tAGS

_____I ___________

4RE4MOJ ENGINEERED SAFETY FEATURES FLOW DIAGRAM Sever.a'l systems of pumps, piping, filters, controls, equipment and their physical supports.are necessary to operate the reactor coolant system. The volume of water in the RCS needs constant adjustment.

The purity of the reactor coolant and the concentration of chem-ical additives in it need continuous monitoring and maintenance.

Periodically new reactor fuel and used or spent fuel need to be moved. Decay heat in the spent fuel also needs to be removed. In the following paragraphs the major primary auxiliary systems that carry out these functions are briefly described.

After the reactor is shut down, heat is still produced in the fuel due to the continuing decay of fission-produced isotopes.

This heat must be removed when the reactor is shut down and in the "cold" condition.

For example, this is required during the refueling operation.

To accomplish this, reactor coolant is pumped from two of the reactor coolant pipes leading to the steam generators (hot leg), through two RHR heat exchangers for cooling and back to two reactor coolant cold leg pipe connections and into the reactor vessel.The RHR system also serves an emergency core cooling function. Under loss-of-coolant accident conditions, the RHR pumps would act as low-pressure safety injection pumps.Initially they would take borated water from the refueling water storage tank and pump it into the reactor coolant system. After the refueling water has been injected, the RHR pumps and heat exchangers would be used to recirculate and cool water from the contain-ment for reinjection.

004h 661 c~ihad VOluifdeo fai~tful SWstem-(VCS), The chemical and volume control system is designed to perform several complex functions which include:-regulating the concentration of boron in the reactor coolant to control reactivity changes resulting from coolant temperature changes, fuel burnup, fission product buildup and xenon transients.

-maintaining the coolant inventory in the reactor coolant system.-removing fission and activation products in ionic, gaseous or particulate form.-counteracting the production of oxygen resulting from radiolysis of water in the.core region.-supplying filtered water to each reactor coolant pump shaft seal.-Some componentsIf'trthe system also perform an emergency core cooling function.

F66 Nhl Haflng Sytem: storage uhg maipulators and transport mechanisms.

This function is accomplished underwater for shielding and cooling purposes.kif Idig S., r- ., .'-t. l "-' 7' ' .. ..,._- .,6f Sampling System Provision is made for sampling of water from various locations in the reactor coolant sys-tem. Gases from the pressurizer can also be collected and sampled. Sampling and analysis are an integral part of reactor coolant chemistry control. By careful chemistry control, equip-ment maintenance is reduced, better fuel economy realized and personnel exposure to radiation reduced.Boron Recovery System--BRS)

Water which is removed from the reactor coolant system as the system comes to power and heats up is collected and processed in the boron recovery system.Likewise, as the fuel reactivity decreases with core burnup, water is removed from the RCS and replaced with water having.a lower boric acid concentration so that fewer neutrons willbe captured in the boron. The BRS is installed to evaporate the collected letdown water, concentrate the boric acid and condense the distillate.

After further purification, the water and boric acid may be reused at cost savings.PCCW I. *11 ON11MIXE DEM. oIE BED IFILTER DIEMINERAL14i DE kINnE ALVZE R 8ORIC ACID TANKS REACTOR COOLANT SYSTEM INTERFACE WITH CHEMICAL and VOLUME CONTROL SYSTEM 17 Seabrook Station Seabrook, New HampshireA PRESSURIZED WATER REACTOR UNIT GENERATING 1,160 MEGAWATTS OF ELECTRICITY 1 1) Waste disposal building U =entsnn toadwauat pumpbuil ng NI Circulating ate pamploim"Kmovnn tot dorawee A) Rectorcontirmeit (r 0)Waket'-KV naltransiteiond s1.Ractor vessel2 Stenam 9nnetaoa 3. 4. Procto -lant pump

5. Equipmetnt hatch

6. Rafueling casp 7, Polar gantry crane 8. Contaiment spray p 1a0n9 9. Minne shield

10. Main $tean lines11. Reactor coolant pipe

12. High pressute turine 13. Low pressrne turbines (3)14. Generator

15. Exciter 16. Moisture separator renewer17. Turbine hall criae 18. Steam gonerator lead pumps 19. Conden, shelw 20. HlgpresM floetermaems 169 stage)21. Second" componentcoolirg heat exchatgetO

22. Lowpesnuen fodcwatet 23. Non-segregtald ohasm staion serie bus 24C Keater bay Grone25 Main steam cont vaaes.21 Feedwtent, control hiss

27. Main control board28. Reactor protecton and othter log ,cabinets29. Computer room

30. suppobt coert 31. CabW snpredig mom32. Station betooes 3a. Smrtgw 34. Noa!gndrator

35. Fuel torage uar 38. Starting air corprpocir

37. Class! eons alliance 38. Nmw ful sturage 39. Fuel t-ngser canal 40 Cask loading nsa41 Spentd elW 41ag42. Spent fuel poel hot a&chengir43. Spent futl cask shlippng aee

44. Bon, aod etaraue tanks 46. Bantc add mixing46. Let-dms legessfilrs47. Volume, ootrol Was 48a pr: plent sir49. Auxgiery building ahait at50. Let-down detninetallwn and Pltent 51. Primaery coponentuooning pumps 51pia ry ompontentce=Ing

54. Rdaolng aýeormrge tank 55. Spnay chenicel adsP~lart"e 88 W. iesenos tritn,ks J 4 07. Rociortataet -sbL-ptak 88. Basa eson tann k.tod M 60. Primary dr., tank (2l&ZtRoomen yam itank 2 (a Solid wage pmne-Ng 8K Wante bfiqd degeassifier

85. Sta oesoblewasral ono y a-n ,,. an, 68. Coao t1er- c m etedfi 68. Pat&8p.ll~gla.K~toea 78arlicastio meter -psip 71. 'frmlnelrgonoo-

72. ktukttlurptstud fasbey 73. OlDishage valves N, Gkt flush Co44rn 74 Disabenge dervtebft 7&. oherrlmad ,sner vtang wk.9 74L Soe ,all 77. Gas kol-sltatd Sl-naenloatn line, 78.Aauirllary 1-ntfat-.

(41 M tpu unl r 3 atAspaday boiler 81I.Waler treatmenstplant OZ. Baoilr sucl 8B& Condensate stneor tank U4 P-rmay-nrtetanl88 Ser,4lonwanPlplSeabmok Station was designed to be two identical units that would a soma common facilities.

Unit 1 and the common facilities were completed in t and Unit 1 began commercial operation in 1990. Unit 2 was cancelled in 1 25% completion.

This rendering was Created in the late t970s and showspftt of Seabrook Station " key plant sys-tems. Although many of the cutaways in this randeog are drawn in what would have been Unit Z the position of those systems is accurate relative to their actual completed location in Unit 1.

(T he reactor containment building provides the third level of assurance in the "safety-in-depth" concept. It is designed and built to the requirements of the ASME Boiler and Pressure Vessel Code,Section III, Division 2. In addition, 117 other codes and specifica-tions, 19 NRC regulations and regulatory guides, and 30 United Engineers

& Constructors specifications contain requirements applicable to the design, construction and testing of the structure.

These are listed in the Updated Final Safety Analysis Report.

The containment building houses the major portion of the nuclear steam supply system.During the operating life of the plant, it also provides the following functions:

a. Provides continuing radiation shielding during normal plant operation in accordance with I OCFR20 and during accident conditions in accordance with I0CFR1 00.b. Protects the reactor vessel and all other safety-related systems, equipment and com-ponents located inside the containment against all postulated externalenvironmental conditions and resulting loads.c. Limits the leakage rate to 0.1 % by weight of the containment contained air mass per day under accident conditions.

The containment is a seismic Category I reinforced concrete dry structure, which is designed to function at atmospheric conditions.

It consists of an upright cylinder topped with a hemi-spherical dome, supported on a reinforced concrete foundation mat which is keyed into the bedrock by the depression for the reactor pit and by continuous bearing around the periph-ery of the foundation mat. The inside diameter of the cylinder is 140 feet and the inside height from the top of the base mat to the apex of the dome is approximately 219 feet. The net free volume is approximately 2,704,000 cubic feet.A welded steel 318-inch liner plate, anchored to the inside face of the containment, serves as a leaktight membrane.

Although not a code requirement, welds that are embedded in concrete and not readily accessible are SEISMIO (DIAGONAL)

REBAR covered by a leak chase system which per- OUTSIDE HOOP REBAR mits leak testing of those welds through-out the life of the plant.

The liner on top of the MERIDIONAL REE nine foot thick foundation mat is protected by ENSIDE a four foot thick concrete mat which supports RE the containment intervals and forms the floor INSIDE HOOP F of the containment.

The containment walls are 4.5 feet thick rein- LINER PLATE CONCRETE forced concrete.

The reinforcing steel in the walls is generally arranged in 11 layers using TYPICAL SECTION OF 185 reinforcing bars which are 2.25 inches in CONTAINMENTCONCRETE WALL diameter.

The same amount of steel used to make the reinforcing would make a plate 6 inches thick.20 Located outside the containment building and having a similar geometry is the reinforcedconcrete containment enclosure building.

This structure provides leak protection for the containment and protects it from certain loads. The containment enclosure building has an inside diameter of 158 feet and a wall thickness of 18 inches. The enclosure space is kept at a slight negative pressure should accident conditions occur. Together the containment build-ing and the containment enclosure provide what is referred to as the double" containment.

Engineer's drawings of the containment are shown on pages 32 and 33. The containment is one of the engineered safety features of the station.

The containment and the containment enclosure together with the enclosure exhaust system are designed to limit post-accident off-site doses to less than the requirements of Title 10 Code of Federal Regulations Part 100 (110CFR1 00). The design pressure of the containment is 52 psi which is 11 percent greaterthan the highest calculated accident pressure.

The containment is designed to perform its functions concurrently with a loss of offsite power and an earthquake with a ground accel-eration equal to one-quarter the acceleration of gravity. The containment is structurally tested by increasing the building pressure to 60 psi with air.Heat removal from the containment during operation is accomplished with six air-to-water coolers which transfer heat from the air space to component cooling water. The reactor coolant pump motor heat is transferred directly to the component cooling water (as described in Section 12). Under accident conditions, heat must be removed from the con-tainment to reduce the pressure in the building and minimize leakage outward. The containment building spray system (CBS) performs that function.The CBS system uses two trains of redundant equipment to pump borated water from the refueling water storage tank and sodium hydroxide from the spray additive tank to ring headers mounted to the containment dome.

The water sprays through nozzles in the headerscooling and condensing steam in the containment building.

When the water has been injected from the refueling water storage tank, the containment spray pumps draw water from the containment sump. The spray water goes through the containment spray heat exchangers for cooling by primary component cooling water before returning to the spray headers. The CBS system is shown on page 15.CONTAINMENT BUILDING SPRAY SYSTEM Containment spray pumps (2) 3010 gpm each Refueling water storage tank 475,000 gallons Spray additive tank 10,700 gallons Containment spray heat exchangers (2) 96.7 x 106 BTU/Hr each Spray headers 4 Spray nozzles 396 21

'econdary plant systems convert the energy of high pressure steam into electricity.

In prin-Uciple, they are the same systems found in any large steam-electric generating station. In a nuclear station the quantity of steam flowing per kilowatt-hour produced is higher than in a fossil station. Equipment therefore is larger in size but the function is the same.The majority of the secondary plant components are located in the turbine building.

They are generally not safety-related components.

However, the secondary plant systems are designed so that failure of a component will not affect the functioning of any safety-related equipment.

The design of the structures and systems are governed by professional society codes. Erection of pressure piping and vessels is inspected and approved by a code inspec-tor before operation is permitted.

Flow Flow Temperature Location #/hr OF A 10,413,427 101 B 10,413,427 215 C 10,413,427 316 D 4,726,573 366 E 15,140,000 440 Pressure (PSIA)F 15,140,000 1000 G 11,960,982 174 H 10,217,778 166 1 7,821,418 2.0" Hg STEAM SEAL REGULATOR MOISTURE SEPARATOR REH EATER REHEATER (4)SA MRAINU T4AINK FEED PUMP GENERATOR REACTOR l FEED (4) COOLANT HPUMP PUMP TURBINSSUE

-- ---LOW PRESSURE TURBNE ----- --- TURBINE (3)a ~GENERATORl REACTOR SE CIRCULATING CONDIENSER WATER (3) PUMP E I TO OCEAN HEATER DRAIN PUMP (2)TANK HEAT BALANCE 100% LOAD 22 S team produced in the steam generators leaves the containment through four 30-inch main steam lines. These are seismically supported and restrained against a hypotheticalpipe rupture until they reach the main steam isolation valves outside the containment.

The isolation valves, like valves in every other containment penetration, will close if high pres-sure is sensed in the containment building.

By closing, they seal the containment.

Beyond the isolation valves, the main steam pipes continue to the stop and control valves of the tur-bine. The main steam at full load, has a pressure of 1000 psi, a temperature of 545 OF and aflow of 15,140,000 pounds per hour.Main steam is admitted to the high pressure (HP) turbine where it expands while doing work and rotating the turbine. Approximately 60 percent of the usable energy is removed from the steam in the HP turbine. The steam exhausts from the HP turbine through piping to four moisture separator reheaters where the saturated steam is dried and reheated before admis-sion to the three low-pressure (LP) turbines in parallel.

All the turbines, one HP and three LP, are connected on the same shaft to the generator.

Steam exhausts from the LP turbines into the condenser where a high vacuum exists (two inches of mercury absolute pressure.)

Main steam is also used to power the small turbines which drive the steam generator feed pumps returning feedwater to the steam generators.

In an emergency, main steam also pow-ers an emergency feedwater pump to remove decay heat from the primary system via thesteam generators.

Main steam may be valved into the condenser through "dump" valves or via atmospheric relief valves to the outside air during start up or to reduce the abruptness of large load changes on the primary system.Steam exhausted from the LP turbines is condensed back to water, which at this point in the cycle is called "condensate".

The condensate is pumped through five stages of feedwater heaters to the steam generator feed pumps. The feed pumps raise the condensate pressure from 300 psi to feedwater pressure of 1180 psi. After one more stage of heating the feedwater goes through control valves and flows into the four steam generators at 1000 psi. From the hotwell of the condenser to the steam generators the condensate/feedwater has increased in pressure from a vacuum to 1000 psi and in temperature from 1 0 OF to 440 OF, thus complet-ing the steam-feedwater cycle.23 h~e function of the circulating water system (CWS) is to condense the turbine steam back Itofeedwater after the steam is exhausted from the low-pressure turbines.

For this reason, the CWS is also referred to as the condenser cooling system. The major components of the CWS are the inlet and discharge tunnels, the three circulating water pumps, the condenser, travelling screens and valves. The screen wash and vacuum priming systems are integral to the functioning of the CWS.Ocean water is drawn from three inlets located 7,000 feet offshore and 17,140 feet from the station by the three circulating water pumps. The inlets located in 60 feet of water are 10 feet apart. The water enters through a 30-foot diameter velocity cap designed to minimize fish entrapment.

Nine-foot diameter shafts connect the inlets to the intake tunnel 1 60 feet below sea level. The tunnel, bored at a 22-foot diameter from the bedrock, is lined with reinforced concrete to a finished diameter of 1 9 feet. Dropping at a slope of .5 percent towards the station, the tunnel is 260 feet below sea level at the station where it connects to a vertical riser and transition structure.

Eleven-foot diameter butterfly valves direct the flow from the transition structure to the circulating water pumphouse.

Biofouling in the inlet tunnel is controlled by a continuous low level of chlorination.

The ability to reverse flow in the tunnels and use thermal shock for biofouling control has also been provided.

A chlorination system injects sodium hypochlorite solution at various loca-tions in the CW system.The pumphouse is designed with three circulating water pumps which pump the ocean water to the condenser and through the condenser tubing. The pumps also provide sufficient pressure to pump the water back to its discharge point in the ocean.The condenser is arranged in three shells, one under each LP turbine. It has a two-pass con-figuration and uses titanium tubes to minimize salt leakage into the fee-dwater.

The circulating water temperature is raised 34 IT while in the condenser.

The heated water returns to the ocean in the 1 6,483-foot long discharge tunnel and discharges through a series of 22 nozzles located just above the seabed. The nozzles form a diffuser which rap-idly mixes the discharge flow and drops the temperature of the discharge plume to amaximum of 5 degrees above the intake temperature.

I,,x.I Shlts Seabrook Station CIRCULATING WATER TUNNEL and SHAFT SYSTEM PLAN CIRCULATING WATER SYSTEM DATA Flow Pumps Tunnels Inlet tunnel Discharge tunnel Condenser Tubing Exhaust pressure CW temperature Temperature rise Total heat rejected Travelling screens 450,000 gpm 3 at 150,000 gpm 19 feet ID, concrete lines 17,140 feet long 16,483 feet long 3 shell, double pass, 754,110 sq. ft.530 miles, titanium 2,00" HgA 55 OF 34 'F 7.6 x 10" Btu/hr 3 each 14 feet wide 64 feet high TUNEL S7RUCTIRE U~ CIRCULATING UNIT Z WAl~FLUME PUMPS PUMP I! HOUSE DISCHARGE OISCHARGE TRANSITION TUNNEL STRUCtURE FROM UNITFMECHANICAL VACUUM PUMPHEAT EXCCHANGERS 25

÷H eat'rnust be removed from many pieces of equipment on both the primary and second-Sary.-side of the station. Bearings in large rotating equipment such as the turbine generatorand the reactor coolant pump motors need cooling.

The control room and containmentbuilding need to have the heat load removed for habitability and for other components to function.

Steam from waste disposal and boron recovery evaporators must be cooled. This type of auxiliary cooling is performed by the primary and secondary component cooling sys-tems and the service water system functioning together through heat exchangers.

Pr 4ar COmp r 8 PC The PCC system uses two closed loops to remove heat from auxiliary equipment oil the pri-mary (reactor) side of the station. One loop serves A train equipment and the other serves the B train components.

The PCC system is a safety system since it is depended upon to cool emergency core cooling system pumps, to remove decay heat and to cool the containment.

The PCC system components, piping and supports are designed for seismic forces and post accident operation.

PRIMARY rmMPnwNFMT COflLIN System pressure and temperature PCC water pumps PCC heat exchangers Heat loads served by each loop: Containment spray pump RHR pump Safety injection coolersContainment coolers Spent fuel HX Reactor coolant pumps 150 psi, 120 'F 4 at 700 hp and 11000 gpm 2 at 210 x 106 Btu/hr.Containment spray HX RHIR heat exchanger Charging pump Enclosure cooler Evaporators Miscellaneous HX$eo ty COnpmoneult CciIng S iWniA(SetC The SCC system removes heat from auxiliary equipment on the secondary (turbine) side of the station. It has two loops arranged to serve A and B train components independently.) j iS stbr~n PALessL SCC Water pu SCC~ heW, ex SECONDARY COMPONENT COOLING SYSTEM ire, temperature, flow 50 psi, 85 'F, 10,000 gpm imps 3 at 5000 gpm, half-size hangers 2 at 23.8 x 106 Btu/hr, H-eatleads served:." -"Turbi ne, coolers.cssor'Ae oolers//J 0uu To capacity Pump motor bearing coolers Isolated phase bus coolers Service Water Syste-SW)The service water system transfers heat from the PCC, SCC and diesel generator heat exchang-ers to either the ocean or the cooling tower. The SW system is a safety class system since it may be called upon to handle post-accident cooling. All heat removed from the auxiliary com-ponents must ultimately be transferred to the environment especially in a post-accident situation.

The ultimate heat sink at Seabrook Station is a combination of the ocean cooling tun-nels which are tornado proof and the cooling tower which is seismically designed.Flow per train Heat load SW pumps Cooling tower pumpsCooling tower basinSERVICE WATER SYSTEM 10,500 gpm normal 95.3 x 106 Btu/hr post accident 209 x 106 Btu/hr 4 at 10,500 gpm and 150 psi 4 at 13,000 gpm and 150 psi 4,000,000 gallons capacity 27 T he electrical power system is the source of power for the plant auxiliaries during nor-rmal operation, and for the plant protection system and engineered safety featuresduring abnormal and accident conditions.

The systems which comprise the electric power system are the utility grid and offsite power system, the onsite ac power system, and the onsite dc power system.Seabrook Station has three ties to the New England 345 kV transmission grid. These ties are via transmission lines to substations at Scobie Pond near Derry, New Hampshire; at Tewksbury, Massachusetts; and at Newington, New Hampshire.

The onsite power systems include the 13.8 kV and the 4160 volt distribution systems, including the standby diesel-generators and the connections from the unit and reserve auxil-iary transformers; the 480 volt distribution system; the 120 volt vital instrumentation and control power system; and the 125 volt dc distribution system including the batteries and battery chargers.Under normal operating conditions, the main generator supplies electrical power through a generator circuit breaker via isolated phase bus ducts to the utility grid through the generator step-up transformers and to the plant through the unit auxiliary transformers.

During startupand shutdown, auxiliary power may be taken from the 345 kV system in one of two ways;either by backfeeding through the generator step-up transformers and unit auxiliary transform-ers when the generator circuit breaker is open or from the reserve auxiliary transformers.

28 TO 345 KV SWITCHING SUBSTATION IryE AUX TRANS.

TOI13.5IV9US2 EME"CENCY BUSESINSIDE I DOTnED LINES FOR( ) NINEERE SAFETY F.AtUREj I I 1 II A 28I 11A 4160 VOLT DISTRIBUTION SYSTEM FN, U The design of the electrical systems and the components is governed by 31 industry stan-dards and 36 NRC guides and technical positions.

These include extensive requirements for seismic and environmental design and testing. Safety-related equipment is powered by two redundant trains of electrical equipment.

Each train has its own emergency diesel generator and station batteries.

Power and control cables for the two trains are physically separated in their raceways which may be cable tray, conduit or buried ducts.Control and instrumentation of the station equipment is centralized in the main control room. Local control panels are used for equipment whose operation does not require imme-diate attention.

The status of equipment and process systems is indicated in the control room directly or through multiplexing the signals to an extensive system of computers.

29 I++ --a I,I I PAE in I VITAL DISTRIBUTIOI 120 VAC VITAL DISTRIBUTION 30 COMMODITY Structural Conc.*Structural Rebar*Structural Formwork*

Cadwelds Structural Steel Small Bore Pipe Large Bore Pipe Large Bore Welds Large Bore Hangers Large Bore Valves Conduit Cable Tray Cable Pulling Cable Terminations Tubing PRINCIPAL MATERIALS UNIT OF MEASURE CY TN SF EA TN LF LF EA EA EA LF LF LF EA LF UNIT 1 & C 274,914 34,160 2,796,747 47,975 12,168 151,818 168,216 19,846 10,059 2,361 641,381 **88,547 6,160,931 230,705 193,669**Exposed, Rigid & PVC Ductbank*Excludes Tunnel Work.4>2 At:, 14, fV 31 v CONTAINMENT BUILDING FLOOR PLAN@ EL. (-) 26'-0" 32

(ý -NORTH CONTAINMENT STRUCTURE GENERAL ARRANGEMENT 33 A I U'e SEPI Seabrook Station Seabrook, New Hampshire S 2000 -December 2001

@ 0 FPL Energy Seabrook Station FPL Energy w.O. Box 3o0 Seabrook, NH 03874 Seabrook Station (603) 773-7000 September 25, 2006NPDES Permit No. NH0020338 SBK-L-06180 United States Environmental Protection Agency Region I 1 Congress Street, Suite 1100 Boston, MA 02114-2023 Attention: Shelley Puleo Environmental Protection Specialist Municipal Assistance Unit Seabrook StationNPDES Permit NH0020338 Renewal Application FPL Energy Seabrook LLC has enclosed a renewal application for National Pollutant Discharge Elimination System (NPDES) Permit NH0020338 pursuant to 40 CFR 122.21 (d). FPL Energy Seabrook is the principal owner and operator of Seabrook Station a nuclear electric generatingfacility located in Seabrook, NH. Seabrook Station commenced commercial operation in August 1990, generating in excess of 139 million megawatt hours of electrical energy with a capacity factor of approximately 85 percent. Seabrook Station has held the referenced NPDES Permit since construction of the facility began in 1976.This renewal application is comprised of completed EPA Forms 1 "General Information" and 2C"Wastewater Discharge Information" per your letter of December 15, 2005, and the following supplemental information:

e Tab 1 EPA Form 1 and Supporting Information o Tab 2 EPA Form 2C and Supporting Information 0 Tab 3 Annotated NPDES Permit, Proposed Changes to Monitoring Requirements andEffluent Limitations 9 Tab 4 Clean Water Act § 316 (a) and § 316 (b) Certification FPL Energy Seabrook previously submitted on May 4, 2006, a Proposal for Information Collection (PIC) as required by CWA § 316 (b) Phase II Regulation, 40 CFR § 125.95 (b)(1).The Seabrook Station PIC is integral to this NPDES Permit renewal application.

The PIC demonstrates that Seabrook Station's Cooling Water Intake Structure design is "best technology an FPL Group company SBK-L-06180 Page 2 available" and meets the National Performance Standards of 40 CFR § 125.94 (b). The PIC also includes the information required by 40 CFR § § 122.21 (r)(2), (3) and (5) describing the source water body, cooling water system intake structures and cooling water system operation, respectively.

FPL Energy Seabrook intends to submit a Comprehensive Demonstration Study (CDS) subsequent to receiving EPA review comments on the PIC but not later than January 7, 2008. The CDS will supplement this NPDES Permit renewal application.

I certify under penalty of law that this document and all attachments were prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gather and evaluate the information submitted.

Based on my inquiry of the person or persons who manage the system, or those persons directly responsible for gathering the information, the information submitted is, to the best of my knowledge and belief, true, accurate,and complete.

I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment for knowing violations.

If you have questions on this matter, please contact Mr. James M. Peschel, Regulatory Programs Manager, at (603) 773-7194.Very truly yours, FPL ENERGY SEABROOK, LLC Gene St. PierreSite Vice President cc: Mr. Jeffrey Andrews New Hampshire Department of Environmental Services (NHDES)Water Division 29 Hazen Drive, P.O.

Box 95Concord, New Hampshire 03302-0095 United States Nuclear Regulatory Commission Attn: Document Control Desk Washington, D.C. 20555-0001 C

FPL Energy Seabrook Station .-NPDES Permit NH0020338 Renewal Application September 2006 Form Approved.

OMB No. 2040-0066.

1. EPA 1.0. NUMBER

'31 '. I 's GENERAL INSTRUCTIONS If a preprinted label has been provided, affix it in the designated space. Review the information carefully-, if any of it is incorrect, cross through it and enter te correct data in the appropriate fill-in area below. Also, if any of the preprinted data Is absent (the area to the left of the label space lists the information that shiould appear), please provide it in the proper fill-in area(s) below. If the label is complete and correct, you need not complete items 1, 111, V, and VI (except V/-B which must be completed regardless).

Complete all items it no label has been provided. Refer to the instructions for detailed itemdescriptions and for the legal authorizations under which this data is otlected.INSTRUCTIONS:

Complete A through J to determine whether you need to submit any permit application forms to the EPA. If you answer 'yes" to any questions, you must submit this form and the supplemental form listed in the parenthesis following the question.

Mark "X" In the box In the third column if the supplemental form is attached.

If you answer no" to each question, you need not submit any of these forms. You may answer no" if your activity is excluded from permit requirements; see Section C of the instructions.

See also, Section D of the instructions for definitions of bold-faced terms.Mark Wx Mare-X" YES NO IFORM Y NO FORMSPECIFIC QUESTIONS ArTACHE SPECIFIC QUESTIONS ATTACHED A. Is this facility a publicly owned treatment works which B. Does or will this facility (either existing or proposed)results In a discharge to waters of the U.S.? (FORM 2A) include a concentrated animal feeding operation or aquatic animal production facility which results in a a 7 re r discharge to waters of the U.S.? (FORM 2B) , 20 a C. Is this a facility which currently results in discharges to D. Is this a proposed facility (other than those described in A waters of the U.S. other than those described in A or B or B above) which will result in a discharge to waters of above? (FORM 2C) M 24 the U.S.? (FORM 2D)E. Does or will this facility treat, store, or dispose of F. Do you or will you Inject at this facility industrial or hazardous wastes? (FORM 3) X municipal effluent below the lowermost stratum containing, within one quarter mile of the well bore, o. underground sources of drinking water? (FORM 4)' 31 W a G. Do you or will you inject at this facility any produced water H. Do you or will you inject at this facility fluids for special or other fluids which are brought to the surface in

• processes such as mining of sulfur by the Frasch process, connection with conventional oil or natural gas production, solution mining of minerals, in situ combustion of fossil Inject fluids used for enhanced recovery of oil or natural fuel, or recovery of geothermal energy? (FORM 4)gas, or inject fluids for storage of liquid hydrocarbons?(FORM 4) _ _ _ _ _ _ _ _ _ _ _Is this facility a proposed stationary source which is one J. Is this facility a proposed stationary source which is of the 28 industrial categories listed in the instructions and NOT one of the 28 industrial categories listed in the which will potentially emit 100 tons per year of any air Instructions and which will potentially emit 250 4 ns per7 pollutant regulated under the Clean Air Act and may affect year of any air pollutant regulated under the Clean Air Act or be located in an attainment area? (FORM 5) , , and may affect or be located In an attainment area? s (FORM 5)IVl. NAME OF FACILIN D SIc P IIIIIIII1 I I I I I I I I I I I I I I I I I I I I I I I I I I I i IV, FACILITY LONTACTI.B. PHONE (area code & no.)estevce Piresdrent I I I V.FACILTY MAILING ADDRESS A.STREE OR P..BOX. .... ... ...

B. CITY OR TOWN C. STATE ZIP CODE FE Seabrook uA8 VEP FACILITY LOCAC TON A. STREET, ROUTE NO. OR OTHER SPECIFIC a r o' a'y It I Id .I Il I I I I I I I I I I I I I I I I I I B. COUTY NAM EPA Form 3510-1 (8-90)CONTINUE ON REVERSE CONTINUED FROM THE FRONT VII. SIC CODES (4-digit, in order of N)A. FIRST B. SECOND (Specify)

Electric Services I I(pecify)a74 91 I7 C. THIRD D. FOURTH S(specify) cl i ' (Specif[y)

Vill. OPERATOR INFORMATION A. NAME B. Is the name listed in Item I I I I I I I I I I I I I I l I l I I L I I I I I I r -I -T ] VIII-A also the owner?

JsFPLI, Elnergy Seabrook LLCI 0 YES O]NO C. STATUS OF OPERATOR (Enter the aopropriate letter into the anso'e,r box: if "'Other. -speci'y.)

I D. PHONE (aree code & no.)F = FEDERAL S = STATE P = PRIVATE M = PUBLIC (otherthanfederalorstate)

I (specify)0 = OTHER (specify)

K-j'1 I I II I I I I I A (603) 773-7471-E. STREET OR P.O. BOX P !o1.. Io6 , 13/ 1 0 I I I 1 1 1 1 1 1 1 1 1 1 1 1 F. CITY OR TOWN C, , ,, , , ,,,,I I I I I ,, , , BSeabrook I I I X. EXISTING ENVIRONMENTAL PERMITS A. NPDES (Discharges to Surface Water)Sseabxook I I I......, , 2" * ," , , , .....9 N i I I I I I NXO002 0338I I I I Is -.. .. .1 1.B. UIC (Undervround Iniection of Fluids)E. OTHER (specify)-I T I -I I 1 1 1 1 1 1 1 1 1 .D JIý -O -' 1 1 1 (pcf)HzrosWseLmtdPri C- RCRA ý (Hs rdos ct) E. OTHER (specify)ct T J I I ! I I I 'j 1 1 1 I I I I(specify)

TitleV OpSerting Permnit;9 R D0 8 1 2 57 4 46 1TV-OPo1715 I 's 1 SAttach to this application a topographic map of the area extending to at least one mile beyond property boundaries.

The map must show the outline of the facility, the location of each of its existing and proposed intake and discharge structures, each of its hazardous waste treatment, storage, or disposal facilities, and each well where It Injects fluids underground.

Include all springs, rivers, and other surface water bodies in the map area. See instructions for precise requirements.

KII. NATURE OF BUSINESS (provide a brief description) 0 pFPL Energy Seabrook LLC is the operator and principal owner of Seabrook Station, an 1221 MWe (net) nuclear power electrical generating facility located in Seabrook, NH. The facility began commercial operation in 1990.The facility is jointly owned by the following companies:

FPL Energy Seabrook LLC (88.22889%), Massachusetts Municipal Wholesale Electric Company (11.59340%), Taunton Municipal Lighting Plant (00.10034%), Hudson Light & Power Department (00.077371r)

XI1I. CERTIFICATION (see instructions)

I certify under penalty of law that I have personally examined and am familiar with the information submitted in this application and all attachments and that based on my inquiry of those persons immediately responsible for obtaining the information contained in the application, I believe that the information is true, accurate, and complete.

I am aware that there are significant penalties for submitting false information, including the possibility of Fine and imprisonment A. NAME & OFFICIAL TITLE (type orprint)Gene St. Pierre Site Vice President B. SIGNATURE i2 C. DATE SIGNED COMMENTS FOR OFFICIAL USE ONLY.C I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I .I I I I I I I EPA Form 3510-1 (8-90) 0 0 0 0 U'0 Q.0 03 03 CI)a 0 X" 0O Figure 3-2. Location of Seabrook Nuclear Power Station.

JETTY I I DISCHARGE TUNNEL AND SHAFTS EPA ID. NUMBER (copy from, lie,, I of Form I) Form Approved.[NHD081257446 OMB No. 2040-0086.

7 Aoproval expires 3-31-98.Please print or type in the unshaded areas only.0 0 FORM U.S. ENVIRONMENTAL PROTECTION AGENCY APPLICATION FOR PERMIT TO DISCHARGE WASTEWATEREXISTING MANUFACTURING, COMMERCIAL, MINING AND SILVICULTURE OPERATIONS NPDES Consolidated Permits Program I. OUTFALL LOCATION For each outfall, list the latitude and longitude of its location to the nearest 15 seconds and the name of the receiving water.A. OUTFALL NUMBER B. LATITUDE C. LONGITUDE (list) 1. DEG. 2. MIN. 3. SEC. 1. DEG. 2. MIN. 3. SEC. D. RECEIVING WATER (name)01 42 53 43 70 47 27 Atlantic Ocean (normal discharge point)103 42 54 17 70 47 12 Atlantic Ocean (thermal backflush discharge point)II. FLOWS, SOURCES OF POLLUTION, AND TREATMENT TECHNOLOGIES I A. Attach a line drawing showing the water flow through the facility.

Indicate sources of intake water, operations contributing wastewater to the effluent, and treatment units labeled to correspond to the more detailed descriptions in Item B. Construct a water balance on the line drawing by showing average flows between intakes, operations, treatment units, and outfalls.

If a water balance cannot be determined (e.g., for certain mining activities), provide a pictorial description of the nature and amount of any sources of water and any collection or treatment measures.B. For each outfall, provide a description of. (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater.

cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Continue on additional sheets if necessary.

1. OUT- 2. OPERATION(S)

CONTRIBUTING FLOW 3. TREATMENT FALL b. AVERAGE FLOW b. LIST CODES FROM NO. (list) a. OPERATION (list) (include units)

a. DESCRIPTION TABLE 2C-1 Circulating Water Condenser Disinfection (Chlorine) 001 .555,5000,00 GPO 2F Cooling and Service Water Cooling Ocean Discharge 4B Thermal Backflush Ocean Discharge 003 5O0,0OO GPM Iperioit lijit) 4 Oil/Water Separator

1. 11 Flotation 022 17,866 GPD tI Oil Water Separator

1. 2 1064 GPD Flotation 1H Oil Water Separator 113 637 GPO Flotation 1 024 Steam Generator Blowdown (SGB) Ocean Discharge 025A 81,075 GPO 4B 025B sGa Demineralizer RinSes " Ion Exchange 44,755 GPO 2J 025C Waste Holdup Sump 14,107 GPO Multimedia Filtration.

Neutralization 2K 025D Waste & Recovery Test Tanka 16,424 GPO con Exchange.

Coagulation 2 2 Mutimedia Filtration, Carbon Absorbtion 10 2A Reverse Osmosis is 026 Chemical Cleaning Waste No permit limit Specicic to proposed cleaning operation 027 Cooling TOWer Discharge 85,276 Disinfection (Chlorine)

CPS Neutralization Tank (proposed) mutimedla Filtration, Neutralization 028A ________________10 2K 028B CPS Low Conductivity Tank (proposed)

Mutimedia Filtration 028C CPS Rinses Iproposed)

Ion Exchange 2" OFFICIAL USE ONLY (effluent guidelines sub-categories)

EPA Form 3510-2C (8-90)PAGE 1 of 4 CONTINUE ON REVERSE CONTINUED FROM THE FRONT C. Except for storm runoff, leaks, or spills, are any of the discharges described in Items II-A or B intermittent or seasonal?YES (complete the following table) r 1 NO (go to Section 111)3. FREQUENCY

4. FLOW a. DAYS PER S. TOTAL VOLUME 2. OPERATION(s)

WEEK b. MONTHS a. FLOW RATE (m egd) (specify ith -oits)1. OUTFALL CONTRIBUTING FLOW (specify PER YEAR 1. LONG TERM 2. MAXIMUM 1. LONG TERM

2. MAXIMUM C. DURATION NUMBER (list) (list) reroge) (sPecfOyaerage)

AVERAGE DAILY AVERAGE DAILY (,nduys)This information is provided in the following sections titled: EPA Fors 2C Section II, Part 3 (Descriptions) and Section V Part D tList of Pollutants) for each out fall Ill. PRODUCTION A. Doe$ an effluent guideline limitation promulgated by EPA under Section 304 of the Clean Water Act apply to your facility?2] YES (complete Item Ill-B) [3 NO (go Is Section IP)B. Are the limitations in the applicable effluent guideline expressed in terms of production (or otherrmeasure of operation)?

El YES (complete Item 1ll-C) 0 NO (go to Section IV)C. If you answered 'yes" to Item Ill-B, list the quantity which represents an actual measurement of your level of production, expressed in the terms and units used in the applicable effluent guideline, and indicate the affected outfalls.1. AVERAGE DAILY PRODUCTION

2. AFFECTED OUTFALLS a. QUANTITY PER DAY b. UNITS OF MEASURE

c. OPERATION.

PRODUCT, MATERIAL, ETC. (list outofll numbes)(Specify)

________________

IV- IMPROVEMENTS

-A. Are you now required by any Federal, State or local authority to meet any implementation schedule for the construction, upgrading or operations of wastewater treatment equipment or practices or any other environmental programs which may affect the discharges described in this application?

This includes, but is not limited to, permit conditions, administrative or enforcement orders, enforcement compliance schedule letters, stipulations, court orders, and grant or loan conditions.

0] YES (complete the following table) RJ NO (go to Item IV-B)1. IDENTIFICATION OF CONDITION.

2. AFFECTED OUTFALLS 3. BRIEF DESCRIPTION OF PROJECT 4. FINAL COMPLIANCE DATE AGREEMENT, ETC.a. NO. b. SOURCE OF DISCHARGE

a. REQUIRED b. PROJECTED B.

v ou may attach addlit]iona:l s1heetsI describing any additonal water pollution control programs (or other environmental projects which may affect your discharges) you now have underway or which you plan. Indicate whether each program is now underway or planned, and indicate your actual or planned schedules for construction.

[]MARK "X" IF DESCRIPTIONOF ADDITIONAL CONTROL PROGRAMS IS ATTACHED EPA Form 3510-20 (8-90) PAGE 2of4 CONTINUE ON PAGE 3 EPA Form 3510-2C (8-90)

PAGE 2 of 4 CONTINUE ON PAGE 3 I EPA I.D. NUMBER (copy from Ihem I ofFom 1) 1 CONTINUED FROM PAGE 2 V. INTAKE AND EFFLUENT CHARACTERISTICS A, B, & C: See instructions before proceeding

-Complete one set of tables for each outfall -Annotate the outfall number in the space provided.NOTE: Tables V-A, V-B.

and V-C are included on separate sheets numbered V-1 through V-9.0. Use the space below to list any of the pollutants listed in Table 2c-3 of the instructions, which you know or have reason to believe is discharged or may be discharged from any outfall. For every pollutant you list, briefly describe the reasons you believe it to be present and report any analytical data in your possession.

1. POLLUTANT

2. SOURCE 1 1. POLLUTANT

[ 2. SOURCE This information is provided in the following sections titled;EPA Form 2C Section II, Part 3 (Descriptions) and Section V Part D (List of Pollutants) for. each outfall VI. POTENTIAL DISCHARGES NOT COVERED BY ANALYSIS Is any pollutant listed in Item V-C a substance or a component of a substance which you currently use or manufacture as an intermediate or final product or byproduct?

El YES (list anl such pollutants below ) NO (go to liem VI-B)EPA Form 3510-2C (8-90)PAGE 3 of 4CONTINUE ON REVERSE CONTINUED FROM THE FRONT VII. BIOLOGICAL TOXICITY TESTING DATA N Do you have any knowledge or reason to believe that any biological test for acute or chronic toxicity has been made on any of your discharges or on a receiving water In relation to your discharge within the last 3 years?2] YES (identify the levi(s) and describe theirpurposes below) El NO (go to Section VIII)Quarterly Whol.e Effluent Toxicity testing (acute and chronic assays) has been performed throughout the term of the current NPDES Permit. The WET testing results have been reported in the facility Discharge Monitoring Reports.VIII. CONTRACT ANALYSIS INFORMATIONWere any of the analyses reported in Item V performed by a contract laboratory or consulting firm?YES (list the name, address, and lelephone number of andpollulams analyzed by, [] NO (go to Section IX)each such laboratory orfirm below)A. NAME B. ADDRESS C. TELEPHONE D. POLLUTANTS ANALYZED (area code & no.) (list)Areva NP Inc. 29 Research Drive 508 573-6653 Alph/Beta Radioactivity Environmental Laboratory Westborough, MA 01581-3913 Attn: Ashok Banavali, PH.D.Northeast Laboratory Services 227 China Road 207 873-7711 x341 All non-radiological Attn: Paul Lynch, Winslow, ME 04901 analyses Analytical Customer Service Manager IX. CERTIFICATION I certify under penally of law that this document and all attachments were prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gather and evaluate the Information submitted.

Based on my inquiry of the person or persons who manage the system or those persons directly responsible for gathering the information, the information submitted is, to the best of my knowledge and belief, true, accurate, and complete.

I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment for knowing violations.

A. NAME & OFFICIAL TITLE (type or print) B. PHONE NO. (area code & no.)Gene St. Pierre, Site Vice President (603) 771-7471 C. SIGNATURE .D. DATE SIGNED EPA Form 3510-2C (8-90)PAGE 4 of 4 Seabrook Station PIC A 599 WD3 [Ave. dahl, flow, 280W. 2004 A 80490 [Mm .Avg, d3IV~ low. August 2MO -4]B~j 581.8 MOO pdgkId deign low- 3 pumpq CJ 33.1 MGO PIdkW deeplg Io- -2 pump4-187.2 MOD [figha8 pump design 1W319.55 MOO

[CrWW pump design Wm~r o .1 14 MOO jAve. dei now. 2ooo0- 200 0-6 5.1 MGD [2year.24 hwm~sII vtao fel H -40 MOD [Ceictised Ave. ddly nowe. 200 -2M04-5981.83 [Ae. da~ily now. 20W. 2DM4-~ Norma kPow Penn----------

AbmaIFRow Pih FPL Ener Wigted abmke Studr Dt Flow Dt*gbuO and Wder Bdml e Daram Rgt" 3-8 Figure 3-8. Seabrook Nuclear Power Station flow distribution and water balance diagram.2D2G7Se9brvokPICj9vIsIon.doc 5W6 13 Normandeau Associates, Inc.

EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 001 Circulating Water System Discharge Information for Outfall 001 (Circulating Water System)EPA Form 2C Section II, Flows, Sources of Pollution and Treatment Technologies Part B, Description of.- (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff- (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part V.D, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the following sources: All permitted outfalls from this facility ultimately combine with the Circulating Water System and are discharged to the Atlantic Ocean. These oufalls are sampled at representative sample points prior to introduction to the Circulating Water System to ensure compliance with NPDES Permit effluent limitations and monitoring requirements.

In addition to the identified permitted outfalls which discharge to the Circulating Water System, the sources below may also be introduced: " Cooling water drawn from three intake velocity caps and discharged through eleven double discharge diffuser nozzles in the Atlantic Ocean" Closed loop cooling system leakage into the Service Water System.* Residual chlorine.

Chlorine is injected into the Circulating and/or Service Water Systems to prevent biofouling.

• Neutralization Tank discharge of Condensate.

Polishing System and Makeup Water Treatment System wastewater

• Makeup Water Treatment System waste mineral concentrates" System drainage from systems which are not directed to another outfall" Various seawater containing sumps that collect seawater leakage and return it to the Circulating Water System." Condensate hotwell discharges performed to control chemistry parameters, lower hotwell level, or drain for system maintenance.

• Rinses of the Condensate Polishing System in support of start-up and periodically during standby conditions, rinses of the resin vessels following regenerations, regeneration wastewater, sampling system and grab sample waste, system leakage, and system drainage for maintenance (see description below).* Steam Generator drainage" Circulating Water System and Service Water System Forebay Water. Periodically sediment is removed from the forebays by a pumping process. The sediment is typically collected in lined dumpsters and the ocean water is returned to the forebay or may be directed to the Storm Drain System which ultimately discharges to Outfall 001.Discharge description:

The Circulating Water System provides Atlantic Ocean cooling water to the main condensers where the steam exhausted from the low pressure sections of the turbine is condensed and subsequently returned to the Condensate System and Feedwater System. The Circulating Water System also supplies cooling to several mechanical vacuum pump heat exchangers in the Condenser Vacuum System. The Service Water System provides Atlantic Ocean cooling water to various subsystem heat exchangers which are required to support normal operating conditions, shutdown conditions and emergency conditions.

The cooling water flow in the Circulating Water System and Service Water System is conveyed by large high capacity.

centrifugal pumps. During normal full power operation three Circulating Water System pumps are in operation each with a rated pumping capacity of approximately 130,000 gpm and two Service Water System pumps Outfall 001, p. I are in operation each with a rated pumping capacity of approximately 10,500 gpm. The actual operational capacities of these pumps has exceeded their documented rated capacities.

The increased pumping capacity is attributable to conservative estimates of operational pumping capacities by the pump vendor and the operation of a single nuclear unit versus two unit operation. Operation of a single nuclear unit results in a reduction in the Circulating WaterSystem flow resistance.

During most periods of the year when ocean temperatures are cold, a portion of the ocean cooling water leaving the condenser is recirculated through the condenser to maximize plant efficiency by optimizing the temperature and pressure of the secondary coolant water exiting the condenser water boxes. During these periods when ocean cooling water is being recirculated through the condenser, total cooling water flow is reduced and the temperature rise across the condenser is elevated.

The effect of condenser cooling water recirculation can be seen inmonthly Discharge Monitoring Reports which document cooling water flow and temperature increase across the condensers. During plant shutdown conditions (e.g. plant refueling outages) there is no transfer of heat to the Main Condenser.

During refueling, the Steam Generators are placed in a wet layup condition and the Condensate System and Feedwater System are not in operation. During refueling, the Service Water System pumps are operated toremove heat from the Spent Fuel Cooling System and to provide cooling to other plant heat loads. A Circulating Water System pump (or pumps) may be operated during a refueling outage to support effluent discharges.

The Circulating Water System consists of the following principal structures:* Two tunnels connecting the plant site with three submerged offshore intakes and a multiport discharge diffuser* An intake transition structure* A pumphouse for the Circulating Water System and a pumphouse for the Service Water System* Flumes which join the intake transition structure to the pumphouses

• A discharge transition structure* An underground piping system, interconnecting the pumps in the pumphouses, the Main Condensers, heatexchangers and the transition structures Current overview diagrams of the Circulating Water System and Service Water System follow this description.

During normal operation, the Circulating Water System provides a continuous flow of approximately 390,000 gpm to the condensers and the Service Water System provides a continuous flow of approximately 21,000 gpm to various subsystem heat exchangers.

The Circulating Water System tunnels start 260 feet below the plant level (240 feet below mean sea level), at the bottom of vertical 19'-0" finished diameter land shafts, and extend out under the ocean at an ascending grade of about 0.5 percent until they reach their respective offshore terminus locations about 160 feet below the ocean's surface. The tunnels, which were machine bored through bedrock to a 22'-0" diameter, are concrete lined to provide the finished 19 foot finished diameter.The intake tunnel is approximately 17,000 feet long, and is connected to the ocean by means of three 9'-10 1/2"finished diameter concrete-lined shafts, spaced between 103 and 110 feet apart and located approximately 7000 feet off the shoreline in 60 feet of water. A submerged 30'-6" diameter concrete intake structure intake head is mounted on the top of each shaft to minimize fish entrapment by reducing the intake velocity.The discharge tunnel is approximately 16,500 feet long, and is connected to the ocean by means of eleven, 5'-1"finished inside diameter concrete lined shafts, spaced about 100 feet apart, located approximately 5000 feet off the Seabrook Beach shoreline in water up to 70 feet deep. A double-nozzle diffuser is attached to the top of each shaft to increase the discharge velocity and diffuse the heated water.

The circulating water portion of the pumphouse encloses three 14' wide circulating water travelling screens and threecirculating water pumps.

A reinforced concrete wall separates the circulating water portion from the service water portion of the pumphouse. The Service Water System pumps are located in the service water portion of the purnphouse as are the service water travelling screens. The circulating water is pumped through a 11 foot diameter pipe to the condensers and is returned through a 10 foot diameter discharge pipe connected with the tunnel transistion structures.

Water to the service water section of the pumphouse is supplied by two pipes branching off each of the tunnel transition structures.

Outfall 001, p. 2 This outfall receives inputs from all of the other outfalls described within this permit renewal application. All othersources listed in those outfalls ultimately are discharged via this system.

Outfall 001 also receives the effluent from the Water Treatment System. This effluent includes a waste mineral concentrate stream and the effluent from the Neutralization Tank.Trace quantities of typical janitorial cleaning products may also be incidentally introduced into floor drains and into the Circulating Water System in conjunction with cleaning activities. The practice is to dispose of janitorial cleaning.wastes which have been used outside of the Radiologically Controlled Area in the sanitary waste system which is discharged to the Town of Seabrook Publically Owned Treatment Works. Janitorial cleaning wastes which have been used inside of the Radiologically Controlled Area have the potential to contain radioactive contamination and therefore must be disposed of in floor drains or sinks which are directed to the Waste Test Tanks (Outfall 025D) and ultimately discharged to Outfall 001. Wastewater collected in the Waste Test Tanks is sampled for radioactivity content prior to each discharge to ensure Nuclear Regulatory Commission radioactive effluent limits are complied with prior to discharge. Compliance with Nuclear Regulatory Commission radioactive effluent limits specified in 10 CFR 20 is a requirement of the Seabrook Station Operating License.Alternate paths for this discharge:

• None anticipated.

Potential chemicals in discharge:

• Chemicals identified in all other outfalls.Note: Some of the chemicals listed below are also listed in other outfalls.

They are listed below because they are also discharged directly into this outfall.

• Total Residual Chlorine

-Sodium hypochlorite addition for biofouling control, Service and Circulating waterleakage and drainage, Makeup Water Treatment System cleaning agent, potable water.

• Dynacool 1383 Antiscalant

-Chlorination line antiscalant" Ammonia/Ammonium Hydroxide

-Hotwell discharges, Component cooling water drainage, Steam Generator drainage, trace quantities from silica analyzer cleaning" Methoxypropylarnine

-condenser hotwell discharges, Steam Generator drainage* Brine (concentrated potable water constituents) -makeup water treatment system waste" Demineralized water -water treatment effluent waste, cooloing water, flush and rinse water, Steam Generator drainage" Domestic water constituents (washwater residual, hydrolazing, cooling water, fire protection, potable)" Groundwater constituents -various vaults/plant areas where groundwater in-filtration occurs" Rainwater constituents

-rainwater that collects in vault areas* Hydrazine

-condenser hotwell discharges, Component Cooling Water System drainage* Hydrogen Peroxide -Makeup Water Treatment System cleaning agent,* Ethanolamine

-Condenser Hotwell discharges, Steam Generator drainage" Diisopropylamine -trace quantities from sodium analyzer drains* Sodium Chloride -Makeup Water Treatment System chemical additive" Sodium Hydroxide

-Makeup Water Treatment System cleaning agent, Condensate Polishing System regenerant chemical." Suspended solids -all potential inputs to the discharge* Citric Acid -trace quantities from silica analyzer drains* Silica standard (500ppb) -trace quantities from calibration of silica analyzers" Ammonium molybdate

-trace quantities from silica analyzer drains" Amino Acid

-trace quantities from siiicaanalyzers Outfall 001, p. 3

" Chlorhexidine Di-Gluconate (Hydrosep)

-emergency eyewash station biological growth inhibitor" Sulfuric Acid -CPS regenerant chemical.* Bulab 9328 -Corrosion inhibitor for freshwater systems (used on auxilliary cooling tower previously)" Bulab 6002 -Biocide for fresh water systems (used on auxilliary cooling tower previously)" Acetaldehyde

-potential breakdown product of ethanolamine, all sources of ethanolamine" Acetic Acid -potential breakdown product of ethanolamine, all sources of ethanolamine" Diethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine" Dimethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine" Monoethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Monomethylamine

-potential breakdown product of ethanolarnine, all sources of ethanolamine" Triethanolamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Trimethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine" Acrylonitrile

-potential breakdown product of methoxypropylamine, all sources of methoxypropylarnine" Cresol -trace quantities from cleaning products, petroleum containing products" Phenol -trace quantities from cleaning products* Flocon -flocculent used in the Makeup Water Treatment System for removal of particulates" Morpholine

-Secondary chemical additive, Steam Generator soak agent, hotwell discharges

• Sodium Thiosulfate

-Water Treatment System additive for chlorine removal Proposed chemicals for future discharge:

• Chemicals identified in all other outfalls.Note: Some of the chemicals listed below are also listed in other outfalls.

They are listed below because they are also discharged directly into this outfall.* Pyrolidine

-Secondary chemical additive* Carbohydrazide

-Secondary and closed cooling loop additive

• Dimethylamine

-Secondary chemical additive* 5-aminopentanol

-Secondary chemical additive* 1,2 diaminoethane

-Secondary chemical additive a 3-hydroxyquinuclidine

-Secondary chemical additive* 2-amino,2-methylpropanol

-Secondary chemical additive 0 EDTA -Steam Generator and Generator Stator Coolant System cleaning agent

• EVAC Biocide -Under consideration for mollusk control in the Circulating Water System* H-130M Biocide -Under consideration for mollusk control in the Circulating Water System*e Thruguard 300 -Under consideration to be used as an additive to the sodium hypochlorite injection line to reduce calcium carbonate scale formation.

• Diethylhydroxylamine-Secondary chemical additive 0 Steam Generator scale conditioning agents containing one, or more, lower alkyl amines and/or lower alkanol amines, combined with one, or more cyclic imines. These Steam Generator scale conditioning agents may be used during outages. The scale removal process employs the use of a vendor demineralizer skid which is expected to remove all but trace quantities of these chemicals.

Potential alky! amines and alkanol amines: 1,2- Diamino ethane Diamino propane Diethylamine Dimethylarnine Ethanolamine Ethylamine Outfall 001, p. 4 Ethylene diamine Methoxy propylamine Methylamine2-methyl-2-amino- 1 -propanol Potential cyclic imines: Bis-terpyridine2,9-Dimethyl- 1, 1O-phenanthroline 4,7-Dimethyl-l

,10-phenanthroline 2,2'-Dipyridyl

.4,4'-Dipyridyl Iso-nicoteine 1,1 0-phenanthroline Terpyridine Maximum daily flow: The current NPDES Permit monthly average and maximum daily flow limit for this outfall is 720,000,000 GPD.Average of monthly average values 2000 -2004, 599 MGD Average of maximum daily flow values, 2000 -2004, 684 MGD Discharge frequency:

Outfall 001 is a continuous discharge.

Pollutants from Form 2C. Tables 2C-3 and 2C-4: Any chemical listed under all other outfalls Acetaldehyde Acetic acid Acrylonitrile Ammonium hydroxide Cresol Phenol Diethylamine Dimethylamine Hydrochloric Acid Monoethylamine

Monomethylamine Phenol Sodium hypochlorite Sulfuric acid Triethanolamine Outfall 00 1, p. 5 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 003 Thermal Backflush Discharge Information for Outfall 003 Thermal Backflush EPA Form 2C Section I, Flows, Sources of Pollution and Treatment Technologies Part B, Description of: (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation, and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics

_Part V.D, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4.Discharge includes wastewater from the following soufrces: " Reversal of normal Circulating Water System flow as described in Outfall 001. Cooling water is drawn from eleven double discharge diffuser nozzles and discharged through three intake velocity caps in the Atlantic Ocean* The NPDES Permit prohibits Circulating Water System chlorination during the thermal backflush evolution.

Chlorination of the safety-related Service Water System during the backflush evolution is authorized." Additional discharge wastewater description to be provided in update to "Alternatives to Thermal Backflushing" study if thermal backflush is proposed to be used.Discharge description:

The NPDES Permit requires that if thermal backflushing is proposed to be used, the December 16, 1994, "Alternatives to Thermal Backflushing" study will be updated and submitted to the Regional Administrator, the Director of the NH Department of Environmental Services and the Technical Advisory Committee prior to conducting this evolution.

A general description of thermal backflushing follows. Comprehensive discharge description to be provided in update to "Alternatives to Thermal Backflushing" study if thermal backflush is proposed to be used.In addition to chlorination, thermal backflushing of the intake tunnel may be employed to remove sessile biofouling organisms attached to system components. This method involves the reversal of the normal cooling water flow such that the three intake structures serve as the discharge points (Outfall 003) and the discharge diffuser ports, conversely, function as the intake structure.

Temperatures within the intake tunnel will be elevated to a maximum of 120 OF for a maximum of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. The entire flow reversal and heat treatment cycle will occur over a six-hour period at a cooling water flow rate not exceeding 500,000 gallons per minute. There will be no chlorination of the condenser cooling water during the thermal backflushing treatment. The thermal backflushing operation may be used infrequently to compliment the normal Circulating Water System chlorination procedures for those sessile organisms that are not controlled by the sodium hypochlorite injection or for those organisms located upstream of the sodium hypochlorite injection points.Alternate paths for this discharge:None anticipated.

Potential chemicals in discharge:

Same list as specified for Outfall 001 Proposed chemicals for future discharge:

Same list as specified for Outfall 001 Outfall 003, p. 1 Maximum daily flow: The NPDES Permit specifies a maximum daily flow of 500,000 GPM for Outfall 003. No change to this flow limit is proposed.Discharge frequency:

Continuous discharge during the period of thermal backflush.

This is an intermittent flow which has not been used as of the filing of this NPDES Permit renewal application.

Pollutants from Form 2C, Tables 2C-3 and 2C-4: Same list as specified for Outfall 001 Outfall 003, p. 2 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants).Outfall 022 Oil/Water Separator Vault #1 Discharge Information for Outfall 022 Oil/Water Separator Vault # 1 EPA Form 2C Section 1I, Flows, Sources of Pollution and Treatment Technologies Part B, Description of- (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part V.D, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Dischar2e includes wastewater from the following sources: Floor drains in the following buildings and rooms: Emergency Feedwater Pumphouse Turbine Building Lube Oil Building Lube Oil Storage Room Auxiliary Boiler Room (from Oil/Water Separator Vault #2 when not in service)Diesel Generator Building (from Oil/Water Separator Vault #2 when not in service)Condensate Polisher Building Discharge description:

The Floor Drainage Oil/Water Separation System is designed to process non-corrosive oily and potentially oily drainage and leakage sources to produce an effluent containing less than 15 mg/L oil content which conforms to theEffluent Guidelines and Standards set forth by the EPA in 40 CFR 423 for the Steam Electric Power Generating Point Source Category. The processed effluent is discharged directly to the Circulating Water (CW) discharge (Outfall 001).The Oil/Water Separation System is comprised of an oil separator, which contains a gravity settling section to which the oil/water streams are piped, and a tilted plate separator section to effect separation of oil from water. An effluent tank with a pump and a coalescing filter are also provided.

The filter is utilized for final polishing of the effluent prior to discharge.

Operation of the Oil/Water Separation System is initiated upon reaching a setpoint level in the effluent tank.Each separator is designed to process water with an oil content less than 1500 mg/L and discharge a maximum of 85 gpm (122,400 gpd). The gravity settling section is provided to limit suspended solid loading into the oil separation section to 20 ppm. The down flow tilted plate separator is designed to process an oil/water solution and produce aneffluent with an oil concentration conforming to EPA effluent guidelines.

The final polishing coalescing filter is included in the event that separator loadings exceed design values. This filter can reduce the oil content from about 15 mg/L to less than 10 mg/L. Separated oil is collected in the oil holding tank and is removed periodically.

Settled solids in the gravity separator are likewise removed.Oil/Water Separator Vault #1 is located in the yard area below grade adjacent to the east side of the Turbine Building.

The location of the oil/water separator is sufficiently deep to prevent the freezing of the water at low or no-flow conditions.

The vault housing the oil/water separator, sump and filter is covered to protect the system from the environment.

The vault is ventilated by a ventilation fan. Electrical equipment and lighting in the vault area are explosion proofOil/Water Separator Vault #1 processes influents from: the Turbine Building sump, Emergency Feedwater Pumphouse floor drains, Lube Oil Storage Building sump, Lube Oil Storage Room sump, and influent to Oil/Water Outfall 022, p. 1 Separator Vault #2 when it is out of service. The Turbine Building and Emergency Feedwater Pumphouse drains are arranged to collect leakage and drainage at the potential sources of oil in these buildings via floor and hub drains and to convey these fluids to the oil/water separator.

The Lube Oil Storage Building and the Lube Oil Storage Room sumps are conveyed to an Oil Holding Tank. The Lube Oil Storage Building and Lube Oil Storage Room sump discharge valves are maintained closed and manually controlled to ensure excessive quantities of oil are not conveyed to the Oil Holding Tank.The Emergency Feedwater Pumphouse drains may receive: " pump shaft seal and valve stem leakage of demineralized water from the Condensate Storage Tank* steam leakage from the Auxiliary Steam or Main Steam systems" lubricating oil or turbine control oil leakage" potable water with trace levels of cleaners" Feedwater System leakage and drainage The Turbine Building drains and sump may receive:* secondary system leakage and drainage

• leakage of demineralized water, potable water and salt water sources to the sump" leakage from pump seals which are supplied with demineralized or secondary plant water* leakage from steam seals and blowdown of steam traps to the sump" leakage of lubricating oil, hydraulic oil and seal oil from equipment in the Turbine Building During refueling or maintenance outages, many of the secondary systems and seawater sytems may be drained to the Turbine Building sump and be processed by the oil/water separator.

Steam Generator drainage may also be directed to this discharge point to allow use of raditation monitoring equipment present at the discharge of the Turbine Building sump.The CPS Building drains and sunp may receive:* Sampling waste from CPS sample sink and process instrumentation

• Drainage from CPS system/components for maintenance

• leakage of ethylene glycol from the glycol mixing station (unanticipated)" leakage of motor lubricants used for system pumps* leakage of CPS fluids from pump seals or leakage.* Demineralized water used for process instrumentation and safety shower* Fire protection water (upon activation)

Alternate paths for this discharge: " Oil/Water Separator Vault

1. 2 (Outfall 023)" Turbine Building Auxiliary Sump (holding only-not discharged)" Circulating Water System forebay for Unit 2 (holding only-not discharged)

Potential chemicals in discharge:

• Any chemicals identified in Oil/Water Separator Vault #2 (Outfall 023), Steam Generator Blowdown (025A), Steam Generator Blowdown Demineralizer Rinses (025B), and Waste Holdup Sump (025C).Note: Some of the chemicals listed below are also listed in outfalls 023, 025A, 025B, and 025C. They are listed below because they are also directly discharged into this outfall.Outfall 022, p. 2

" Total Residual Chlorine -chlorinated ocean cooling water system leakage and drainage, chlorinated Fire Protection System water" Ammonia/Ammonium hydroxide

-secondary system leakage and drainage, Secondary Component Cooling Water System filter flushes, secondary system sampling waste, Condensate System flushes (including filter flushes), Steam Generator drainage, Feedwater System flushes, trace quantities from silica analyzer cleaning* Methoxypropylamine-secondary system leakage and drainage, secondary system sampling waste, Steam Generator drainage, Condensate System flushes (including filter flushes), Feedwater System flushes" Hydrazine

-secondary system leakage and drainage, secondary system sampling waste, Steam Generator Drainage, Secondary Component Cooling Water System filter flushes, Condensate System flushes (including filter flushes), Feedwater System flushes" Ethanolamine

-secondary system leakage and drainage, secondary system sampling waste, Steam Generatordrainage, Condensate System flushes (including filter flushes), Feedwater System flushes* Ethylene glycol -leakage from heating and cooling systems" Diisopropylamine -trace quantities from sodium analyzer drains" Sodium Hydroxide -trace quantities from hydrazine analyzer drains, ion chromatography analyzer drains" Sodium tetraborate -trace quantities from ion chromatography analyzer drains* Methanesulfonic acid -trace quantities from ion chromatography analyzer drains* Sulfuric Acid -trace quantities from ion chromatography analyzer drains

• Sodium Carbonate/Bicarbonate

-trace quantities from ion chromatography analyzer drains* Potassium Chloride -trace quantities used in calibration of conductivity instrumentation

• Domestic water constituents (washing, hydrolazing, cooling water, fire protection, potable)* Groundwater constituents

-various vaults/plant areas where groundwater infiltration occurs

• Rainwater constituents

-rainwater collected in vault areas* Suspended solids -all potential inputs may contain suspended solids* Lubricating oils -turbine lube oil, seal oil, pump motor lubricating oils* Electrohydraulic fluid -Turbine valves electrohydraulic control system leakage a Chlorhexidine Di-Gluconate (Hydrosep)

-emergency eyewash station biological growth inhibitor* Morpholine- Steam Generator drainage, secondary system leakage and drainage" Acetaldehyde

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Acetic Acid -potential breakdown product of ethanolamine, all sources of ethanolamine" Diethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Dimethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Monoethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Monomethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine e Triethanolamine

-potential breakdown product of ethanolamine, all sources of ethanolamine" Trimethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Acrylonitrile- potential breakdown product of methoxypropylamine, all sources of methoxypropylamine

• Cresol -trace quantities from cleaning products* Phenol -trace quantities from cleaning products* Sodium hypochlorite -Chemical additive to Fire Protection System, Circulating Water system, Service Water System, and cleaning solutions* Potassium Hydroxide -trace quantities from oxygen analyzer drains* Sodium Fluoride -trace quantities form silica analyzer drains" Hydrochloric Acid -trace quantities from conductivity cell cleanings* Citric Acid -trace quantities from silica analyzer drains* Silica standard

-trace quantities from calibration of silica analyzers

• Ammonium Molybdate -trace quantities from silica analyzer drains* Amino Acid -trace quantities from silica analyzer drainsOutfall 022, p. 3 Proposed chemicals for future discharge:

• Any chemicals identified in Oil/Water Separator Vault #2 (Outfall 023), Steam Generator Blowdown (025A), Steam Generator Blowdown Demineralizer Rinses (025B), and Waste Holdup Sump (025C).Note: Some of the chemicals listed below are also listed in outfalls 023, 025A, 025B, and 025C. They arelisted below because they are also directly discharged into this outfall.* Pyrolidine

-Secondary chemical additive

• Dimethylamine

-Secondary chemical additive 0 5-aminopentanol

-Secondary chemical additive 0 1,2 diaminoethane

-Secondary chemical additive 0 3-hydroxyquinuclidine

-Secondary chemical additive 0 2-amino,2-methylpropanol

-Secondary chemical additive* EDTA -Steam Generator and Generator Stator Coolant System cleaning agent a Carbohydrazide

-Secondary chemical additive, Closed cooling loop additive* Diethylhydroxylamine-Secondary chemical additive* Hydrogen peroxide- Generator Stator Coolant system cleaning agent 0 Steam Generator scale conditioning agents containing one, or more, lower alkyl amines and/or loweralkanol amines, combined with one, or more cyclic imines. These Steam Generator scale conditioning agents may be used during outages. The scale removal process employs the use of a vendor demineralizer skid which is expected to remove all but trace quantities of these chemicals.

Potential alkyl amines and alkanol amines: 1,2- Diamino ethane Diamino propane Diethylamine Dimethylamine Ethanolamine EthylamineEthylene diamine Methoxy propylamine Methylamine 2-methyl-2-amino-1-propanol Potential cyclic imines: Bis-terpyridine 2,9-Dimethyl-1,1 0-phenanthroline 4,7-Dimethyl-1, 1 0-phenanthroline 2,2'-Dipyridyl 4,4'-Dipyridyl Iso-nicoteine 1,1 0-phenanthroline Terpyridine Maximum daily flow: The current NPDES Permit maximum daily flow limit for this outfall is 122,400 GPD.Outfall 022 has a maximum capacity of 85 gpm (122,400 GPD). The average daily flow for this outfall during the period 2000 -2004 is approximately 17,866 GPD (average of average monthly flows reported in DMRs).Outfall 022, p. 4 Dischar2e frequency:

Outfall 022 is a batch discharge, occurring intermittently when the oil/water separator vault reaches the level setpoint.

The discharge is treated as a continuous discharge as the discharge normally occurs many times over the period of a day.Pollutants from Form 2C. Tables 2C-3 and 2C-4: Ammonia Ammonium hydroxide Cresol Diethylamine Dimethylamine Hydrochloric Acid Monoethylamine Monomethylamine Phenol Potassium Hydroxide Sodium fluoride Sodium hypochlorite Sulfuric acid Triethanolamine Triethylamine Acetaldehyde Acetic acid AcrylonitrileOutfall 022, p. 5 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 023 Oil/Water Separator Vault #2 Discharge Information for Outfall 023 Oil/Water Separator Vault #2 EPA Form 2C Section II, Flows, Sources of Pollution and Treatment Technologies Part B, Description of.- (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part V.D, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the following sources:

Floor drains in the in the following buildings and rooms: Auxiliary Boiler Room Diesel Generator Building Emergency Feedwater Pumphouse (from Oil/Water Separator Vault #I when not in service)Turbine Building (from Oil/Water Separator Vault

1. 1 when not in service)Lube Oil Storage Room (from Oil/Water Separator Vault #1 when not in service)Lube Oil Building (from Oil/Water Separator Vault #1 when not in service)Discharge description:

The Floor Drainage Oil/Water Separation System is designed to process non-corrosive oily and potentially oilydrainage and leakage sources to produce an effluent containing less than 15 mg/L oil content which conforms to the Effluent Guidelines and Standards set forth by the EPA in 40 CFR 423 for the Steam Electric Power Generating Point Source Category.

The processed effluent is discharged to the Storm Drainage System (Outfall 002B) and ultimately to the Circulating Water System (Outfall 001).The Oil/Water Separation System is comprised of an oil separator, which contains a gravity settling section to which the oil/water streams are piped, and a tilted plate separator section to effect separation of oil from water. An effluent tank with a pump and a coalescing filter are also provided.

The filter is utilized for final polishing of the effluent prior to discharge.

Operation of the Oil/Water Separation System is initiated upon reaching a setpoint level in the effluent tank.Each separator is designed to process water with an oil content less than 1500 mg/L and discharge a maximum of 85 gpm (122,400 gpd). The gravity settling section is provided to limit suspended solid loading into the oil separationsection to 20 ppm. The down flow tilted plate separator is designed to process an oil/water solution and produce aneffluent with an oil concentration conforming to EPA effluent guidelines. The final polishing coalescing filter is included in the event that separator loadings exceed design values. This filter can reduce the oil content from about 15 mg/L to less than 10 mg/L. Separated oil is collected in the oil holding tank and is removed. Settled solids in the gravity separator are likewise removed.Oil/Water Separator Vault

1. 2 is located in the yard area below grade adjacent to the west side of the Administration Building.

The location of the separator is sufficiently deep to prevent the freezing of the water at low or no-flow conditions.

The vault housing the oil separator, sump and filter is covered to protect the system from the environment.

The vault is ventilated by a natural circulation system. Electrical equipment and lighting in the vault area are explosion proof.Oil/Water Separator Vault #2 processes influents from: the Diesel Generator Building sumps, Auxiliary Boiler room floor drains, and influent to Oil/Water Separator Vault

1. 1- when it is out of service. The Diesel Generator Building sumps collect drainage from the Auxiliary Steam and Condensate heater traps. Leakage of diesel engine lube oil and Outfall 023, p. I fuel oil is also a potential source to the sumps. Effluent from the sump in the diesel fuel oil tank area is pumped directly to the oil separator settling section. Auxiliary Boiler room system equipment leakage consists of demineralized water, condensed steam, fuel oil, and lube oil. Other discharges to this discharge point include Auxiliary Boiler blowdown and drainage, Auxiliary Boiler stack drainage, and Sample System drainage. Effluent in this area is collected in the area floor and hub drains and gravity drains which are directed to the oil/water separator.

Alternate paths for this discharge: " Oil/Water Separator Vault #1 (Outfall 022)* Turbine Building Auxiliary Sump (holding only-not discharged)" Unit II Circulating Water Forebay (holding only-not discharged)

Potential chemicals in discharge:* Any chemical identified in Oil/Water Separator Vault #1 (Outfall 022) discharge Note: Some of the chemicals listed below are also listed in Outfall 022. They are listed below because the y are also directly discharged into this outfall.* Hydrazine

-additive in Auxiliary Steam System, may be present in auxiliary boiler blowdown and drains, auxiliary steam system leakage, sample system drainage* Ammonia/Ammonium hydroxide

-auxiliary boiler blowdown and drains, auxiliary steam system leakage, sample system drainage" Methoxypropylamine

-auxiliary boiler blowdown and drains, auxiliary steam system leakage, sample system drainage* Ethanolamine-auxiliary boiler blowdown and drains, auxiliary steam system leakage, sample system drainage" Domestic.water constituents

-washing, hydrolazing, cooling water, fire protection water, potable water" Groundwater constituents

-groundwater infiltration" Rainwater constituents

-rainwater collection into sumps" Suspended Solids -all potential inputs may contain suspended solids" Lubricating oils -pump motor lubricating oils" Fuel oils -leakage from fuel oil delivery system to auxiliary boilers" Fly Ash -rain water wash of auxiliary boiler stack" Chlorhexidine Di-Gluconate (Hydrosep)

-emergency eyewash station biological growth inhibitor* Morpholine-Auxiliary boiler condensate returns* Sulfuric acid- Auxiliary boiler stack wash* Acetaldehyde-potential breakdown product of ethanolamine, all sources of ethanolamine* Acetic acid- potential breakdown product of ethanolamine, all sources of ethanolamine

• Diethylamine-potential breakdown product of ethanolamine, all sources of ethanolamine

• Dimethylamine-potential breakdown product of ethanolarnine, all sources of ethanolamine

• Monoethylamine- potential breakdown product of ethanolamine, all sources of ethanolamine

• Monomethylamine-potential breakdown product of ethanolamine, all sources of ethanolamine

• Triethanolamine-potential breakdown product of ethanolamine, all sources of ethanolamine

• Trimethylamine-potential breakdown product of ethanolaniine, all sources of ethanolamine" Acrylonitrile-potential breakdown product of methoxypropylamine, all sources of methoxypropylamine" Cresol- trace quantities from cleaning products" Phenol- trace quantities from cleaning products* Sodium hypochiorite-chemical additive to Fire Protection water, Circulating Water system, Service Water system, and cleaning solutions Outfall 023, p. 2 Proposed chemicals for future discharge:

• Any chemical identified in Oil/Water Separator Vault #1 (Outfall 022) discharge Maximum daily flow: The current NPDES Permit maximum daily flow limit for this outfall is 122,400 GPD.Outfall 023 has a maximum capacity of 85 gpm (122,400 GPD). The average daily flow for this outfall over the period 2000 to 2004 is approximately 1,664 GPD (average of average monthly flows reported in DMRs).Discharge freguency:

Outfall 023 is a batch discharge, occuring intermittently when the oil/water separator vault reaches the level setpoint.The discharge is treated as a continuous discharge as the discharge normally occurs many times over the period of a day.Pollutants from Form 2C, Tables 2C-3 and 2C-4: Ammonia Ammonium hydroxide Cresol Diethylamine Dimethylamine Monoethylamine Monomethylamine Phenol Potassium Hydroxide Sodium hypochlorite Sulfuric acid Triethanolamine

Triethylamine Acetaldehyde Acetic acid Acrylonitrile Outfall 023, p. 3 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 024 Oil/Water Separator Vault #3 Discharge Information for Outfall 024 Oil/Water Separator Vault #3 EPA Form 2C Section IL Flows, Sources of Pollution and Treatment Technologies Part B, Description of: (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part VI.D, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the following sources: " Fire Protection Pumphouse Drains* Fire Protection Diesel Pump Fuel Oil Tank areas* Auxiliary Boiler Fuel Oil Storage Tank area Discharge description:

The Floor Drainage Oil/Water Separation System is designed to process non-corrosive oily and potentially oily drainage and leakage sources to produce an effluent containing less than 15 mg/L oil content which conforms to the Effluent Guidelines and Standards set forth by the EPA in 40 CFR 423 for the Steam Electric Power Generating Point Source Category.

The processed effluent is discharged to the Storm Drainage System (Outfall 002B) and ultimately to the Circulating Water System (Outfall 001).The Oil/Water Separation System is comprised of an oil separator, which contains a gravity settling section to which the oil/water streams are piped, and a tilted plate separator section to effect separation of oil from water. An effluent tank with a pump and a coalescing filter are also provided.

The filter is utilized for final polishing of the effluent prior to discharge.

Operation of the Oil/Water Separation System is initiated upon reaching a setpoint level in the effluent tank.Each separator is designed to process water with an oil content less than 1500 mg/L and discharge a maximum of 85 gpm (122,400 gpd). The gravity settling section is provided to limit suspended solid loading into the oil separation section to 20 ppm. The down flow tilted plate separator is designed to process an oil/water solution and produce an effluent with an oil concentration conforming to EPA effluent guidelines.

The final polishing coalescing filter is included in the event that separator loadings exceed design values. This filter can reduce the oil content from about 15 mg/L to less than 10 mg/L. Separated oil is collected in the oil holding tank and is removed periodically.

Settled solids in the gravity separator are likewise removed.Oil/Water Separator Vault #3 is located in the yard area below grade north of the fire pumphouse. The location of the separator is sufficiently deep to prevent the freezing of the water at low or no-flow conditions.

The vault housingthe oil separator, sump and filter is covered to protect the system from the environment. The vault is vented by natural circulation.

Electrical equipment and lighting in the vault area are explosion proof.Oil Water Separator Vault #3 processes influents from the Fire Protection pumphouse drainage trench, Auxiliary Boiler Fuel Oil Storage Tank area, and the diesel fire pump fuel oil day tank areas. There can be leakage of sodium hypochlorite, which is added to the fire protection water as a biocide. Additional sources of leakage are distilled water condensing on the steam heater as well as lubricating and fuel oil from the diesel engines. Effluent from the fire pumphouse floor and hub drains, and the curbed area for the fuel oil day tank (Tank 35A) is collected and piped to Collection Sump #4. This sump is designed to contain a tank rupture. From there it is discharged to Oil/Water Separator Vault #3. Effluent from the curbed area around the fuel oil day tank (Tank 35B) drains to a separate sumnp which is also directly connected to Oil/Water Separator Vault

1. 3.Outfall 024, p. 1 Alternate paths for this discharge:

• There are no planned alternate paths for this discharge Potential chemicals in discharge: " Residual Chlorine

-fire protection water leakage, sampling, and drainage" Fuel oil -leakage from diesel engine systems, trace amounts from filling and sampling activities at storage tanks

• Lubricating oil -leakage from fire pump diesel engines and motors" Ethylene Glycol -leakage from fire pump diesel engine(s) coolant" Domestic water constituents -washing, hydrolazing, cooling water, fire protection water, potable water* Groundwater constituents

-groundwater infiltration into sumps* Rainwater constituents

-rainwater collection in sumps* Chlorhexidine Di-Gluconate (Hydrosep) -emergency eyewash station biological growth inhibitor" Cresol -trace quantities form cleaning products, petroleum containing compounds" Phenol -trace quantities form cleaning products" Sodium Hypochlorite

-chemical additive to Fire Protection water Proposed chemicals for future discharge:

None currently identified Maximum daily flow: The current NPDES Permit maximum daily flow limit for this outfall is 122,400 GPD.Outfall 024 has a maximum capacity of 85 gpm (122,400 GPD). The average daily flow for this outfall over the period 2000 to 2004 is approximately 637 GPD (average of average monthly flows reported in DMRs).Discharge frequency:

Outfall 024 is a batch discharge, occurring intermittently when the oil water/separator vault reaches the level setpoint.

The discharge is treated as a continuous discharge as the discharges may occur many times over the period of a day.Pollutants from Form 2C, Tables 2C-3 and 2C-4: Cresol Phenol Sodium hypochlorite Outfall 024, p. 2 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 025A Steam Generator Blowdown Discharge Information for Outfall 025(A)(Steam Generator Blowdown)EPA Form 2CSection II, Flows, Sources of Pollution and Treatment Technologies Part B, Description of.- (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part V.D, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the following sources: Bottoms fluid from the Blowdown Flash Tank is discharged directly to the Circulating Water System (Outfall 001)when the Steam Generator Blowdown Recovery sub system is unavailable (e.g. during regeneration and rinsing ofthe demineralizer beds), during plant start up and shut down, and when the quality of the effluent is unacceptable for reuse in the Condensate System.Discharge description:

Outfall #025 is a combination of four discrete waste streams which are individually sampled to ensure compliance with NPDES Permit effluent limitations and monitoring requirements.

The four outfall designations are as follows: 025A -Steam Generator Blowdown 025B -Steam Generator Blowdown Demineralizer Rinses 025C -Waste Holdup Surnp 025D -Waste Test Tanks and Recovery Test Tanks The following description is for 025A Steam Generator Blowdown only. Because portions of the other 025 outfalls interface with 025A, they are also briefly discussed.

The Steam Generator Blowdown System removes suspended solids and dissolved impurities from the secondary side of the Steam Generators.

Removal of these solids and impurities minimizes chemical deposition on the Steam Generator tube surfaces.

This is important for limiting any reduction in the heat transfer capability (primary to secondary) of the plant and for reducing the rate of Steam Generator tube corrosion.

A current overview drawing of the Steam Generator Blowdown System follows this description.

The Steam Generator Blowdown System also aids in limiting the buildup of radioactive isotopes in the Steam Generators if a primary to secondary leak occurs.During refueling or extended outages, a portion of the Steam Generator Blowdown System is used in conjunction with the Steam Generator Recirculation and Wet Layup System to maintain the required chemistry control regime inthe Steam Generators.

The major sub-systems in the Steam Generator Blowdown System are: Steam Generator Blowdown System Flash Tank Subsystem:

This sub-system receives the effluent from the (four) Steam Generators.

The blowdown fluid pressure is reduced from 1000 psig to 55 psig. Approximately 30%

of the blowdown liquid is flashed to vapor in the Blowdown Flash Tank at this pressure.

The distillate is then normally directed to the feedwater heater shell side for reuse in the Feedwater System. The remaining liquid (bottoms) is then cooled in the Blowdown Flash Tank bottoms coolers and normally directed to the Steam Generator Blowdown Recovery sub-system and then to the main condenser for reuse in the Condensate System.Outfall 025A, p. 1 When the Blowdown Flash Tank distillate's normal flowpath to the feedwater heater shell side is unavailable, the vapor can either be released to the atmosphere, if it is of acceptable quality, or directed to the flash steam condenser/cooler.

This condensate is then transferred to either the Waste Test Tanks (Outfall 025D) for discharge or to the main condenser for reuse in the Condensate System.When the Steam Generator Blowdown Flash Tank bottoms recovery flowpath through the blowdown recovery subsystem is unavailable, the liquid can be discharged via the Circulating Water System (Outfall 001), if the quality is acceptable, or if unacceptable it will be directed to either the Blowdown Evaporation sub-system or to the Floor Drain Tanks.Steam Generator Blowdown System Recovery Subsystem:

This sub-system receives the cooled fluid from the Blowdown Flash Tank bottoms coolers. The liquid is further cooled (maximum temperature 11 0 0 F) prior to being processed through the blowdown demineralizer skid. The demineralizer skid removes suspended solids and contaminants from the blowdown liquid. After the fluid leaves the demineralizer it is (normally) returned to the main condenser for reuse in the Condensate System. Otherwise it is directed to the Waste Holdup Sump (Outfall 025C) for discharge if the main condenser is unavailable.

Steam Generator Blowdown System Evaporation Subsystem:

This sub-system may be used when there is a primary to secondary leak in the Steam Generator tubes. The evaporators separate the potentially reusable distillate and simultaneously concentrate any contaminants in theevaporator bottoms liquid. The distillate is directed to the distillate cooler, where non-condensable gases are transferred to the equipment vent system for disposal. The condensate is accumulated and, if the conductivity is acceptable, will be sent to the main condenser.

Otherwise it will be sent to the Waste Test Tanks or recirculated back to the evaporator for further processing.

The bottoms product is concentrated in the bottom of the evaporator by recirculating it back to the evaporator inlet after it has been through the bottoms cooler. The concentrated liquid is periodically discharged to the Waste Concentrate Tank for further processing.

If the evaporators are out of service, a valve line up can be manually performed to transfer the blowdown liquid to the Liquid Waste System.

The Liquid Waste System evaporator would then process the Steam Generator blowdown liquid for transfer to the Waste Test Tanks (Outfall 025D) for discharge.

Steam Generator Blowdown System Startup The Steam Generator Blowdown subsystems are lined up for operation concurrently with the reactor plant startup.After the Steam Generator pressures have increased, flow to the Blowdown Flash Tank is commenced.

During startup, all the system controls and valve manipulations are done manually.

Initial blowdown rates are set at maximum to establish, as rapidly as possible, the Steam Generator secondary water chemistry requirements.

This blowdown flow is normally aligned directly to the Circulating Water System (Outfall 001) during plant start up.Once steady state conditions are established, controls are placed in automatic operation.

Typically, during plantstartup, the Blowdown Flash Tank vapor is aligned to the secondary system for reuse. Steam Generator blowdown liquid bottoms typically stay aligned to the Circulating Water System until the plant is at full power. The recovery system is normally placed in service after reaching full power.The Blowdown Flash Tank subsystem operates automatically after startup is completed.

The startup of the Steam Generator Blowdown Recovery Subsystem is manually accomplished.

Prior to placing a demineralizer in service it is subjected to a pre-service rinse. The pre-service rinse water is directed to the Turbine Building sump which isprocessed by Oil/Water Separator Vault #1 (Outfall 022) and ultimately discharged to the Circulating Water System(Outfall 001).

The Steam Generator blowdown liquid flow is then admitted to the demineralizers in the Steam Generator Blowdown Recovery Subsystem, and the effluent is normally returned to the Main Condenser for reuse in the Condensate System. The Steam Generator Blowdown Evaporation Subsystem may be manually started if radioactivity has been detected in the Blowdown Flash Tank Subsystem and further liquid processing is desired.Outfall 025A, p. 2 Nonmal Operation The Steam Generator Blowdown subsystems processes are automatically controlled after the manual startup requirements have been fulfilled. Although subsystem processes are continuously monitored for radiation and conductivity levels, periodic sampling for chemical analysis is also required.

A small quantity of the blowdown from each steam generator is drawn off automatically into the sample system for monitoring of the radioactivity andchemical parameters in the blowdown.

This action ensures the quality of the Steam Generator blowdown effluentwill support its reuse; unsatisfactory quality will necessitate storage and subsequent discharge.

Normal system operation requires minimal operator attention.

The operator monitors local parameters and corrects any undesirable conditions as they develop.

Steam Generator Blowdown System Shutdown Typically the Steam Generator Blowdown System is removed from service only for maintenance or during a plant outage in which the the reactor is shut down and the primary system temperature is reduced to 350 *F or below. The bottoms of the Blowdown Flash Tank are normally directed to the Circulating Water System (Outfall 001) when the plant power level has been decreased to approximately 30%. The Steam Generator Blowdown System is normally shutdown when steam pressure in the Steam Generators decreases to below 50 psig. The system is shutdown by isolating all flow paths into and out of all subsystems.

The Steam Generator Blowdown Flash Tank Subsystem is filled with water, vented, and isolated if shutdown is for an extended duration.

The Steam Generator Blowdown Recovery Subsystem is shutdown by isolating the subsystem and aligning the controls to shutdown.The Steam Generator Blowdown Evaporation Subsystem is isolated and shutdown after the components and the discharge piping have been flushed with evaporator distillate.

Demineralized water is used to flush the subsystem,evaporator demister pad, and to fill components to capacity.

The subsystem is vented to ensure that filling of system components is completed.

The subsystem controls are aligned for shutdown, any residual heat from the components will be dissipated to the building environment.

During a prolonged shutdown period such as a refueling outage, a portion of the Steam Generator Blowdown System piping is utilized for Steam Generator wet lay-up and recirculation.

When the system is aligned to recirculate aSteam Generator, the blowdown flow path is used, but is isolated from the Blowdown Flash Tank. This flow path functions as the supply path to the Steam Generator Wet Layup System. The return path from the Steam Generator Wet Layup System to the Steam Generator is through the Emergency Feedwater/Feedwater Systems. This alternate flow path can also be used during a refueling or maintenance outage to drain a Steam Generator. Steam Generatordrainage can directed to the Turbine Building sump for processing by Oil/Water Separator Vault #1 (Outfall 022), the Storm Drain System, the Waste Holdup Sump (Outfall 025C) or the Waste Liquid processing system (Outfall 025D) prior to discharge to the Circulating Water System (Outfall 001).Demineralizer Regeneration Support equipment is needed to regenerate the resin beds in the demineralizers. The regeneration equipment consists of an Acid Skid, a Caustic Skid and the Waste Holdup Sump (Outfall 025C). The Acid Skid is used to reactivate theCation (positive ion) resin beads within the mixed-bed demineralizers and the lead cation demineralizer.

The Caustic Skid reactivates the Anion (negative ion) resin beads within the mixed-bed demineralizers.

The regenerationwaste water is directed to the Waste Holdup Sump. The Waste Holdup Sump liquid is discharged to the Waste Liquid System which is discharged to the Circulating Water System (Outfall 001). Manual startup of this process is needed to initiate the regeneration cycle. After the process is started the remainder is normally automatically sequenced.

The entire regeneration process can be manually controlled.

Interlocks ensure that only one mixed-bed demineralizer is regenerated at a time. Interlocks will also stop the regeneration cycle if there is not enough Acid orCaustic available to complete a cycle or if the level in the Waste Holdup Sump is above a setpoint level.Upon completion of the regeneration the demineralizer resin beds are rinsed with Steam Generator blowdown water or demineralized water. The rinse water is sampled to ensure compliance with the NPDES Permit effluent Outfall 025A, p. 3 limitations and monitoring requirements for Outfall 025B. The rinse water is ultimately directed to Outfall 001.Before the demineralizer beds are placed in service, a pre-service rinse of the beds is performed with the waste water being directed to the Turbine Building Sump. The pre-service rinse water is processed by Oil/Water Separator Vault#1 (Outfall 022). Upon completion of the pre-service rinse the demineralizer is placed in service with its discharge directed to the main condenser for reuse in the Condensate System.Alternate paths for this discharge:

• Waste Holdup Sump (025C)" Waste Test Tank (s) (025D)" Turbine Building Sump" Storm Drains (if no beta/gamma radioactivity detected)" Auxiliary Turbine Building Sump (holding only -not discharged)" Unit II Circulating Water System forebay (holding only -not discharged)

Potential chemicals in discharge:

• Ammonia/Ammonium hydroxide

-Secondary chemical additive (from thermal decomposition of hydrazine), Steam Generator drainage" Methoxypropylamine

-Secondary chemical additive, Steam Generator drainage* Hydrazine

-Secondary chemical additive, Steam Generator drainage" Suspended solids -particulates from all inputs* Ethanolamine

-Secondary chemical additive, Steam Generator drainage" Morpholine

-Seocndary-chemical additive, Steam Generator soak agent" Acetaldehyde

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Acetic Acid -potential breakdown product of ethanolamine, all sources of ethanolamine" Diethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine" Dimethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Monoethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine" Monomethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine" Triethanolamine

-potential breakdown product of ethanolamine, all sources of ethdnolanine" Trimethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Acrylonitrile

-potential breakdown product of methoxypropylamine, all sources of methoxypropylamine Proposed chemicals for future discharge:

• Pyrolidine

-Secondary chemical additive

• Dimethylamine

-Secondary chemical additive a 5-aminopentanol

-Secondary chemical additive* 1,2 diaminoethane

-Secondary chemical additive

• 3-hydroxyquinuclidine

-Secondary chemical additive 0 2-amino,2-methylpropanol

-Secondary chemical additive a EDTA -Steam Generator cleaning agent* Diethylhydroxylamine

-Secondary chemical additive a Carbohydrazide

-Secondary chemical additive 9 Steam Generator scale conditioning agents containing one, or more, lower alkyl amines and/or lower alkanol amines, combined with one, or more cyclic imines. These Steam Generator scale conditioning agents may be used during outages. The scale removal process employs the use of a vendor demnineralizer skid which is expected to remove all but trace quantities of these chemicals.Outfall 025A, p. 4 Potential alkyl amines and alkanol amines: 1,2- Diamino ethane Diamino propane Diethylamine Dimethylamine Ethanolamine Ethylamine Ethylene diamine Methoxy propylamine Methylamine 2-methyl-2-amino-1-propanol Potential cyclic imines: Bis-terpyridine 2,9-Dimethyl-1, 1 0-phenanthroline 4,7-Dimethyl-1, 1O-phenanthroline 2,2'-Dipyridyl 4,4'-Dipyridyl Iso-nicoteine 1, 10-phenanthroline Terpyridine Maximum daily flow: The current NPDES Permit maximum daily flow limit for Outfall 025 is 425,000 GPD.The maximum capacity for the Steam Generator Blowdown flow rate is approximately 100 gpm from each of the four Steam Generators.

This flowrate represents total flow from each Steam Generator.

The Blowdown Flash Tank liquid bottoms are discharged at a rate of approximately 70 gpm to the Circulating Water System (Outfall 001). The Blowdown Flash Tank distillate is returned to the secondary system at a rate of approximately 30 gprm These maximum flowrates would normally be used only during plant startups, shutdowns or chemical upsets.The actual average flow from Outfall 025A for the period 2000 -2004 is 81,075 GPD.Discharge frequency:

Outfall 025A is a continuous discharge which is initiated on an intermittent basis. The Steam Generator Blowdown discharge is performed when the Steam Generator Blowdown System Recovery Subsystem is unavailable, also during plant startup and shutdown evolutions and when the quality of the Steam Generator Blowdown Flash Tank bottoms liquid is unacceptable for reuse in the Condensate System. The discharge duration may range from a very short duration to a week or more on a continuous basis.Pollutants from Form 2C, Tables 2C-3 and 2C-4: Ammonia Ammonium hydroxide Diethylamine Dimethylamine Monoethylamine Monomethylamine Triethanolamine Triethylamine Outfall 025A, p. 5 Acetaldehyde Acetic acid Acrylonitrile Ouffall 025A, p. 6 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 025B Steam Generator Blowdown Rinses Discharge Information for Outfall 025(B)(Steam Generator Blowdown Rinses)EPA Form 2C Section II, Flows, Sources of Pollution and Treatment Technologies Part B, Description of: (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part V.D, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the followin2 sources: Rinse water from Steam Generator Blowdown demineralizer rinses. Rinse water is directed from the effluent of the demineralizer(s) to either the Waste Holdup Sump (Outfall 025C), the Turbine Building sump or directly to the Circulating Water System (Outfall 001). These rinses are required following regenerations of the demineralizer beds or for pre-service rinses of the demineralizer beds. The rinse water source may either be Steam Generator Blowdown water or demineralized water.Discharge description:

Outfall #025 is a combination of four discrete waste streams which are individually sampled to ensure compliance with NPDES Permit effluent limitations and monitoring requirements. The four outfall designations are as follows: 025A -Steam Generator Blowdown 025B -Steam Generator Blowdown Demineralizer Rinses 025C -Waste Holdup Sump025D -Waste Test Tanks and Recovery Test Tanks The following description is for 025B Steam Generator Blowdown Demineralizer Rinses only. Because portions of the other 025 outfalls interface with 025B, they are also briefly discussed.

This discharge consists of rinse water used to remove impurities from the demineralizers prior to their use for Steam Generator blowdown recovery.

The demineralizer impurities result from the regeneration of the resins with sulfuric acid and sodium hydroxide.

The acid is used to reactivate the cation (positive ion) resin beads within the mixed-bed and cation bed demineralizers. The caustic reactivates the anion (negative ion)resin beads in the mixed-bed demineralizers. Manual startup of this process is required to initiate the regeneration cycle. After the process is started, the remainder is normally automatically sequenced.

The entire regeneration process can be manually controlled.

Upon completion of the regeneration the demineralizer resin beds are rinsed with Steam Generator Blowdown Flash Tank bottoms liquid water or demineralized water. The rinse water is sampled to ensure compliance with the NPDES Permit effluent limitations and monitoring requirements.

The rinse water is normally directed to Outfall 001. Before the demineralizer beds are placed in service, a pre-service rinse of the beds is performed with the waste water being directed to the Turbine Building Sump. The pre-service rinse water is processed by Oil/Water Separator Vault

1. 1 (Outfall 022). Upon completion of the pre-service rinse the demineralizer is placed in service with its discharge directed to the main condenser for reuse in the Condensate System.Alternate paths for this discharge:

.Waste Holdup Sump (025C)Outfall 025B, p. 1

• Waste Test Tank(s) (025D)" Turbine Building Sump" Auxiliary Turbine Building Sump -(holding only -not discharged)

• Unit II Circulating Water forebay -(holding only -not discharged)

Potential chemicals in discharge:

• Ammonia/Ammonium hydroxide

-Secondary chemical additive (from thermal decomposition of hydrazine) Steam Generator drainage" Methoxypropylamine

-Secondary chemical additive, Steam Generator drainage" Hydrazine

-Secondary chemical additive, Steam Generator drainage" Suspended solids -particulates from all inputs" Ethanolamine

-Secondary chemcical additive, Steam Generator drainage," Sulfuric Acid -trace levels remaining form demineralizer regeneration process* Sodium Hydroxide -trace levels remaining form demineralizer regeneration process" Morpholine

-Secondary chemical additive, Steam generator soak agent" Acetaldehyde

-potential breakdown product of ethanolamine, all sources of ethanolamine" Acetic Acid -potential breakdown product of ethanolamine, all sources of ethanolamine

• Diethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Dimethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Monoethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine* Monomethylamine -

potential breakdown product of ethanolamine, all sources of ethanolarnine

• Triethanolamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Trimethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Acrylonitrile

-potential breakdown product ofmethoxypropylamine, all sources of methoxypropylamine Proposed chemicals for future discharge:

• Pyrolidine

-Secondary chemical additive* Dimethylamine

-Secondary chemical additive* 5-aminopentanol

-Secondary chemical additive* 1,2 diaminoethane

-Secondary chemical additive* 3-hydroxyquinuclidine

-Secondary chemical additive

• 2-amino,2-methylpropanol

-Secondary chemical additive* Diethylhydroxylamine

-Secondary chemical additive* EDTA -Steam Generator cleaning agent a Carbohydrazide

-Secondary chemical additive, Primary Component Cooling Water sytem additive

• Steam Generator scale conditioning agents containing one, or more, lower alkyl amines and/or lower alkanol amines, combined with one, or more cyclic imines. These Steam Generator scaleconditioning agents may be used during outages. The scale removal process employs the use of avendor demineralizer skid which is expected to remove all but trace quantities of these chemicals.

Potential alkyl amines and alkanol amines: 1,2- Diamino ethane Diamino propane Diethylamine Dimethylamine Ethanolamine EthylamineEthylene diamineOutfall 025B, p. 2 Methoxy propylarnine Methylamine 2-methyl-2-arnmo-l -propanol Potential cyclic imines: Bis-terpyridine 2,9-Dimethyl-1, 10-phenanthroline 4,7-Dimethyl-1, 10-phenanthroline 2,2'-Dipyridyl 4,4'-Dipyridyl Iso-nicoteine 1,1 0-phenanthroline Terpyridine Maximum daily flow: The current NPDES Permit maximum daily flow limit for Outfall 025B is 210,000 GPD. When the Steam Generators are used to supply demineralizer rinse water, the maximum demineralizer rinse flowrate is 140 gpm. When dernineralized water is used to supply demineralizer rinse water the flowrate is lower.The actual average flow from Outfall 025B for the period April 2002 -2004 is 44,755 GPD.Discharge frequency:

Outfall 025B is a continuous discharge which is initiated on an intermittent basis. The duration of the Steam Generator Blowdown rinses may range from a very short duration to a day or more on a continuous basis.Pollutants from Form 2C, Tables 2C-3 and 2C-4: Ammonia Ammonium hydroxide Diethylamine Dirnethylamine Monoethylamine Monomethylamine Triethanolamine TriethylamineSoduium HydroxideSulfuric Acid Acetaldehyde Acetic acid Acrylonitrile Outfall 025B, p. 3 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 025C Waste Holdup Sump Discharge Information for Outfall 025(C)(Waste Holdup Sump)EPA Form 2C Section II, Flows, Sources of Pollution and Treatment Technologies Part B, Description of- (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V Intake and Effluent Characteristics Part V.D, List of Pollutants from Form 2Co Tables 2C-3 and 2C-4 Discharge includes wastewater from the following sources: " Rinse water from dernineralizer flushes. Rinse water is directed from the effluent of the demeralizer(s) to either the Waste Holdup Sump or directly to the Circulating Water System (Outfall 001). These rinses are required following regeneration of the demineralizer beds or pre-service rinses of the demineralizer beds. The rinse water source may be Steam Generator Blowdown water or demineralized water." Fluid used during the regeneration of the demineralizer beds. The fluid is directed into the Waste Holdup Sump and then discharged to the Waste Liquid System which discharges to the CirculatingWater System (Outfall 001). This wastewater contains acid and caustic wastes from the regeneration process as well as ionic constituents present on the resin from loading.* Drainage from the Steam Generator Blowdown System Recovery Subsystem room drains. This may include acid and caustic waste from system leakage and drainage for maintenance, eyewash drains from the room containing demineralized water and biocide, Steam Generator water from system component leakage, sample system drains, and floor wash water." Drainage from nearby systems for maintenance outages may also be directed to the Waste Holdup Sump. These include drainage from ocean water systems, the Primary Component Cooling WaterSystem, the Potable Water System, and the Demineralized Water System.* Drainage of the Steam Generators may also be directed to this sump if other paths are not available.

• Auxiliary Steam System relief valves Discharge description:

Outfall #025 is a combination of four discrete waste streams which are individually sampled to ensure compliance with NPDES Permit effluent limitations and monitoring requirements. The four outfall designations are as follows: 025A -Steam Generator Blowdown025B -Steam Generator Blowdown Demineralizer Rinses 025C -Waste Holdup Sump 025D -Waste Test Tanks and Recovery Test Tanks The following description is for 025C Steam Generator Blowdown Waste Holdup Sump only. Because portions of the other 025 outfalls interface with 025C, they are also briefly discussed.

Outfall 025C, p. 1 Support equipment is needed to regenerate the resins in the Steam Generator Blowdown System recoverysubsystem demineralizers.

The basic regeneration equipment consists of an Acid Skid, a Caustic Skid and the Waste Holdup Sump.Sulfuric acid is used to reactivate the Cation (positive ion) resin beads within the mixed-bed demineralizers and the lead cation bed demineralizer.

Sodium hydroxide is used to reactivate the Anion (negative ion)resin beads within the mixed-bed demineralizers.. Following a cation bed regeneration, the contents of the sump may be acidic with pH less than 2. The Waste Holdup Sump transfers liquids to the Waste Liquid System for direct discharge to the Circulating Water System (Outfall 001) or to either of the ChemicalDrain Treatment Tanks which are directed to the Waste Test Tanks (Outfall 025D). Manual startup of this process is needed to initiate the regeneration cycle. After the process is started the remainder is automatically sequenced.

The entire regeneration process can be manually controlled.

Interlocks ensure that only one mixed-bed demineralizer is regenerated at a time. Interlocks will also stop the regeneration cycle if there is not enough acid or caustic available to complete a cycle, or if the level in the Waste Holdup Sump is above a setpoint level.The Steam Generator Waste Holdup Sump is a 30,000 gallon sump designed to contain fluids from the regeneration of the demineralizer beds.

It is a concrete sump lined with PlasiteTM liner. The sump also captures some of the floor drains from the demineralizer room. The sump is normally directed to the Waste Liquid System for direct discharge to the Circulating Water System. It is sampled once prior to or duringbatch discharge for oil and grease and total suspended solids.

The relatively low flow volume of the discharge and the buffering action of the seawater ensures that all pH limits at Outfall 001 are met. The sump may also be discharged to the Chemical Drain Treatment Tanks which are directed to the Waste Test Tanks. There is a recirculation system on the sump which allows for mixing and sampling prior to discharge. This recirculation system also contains components which remove larger suspended solids. Themaximum discharge rate for the Waste Holdup Sump is 75 gpm.Alternate paths for this discharge: " Waste Test Tank(s) (025D)* Turbine Building Sump* Storm Drains (if no beta/gamma radioactivity detected)* Turbine Building Auxiliary Sump -(holding only -no discharge)

Potential chemicals in discharge:

• Any chemicals listed in outfalls Steam Generator Blowdown (025A) and Steam Generator Blowdown demineralizer Rinses (025B)Note: Some of the chemicals listed below are also listed in outfalls 025A and 025B. They are listed below because they are also directly discharged into this outfall.* Ammonia/Ammonium hydroxide

-Secondary chemical additive (from thermal decomposition of hydrazine), Primary Component Cooling water drainage, Steam Generator drainage, sample system waste, trace quantities from silica analyzer cleaning* Methoxypropylamine

-Secondary chemical additive, Steam Generator drainage, sample system waste" Hydrazine

-Secondary chemical additive, Steam Generator drainage, Primary Component Cooling Water System drainage, sample system waste* Suspended solids

-particulates from all potential inputs

• Ethanolamine

-Secondary chemical additive, Steam Generator drainage, sample system waste* Total Residual Chlorine

-Ocean cooling water system leakage and drainage, fire protection water* Diisopropylamine

-trace quantities from sodium analyzer drains Outfall 025C, p. 2

" Sodium Hydroxide

-Regeneration of demineralizer beds, leakage from caustic skid, drainage of system components for maintenance" Sufuric Acid -Regeneration of demineralizer beds, leakage from acid skid, drainage of system components for maintenance" Domestic water constituents (washing, hydrolazing, cooling water, fire protection, potable)" Chlorhexidine Di-Gluconate (Hydrosep)

-emergency eyewash station biological growth inhibitor" Morpholine

-Secondary chemical additive, Steam Generator soak agent" Acetaldehyde

-potential breakdown product of ethanolamine, all sources of ethanolamine" Acetic Acid -potential breakdown product of ethanolamine, all sources of ethanolamine" Diethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine" Dimethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine" Monoethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine" Monomethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Triethanolamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Trimethylamine

-potential breakdown product of ethanolamine, all sources of ethanolamine

• Acrylonitrile

-potential breakdown product of methoxypropylamine, all sources of methoxypropylamine

• Cresol -trace quantities from cleaning products" Phenol -trace quantities from cleaning products* Sodium Hypochlorite

-Chemical additive to fire protection system, Circulating Water system, Service Water system, and cleaning solutions" Morpholine

-Steam generator drainage, secondary system leakage and drainage* Citric Acid -trace quantities from silica analyzer drains" Silica standard (500ppb) -trace quantities from calibration of silica analyzers" Ammonium Molybdate

-trace quantities from silica analyzer drains" Amino Acid -trace quantities from silica analyzers" Styrene -potential from resin degredation" Epichlorohydrin

-very limited potential from rinses of new resins" Sodium Fluoride -trace quantities from sodium analyzer cleaning Proposed chemicals for future discharge:* Any chemicals listed in outfalls Steam Generator Blowdown (025A) and Steam Generator Blowdown demineralizer Rinses (025B)Note: Some of the chemicals listed below are also listed in outfalls 025A and 025B. They are listed below because they are also directly discharged into this outfall..* Pyrolidine

-Secondary chemical additive a Dimethylamine

-Secondary chemical additive 0 5-aminopentanol

-Secondary chemical additive* 1,2 diaminoethane

-Secondary chemical additive 0 3-hydroxyquinuclidine

-Secondary chemical additive a 2-amino,2-methylpropanol

-Secondary chemical additive 0 (authorized for discharge in current NPDES Permit at. 1 ppm)0 EDTA -Steam Generator cleaning agent 0 Carbohydrazide-Secondary chemical additive, Primary Component Cooling Water system additive 0 Diethylhydroxylarnine-Secondary chemical additive a Steam Generator scale conditioning agents containing one, or more, lower alkyl amines and/or lower alkanol amines, combined with one, or more cyclic imines. These Steam Generator scale conditioning agents may be used during outages. The scale removal process employs the use of a vendor demineralizer skid which is expected to remove all but trace quantities of these chemicals.Outfall 025C, p. 3 Potential alkyl amines and alkanol amines: 1,2- Diamino ethaneDiamino propane Diethylamine Dimethylamine Ethanolarnine EthylamineEthylene diamineMethoxy propylamine Methylamine 2-methyl-2-amino-I -propanol Potential cyclic imines: Bis-terpyridine 2,9-Dimethyl-1, 1 0-phenanthroline 4,7-Dimethyl-1, 1 0-phenanthroline 2,2'-Dipyridyl 4,4'-Dipyridyl Iso-nicoteine 1, 10-phenanthroline Terpyridine Maximum daily flow: The current NPDES Permit maximum daily flow limit for Outfall 025C is 60,000 GPD. The actual average flow from Outfall 025C for the period April 2002 -2004 is 14,107 GPD.-Discharge frequency:

Outfall 025C is a batch release which occurs on an intermittent basis. The Waste Holdup Sump is recirculated and discharged as a batch when necessary.

Several batch discharges may occur during a week.More than one Waste Holdup Sump discharge per day is infrequent.

Pollutants from Form 2C, Tables 2C-3 and 2C-4: Ammonia Styrene Ammonium hydroxide Triethanolamine Cresol Triethylamine Diethylamine Phenol Dimethylamine Sodium fluoride Monoethylamine Epichlorohydrin Monomethylarine AcetaldehydeSulfuric acid Acetic acid Sodium Hydroxide Acrylonitrile Outfall 025C, p. 4 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D, (List of Pollutants)

Outfall 025D Waste Test Tanks and Recovery Test Tanks Discharge Information for Outfall 025(D)(Waste Test Tanks and Recovery Test Tanks)EPA Form 2C Section II, Flows, Sources of Pollution and Treatment Technologies Part B, Description of" (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part VD, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the followin2 sources:* Distillate from the Blowdown Flash Tank that is directed to the Flash Steam Condenser/Cooler and then to the Waste Test Tanks (Outfall 025D). This path is only used when there is a primary to secondary system leak." Bottoms fluid from the Blowdown Flash Tank which is directed to the Evaporators.

The distillate from the Evaporators is directed to the Distillate Condenser and then to the Waste Test Tanks. This flow path is used when the conductivity of the liquid is unacceptable for reuse.* Chemical Drain Tank. This tank receives inputs from laboratory drains, some floor drains, decontamination sink drains, and machine shop decontamination area drains.* Chemical Drain Treatment Tanks. These tanks receive inputs form the Chemical Drain Tanks." Floor Drains Tanks. These tanks receive inputs from most of the Radiologically Controlled Area floor drains and sumps, Chemical Drain Treatment Tanks, Boron Waste Storage Tanks and Recovery Test Tanks." Boron Waste Storage Tanks. These tanks receive inputs from the Primary Drain Tank, Primary Drain Tank Degassifier, Letdown System degassifier, and the Spent Fuel Pool Cooling System.* Recovery Test Tanks. These tanks receive inputs from the Steam Generator Blowdown SystemRecovery Subsystem evaporators and Waste Liquid System evaporators.

• Bottoms fluid from the Blowdown Flash Tank is directed to the Flash Tank Distillate Pump and then to the Waste Test Tank during either startup or shutdown when the Steam Generator pressure is below 55 psig.Discharge description:

Outfall #025 is a combination of four discrete waste streams which are individually sampled to ensure compliance with NPDES Permit effluent limitations and monitoring requirements. The four outfall designations are as follows: 025A -Steam Generator Blowdown 025B -Steam Generator Blowdown Demineralizer Rinses 025C -Waste Holdup Sump 025D -Waste Test Tanks and Recovery Test Tanks The following description is for 025D Waste Test Tanks and Recovery Test Tanks only. Because portions of the other 025 outfalls interface with 025D, they are also briefly discussed.

The Waste Test Tanks (Outfall 025D) receive inputs from many sources. Floor drains that are located within the Radiologically Controlled Area are directed to the Waste Test Tanks (with a few exceptions).

Most of the inputs to the tanks are normally processed through a vendor treatment system normally consisting of filtration and demineralization.

Reverse Osmosis capability is also provided and operated intermittently when necessary.

Other plant equipment for waste solidification and liquid waste treatment is.not currently being used and there are no plans for use in the future. The Waste Test Tanks are discharged Outfall 025D, p. 1 through the Waste Liquid System to the Circulating Water System (Outfall 001). The tanks have recirculation capability and are limited to a discharge rate of 150 gpm by pump design capacity.The Recovery Test Tanks may receive inputs from the same sources as the Waste Test Tanks as well as the Steam Generator Blowdown System Recovery Subsystem evaporators and Waste Liquid System evaporators.

These tanks may also be discharged through the Waste Liquid System to Outfall 001. The Recovery Test Tanks also have recirculation capability and a maximum discharge rate of 150 gpm by pump-design capacity.Alternate paths for this discharge:

• None planned Potential chemicals in discharge:

• Any chemicals listed in outfalls Steam Generator Blowdown (025A), Steam Generator Blowdown demineralizer Rinses (025B), and Waste Holdup Sump (025C)Note: Some of the chemicals listed below are also listed in outfalls 025A, 025B, and 025C. They are listed below because they are also directly discharged into this outfall." Ammonia/Ammonium hydroxide

-Secondary chemical additive (from thermal decomposition of hydrazine), sample system drainage, Primary Component Cooling Water system leakage and drainage* Methoxypropylamine

-Secondary chemical additive, sample system drainage" Hydrazine

-Secondary chemical additive, sample system drainage, drainage and leakage from Primary Component Cooling Water System" Ethanolamine

-Secondary chemical additive, sample system drainage" Residual Chlorine

-Ocean cooling water system leakage and drainage, Fire Protection System water" Diisopropylamine -trace quantities from sodium analyzer drainage" Potassium Chloride -trace quantities used in calibration of conductivity instrumentation" Domestic water constituents (washing, hydrolazing, cooling water, fire protection, potable)

• Groundwater constituents

-various vaults/plant areas where groundwater in-filtration occurs* Rainwater constituents

-rainwater that collects in vault areas" Ethylene Glycol

-potential leakage from building heating and cooling systems" Suspended solids -particulates from all potential inputs" Lubricating oils -oils used in many system pumps" Sodium Fluoride -trace quantities from sodium analyzer cleaning" Laboratory chemicals and samples -Samples and reagent chemicals used in analytical methods. A subset of these samples and chemicals is hazardous by pH characteristic and are discharged pursuant to a Hazardous Waste Limited Permit for Elementary Neutralization." Boric Acid -chemical additive utilized in primary system to control the fission process" Lithium Hydroxide

-chemical additive utilized in primary system for pH control

• Hydrogen Peroxide-chemical additive utilized in primary system, also used for Total Organic Carbon destruction in liquid waste systems and sumps* Morpholine

-Secondary chemical additive, Steam Generator soak agent* Acetaldehyde

-potential breakdown product of ethanolamine

• Acetic Acid -potential breakdown product of ethanolamine

• Diethylamine

-potential breakdown product of ethanolamine" Dimethylamine

-potential breakdown product of ethanolamine

• Monoethylamine

-potential breakdown product of ethanolamine" Monomethylamine

-potential breakdown product of ethanolamine" Triethanolamine

-potential breakdown product of ethanolamine" Trimethylamine

-potential breakdown product of ethanolamine Outfall 025D, p. 2

" Acrylonitrile

-potential breakdown product of methoxypropylamine" Cresol -trace quantities from cleaning products" Phenol -trace quantities from cleaning products" Epichlorohydrin -very limited potential from rinsing of new resins" Cat Floc TL -flocculant used in the radwaste system to facilitate removal of radioisotopes" Cat Floc L -flocculantused in the radwaste system to facilitate removal of radioisotopes" Nalcolyte 7134 -flocculant used in the radwaste system to facilitate removal of radioisotopes

• Chlorhexidine Di-Gluconate (Hydrosep)

-emergency eyewash station biological growth inhibitor* DC- 13 -Cleaning product used in Radiologically Controlled Area The following Bulk Chemicals, Process Chemicals and Lab Chemicals are proposed for addition to NPDES Permit, Attachment C. The Lab Chemicals identified below supercede those identified in FPL Energy Letter dated September 20, 2004.Bulk Chemicals: " GOSH NRC as a non EDTA containing alternative cleaner to DC-13 in the Radiologically Controlled Area, 251bs/yr* ECOgent as a non EDTA containing alternative cleaner to DC-13 in the Radiologically Controlled Area, 251bs/yr" Durasolution as a non EDTA containing alternative cleaner to DC- 13 in the Radiologically Controlled Area, 251bs/yr" D-Bact as a non EDTA containing alternative respirator sanitizer to MSA Confidence Plus in the Radiologically Controlled Area, 251bs/yr* D-Lead as a non EDTA containing alternative respirator detergent to MSA Confidence Plus in theRadiologically Controlled Area, 251bs/yr Process Chemicals: " Sulfuric Acid for Reverse Osmosis Membrane pH control, 50lbs/yr." Hydrogen Peroxide increase to 50lbs/yr and the frequency to batch 2/M for Total Organic Carbon destruction in Radiologically Controlled Area sumps." KLEEN MCT511 by GE Betz for Reverse Osmosis Membrane Cleaning, 10lbs/yr, batch 2/month" KLEEN MCT103 by GE Betz for Reverse Osmosis Membrane Cleaning, 101bs/yr, batch 2/month" Sodium Metabisulfite Storage Solution for Reverse Osmosis Membrane Layup, 10lbs/yr, batch 2/month Lab Chemicals:

The following. HACH Reagents will be only used in deminimus quantifies when optimizing or troubleshooting the radioactive liquid waste processing system. Actual quantities used on an annual basis will be less than a few hundred grns per Reagent.* HACH Dissolved Oxygen Reagent (Cat ID 2515025)* HACH Hydrazine Reagent (Cat ID 2524025)* HACH Free Ammonia Reagent (Cat ID 2877336)* HACH Monochlor F Reagent (Cat ID 2802299)* HACH TPTZ Iron Reagent (Cat ID 2608799)* HACH Acid Reagent (Cat ID 2107469)* HACH Detergent Reagent (Cat ID 100868)" HACH Benzene Reagent (Cat ID 1444017)* HACH Buffer Solution, Sulfate Type (Cat ID 45249)Outfall 025D, p. 3 Proposed chemicals for future discharge:* Any chemicals listed in outfalls Steam Generator Blowdown (025A), Steam Generator Blowdown demineralizer Rinses (025B), and Waste Holdup Sump (025C)

Note: Some of the chemicals listed below are also listed in outfalls 025A, 025B, and 025C. They are listed below because they are also directly discharged into this outfall.* Pyrolidine

-Secondary chemical additive* Dimethylamine

-Secondary chemical additive* 5-aminopentanol

-Secondary chemical additive.1,2 diaminoethane

-Secondary chemical additive

• 3-hydroxyquinuclidine

-Secondary chemical additive* 2-amino,2-methylpropanol

-Secondary chemical additive* EDTA -Steam Generator cleaning agent* Diethylhydroxylamine

-Secondary chemical additive* Zinc Acetate -Primary chemical additive" Carbohydrazide

-Secondary chemical additive and Primary Component Cooling Water System additive* Steam Generator scale conditioning agents containing one, or more, lower alkyl amines and/or lower alkanol amines, combined with one, or more cyclic imines. These Steam Generator scale conditioning agents may be used during outages. The scale removal process employs the use of a vendor demineralizer skid which is expected to remove all but trace quantities of these chemicals.

Potential alkyl amines and alkanol amines: 1,2- Diamino ethane Diamino propane Diethylamine Dimethylamine Ethanolarnine Ethylamine Ethylene diamine Methoxy propylamine Methylamine 2-methyl-2-amino-1-propanol Potential cyclic imines: Bis-terpyridine 2,9-Dimethyl-1,1 0-phenanthrolme 4,7-Dimethyl-1, 10-phenanthroline 2,2'-Dipyridyl 4,4'-Dipyridyl Iso-nicoteine 1,1 0-phenanthroline Terpyridine Maximum daily flow:The current NPDES Permit maximum daily flow limit for Outfall 025D is 100,000 GPD. The actual average flow from Outfall 025D for the period April 2002

-2004 is 16,424 GPD.Outfall 025D, p. 4 Discharge freique'ncy:

Outfall 025D is a batch discharge which occurs on an intermittent basis.

The Waste Test Tank or RecoveryTest Tank is recirculated and discharged as a batch when necessary.

Several batch discharges may occur during a week. More than one Waste Test Tank or Recovery Test Tank discharge per day is occasionally performed.

Pollutants from Form 2C. Tables 2C-3 and 2C-4: Acetic Acid *Ammonia Ammonium chloride *Ammonium fluoride *Ammonium hydroxide

• Antimony trioxide *Cresol Diethylamine Dimethylamine Epichlorohydrin Monoethylamnine Monomethylamine Phenol Phosphoric Acid *Potassium Permanganate

• Sodium bifluoride

• Sodium bisulfite

• Sodium fluoride

• Sodium hydroxide

• Sodium phosphate Sulfuric acid *Toluene *Triethanolamine Triethylamine Trimethylamine Acetaldehyde Acrylonitrile

• laboratory products used in deminimus quantities Outfall 025D, p. 5 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 026 Chemical Cleaning Waste Discharge Information for Outfall 026 (Chemical Cleaning Wastes)EPA Form 2C Section II, Flows, Sources of Pollution and Treatment Technologies Part B, Description of: (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part VD, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the following sources:.Treated chemical cleaning wastes from either stationary or portable treatment facilities. These facilities may be used to facilitate cleaning of plant systems or components. Chemical cleaning may be performed on non-metallic as well as metallic systems.Discharge description:

A specific chemical cleaning waste discharge description is not provided in this NPDES Permit renewal application as there are no specific plans to perform a chemical cleaning operation at this time. The current NPDES Permit requires that the EPA Regional Administrator and the Director of the New Hampshire Department of Environmental Services be notified at least 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> prior to the discharge of chemical cleaning wastes from stationary or portable facilities. This notification must identify the chemicals to be used, an estimate of the duration of the operation and the point or location of wastewater release into the discharge tunnel.

The types of chemical cleaning activities vary widely with application. The chemicals used in the processes willdepend upon a number of variables including:

environmental impact, system materials, fouling characteristics, availability of materials, residual affects on materials, operational considerations, and other factors. The discharge is from equipment that is designed to perform a chemical cleaning operation on plant components and systems. This discharge is not applicable to the use of janitorial cleaning products used in maintaining general plant cleanliness.

The discharge of wastes from chemical cleaning equipment is ultimately discharged to Outfall 001. Sampling and monitoring requirements may vary dependent on the application and chemicals that are used.Alternate paths for this discharge:

• No alternate paths anticipated Potential chemicals in discharge:

• Varies with application Maximum daily flow: The current NPDES Permit flow limit for Outfall 026 is 450,000 GPD. No change in the current NPDES Permit is proposed.Outfall 026, p. 1 Discharae frequency:

Outfall 026 is normally a batch discharge which occurs on an intermittent basis. A discrete batch of the wastewater would be discharged after applicable monitoring requirements and effluent limitations had been met.Proposed chemicals for future discharge:

• Varies with application Pollutants from Form 2C. Tables 2C-3 and 2C-4: Varies with application Outfall 026, p. 2 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 027 Cooling Tower Discharge Discharge Information for Outfall 027 (Cooling Tower Discharge)

EPA Form 2C Section A1, Flows, Sources of Pollution and Treatment Technologies Part B, Description of: (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.,Section V, Intake and Effluent Characteristics Part V.D, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the following sources:Cooling Tower discharges include the following evolutions.

Each of the following discharges are sampled to ensure compliance with the effluent limitations and monitoring requirements of the NPDES Permit." Cooling Tower blowdown -primarily potable water with some seawater present. Chemicals introduced include sodium hypochlorite for biological fouling control and sodium silicate as a scale inhibitor.

Blowdown may be performed to reduce the salinity and/or total dissolved solids in the Cooling Tower to maintain heat transfer capabilities." Cooling Tower discharges

-other discharges of Cooling Tower water occur when Service Water System cooling is swapped from the ocean water supply to the Cooling Tower, and upon return to the ocean water supply.Discharge description:The Cooling Tower (part of the Service Water System) is designed to provide cooling water to plant systems.During normal operating conditions, extended use of the Cooling Tower is infrequent.

Normally, the cooling waterfor plant systems is supplied by the ocean Service Water pumps, however on occasion the Cooling Tower is placed in service providing the cooling water supply. The Seabrook Station Operating License requires the Cooling Tower be placed in service on a quarterly basis to verify that the cooling water supply can be aligned to the safety-related source of cooling water provided by the Cooling Tower. This evolution occurs approximately every six weeks because each of the two Cooling Tower water trains must be tested each quarter. The Cooling Tower may also be operated to allow maintenance to be performed on the ocean cooling water pumps or during winter months to warm the fresh water supply in the tower basin. The Cooling Tower provides a safety-related source of cooling water in that it is designed to function after a seismic event where it is postulated that the ocean cooling water supply is unavailable due to collapse and blockage of the cooling water tunnels. During accident conditions involving the unavailability of the ocean cooling water supply, the Cooling Tower would supply cooling water to plant systems that are required for safe shutdown. The entire Cooling Tower is constructed over a storage basin that contains 3,900,000 gallons of fresh water (primarily). This volume of water is sufficient to dissipate the design heat loads for seven days without the addition of makeup to the basinThe Cooling Tower is comprised of a storage basin, two centrifugal pumps, three fans, a spray header and associated piping and components.

The system pumps provide flow through the plant heat exchangers to remove heat. Heated water is returned to the Cooling Tower and is discharged through a spray header. The spray headers form a horizontal grid and are situated directly above the ceramic fill in the Cooling Tower. The ceramic fill is composed of brick-like clay tiles built up in layers supported by cast iron lintels.

Each tile has vertically oriented, square holes which, when the tiles are layered, form thousands of offset, cascade water paths through the fill. The cascade water paths provide even distribution and increased fill surface area, which enhances the cooling process. As the heated water passes downward through the fill, an induced flow of cooling air passes upward through the fill. The heat in the service water is transferred to the air flowing in the opposite direction. The cooled service water falls into the storage basin and is ready to repeat the cycle. The heated air is expelled via the Cooling Tower fan velocity stacks on top of the structure.

Some water droplets are entrained into this air flow, but are significantly removed by a series of mist eliminators.

The mist eliminators limit carryover to 0.03%.Outfall 027, p. 1 Normal makeup water is supplied from the Potable Water System. Water may also be supplied from other sources if potable water is not available or a more rapid makeup is desired. Some other sources include: seawater from the forebays, fire protection main water, water from the Brown's river, seawater from Hampton Harbor, or any other onsite water that may be available for use in an emergency.

Although the Cooling Tower can operate on seawater, it is prudent to maintain the salinity and total dissolved solids of the basin water as low as possible during normal operation.

The normal total dissolved solids level of the Cooling Tower water is 3000 -5000 ppm (compared to seawater at 35,000 ppm). This is accomplished by aligning the Cooling Tower water discharge path to Outfall 001 for a period of time when first placing the system in operation.

This action flushes seawater from the system piping before returning the discharge to the Cooling Tower. When the Cooling Tower is removed from service, the Cooling Tower water that is trapped in the Service Water System piping is displaced by seawater and discharged to Outfall 001. The evolution of placing the tower in service, and removing it from service, typically results in a discharge of between 50,000 to 200,000 gallons of Cooling Tower water.Cooling Tower blowdown is a discharge of a volume of the Cooling Tower water inventory to Outfall 001, specifically intended on reducing water level in the basin. This blowdown is typically performed to reduce tower salinity and/or total dissolved solids following extended operation.

The reduction in these parameters occurs due to the makeup of fresh water to the system.

Blowdown may also be performed to prevent overflow of the basin if the Cooling Tower water level reaches a high level such as the result of a series of rainfall events.Cooling Tower water is treated to minimize biofouling and scaling of the system components.

Sodium hypochlorite is normally added to the Cooling Tower during summer months to inhibit biological growth. A silica based anti-scalant is also added to minimize scaling in the Cooling Tower.

The anti-scalant is added on an as-needed basis asdetermined by basin water sampling.

Alternate paths for this discharge:

• No alternate paths anticipated Potential chemicals in discharge:

• Total Residual Chlorine -

ocean water system input, Fire Protection System water from fill" Sodium Hypochlorite

-added to inhibit biological growth, seawater input, Fire Protection System water input" Domestic water constituents

-primary fill media, fire protection, washing, hydrolazing

• Rainwater constituents

-rainwater that collects in open basin" Suspended solids- all potential inputs to the cooling tower" Chlorhexidine Di-Gluconate (Hydrosep)

-emergency eyewash station biological growth inhibitor" Sodium Silicate-scale inhibitor additive Proposed chemicals for future discharge:

None anticipated Maximum daily flow: The current NPDES Permit does not contain a flow limit for Outfall 027.

Average flows for Outfall 027 during the period April 2002 thru 2004 are 85,276 GPD. When placing the Cooling Tower in service and when removing the Cooling Tower from service approximately 50,000 to 200,000 gallons of Cooling Tower water is discharged to Outfall 001. In the event that the Cooling Tower is operated for an extended period, necessitating a blowdown evolution it is estimated that approximately 500,000 gallons of Cooling Tower may be discharged.

Outfall 027, p. 2 Discharge frequency:

Outfall 027 is considered a continuous discharge which occurs on an intermittent basis. Cooling Tower discharges may occur for a short period of time such as during swapover or a significant period of time during a blowdown following extended Cooling Tower operation.Pollutants from Form 2C, Tables 2C-3 and 2C-4: Sodium Hypochlorite Outfall 027, p. 3 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 28A Condensate Polishing System (CPS)Neutralization Tank Discharge Information for Outfall 028A CPS Neutralization Tank EPA Form 2C Section IL, Flows, Sources of Pollution and Treatment Technologies Part B, Description of: (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part V.D, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the following sources: Fluid used during the regeneration of the Condensate Polisher demineralizer beds. The fluid is directed into the neutralization tank and then discharged to the Circulating Water System (Outfall 001). This wastewater contains acid and caustic wastes from the regeneration process as well as ionic constituents present on the resin from loading.

• Rinse water from the Condensate Polisher demineralizers.

Rinse water may be directed from the effluent of the demeralizer(s) to the neutralization tank. These rinses are required following regeneration of the dernineralizer beds or pre-service rinses of the demineralizer beds. The rinse water source is demineralized water.System drainage for maintenance activities. Regeneration system components may be drained for maintenance activities.

System drain water could contain acid and caustic as well as low levels of anmines from vessels and piping. If maintenance needs to be performed on the Sodium Hydroxide orSulfuric Acid tanks, their fluids may also be drained to this neutralization tank. Acid and caustic waste is neutralized to a pH of between 2 and 12.5 prior to discharge.

The Leased Makeup Water Treatment System (LMWTS) cleaning wastes are also directed into the neutralization tank. Cleaning is typically performed using Sodium Hydroxide and Sulfuric Acid and the wastes are generally neutralized in the water treatment system prior to discharge into the neutralization tank. Other infrequently used cleaning agents include Hydrogen Peroxide, Sodium Hypochlorite, and Sodium Chloride.Discharme description:

The CPS was completed and initially operated in 2005 during the term of the current NPDES Permit as documented in the renewal application for the current NPDES Permit submitted in April 1998. It is an integral part of the Condensate System. The CPS is designed to remove dissolved and suspended impurities from the Condensate System that can cause corrosion and fouling of secondary components.

The system is normally maintained in a standby condition and is placed in operation to remove secondary system contaminants to support plant start up or to remove impurities introduced by a condenser tube leak.

The basic system design consists of cation resin vessels, mixed bed resin vessels, pumps and associated equipment, and an external resin regeneration and waste processing system. The CPS is designed to accommodate approximately one third of the total condensate flow. The resin vessels remove the ionicconstituents from the condensate system including the amines used for secondary chemistry control. The auxiliary regeneration and waste system is used to regenerate the resin for re-use and to discharge the regeneration and rinsate wastes. Sodium Hydroxide and Sulfuric Acid are used as regenerant chemicals.

Outfall 028A, p. 1 The discharges from the CPS System include: rinses of the system in support of plant start-up, periodic rinses during standby conditions, rinses of the resin vessels following regenerations, regeneration wastewater, sampling system and grab sample waste, system leakage, and system drainage for maintenance.

The CPS regenerant waste is collected in the neutralization tank and sampled prior to discharge.

The tank volume is 32,000 gallons. The neutralization tank is recirculated, via pumps installed in the tank and an eductor system to facilitate mixing. The tank is discharged at a maximum rate of 300gpm.Alternate paths for this discharge:

• None anticipated.

Potential chemicals in discharge:

• Any chemicals identified in CPS Low Conductivity Tank (028B).Note: Some of the chemicals listed below are also listed in outfalls 028B. They are listed below because they are also directly discharged into this outfall.The potential chemicals in this are very similar to those in Outfall 025C. The CPS system process is similar to the Steam Generator Blowdown Reclaim System in that it removes unwanted Secondary Plant impurities by demineralization.

The regeneration process to regenerate the demineralizers is also like that of the Steam Generator Blowdown Reclaim System.'" Ammonia/Ammonium hydroxide

-Secondary chemical additive (from thermal decomposition ofhydrazine), Primary Component Cooling water drainage, Steam Generator drainage, sample system waste, trace quantities from silica analyzer cleaning, and potential CPS regeneration chemical.* Methoxypropylamine

-Secondary chemical additive, Steam Generator drainage, sample system waste" Hydrazine

-Secondary chemical additive, Steam Generator drainage, Primary Component CoolingWater System drainage, sample system waste* Suspended solids

-particulates from all potential inputs" Ethanolamine

-Secondary chemical additive, Steam Generator drainage, sample systemwaste

• Total Residual Chlorine -Ocean cooling water system leakage and drainage, fire protection water, LMWTS cleaning waste* Sodium Hydroxide

-Regeneration of demineralizer beds, leakage from caustic skid, drainage of system components for maintenance" Sufuric acid -Regeneration of demineralizer beds, leakage from acid skid, drainage of system components for maintenance

• Domestic water constituents (washing, hydrolazing, cooling water, fire protection, potable)" Sodium Chloride-LMWTS cleaning waste" Chlorhexidine Di-Gluconate (Hydrosep)

-emergency eyewash station biological growth inhibitor* Morpholine

-Secondary chemical additive, Steam Generator soak agent" Acetaldehyde-potential breakdown product of ethanolamine, all sources of ethanolamine

• Acetic acid-potential breakdown product of ethanolamine, all sources of ethanolamine

• Diethylamine-potential breakdown product of ethanolamine, all sources of ethanolamine

• Dimethylamine-potential breakdown product of ethanolamine, all sources of ethanolamine

• Monoethylamine-potential breakdown product of ethanolamine, all sources of ethanolamine" Monomethylamine-potential breakdown product of ethanolamine, all sources of ethanolamine

• Triethanolamine- potential breakdown product of ethanolamine, all sources of ethanolamine" Trimethylamine- potential breakdown product of ethanolamine, all sources of ethanolamine" Acrylonitrile-potential breakdown product of methoxypropylamine, all sources of methoxypropylamine" Cresol- trace quantities from cleaning products Outfall 028A, p. 2

• Phenol- trace quantities from cleaning products" Sodium hypochlorite-Chemical additive to fire protection system, Circulating Water system, Service Water system, LMWTS cleaning agent, and cleaning solutions." Morpholine-Steam generator drainage, secondary system leakage and drainage" Styrene- potential from resin degredation" Epichlorohydrin-very limited potential from rinses of new resins" Hydrogen Peroxide-LMWTS cleaning Proposed chemicals for future dischar2e:

• Pyrolidine

.Secondary chemical additive 0 Dimethylamine

-Secondary chemical additive 0 5-aminopentanol

-Secondary chemical additive* 1,2 diaminoethane

-Secondary chemical additive 0 3-hydroxyquinuclidine

-Secondary chemical additive

• 2-amino,2-methylpropanol

-Secondary chemical additive 0 (authorized for discharge in current NPDES Permit at. 1 ppm)* EDTA -Steam Generator cleaning agent 0 Carbohydrazide-Secondary chemical additive, Primary Component Cooling Water system additive a Diethylhydroxylamine-Secondary chemical additive* Polyacrylic Acid- Secondary chemical additive that aids in maintaining Iron in solution* Ammonium Sulfate- potential future CPS regeneration chemical* Sodium Bicarbonate-potential future CPS regeneration chemical Maximum daily flow: The proposed NPDES Permit maximum daily flow limit for Outfall 028A is 96,000 GPD. The maximumdaily flow is based on an expected maximum of three batch discharges per day.Discharge frequency:

Outfall 028A is a batch release that occurs on an intermittent basis. The CPS Neutralization Tank is recirculated and discharged as a batch when necessary.

Several batch discharges may occur during a week.More than one Neutralization Tank discharge per day is infrequent.

Pollutants from Form 2C. Tables 2C-3 and 2C-4: Ammonia Phenol Ammonium hydroxide Sodium fluoride Cresol Epichlorohydrin Diethylamine Acetaldehyde Dimethylamine Acetic acid Monoethylarnine Acrylonitrile MonomethylamineSulfuric acid Sodium Hydroxide Styrene -Triethanolanine Triethylamine Outfall 028A, p. 3 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 28B Condensate Polishing System (CPS)Low Conductivity Tank Discharge Information for Outfall 028B CPS Low Conductivity Tank EPA Form 2C Section IA Flows, Sources of Pollution and Treatment Technologies Part B, Description of.' (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part VD, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the following sources: Fluids used during the backwash and transfer of the Condensate Polisher demineralizer beds. The fluid is directed into the Low Conductivity tank and then discharged to the Circulating Water System (Outfall 001).This wastewater contains low concentrations of acid and caustic wastes from the regeneration process as well as trace levels of ionic constituents present on the resin following regeneration.

Backwash waste contains particulate matter that has been trapped in the demineralizers during system operation.

0 Drain water from Condensate Polisher demineralizers and Low Conductivity system piping contents that may be drained for maintenance.

Discharge description:

The CPS was completed and initially operated in 2005 during the term of the current NPDES Permit as documented in the renewal application for the current NPDES Permit submitted in April 1998. It is an integral part of the Condensate System. The CPS is designed to remove dissolved and suspended impurities from the Condensate System that can cause corrosion and fouling of secondary components.

The system is normally maintained in a standby condition and is placed in operation to remove secondary system contaminants to support plant start up or to remove impurities introduced by a condenser tube leak.The basic system design consists of cation resin vessels, mixed bed resin vessels, pumps and associated equipment, and an external resin regeneration and waste processing system. The CPS is designed to accommodate approximately one third of the total condensate flow. The resin vessels remove the ionic constituents from the condensate system including the amines used for secondary chemistry control. The auxiliary regeneration and waste system is used to regenerate the resin for re-use and to discharge the regeneration and rinsate wastes. Sodium Hydroxide and Sulfuric Acid are used as regenerant chemicals.

The discharges from the CPS System include: rinses of the system in support of plant start-up, periodic rinses during standby conditions, rinses of the resin vessels following regenerations, regeneration wastewater, sampling system and grab sample waste, system leakage, and system drainage for maintenance.

The Low Conductivity Tank receives fluids from backwashes of the demineralizers and from activities involving transfer of the resin from various resin vessels in the system. The conductivity of the water in this tank is generally low as concentrated regeneration chemicals and concentrated arnines are not present in the wastes.The CPS low conductivity waste is collected in the Low Conductivity Tank and sampled prior to discharge.

The tank volume is 32,000 gallons. The Low Conductivity Tank is recirculated via pumps installed in the tank to facilitate mixing and sampling.

The tank is discharged at a maximum rate of 300gpm.Outfall 028B, p. 1 Alternate paths for this discharge:

• CPS Neutralization Tank (Outfall 028A)

Potential chemicals in discharge:The potential chemicals in this are very similar to those in Outfall 028A. Although the chemical list below is extensive, most of the chemicals listed would only be present in very low concentrations. The waste stream is expected to have only low concentrations of Secondary System and regeneration chemicals.

• Ammonia/Ammonium hydroxide

-Secondary chemical additive (from thermal decomposition of hydrazine), Primary Component Cooling water drainage, Steam Generator drainage, sample system waste, trace quantities from silica analyzer cleaning, and CPS regeneration chemical (potential)." Methoxypropylamine

-Secondary chemical additive, Steam Generator drainage, sample system waste* Hydrazine

-Secondary chemical additive, Steam Generator drainage, Primary Component Cooling Water System drainage, sample system waste" Suspended solids -particulates from all potential inputs" Ethanolamine

-Secondary chemical additive, Steam Generator drainage, sample system waste* Sodium Hydroxide

-Regeneration of demineralizer beds, leakage from caustic skid, drainage of system components for maintenance" Sufuric acid -Regeneration of demineralizer beds, leakage from acid skid, drainage of system components for maintenance" Domestic water constituents (washing, hydrolazing, cooling water, fire protection, potable)

• Morpholine

-Secondary chemical additive, Steam Generator soak agent* Acetaldehyde- potential breakdown product of ethanolamine, all sources of ethanolamine" Acetic acid- potential breakdown product of ethanolamine, all sources of ethanolamine" Diethylamine- potential breakdown product of ethanolamine, all sources of ethanolamine

• Dimethylamine- potential breakdown product of ethanolamine, all sources of ethanolamine a Monoethylamine- potential breakdown product of ethanolamine, all sources of ethanolamine" Monomethylamine- potential breakdown product of ethanolamine, all sources of ethanolamine

• Triethanolamine-potential breakdown product of ethanolamine, all sources of ethanolamine

• Trimethylamine- potential breakdown product of ethanolamine, all sources of ethanolamine" Acrylonitrile- potential breakdown product of methoxypropylamine, all sources of methoxypropylamine" Morpholine-Steam generator drainage, secondary system leakage and drainage" Styrene- potential from resin degredation" very limited potential from rinses of new resins Proposed chemicals for future discharge:

a Pyrolidine

-Secondary chemical additive* Dimethylamine

-Secondary chemical additive* 5-aminopentanol

-Secondary chemical additive* 1,2 diaminoethane -Secondary chemical additive

• 3-hydroxyquinuclidine

-Secondary chemical additive

• 2-amino,2-methylpropanol

-Secondary chemical additive* (authorized for discharge in current NPDES Permit at .1 ppm)" EDTA -Steam Generator cleaning agent" Carbohydrazide- Secondary chemical additive, Primary Component Cooling Water system additive

• Diethylhydroxylamine- Secondary chemical additive" Polyacrylic Acid-Secondary chemical additive that aids in maintaining Iron in solution" Ammonium Sulfate- potential future CPS regeneration chemical" Sodium Bicarbonate-potential future CPS regeneration chemical Outfall 028B, p. 2 Maximum daily flow: The proposed NPDES Permit maximum daily flow limit for Outfall 028B is 96,000 GPD. The maximum daily flow is based on an expected maximum of three batch discharges per day.Discharge frequency:

Outfall 028B is a batch release that occurs on an intermittent basis. The CPS Low Conductivity Tank is recirculated and discharged as a batch when necessary.

Several batch discharges may occur during a week. More than one Low Conductivity Tank discharge per day is infrequent.

Pollutants from Form 2C. Tables 2C-3 and 2C-4: Ammonia Ammonium hydroxide Cresol Diethylamine Dimethylamine Monoethylamine Monomethylamine Sulfuric acid Sodium Hydroxide Styrene Triethanolamine Triethylamine Phenol Sodium fluoride Epichlorohydrin Acetaldehyde Acetic acid Acrylonitrile Outfall 028B, p. 3 EPA Form 2C Section II, Part B (Descriptions) and Section V, Part D (List of Pollutants)

Outfall 28C Condensate Polishing System (CPS)Rinses Discharge Information for Outfall 028C CPS Rinses EPA Form 2C Section 11, Flows, Sources of Pollution and Treatment Technologies Part B, Description of: (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, cooling water, and storm water runoff; (2) The average flow contributed by each operation; and (3) The treatment received by the wastewater.

Section V, Intake and Effluent Characteristics Part V.D, List of Pollutants from Form 2C, Tables 2C-3 and 2C-4 Discharge includes wastewater from the following sources: 0 Fluids used during rinses of the Condensate Polisher demineralizer beds after regeneration.

The CPS resin isrinsed prior to placing the resin into the service vessels. The resin is rinsed to remove residual concentrations of Sodium Hydroxide and Sulfuric Acid remaining on the resin following regeneration. Rinse water is directedfrom the effluent of the resin vessels to Circulating Water System. The rinse water source is demineralized water.Discharge description:

The CPS was completed and initially operated in 2005 during the term of the current NPDES Permit as documented in the renewal application for the current NPDES Permit submitted in April 1998. It is an integral part of the Condensate System. The CPS is designed to remove dissolved and suspended impurities from the Condensate System that can cause corrosion and fouling of secondary components.

The system is normally maintained in astandby condition and is placed in operation to remove secondary system contaminants to support plant start up or toremove impurities introduced by a condenser tube leak.The basic system design consists of cation resin vessels, mixed bed resin vessels, pumps and associated equipment, and an external resin regeneration and waste processing system. The CPS is designed to accommodate approximately one third of the total condensate flow.

The resin vessels remove the ionic constituents from thecondensate system including the amines used for secondary chemistry control. The auxiliary regeneration and waste system is used to regenerate the resin for re-use and to discharge the regeneration and rinsate wastes. Sodium Hydroxide and Sulfuric Acid are used as regenerant chemicals.The discharges from the CPS System include: rinses of the system in support of plant start-up, periodic rinses during standby conditions, rinses of the resin vessels following regenerations, regeneration wastewater, sampling system andgrab sample waste, system leakage, and system drainage for maintenance.

The CPS rinse discharge consists of water used to remove impurities from the demineralizers prior to their use for Condensate System clean up. The demineralizer impurities result from the regeneration of the resins with Sulfuric Acid and Sodium Hydroxide. The acid is used to reactivate the cation (positive ion) resin beads within the mixed-bed and cation bed demineralizers.

The caustic reactivates the anion (negative ion) resin beads in the mixed-bed demineralizers.

The regeneration process is started manually.

Upon completion of the regeneration, the demineralizer resin beds are rinsed with demineralized water. The rinse water is sampled to ensure compliance with the NPDES Permit effluent limitations and monitoring requirements.

The rinse water is directed to Outfall 001.Alternate paths for this dischar2e:

• None anticipated Outfall 028C, p. 1 Potential chemicals in discharge:

The potential chemicals in this are very similar to those in Outfall 028A. Although the chemical list below is extensive, most of the chemicals listed would only be present in very low concentrations.

The waste stream is expected to have only low concentrations of Secondary System and regeneration chemicals." Ammonia/Ammonium hydroxide

-Secondary chemical additive (from thermal decomposition of hydrazine),Primary Component Cooling water drainage, Steam Generator drainage, sample system waste, trace quantities from silica analyzer cleaning, and CPS regeneration chemical.* Methoxypropylamine

-Secondary chemical additive, Steam Generator drainage, sample system waste* Hydrazine

-Secondary chemical additive, Steam Generator drainage, Primary Component Cooling WaterSystem drainage, sample system waste" Suspended solids -particulates from all potential inputs* Ethanolamine

-Secondary chemical additive, Steam Generator drainage, sample system waste" Sodium Hydroxide

-Regeneration of demineralizer beds, leakage from caustic skid, drainage of system components for maintenance" Sufuric acid -Regeneration of demineralizer beds, leakage from acid skid, drainage of system components for maintenance

• Domestic water constituents (washing, hydrolazing, cooling water, fire protection, potable)" Morpholine

-Secondary chemical additive, Steam Generator soak agent" Acetaldehyde-potential breakdown product of ethanolamine, all sources of ethanolamine" Acetic acid- potential breakdown product of ethanolamine, all sources of ethanolamine" Diethylamiine-potential breakdown product of ethanolamine, all sources of ethanolamine" Dimethylamine-potential breakdown product of ethanolamine, all sources of ethanolamine

• Monoethylamine-potential breakdown product of ethanolamine, all sources of ethanolamine" Monomethylamine-potential breakdown product of ethanolamine, all sources of ethanolamine

• Triethanolamine-potential breakdown product of ethanolamine, all sources of ethanolamine

• Trimethylamine-potential breakdown product of ethanolamine, all sources of ethanolamine" Acrylonitrile-potential breakdown product of methoxypropylamine, all sources of methoxypropylarnine

• Morpholine-Steam generator drainage, secondary system leakage and drainage" Styrene- potential from resin degredation" Epichlorohydrin-very limited potential from rinses of new resins Proposed chemicals for future discharge:

0 Pyrolidine

-Secondary chemical additive* Dimethylamine

-Secondary chemical additive a 5-aminopentanol

-Secondary chemical additive* 1,2 diaminoethane

-Secondary chemical additive a 3-hydroxyquinuclidine

-Secondary chemical additive 0 2-amino,2-methylpropanol

-Secondary chemical additive a (authorized for discharge in current NPDES Permit at. 1 ppm)* Carbohydrazide-Secondary chemical additive, Primary Component Cooling Water system additiveDiethylhydroxylamine- Secondary chemical additive

• Polyacrylic Acid- Secondary chemical that aids in maintaining Iron in solution* Ammonium Sulfate- potential future CPS regeneration chemical* Sodium Bicarbonate-potential future CPS regeneration chemical Outfall 028C, p. 2 Maximum daily flow: The proposed NPDES Permit maximum daily flow limit for Outfall 028C is 500,000 GPD.

The maximum daily flow is based upon the highest system flow rate occurring over the entire 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> period. System rinse flow rates vary from approximately 200gpm to 340gpm.Discharge frequency:Outfall 028C is a continuous is initiated on an intermittent basis. The duration of the CPS rinses may range from a very short duration to a day or more on a continuous basis.Pollutants from Form 2C. Tables 2C-3 and 2C-4: Ammonia Ammonium hydroxide Cresol Diethylamine Dimethylamine Monoethylamine Monomethylamine Sulfuric acid Sodium Hydroxide Styrene Triethanolamine Triethylamine PhenolSodium fluoride Epichlorohydrin Acetaldehyde Acetic acid Acrylonitrile Outfall 028C, p. 3 A AR EVA EPA Application Form 2C -Wastewater Discharge Information Consolidated Permits Program Laboratory Analysis of Wastewater Samples at the Seabrook Nuclear Power Station September 6, 2006 EL 116/06 AREVA NP INC.ENVIRONMENTAL LABORATORY 29 Research Drive Westborough, MA 01581-3913 Tel: 508-573-6650 Fax: 508-573-6680 0 PLEASE PRINT OR TYPE IN THE UNSHADED AREAS ONLY. You may report some or all of this information EPA I.D. NUMBER (copyfrom Item I of Form I)on separate sheets (use the same format) instead of completing these pagesI NHD081257446 SEE INSTRUCTIONS.

I V. INTAKE AND EFFLUENT CHARACTERISTICS (continued from page 3 of Form 2-C)OUTFALL NO.

001-1 PART A -You must provide the results of at least one analysis for every pollutant in this table. Complete one table for each outfall. See instructions for additional details.3. UNITS 4. INTAKE2. EFFLUENT (specify i/blank) (optional)

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM a. MAXIMUM DAILY VALUE (ifavailable) (if available)

AVERAGE VALUE (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF 1. POLLUTANT CONCENTRATION (2)

MASS CONCENTRATION (2)

MASS M1l CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2)

MASS ANALYSES a. Biochemical Oxygen ND Demand (BOD)b. Chemical Oxygen 140 774,587 1 Mg/L lbs/d Demand (COD)c. Total Organic Carbon ND 1 (TOC) NDO1 d. Total Suspended Solids (TSS) 26 143,852 1 mg/L lbs/de. Ammonia (as N) ND 1 VALUE VALUE VALUE VALUE f. Flow 663 1 MGPD g. Temperature VALUE VALUE VALUE C VALUE (winter) "I h. Temperature (summer)VALUE VALUE VALUE 1 VALUE 1. pH MINIMUM MAXIMUM {MINIMUM MAXIMUM 1 STANDARD UNITS PART B -Mark "X" in column 2-a for each pollutant you know or have reason to believe is present. Mark "X" in column 2-b for each pollutant you believe to be absent. If you mark column 2a for any pollutant which is limited either directly, or indirectly but expressly, in an effluent limitations guideline, you must provide the results of at least one analysis for that pollutant. For other pollutants for which you mark column 2a, you must provide r.,~ntit~tio da~ta.,. n n~f ther n a~nra in n.ra, dlieh~rno= ,nn tIal, fnr.- ,,,,h ntfallI tha tn, additinnnl and renuiimrnentn

2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AVERAGE AND b. a. MAXIMUM DAILY VALUE (i, available) (if available)

VALUE CAS NO. BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN (1) b. NO. OF (ifavailable)

PRESENT ABSENT CONCENTRATION

12) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION (2) MASS ANALYSES a. Bromide (24959-67-9) 82 453,687 mg/L ibs/d b. Chlorine, Total 3bs/d Residual X0.10* 553.3 ppm c. Color X d. Fecal Coliform X e. Fluoride (16984-48-8)

X f. Nitrate-Nitrite (as N) ND EPA Form 3510-2C (8-90)*as Total Residual Oxidant (TRO)PAGE V-1 Outfall #001-1 CONTINUE ON REVERS ITEM V-B CONTINUED FROM FRONT2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE a. LONG TERM AVRG, VALUE a. LONG TERM AND a. b. a. MAXIMUM DAILY VALUE (if available) (if available)

AVERAGE VALUE CAS NO. BELIEVED BELIEVED (t) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (if available)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES g. Nitrogen, 1 Total Organic (w. ND N) _h. Oil and ND Grease N i. Phosphorus 1 (as P). Total ND (7723-14-0)

.J. Radioactivity (1) Alpha, Total x ND 1 pCi/kg (2) Beta, Total 461 (3) Radium, Total x _ _ _ _(4) Radium 226.Total x/k. Sulfate (SW 2500 1383191C mg/ l bs/d (14808-79-8)

I. Sulfide ND (asS) ND_1 m. Sulfite (as SOj) ND (14265-45-3) x I n. Surfactants x NDo. Aluminum, Total (7429-90-5) x p. Barium, Total (7440-39-3) x q. Boron, Total 1D (7440-42-8)

A ND r. Cobalt, Total ND1 (7440-48-4)

/ _ _ D 1 a. Iron, Total 0 1 mg/L lbs/d (7439-89-6) 0.02 10.71 I. Magnesium.

Total 1200 6369317 mg/L lbs/d ( 7 4 3 9 -9 5 -4 ) ....u. Molybdenum, Total N (7439-98-7) xD 1 v. Manganese, Total 0.01 55.3 1 mg/L ls/d (7439-96-5) x w. Tin, Total (7440-31-5) x x. Titanium, Total (7440-32-6)

EPA Form 3510-2C (8-90)PAGE V-2 Outfall #001-1 CONTINUE ON PAGE V-3 EPA I.D. NUMBER (copyfrom Item I of Form 1) OUTFALL NUMBER NHD081257446 001-1 I CONTINUED FROM PAGE 3 OF FORM 2-C PART C -If you are a primary industry and this outfall contains process wastewater, refer to Table 2c-2 in the instructions to determine which of the GC/MS fractions you must test for. Mark X in cotumn 2-a for a(( such GG/MS fractions that apply to your industry and for ALL toxic metals, cyanides, and total phenols. If you are not required to mark column 2-a (secondary industries, nonprmcess wastewater outfalls, and nonrequired GC/MS fractions), mark *X* in column 2-b for each pollutant you know or have reason to believe is present. Mark "X" in column 2-c for each pollutant you believe is absent. If you mark column 2a for any pollutant, you mus provide the results of at least one analysis for that pollutant.

If you mark column 2b for any pollutant, you must provide the results of at least one analysis for that pollutant if you know or have reason to believe it will be discharged in concentrations of 10 ppb or greater. If you mark column 2b for acrolein, acrylonitrile, 2,4 dinitrophenol, or 2-methyl-4, 6 dinitrophenot, you must provide the results of at least one analysis for each of these pollutants which you know or have reason to believe that youdischarge in concentrations of 100 ppb or greater. Otherwise, for pollutants for which you mark column 2b, you must either submit at least one analysis or briefly describe the reasons the pollutant is expected to be discharged.

Note that there are 7 pages to this part; please review each carefully.

Complete one table (all 7 pages) for each outfall. See instructions for additional details and requirements.

2. MARK X 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND 8. b. C. a. MAXIMUM DAILY VALUE (if available)

VALUE (if available AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED

((1) 1 d. NO. OF a. CONCEN- (1) b. NO. OF (i[available)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRMTRATION (2) MASS CANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE METALS, CYANIDE, AND TOTAL PHENOLS IM. Antimony, Total 1 (7440-36-0)

.ND 1 2M. Arsenic, Total (7440-38-2)

X___ ND______ I_______________

3M. Berytliu m. Total N (7440-41-7)

ND 1 4M. Cadmium, Total 1 (7440-43-9) 1 SM. Chromium, 1 Total (7440-47-3)

Xid 1 6M. Copper, Total xND (7440-50-8)

ND 1 7M. Lead, Total ND (7439-92-1) 1 8M. Mercury, Total XD (7439-97-6)

N 9M. Nickel. Total ND 1 (7440-02-0)

X 10M. Selenium, 1 Total (7782-49-2)

ND 1 11M. Silver, Total ND (7440-22-4)

ND 1 12M. Thallium, Total (7440-28-0)

X ND 1 13M. Zinc, Total (7440-66-6) 0.04 221.3 1 mg/L ibs/d 14M. Cyanide,Total (57-12-5)

X ND 1 15M. Phenols, ND Total ND 1 DIOXIN 2,3,7,8-Tetra-X DESCRIBE RESULTS chlorodibenzo-P-y Dioxin (1764-01-6)EPA Form 3510-2C (8-90)

PAGE V-3 Outfall #001-1 CONTINUE ON REVERSE CONTINUED FROM THE FRONT 2. MARK "X" 3. EFFLUENT 1 4. UNITS 1 5. INTAKE (ornio.al)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a. LONG TERM AND a. b. c. a MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED S ED LIEV()()d.

NO. OF a. CONCEN- I (1) b. NO. OF (i(available)

REQUIRED PRESENT ABSENT CONCENTRATION (21 MASS CONCENTRATION (2) MASS CONCENTRATI ON (2)MASS ANALYSES TRATION

b. MASS CONCENTRATON (2) MASS ANALYSE_GC/MS FRACTION -VOLATILE COMPOUNDS 1V. Accrolein (107-02-8)

ND 1 2V. Acrylonilfile (107-13-1)

ND 1 3V. Benzene (71-43-2) x ND 1 4V. Bis (Chloro-meihyl) Ether ND 1 (542-88-1) 5V. Bromoform 26 143852 1 (75-25-2) x OV. Carbon Tetrachloride ND 1 (W623-5)x 7V. Chlorobenzene D (108-90-7)

ND1 8V. Chlorodi-bromomethane ND 1 (124-48-1) 9V. Chloroethane D (75-00-3) " ND 1 10V. 2-Chloro-ethylvinyl Ether > ND 1 (110-75-8) x I1 V. Chloroform N (67-66-3)

-ND 12V. Dichloro-bromomethane X ND 1 (75-27-4)13V. Dichloro-difluoromethane ND 1 (75-71-8) x I 14V. 1,t-Dichloro-ND ethane (75-34-3 D 15V. 1,2-Dichloro-N ethane (107-06-2)

Ix 1 16V. 1.1-Dichloro-1 ethylene (75-35-4)

ND1 17V. 1,2-Dichloro-N propane (78-87-5)

N1 18V. 1,3-Dichloro-propylene ND 1 (542-75-6) x 19V. Ethylbenzene NO (100-41-4)

ND 1 20V. Methyl 1 Bromide (74-83-9)

ND 21V. Methyl iND 1 Chloride (74-87-3)

NEPA Form 3510-2C (8-90)PAGE V-4 Outfall #001-1 CONTINUE ON PAGE V-5 CONTINUED FROM PAGE V-4 2. MARK X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT I [b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG: a. LONG TERM AND a. b c. a. MAXIMUM DAILY VALUE (i[available)

VALUE (i[available)

AVERAGE VALUE CAS NUMBER TESTING IBELIEVED BELIEVED (1 1 1 Id'O Fa. LONCErN- 1) b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b MASS CONCENTRATION 1(2) MASS ANALYSE GC/MS FRACTION -VOLATILE COMPOUNDS (continued) 22V. Methylene ND Chloride (75-09-2)

N 23V. 1.1,2,2-Tetrachloroethane ND (79-34-5)24V. Tetrachloro-N ethylene (127-18-4) 1 25V. Toluene N (108-88-3)

NU I 26V. 1,2-Trans-Dichloroethylene X ND 1 (156-60-5)

........27V. 1t1,1-Tdchforo-ND ethane (71-55-6) x 1 28V. 1,1.2-Trichloro-XND ethane (79-00-5)

ND 1 29V Tdchloro-1 ethylene (79-0176)

\D_1 30V. Trichloro-fluoromethane ND 1 (75-69-4)31V. Vinyl Chloride ND (75-01-4)

ND GC/MS FRACTION -ACID COMPOUNDS 1A. 2-Chlorophenol ND (95-57.8).

-___ _______2A. 2,4-Dichloro-N phenol (120-83-2)

ND 1 3A. 2,4-Dimethyl-ND phenol (105-67-9)

ND 1 4A. 4.6-Dlnitro-O-N Cresol (534-52-1)

ND 1 5A. 2.4-Dinitro-ND phenol (51-28-5)

ND 1 6A. 2-Nitrophenol ND (88-75-5)1 7A. 4(-0Nrophenol ND 1 (100.-02-7)

A.4-t 8A. P-Chloro-M-NCresol (59-50-7)

ND 1 9A. Pentachloro-1 phenol (87-86-5) x I 10A. Phenol ND (108-95-2) xD 1 11A. 2,4,6-Tnchloro-ND phenol (88M05-2) x _ 1 EPA Form 3510-2C (8-90)PAGE V-5 Outfall #001-1 CONTINUE ON REVERSE CONTINUED FROM THE FRONT 2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (oplional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavdilablej VALUE (ifavailable)

AVERAGE VALUE (if U E aTiab e ESTING B LEED BELIENT A VENT (OCE T AT) (1) .(1) d. NO .O F a. C O NC E N -(1) b. NO .O F (ANavailable)

REQUIRED PRESENT ABSENT (1)NTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GCIMS FRACTION -BASEINEUTRAL COMPOUNDS IB. Acenaphthene 1 (83-32-9) x ND 1 28. Acenaphtylene (208-96-8) x ND 1 3B. Anthracene N (120-12-7) x ND 1 4B. Benzidine 1 (92-87-5)

ND 5B. Benzo (a)Anthracene XND (56-55-3)

NO 6B. Benzo (a)Pyrene (50-32-8) x ND 78. 3,4-Benzo-fluoranthene ND 1 (205-99-2) x 8B. Benzo (ghi) N Perylene (191-24-2)

ND 9B. Benzo (k)Fluoranthene ND 1 (207-08-9) 10B. Bis (2-Chloro-ethoxy) Methane \/ND (111-91-1) x 118. Bis (2-Chto, ethyl) Ether ND (111-44-4) 128. Bis (2.Chloroisopropyi)

X ND 1 Ether (102-80-1)

.ND 13B. Bis (2-Ethyl-hexyl) Phthalate ND 1 (117-81-7) x 14B. 4-Bromophenyl Phenyl Ether \ ND 1 (101-55-3) x 15B. Butyl Benzyl N Phthalate (85-68-7) x 16B. 2-Chloro-naphthalene ND 1 (91-58-7)178. 4-Chloro-phenyl Phenyl Ether ND 1 (7005-72-3) x 188. Chrysene N/(218-01-9) x ND 198. Dibenzo (a,h)Anthracene X ND20B. 1,2-Dichloro-benzene (95-50-1)

ND 1 21B. 1,3-Di-chloro-1T benzene (541-73-1) x 1 EPA Form 3510-2C (8-90)PAGE V-6 Outfall #001-1 CONTINUE ON PAGE V-7 CONTINUED FROM PAGE V-6 2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (if[avilable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1)AIO 1()MS (1) (1) ) .N.O a. OCN (1)b N.F (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATON (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued)22B. 1,4-Dichloro-3.benzene (106-46-7) x ND 23B. 3,3-Dichloro-N benzldine (91-94-1)

ND .24B. Diethyl N Phthalate (84-66-2)

ND 258. Dimethyl Phthalate IND (131 3) N 26B. Di-N-ButyI ND Phthalate (84-74-2)

ND 27B. 2,4-Dinitro-I toluene (121-14-2)

ND .28B. 2,6-Dinitro-ND toluene (606-20-2)

ND 29B. Di-N-Octyl N1 Phthalate (117-84-0)

ND 30B. 1,2-Diphenyl-hydrazlne (as Azo- N benzene) (122-66-7)

.NDx 31B. Fluoranthene N (206-44-0)

ND 1 32B. Fluorene ND 1 (86-73-7) xD 1 33B. Hexachloro-ND benzene (118-74-1)

ND 34B. Hexachl0tro-ND butadiene (87-68-3) f_)_1350. Hexachloro-cyclopentadiene ND 1 (77-47-4) x 36B Hexachloro-ND ethane (67-72-1)

ND 1 37B. Indeno (1,2.3-cd)

Pyrene ND (193-39-5)

/38B. Isophorone N (78-59-1) 1 398. Naphthalene 1 (91-20-3)

-ND 1 40B. Nitrobenzene ND (98-95-3)

_D 1 418. N-Nitro-sodimethytamine ND (62-75-9), 42B. N-Nitrosodi-N-Propylamlne ND (621-64-7)

N 1 EPA Form 3510-2C (8-90)PAGE V-7 Outfall #001-1 CONTINUE ON REVERSE CONTINUED FROM THE FRONT 2. MARK "X" 3. EFFLUENT

4. UNITS 5. INTAKE (oplional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a. LONG TERM ANDa b. c. a. MAXIMUM DAILY VALUE (if aailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (i[available)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATON (2)MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 43B. N-Nitro-sodiphenylamine

> ND 1 (86-30-6)44B. Phenanthrene

\(85-01-8)-

ND 1 45B. Pyrene (129-00-0) x ND 1 46B. 1,2.4-Tri-chlorobenzene ND (120-82-1) xD 1 GC/MS FRACTION -PESTICIDES 1 P. Aldrin (309-00-2) x 2P. I3-BHC (319-84-6) a x 3P. P-BHC (319-85-7) x 4P. y-BHC (58-89-9) x 5P. 8-BHC (319-86-8) x 6P. Chlordane X (57-74-9) x 7P. 4,4'-DDT (50-29-3) x 8P. 4,4'-DDE (72-55-9) x 9P. 4,4'-DDD (72-54-8) x loP. Dieldrin (60-57-1) x II P. a-Enosulfan (115-29-7) x 12P. fI-Endosulfan (115-29-7) x _13P. Endosulfan Sulfate (1031-07-8) x 14P. Endrin (72-20-8)

__15P. Endrin Aldehyde (7421-93-4)

____16P. Heptachlor (76-44-8)

_EPA Form 3510-2C (8-90)

PAGE V-8 CONTINUE ON PAGE V-9 Outfall #001-1 EPA I.D. NUMBER (copyfrom Item I of Forn 1) OUTFALL NUMBER NHD081257446 001-1 CONTINUED FROM PAGE V-8 2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optcrna/1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavoilable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) [)(1) d. NO. OF a. CONCEN-

b. NO. OF (ifavailable)

REURDPESN BETCOCN)TO (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TTIN b. MASS COCNRAIN(2 A) NLS GC/MS FRACTION -PESTICIDES (continued)17P. Heptachlor Epoxida (1024-57-3) x18P. PCB-1242 (53469-21-9) x 19P. PCB-1254 (11097-69-1) x 20P. PCB-1221 (11104-28-2) x__21P. PCB-1232 (11141-16-5) x 22P. PCB-1248 (12672-29-6) x 23P. PCB-1260 (11096-82-5) x 24P. PC8-1016 (12674-11-2) x 25P. Toxaphene (8001-35-2) xEPA Form 3510-2C (8-90)PAGE V-9 Outfall #001-1 PLEASE PRINT OR TYPE IN THE UNSHADED AREAS ONLY. You may report some or all of this information EPA I.D. NUMBER (copy from Item I of Form 1)on separate sheets (use the same format) instead of completing these pages. NHDO 81257446 SEE INSTRUCTIONS.

V. INTAKE AND EFFLUENT CHARACTERISTICS (continued from page 3 of Form 2-C)OUTFALL NO.022 PART A -You must provide the results of at least one analysis for every pollutant in this table. Complete one table for each outfall. See instructions for additional details.3. UNITS 4. INTAKE2. EFFLUENT (specify i(blank) (optional)

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

VALUE a. LONG TERM a. MAXIMUM DAILY VALUE (ifavailable) (f available)

AVERAGE VALUE (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF 1. POLLUTANT CONCENTRATION (2)

MASS CONCENTRATION (2) MASS (1) CONCENTRATION (2)

MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES a. Biochemical Oxygen Demand (BOD) 12 2.1 mg/L ,bs/d b. Chemical Oxygen 24 4.1 1 Mg/L lbs/d Demand (COD)c. Total Organic Carbon (TOC) 9.2 1.6 1 mg/L ibs/dd. Total Suspended Solids (TSS) ND e. Ammonia (as N) 130 22.4 1 mg/L lbs/d VALUE VALUE VALUE VALUE f. Flow 20,610 1 GPD g. Temperature VALUE VALUE VALUE VALUE (winter)h. Temperature VALUE VALUE VALUE VALUE (summer) 27 1 MINIMUM MAXIMUM MINIMUM MAXIMUM SADR NT i. pH 9.99STANDARD UNITS PART B- Mark "X" in column 2-a for each pollutant you know or have reason to believe is present. Mark "X* in column 2-b for each pollutant you believe to be absent. If you mark column 2a for any pollutant which is limited either directly, or indirectly but expressly, in an effluent limitations guideline, you must provide the results of at least one analysis for that pollutant.

For other pollutants for which you mark column 2a, you must provide quantitative data or an explanation of their presence in your discharge.

Complete one table for each outfall. See the instructions for additional details and requirements.

2. MARK X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. pOLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AVERAGE AND a. b. a. MAXIMUM DAILY VALUE (ifavailable) (ifavailable)

VALUE GAS NO. BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES a. Bromide ND (24959-67-9)

X ND b. Chlorine, Total Residual X c. Color X "_'d. Fecal Coliform X e. Fluoride (16984-48-8)

X f. Nitrate-Nitrite ND (asr ND ___ ___EPA Form 3510-2C (8-90)PAGE V-1 Outfall #022 CONTINUE ON REVERS ITEM V-B CONTINUED FROM FRONT

2. MARK "X 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

VALUE a. LONG TERM AND a. b. a. MAXIMUM DAILY VALUE (ilfavailable) (i( available)

AVERAGE VALUE CAS NO. BELIEVED BELIEVED (I) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF f(iavailable)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES g. Nitrogen, \Total Organic (as ND 1 N) ___ __ _________h Oil and 1 Grease ND 3 I. Phosphorus (as P), Total > ND 1 (7723-14-0) x j. Radioactivity (1) Alpha. Total x ND 1 pCi/kg (2) Beta, Total x ND 1 pCi/kg (3) Radium, Total x (4) Radium 226, Total x k. Sulfate 460 79.1 1 mg/i lbs/d (f14808-79-8)

I. Sulfide N1 (asS) _ _ 1 m. Sulfite (W' SO,)(14265-45-3) x n. Surfactants x 0.062 0.01 1 mg/1 lbs/do. Aluminum, Total (7429-90-5) x p. Barium, Total (7440-39-3) x q. Boron, Total (7440-42-8) x r, Cobalt, Total (7440-48-4) x s. Iron, Total (7439-89")

0.02 <0.01 1 mg/L lbs/d 1. Magnesium.

Total X ND 1 (7439-95-4)

/u. Molybdenum, Total V 1 (7439-98-7)

'v. Manganese, Total X ND (7439-96-5)

N w. Tin, Total (7440-31-5) x I -A x. Titanium.Total (7440-32-6)x EPA Form 3510-2C (8-90)PAGE V-2 Outfall 4022 CONTINUE ON PAGE V-3 EPA I.D. NUMBER (copy from Item I of Fomn I) OUTFALL NUMBER NHDO81257446 022CONTINUED FROM PAGE 3 OF FORM 2-C PART C -If you are a primary industry and this outfall contains process wastewater, refer to Table 2c-2 in the instructions to determine which of the GC/MS fractions you must lest for. Mark 'X" in column 2-a for all such GC/MS fractions that apply to your industry and for ALL toxic metals, cyanides, and total phenols. If you are not required to mark column 2-a (secondary industries, nonprocess wastewater outfales, and nonrequired GC/MS fractions), mark "X" in column 2-b for each pollutant you know or have reason to believe is present. Mark *X" in column 2-c for each pollutant you believe is absent. If you mark column 2a for any pollutant, you mus provide the results of at least one analysis for that pollutant.

If you mark column 2b for any pollutant, you must provide the results of at least one analysis for that pollutant if you know or have reason to believe it will be discharged in concentrations of 10 ppb or greater. If you mark column 2b for acrolein, acrylonitrile, 2,4 dinitrophenol, or 2-methyl-4, 6 dinitrophenol, you must provide the results of at least one analysis for each of these pollutants which you know or have reason to believe that you discharge in concentrations of 100 ppb or greater. Otherwise, for pollutants for which you mark column 2b, you must either submit at least one analysis or briefly describe the reasons the pollutant is expected to be discharged.

Note that there are 7 pages to this part; please review each carefully.

Complete one table (all 7 pages) for each outfall. See instructions for additional details and requirements.

2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (oplional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND : a. b. c. a. MAXIMUM DAILY VALUE (if available)

VALUE (i]favailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (t) (1) () Id. NO. OF a. CONCEN- (t) b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2)

MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE METALS, CYANIDE, AND TOTAL PHENOLS 1M. Antimony, Total ND 1 (7440-36-0)

X I 2M. Arsenic, Total ND 1 (7440-38-2)

ND 3M. Beryllium, Total 1 (7440-41-7)

_ _ _ _4M. Cadmium, Total 1 (7440-43-9)_ND I I 5M. Chromium, 1 Total (7440-47-3)

ND 6M. Copper, Total ND 1 (7440-50-8) _ _ ND_1 7M. Lead, Total 1 mg/L lbs/d (7439-92-1)0.004

<0.01m 8M. Mercury, Total (7439-97-6) oND 1 9M. Nickel, Total ND 1 (7440-02-0)

__ __iOM. Selenium, ND 1 Total (7782-49-2)

NO 11M. Silver, Total ND 1 (7440-22-4)

X ND 12M. Thallium, Total (7440-28-0)

XD 13M. Zinc, Total 0.03 0.01 1 mg/L lbs/d (7440-66-6)

_. 0.03 0.01 1 mg/L ibs/d 14M. Cyanide, D1 Total (57-12-5) , _ N_ 1 15M. Phenols, 1 Total ND DIOXIN 2.3'7,8-Tetra-

-/ DESCRIBE RESULTS chlorodibenzo-P-X ,Dioxin (1764-01-6)EPA Form 3510-2C (8-90)PAGE V-3 Outfall #022 CONTINUE ON REVERSE CONTINUED FROM THE FRONT 2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (if'available)

VALUE (i[available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1)(11) .(1) d. NO. OF a. CONCEN- (1)Ab. NO. OF (i[available)

REQUIRED PRESENT ABSENT CONCENTRATIONCE2)RATION ONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -VOLATILE COMPOUNDS IV. Accrolein D1 (107-02-8)1 ND 1 2V. Acrylonitile

\/(107-13-1) x 0.230 0.04 1 mg/L lbs/d 3V. Benzene (71-43-2)

ND 1 4V. Bis (Chloro-methyl) Ether ND 1 (542-88-1) x 5V. Bromoform (75-25-2) x ND I 6V. Carbon Tetrachlonde ND 1 (56-23-5) x TV. Chlorobenzene N (108-90-7)

ND 1 8V. Chlorodi-bromomethane ND 1 (124-48-1) x 9V. Chloroethane N (75-00-3)

ND 1 1OV. 2-Chloro-ethylvinyl Ether ND 1 (110-75-8) x ND 3.1 lV. Chloroform

\/(67-66-3) , ND 1 12V. Dichloro-bromomethane ND 1 (75-27-4) xN 13V. Dichloro-difluoromethane ND 1 (75-71-8)14V. 1,1-Dichloro-ND 1 ethane (75-34-3)

ND 1 15V. 1,2-Dlchloro-ND 1 ethane (107-06-2)

ND 1 16V. 1,1-Dichloro-1 ethylene (75-35-4)

ND 1 17V. 1,2-Dichloro-ND propane (78-87-5)

ND 1 18V. 1,3-Dichloro-propylene ND 1 (542-75-6) x I 19V. Ethylbenzene ND (100-41-4)

Nx 1 20V. Methy 1 Bromide (74-83-9)

.ND 21V. Methyl 1 Chloride (74-87-3)

ND EPA Form 3510-2C (8-90)PAGE V-4 Outfall #022 CONTINUE ON PAGE V-5 CONTINUED FROM PAGE V-4 2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (oplional)

1. POLLUTANT 1 b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. C. a. MAXIMUM DAILY VALUE (i(available)

VALUE Qfavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED ()(1)] (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2)

MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b MASS CONCENTRATION 121 MASS ANALYSE GCJMS FRACTION -VOLATILE COMPOUNDS (continued) 22V. Methylene N Chloride (75-09-2)

ND 23V. 1.1,2.2-Tetrachloroethane ND (79-34-5)24V. Telrachloro-x ND ethylene (127-18-4)

ND 1 25V. Toluene D (108-88-3)

ND1 26V. 1.2-Trans-Dichloroethylene ND 1 (156-60-5) 27V. 1.1,1-Trichloro-XND1 ethane (71-55-6)

ND 1 28V. 1,1,2-Tdchloro-ND ethane (79-00-5)

.ND 1 29V Trichloro-x ethylene (79-01-6)

ND 1 30V. Trichloro-fluoromethane ND 1 (75-69-4)31V. Vinyl Chloride ND (75-01-4)

ND GC/MS FRACTION -ACID COMPOUNDS IA. 2-Chlorophenol N (95-57-8)

ND 1 2A. 2.4-Dichloro-N phenol (120-83-2)

ND 1 3A. 2,4-Dimethyl.

1 phenol (105-67-9)

ND 4A. 4,6-Dinitro-O-1 Cresol (534-52-1)

ND 5A. 2.4-Dinitro-ND phenol (51-28-5) , ND 1 6A. 2-Nitrophenol ND (88-75-5)

ND 1 7A. 4-Nitrophenol ND (100-02-7)

ND 1 8A. P-Chloro-M-N Cresol (59-50-7)

ND 1 9A. Pentachloro-ND phenol (87-86-5)

_D 1 IOA. Phenol ND (10B-95-2) x_ 1 11A. 2,4,6-Trichloro-ND1 phenol (88-05-2)

'ND 1 I EPA Form 3510-2C (8-90)PAGE V-5 Outfall #022 CONTINUE ON REVERSE CONTINUED FROM THE FRONT 1 2. MARK "X'3. EFFLUENT 1 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE

c. LONG TERM AVRG.

a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifMavilable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED ( I d. NO. OF a. CONCEN- J)b. NO. OF (i[available)

REQUIRED PRESENT ABSENT CONCENTRATION

12) MASS CONCENTRATION (2) MASS CONCENTRATION1 (2) MASS ANALYSES TRATION b.MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS 1B. Acenaphthene NO (83-32-9)

.28. Acenaphtylene (208-96-8)

_ NO 1 3B. Anthracene

\/(120-12-7)

ND 1 4B. Benzidine N (92-87-5)

ND 1 5B. Benzo (a)Anthracene XN (56-55-3)

ND .i 6B. Benzo (a) N Pyrene (50-32-8) xND 1 7B. 3,4-Benzo-fluoranthene ND (205-99-2)

I 8B. Benzo (ghi) NO Perylene (191-24-2)

ND 1 9B. Benzo (k)Fluoranthene XND (207-08-9)

ND 10B. Bis (2-Chloro-ethoxy) Methane ND (111-91-1))

ND 1 11B. Sis (2-Chloro-(111-44-4) x ND 1 128. Bis (2-Chloroisopropyl)

ND 1 Ether (102-80-1) x 138. Bis (2-Ethyl-heýyl) Phthatete IND (117-81-7)

N 148. 4-Bromophenyl Phenyl Ether ND (101-55-3) 1 158. Butyl Benzyl 1 Phthalate (85-68-7)

ND 168. 2-Chloro-naphthalene ND 1 (91-511-7) 17B. 4-Chloro-phenyl Phenyl Ether xN1 (7005-72-3) 18B. Chrysene N (218-01-9) x ND 19B. Dibenzo (ah)Anthracene ND (53-70-3)

N 208. 1,2-Dlchloro-1D benzene (95-50-1)

ND 218.1,3-Di-chloro-ND benzene (541-73-1)

ND _EPA Form 3510-2C (8-90)PAGE V-6 Outfall #022 CONTINUE ON PAGE V-7 CONTINUED FROM PAGE V-6 2. MARK "X 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED j)() [ 1[d. NO. OF a. CONCEN- (11 b. NO. OF (ifavilable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION 121 MASS ANALYSE GCIMS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 22B. 1,4-Dichloro.

N benzene (106-46-7)

N 23B, 3,3-Dichloro-

' 1 benzidlne (91-94-1)

ND 1 24B. Diethyl ND Phthalate (84-66-2)

ND 125B. Dimethyl Phthalate ND 1 (131 3) x 26B. DI-N-Butyl 1 Phthalate (84-74-2)

ND 27B. 2,4-Dinitro-1 toluene (121-14-2)

ND28B. 2,6-Dinitro-N toluene (606-20-2)

ND 1 298. DI-N-Octyl 1 Phthalate (117-84-0)

ND 308. 1,2-Diphenyl-hydrazine (as Azo. N1 benzene) (122-66-7)

ND)31B. Fluoranthene (206-44-0)

ND 1 32B. Fluorene .(86-73-7)

ND 1 33B. Hexachloro-N benzene (118-74-1)

ND 1 34B. Hexachloro-ND butadiene (87-68-3)

ND\35B. Hexachloro-cyclopentadlene ND 1 (77-47-4) x .I 368 Hexachloro-1 ethane (67-72-1)

ND 37B. Indeno (1,2.3-cd)

Pyrene ' ND 1 (193-39-5) x 38B. Isophorone ND (78-59-1)

ND 1 39B. Naphthalene ND (91-20-3)

ND 1 40B. Nitrobenzene ND (98-95-3)

ND 1 41B. N-Nitro-sodimethylamine eND (62-75-9)42B. N-Nitrosodi-N-Propylamine N ,(621-6-7)

NDEPA Form 3510-2C (8-90)

PAGE V-7 CONTINUE ON REVERSE Outfall #022 CONTINUED FROM THE FRONT2. MARK X" 3. EFFLUENT 4. UNITS 5. INTAKE (oplional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c LONG TERM AVRG. a. LONG TERM AND a. b. C. a. MAXIMUM DAILY VALUE (ifavwilable)

VALUE (i~favailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCEMASS TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (coininued) 438. N-Nitro-sodiphenylamine X ND 1 (86-30-6)44B. Phenanthrene ND (85-01-8) 1 45B. Pyrene ND (129-00-0) ,D 1 46B. 1,2,4-Tri-chlorobenzene ND (120-82-1)

ND 1 I GC/MS FRACTION -PESTICIDES 1P. Aldrin (309-00-2) x 2P. a-BHC X (319-84-6) x 3P. P-BHC (319-85-7) x 4P. y-BHC (58-89-9) x 5P. a-BHC (319-86-8) x 6P. Chlordane X (57-74-9) x 7P. 4,4'-DDT (50-29-3) x 8P. 4,4'-DDE (72-55-9) x 9P. 4,4'-DDD (72-54-8) x 10P. Dieldrin (60-57-1) x 111P. a-Enosulfan x (115-29-7)

/_________

12P. (1-Endosulfan (115-29-7) x 13P. Endosulfan Sulfate (1031-07-8) x14P. Enddn (72-20-8) x 15P. Endrin Aldehyde (7421-93-4) x 16P. Heptachlor (76-44-8) 1 .1 x IEPA Form 3510-2C (8-90)PAGE V-8 Outfall #022 CONTINUE ON PAGE V-9 EPA I.D. NUMBER (copyfr-om Item I of Form 1) OUTFALL NUMBER NHD081257446 022 CONTINUED FROM PAGE V-8 I 7 -T -1 2. MARK "X" 3. EFFLUENT 4. UNITS 1 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (if available)

VALUE (ifavailable)

AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED (1) f (1) 1 (1) d. NO. OF a. CONCEN- (1) ,b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATIONI 1[2) MASS CONCENTRATIONJ (2} MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION

12) MASS ANALYSE GCIMS FRACTION -PESTICIDES (continued) 17P. Heplachlor Epoxide (1024-57-3)

_______________

__________

_____18P. PCB-1242 (53469-21-9)

________________

19P. PCB-1254 (11097-69-1)

_______________________20P. PCB-1221 (1110G4-28-2) x_______________________

_____________

__________

21P. PCB-1232 (11141 -1 6-5) x_________________

22P. PCB-1 248 (12672-29-6) x____23P. PCB-1 260 (11096-82-5) 24P. PCB-1 01 6 (12674-11-2) x_____ _25P. Toxaphene (800_-35-2 x _ _ _ _ _

_ _ _ _ _ _ _ _ _ _EPA Form 3510-2C (8-90)PAGE V-9 Outfall #022 PLEASE PRINT OR TYPE IN THE UNSHADED AREAS ONLY. You may report some or all of this information EPA I.D. NUMBER (copyfrom Item I of Form 1)on separate sheets (use the same format) instead of completing these pages. NHDO 81257446 SEE INSTRUCTIONS.

V. INTAKE AND EFFLUENT CHARACTERISTICS (continued from page 3 of Form 2-C)OUTFALL NO.023 PART A -You must provide the results of at least one analysis for every pollutant in this table. Complete one table for each outfall. See Instructions for additional details.3. UNITS 4. INTAKE 2. EFFLUENT (specify ifblank) (optional)

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM a. MAXIMUM DAILY VALUE (if available) (ifav'ilable)

NO. OF AVERAGE VALUE b. NO. OF (1) (1) (1)1. POLLUTANT CONCENTRATION (2) MASS CONCENTRATION (21 MASS (1) CONCENTRATION (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION (2)

MASS ANALYSES a. Biochemical Oxygen 2.1 0.02 1 mg/L lbs/d Demand (BOD) 2._.2m/_ b_b. Chemical Oxygen ND Demand (COD)c. Total Organic Carbon (TOC) ND 1 d. Total Suspended Solids (M3) 1.0 1 mg/L lbs/d e. Ammonia (as N) ND 1 VALUE VALUE VALUE VALUE f. Flow 1096 1 GPD g. Temperature VALUE VALUE VALUE VALUE (winter) "C h. Temperature VALUE VALUE VALUE VALUE (summer) 23 1.MINIMUM MAXIMUM MINIMUM MAXIMUM i. pH 9.1 9.1 1 STANDARD UNITS PART B -Mark "X" in column 2-a for each pollutant you know or have reason to believe is present. Mark "X" in column 2-b for each pollutant you believe to be absent. If you mark column 2a for any pollutant which is limited either directly, or Indirectly but expressly, In an effluent limitations guideline, you must provide the results of at least one analysis for that pollutant.

For other pollutants for which you mark column 2a, you must provide quantitative data or an explanation of their presence in your discharge.

Complete one table for each outfall. See the instructions for additional details and requirements.

2. MARK "X7 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AVERAGE AND a. b. a. MAXIMUM DAILY VALUE (if.available) (ifavailable)

VALUE CAS NO- BELIEVED BELIEVED (1)d. NO. OF a. CONCEN- b. NO. OF (if available)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES a. Bromide (24959-67-9)

X b. Chlorine, Total Residual x _c. Color X d. Fecal Coliform X e. Fluoride (16984-48-8)

X f. Nitrate-Nitbite ND (as N) NDEPA Form 3510-2C (8-90)PAGE V-1 Outfall #023 CONTINUE ON REVERS ITEM V-B CONTINUED FROM FRONT2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE C. LONG TERM AVRG. VALUE a. LONG TERM AND a. b. a. MAXIMUM DAILY VALUE (if vailable) (ifavailable)

AVERAGE VALUE CAS NO. BELIEVED BELIEVED I1) I1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES g. Nitrogen, 1 Total Organic (as ND 1 N) _h. Oil and 1D Grease 1 i. Phosphorus 1 (as P), Total 0.067 <0.01 1 mg/L ibs/d (7723-14-0) x J. Radioactivity (1) Alpha, Total x ND 1 pCi/kg (2) Beta, Total 43.80 1 pci/kg (3) Radium, Total x (4) Radium 226, Total A k. Sulfate X 15 0.14 1 mg/i lbs/d (14808-79-8) " .9 I. Sulfide ND (as S) ND_1 m. Sulfite (w' SO,)(14265-45-3)

n. Surfactants x o. Aluminum, Total (7429-90-5) x p. Barium, Total (7440-39-3) x q. Boron, Total (7440-42-8)

/x r. Cobalt, Total 17440-48-4)

A s. Iron, Total 00/(7439-89-6)

.0.11 <0.01 1 mg/L ibs/d I Magnesium, Total X 2.3 0.02 1 mg/L lbs/d (7439-95-4)

___u. Molybdenum, Total X 1 (7439-98-7)

v. Manganese, Total ND (7439-96-5)

N w. Tin. Total (7440-31-5)

A x. Titanium, Total (7440-32-6) x EPA Form 3510-2C (8-90)PAGE V-2 Outfall #023 CONTINUE ON PAGE V-3 EPA I.D. NUMBER (copyfrom tem I of Form 1) OUTFALL NUMBER NHD081257446 023 I CONTINUED FROM PAGE 3 OF FORM 2-C PART C -If you are a primary industry and this outfall contains process wastewater.

refer to Table 2c-2 in the instructions to determine which of the GC/MS fractions you must test forc Mark "X" in column 2-a for all such GCIMS fractions that apply to your industry and for ALL toxic metals, cyanides, and total phenols. If you are not required to mark column 2-a (secondary industries, nonprocess wastewater ouffalls, and nonrequired GC/MS fractions), mark "X* in column 2-b for each pollutant you know or have reason to believe is present. Mark "X" in column 2-c for each pollutant you believe Is absent. If you mark column 2a for any pollutant, you mus provide the results of at least one analysis for that pollutant.

If you mark column 2b for any pollutant, you must provide the results of at least one analysis for that pollutant if you know or have reason to believe It wilt be discharged in concentrations of 10 ppb or greater.

If you mark column 2b for acrolein, acrylonitrile, 2.4 dinitrophenol, or 2-methyl-4, 6 dinitrophenol, you must provide the results of at least one analysis for each of these pollutants which you know or have reason to believe that you discharge in concentrations of 100 ppb or greater. Otherwise, for pollutants for which you mark column 2b. you must either submit at least one analysis or briefly describe the masons the pollutant is expected to be discharged.

Note that there are 7 pages to this part; please review each carefully.

Complete one table (all 7 pages) for each outfall. See instructions for additional details and raouirements.

2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE

c. LONG TERM AVRG. a. LONG TERM AND a b c. a. MAXIMUM DAILY VALUE (if available)

VALUE (if I(aailab le) AVERAGE VALUE CAS NUMBER TESTING BELIEVED [BELIEVED 1MA NO. O Ra. CONCEN- b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE METALS, CYANIDE, AND TOTAL PHENOLS 1M. Antimony, Total X ND 1 (7440.36-0) X I 2M. Arsenic. Total ND 1 (7440-38-2)

X 3M. Beryllium, Total N1 (7440-41-7)

X 1 4M. Cadmium, Total XND (7440-43-9)

_D 1 5M. Chromium, ND Total (7440-47-3)

ND 1 6M. Copper. Total 0.004 <0.01 1 mg/L lbs/d (7440-50-8)

0. 004 <0.01 1 mg/_ ibs/d 7M. Lead, Total 1 (7439-92-1)

XD I 8M. Mercury, Total ND (7439-97-6)

X ND 1 9M. Nickel, Total 1 (7440-02-0)

X 1 10M. Selenium, ND Total (7782-49-2)

N 11 M. Silver, Total ND (7440-22-4)

ND_1 12M. Thallium, N Total (7440-28-0)

ND 1 (74 icTotal 0.02 <0.01 1 mg/L lbs/d 14M. Cyanide, Total (57-12-5)

XND 1 15M. Phenols, 00Y Total 0.025 <0.01 1 mg/L ib/d-DIOXIN 2,3,7.8-Tetra-DESCRIBE RESULTS chlorodibenzo-P-X Dioxin (1764-01-6)

EPA Form 3510-2C (8-90)PAGE V-3 CONTINUE ON REVERSE Outfall #023 0 CONTINUED FROM THE FRONT 2. MARK "X 3. EFFLUENT 4. UNITS 5. INTAKE (optional) 1.POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (i/available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED E(1) 1 (1) d. NO. OF a. CONCEN-1)

b. NO. OF (ifavailable)

REQUIREDI PRESENT ABSENT (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) ANALYSE GC/MS FRACTION -VOLATILE COMPOUNDS 1V. Accrolein ND (107-02-8),,_

ND 1 2V. Acrylonitrile N (107-13-1)

ND 1 3V. Benzene N (71-43-2)

ND 1 4V. Bis (Chloro-melhyl) Ether ND 1 (542-88-1)

)5V. Bromoform ND 1 (75-25-2)i 6V. Carbon Tetrachloride ND (56-23-5)7V. Chlorobenzene ND (108-90-7)

ND i 8V. Chlorodi-bromomethane ND 1 (124-48-1)

.x 9V. Chloroethane ND (75-00-3)

ND 1 IOV. 2-Chloro-ethylvinylEther ND (110-75-8) x 11V. Chloroform N/(67-66-3),ND 1 12V. Dichloro-bromomethane ND (75-27-4) x 13V. Dichloro-difuoromethane ND (75-71-8) x I 14V. l.l-Dichloro-ND ethane (75-34-3) 1 15V. 1.2-Dichloro-ND ethane (107-06-2) _ _ i 16V. 1.1-Dichloro-N1 ethylene (75-35-4)

ND 1 17V. 1,2-Dichloro-propane (78-87-5) x ND 18V. 1.3-Dichloro-propyleneaND 1 (542-75-6) 19V. Ethylbenzene ND (100-41-4)

.ND i 20V. Methyl ND Bromide (74-83-9)

ND 21V. Melhyl ND Chloride (74-87-3)

D EPA Form 3510-2C (8-90)PAGE V-4 Outfall 4023CONTINUE ON PAGE V-5 CONTINUED FROM PAGE V-4 2. MARK "X" 3. EFFLUENT 4. UNITS S. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a, b. a. MAXIMUM DAILY VALUE (if available)

VALUE (f available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavrailble)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GCIMS FRACTION -VOLATILE COMPOUNDS (continued) 22V. Methylene 1 Chloride (75-09-2)

ND 23V, 1,1.2,2-Tetrachloroethane ND 1 (79-34-5)24V. Tetrachlor Io- ND ethylene (127-18-4)

ND 25V. Toluene ND (108-88-3)

ND !26V. 1,2-Trans-Dichloroethylene 2 ' ND 1 (156-60-5) x 27V. 1,1,1-Trichloro-ND ethane (71-55-6)

ND 1 28V. l,,2-Thchloro-ethane (79-00-5)

ND 1 29V Trichloro-1 ethylene (79-01-6)

ND 30V. Trichloro-1 fluoromethane ND (75-69-4)31V. Vinyl Chloride ND 1 (75-01-4) x GC/MS FRACTION -ACID COMPOUNDS IA. 2-Chlorophenol ND (95-57-8) 1 2A. 2,4-Dichloro-ND'phenol (120-83-2)

ND 1 3A. 2,4-Dimethyl.

ND phenol (1 05-67-9) f\Nx 4A. 4,6-Dinitro-O-ND Cresol (534-52-1)

ND 1 5A. 2,4-Dinilr-ND phenol (51-28-5)

D\6A. 2-Nitrophenol ND 1 (88-75-5) x 7A. 4-Nitrophenol ND (100-02-7)

______________

BA. P-Chloro-M-ND Cresol (59-50-7) x _T_ _9A. Pentachloro-ND phenol (87-86-5)

ND 1 1 5A. Phenol ND (108-95-2)

_____ _ D_____ 1_________

___11 A. 2.4,6-Trichloro-ND phenol (88-05-2)

ND 1 EPA Form 3510-2C (8-90)PAGE V-5 Outfall #023 CONTINUE ON REVERSE CONTINUED FROM THE FRONT 2. MARK "X" ..._3. EFFLUENT 4. UNITS 5. INTAKE (oplional)

AND a. b. C. a. MAXIMUM DAILY VALUE (if-aailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) 1)(1) d. NO. OF a. CONCEN- (1) b. NO. OF (((available)

REQUIRED PRESENT NABSENT CNCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS18. Acenaphthene (83-32-9) x1 2B. Acenaphtylene (208-96-8) x1 38. Anthracene (120-12-7) x ND 4B. Benzidine (92-87-5) x _ 1 58. Benzo (a)Anthracene ND 1 (56-55-3)6B. Benzo (a) 1 Pyrene (50-32-8)

ND 7B. 3, 4-Benzo-fluoranthene X ND 1 (205-99-2) xN 88. Benzo (ghi) ND Perylene (191-24-2) xND 9B. Benzo (k)Fluoranthene ND (207-08-9) x ND 10B. Bis (2-Chloro-ethoxy) Methane ND I (111-91-1) x 118. Bis (2-Chloro-el/ik) Ether ND 1 (111-44-4) x ND I 128. Bis (2.Chloroisopropyt)

X ND 1 Ether (102-80-1) x 138. Sis (2-Ethyl-Phthalate ND 1 (117-81-7) x _14B. 4-BromophenylPhenyl Ether

'ND.(101-55-3)

N 158. Buty Benzyl a Phthalate (85-68-7)

/N 16B. 2-Chloro-naphthalene ND 1 (91-58-7)178. 4-Chloro-phenyl Phenyt Ether ND 1 (7005-72-3)

/\18B. Chrysene (218-01-9) x ND 1 198. Dibenzo (a.h)Anthracane1 (53-70-3)

X ND 208. 1,2-Dichloro-1 benzene (95-50-1)

..ND 218. 1,3-Di-chloro-benzene (541-73-1)

'x ND 1 EPA Form 3510-2C (8-90)PAGE V-6 Outfall #023 CONTINUE ON PAGE V-7 CONTINUED FROM PAGE V-62. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (i.favailable)

VALUE (if available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) 1)I )d. NO. OF a. CONCEN- b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2)MASS CONCENTRATION (2) MASS C(2( ASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GO/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 22B. 1,4-Dichloro-N benzene (106-46-7)

ND 1 23B. 3,3-Dichloro-x benzidine (91-94-1)

ND 124B. Diethyl N Phthalate (84-66-2)

ND 1 25B. Dlmethyl Phthalate ND (131 3) N I 266. Di-N-Butyl N Phthalate (84-74-2)

ND 127B. 2,4-Dinitro-N toluene (121-14-2)

ND 1 288. 2,6-Dinitro-Ntoluene (606-20-2)

ND 1 29B. Di-N-Octyl N Phthalate (117-84-0)

ND 1 30B. 1.2-Diphenyl-hydrazine (as Azo- 1 benzene) (122-66-7)

ND1 31B. Fluoranthene N (206-44-0)

ND 1 32B. Fluorene ND (86-73-7)

Nx 1 338. Hexachloro-N benzene (118-74-1)

ND 1 34B. Hexachloro-ND1 butadiene (87-68-3)

N__1 358. Hexachloro-cyclopentadiene X ND 1 (77-47-4) x 36B Hexachloro-ND ethane (67-72-1)

N 1 37B. Indeno (1,2,3-cd)

Pyrene XND (193-39-5)

ND 1 38B. Isophorone ND (78-59-1) x 1 39B. Naphthalene ND (91-20-3)

ND 1 40B. Nitrobenzene ND (98-95-3)

_ __1 41B. N-Nitro-sodimethylamine

> ND (62-75-9)42B. N-Nitrosodi-N-Propylamine N (621-64-7)

X NDEPA Form 3510-2C (8-90)PAGE V-7 CONTINUE ON REVERSE Outfall #023 CONTINUED FROM THE FRONT 2. MARK X" 3. EFFLUENT I 4 UNIT1~ I S INJTAKF trntia,,nI(1. POLLUTANT

] b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (((available)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) CI (1) I d. NO. OF a. CONCEN- b. NO. OF (ifavailable)

REQUIRED' PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION (2) MASS ANALYSE GCIMS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 43B. N-Nitro-sodiphenylamine X ND 1 (86-30-6) x 44B. Phenanthrene N (85-01-8)

ND 1 45B. Pyrene ND (129-00-0)

ND 1 46B. 1,2,4-Tri-chlorobenzene N (120-82-1) 1 GC/MS FRACTION -PESTICIDES 1P. Aldnrn (309-00-2) x 2P. a-BHC (319-84-6) 3P. "-HC (319-85-7) 4P. y-BHC (58-89-9) x 5P. -BHC (319-86-8) x 6P. Chlordane (57-74-9) x 7P. 4,4'-DDT (50-29-3) x 8P. 4.4'-DDE (72-55-9) x 9P. 4,4'-DDD (72-54-8) x lOP. Dieldrin (60-57-1) x 11P. a-Enosulfan (115-29-7) x 12P. O-Endosulfan (115-29-7) x 13P. Endosulfan Sulfate (1031-07-8) 14P. Enddn (72-20-8) x 15P. Endrin Aldehyde (7421-93-4) x 16P. Heptachlor X (76-44-8) -f ---tEPA Form 3510-2C (8-90)

PAGE V-8 CONTINUE ON PAGE V-9 Outfall #023 EPA I.D. NUMBER (copy from Item I of Form )) OUTFALL NUMBER NHD081257446 023 CONTINUED FROM PAGE V-8 2. MARK "X" '_3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT 1 lb. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG[ a. LONG TERM a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED ( (1) d. NO. OF a. CONCEN- (11 b. NO. OF ((available)

REQUIRED PRESENT ABSENT CNETRATION(2)M ON MASS (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -PESTICIDES (continued) 17P. Heptachlor Epoxide (1024-57-3) x 18P. PCB-1242 (5346D-21-9) x19P. PCB-1254 (11097-69-1) x 20P. PCB-1221 (11104-28-2) x 21P. PCB-1232 (11141-16-5) x 22P. PCB-1248 (12672-29-6) x 23P. PCB-1260 (11096-82-5)

_24P. PCB-l0i6 (12674-11-2)

_25P. Toxaphene-(801-35-2)

_EPA Form 3510-2C (8-90)PAGE V-9 Outfall #023 l lPLEASE PRINT OR TYPE IN THE UNSHADED AREAS ONLY. You may report some or all of this information EPA I.D. NUMBER (copyfrom Item I offars 1)on separate sheets (use the same format) instead of completing these pages. NHDO81257446 SEE INSTRUCTIONS.

V. INTAKE AND EFFLUENT CHARACTERISTICS (continued from page 3 of Form 2-C)OUTFALL NO.024 PART A -You must provide the results of at least one analysis for every pollutant in this table. Complete one table for each outfall. See instructions for additional details.3. UNITS 4. INTAKE2. EFFLUENT (specify ifblank) (optional)

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM a. MAXIMUM DAILY VALUE (I(available)

(!!available)

AVERAGE VALUE (1) (1) d. NO. OF a. CONCEN- ()b. NO. OF 1. POLLUTANT CONCENTRATION (2) MASS CONCENTRATION (2) MASS (1) CONCENTRATION (2)

MASS ANALYSES TRATION

b. MASS CONCENTRATION

12) MASS ANALYSES a. Biochemical Oxygen 77 0.11 1 mg/L lbs/d Demand (BOD)b. Chemical Oxygen 21 0.03 1 mg/L lbs/d Demand (COD)c. Total Organic Carbon 6.6 0.01 1 mg/L lbs/d (TOC) O,_ 0 1_m/_b/d. Total Suspended Solids (TSS) 2.4 <0.01 1 mg/L lbs/d e. Ammonia (as N) 1.3 <0.01 1 mg/L lbs/d VALUE VALUE VALUE VALUE f. Ftow 164i O g. Temperature VALUE VALUE VALUE VALUE (winter) I h. Temperature VALUE VALUE VALUE VALUE (summer) 20MINIMUM MAXIMUM MINIMUM MAXIMUM L pH 7.4 7.4 1 STANDARD UNITS PART B -Mark X in column 2-a for each pollutant you know or have reason to believe is present. Mark 'X" in column 2-b for each pollutant you believe tobe absent. Ifyou mark column 2a forany pollutant which is limited either directly, or indirectly but expressly, in an effluent limitations guideline, you must provide the results of at least one analysis for that pollutant.

For other pollutants for which you mark column 2a, you must provide quantitative data or an explanation of their presence in your discharge.

Complete one table for each outfall. See the instructions for additional details and requirements.

2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AVERAGE AND a. b. a. MAXIMUM DAILY VALUE (i[available) (i[available)

VALUE CAS NO. BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN (1) b. NO. OF (i[available)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2)

MASS CONCENTRATION (2)

MASS ANALYSES TRATION

b. MASS CONCENTRATION (2) MASS ANALYSES a. Bromide (24959-67-9)

X b. Chlorine, Total ND Residual .A ND1 c. Color X d. Fecal Coliform X e. Fluoride (16984-48-8)

_f. Nitrate-Nitrite (as All __ ___ _ _ _ _ _ _ _ _ ____ _ _ _ _ _ _________

_ _ _ ____EPA Form 3510-2C (8-90)PAGE V-1 Outfall #024 CONTINUE ON REVERS ITEM V-B CONTINUED FROM FRONT 2. MARK X" 3. EFFLUENT

4. UNITS 5. INTAKE (oplional) 1.POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AND a. b. a. MAXIMUM DAILY VALUE (ifavailable) (ifavailable)

AVERAGE VALUE CAS NO. BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2)

MASS CONCENTRATION (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION (2) MASS ANALYSES g. Nitrogen Total Organic ( X ND 1 N)h. Oil and Grease NDI 1 i. Phosphorus 1 (as P), Total 0.094 <0.01 1 Mg/L lbs/d (7723-14-0)

j. Radioactivity (1) Alpha, Total x (2) Beta, Total x (3) Radium, Total x (4) Radium 226, Total x_k. Sulfate (,asSo,)(-O 0 .11 mg/i lbs/d (14808-79-8) 1 I. Sulfide xND (as) _ ND_ 1 m. Sulfite (as SO,)(14265-45-3) x n. Surfactants X o. Aluminum, Total (7429-90-5) x p. Barium, Total (7440-39-3) x q. Boron, Total (7440-42-8) x r. Cobalt, Total (7440-48-4) x .s. Iron, Total (7439-89-6)

.1.3 <0.01 1 mg/L lbs/d L Magnesium, Total X1.1 <0.01 1 mg/L lbs/d (7439-95-4) x u. Molybdenum, Total (7439-98-7) x v. Manganese, Total 1 mg/L lbs/d (7439-96-5) 0 0 w. Tin, Total (7440-31-5)

_x x. Titanium, Total E(740-32-6) ( A EPA Form 3510-2C (8-90)PAGE V-2 CONTINUE ON PAGE V-3 EPA I.D. NUMBER (copyfrom Item I of For. 1) OUTFALL NUMBER NHD081257446 024 CONTINUED FROM PAGE 3 OF FORM 2-C PART C -If you are a primary industry and this outfall contains process wastewater, refer to Table 2c-2 in the instructions to determine which of the GC/MS fractions you must test for. Mark "X" in column 2-a for all such GC/MS fractions that apply to your industry and for ALL toxic metals, cyanides, and total phenols. If you are not required to mark column 2-a (secondary industries, nonprocess wastewater outfalls, and nonrequired GC/MS fractions), mark "X" in column 2-b for each pollutant you know or have reason to believe is present. Mark "X" in column 2-c for each pollutant you believe is absent. If you mark column 2a for any pollutant, you mus provide the results of at least one analysis for that pollutant.

If you mark column 2b for any pollutant, you must provide the results of at least one analysis for that pollutant if you know or have reason to believe it will be discharged in concentrations of 10 ppb or greater. If you mark column 2b for acrolein, acrylonitrile, 2,4 dinilrophenol, or 2-methyl-4, 6 dinitrophenol, you must provide the results of at least one analysis for each of these pollutants which you know or have reason to believe that you discharge in concentrations of 100 ppb or greater. Otherwise, for pollutants for which you mark column 2b, you must either submit at least one analysis or briefly describe the reasons the pollutant is expected to be discharged.

Note that there are 7 pages to this part; please review each carefully.

Complete one table (all 7 pages) for each outfall. See instructions for additional details and renuirements.

2. MARK XX" 3. EFFLUENT 4. UNITS 5, INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- 1) b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT NCENRATION (2) MASS CONCENTRATION (2) MASS CONCENRATION (2) MASS ANALYSES TRATION b, MASS MASS ANALYSE METALS, CYANIDE, AND TOTAL PHENOLS1 M. Antimony, Total N (7440-36-0)

ND 2M. Arsenic, Total \(7440-38-2)

/ ND 1 3M. Beryllium, Total N (7440-41-7)

ND 4M. Cadmium, Total 1 (7440-43-9)

ND _.5M. Chromium, 1 Total (7440-47-3)

ND 6M. Copper, Total (7440-50-8)

X ND 1 7M. Lead, Total (7439-92-1) 0.005 0.01 1 mg/L lbs/d 8M. Mercury, Total (7439-97-6)

X ND 1 9M. Nickel, Total N (7440-02-0)

ND1 10M. Selenium, 1 Total (7782-49-2)

ND 11 M. Silver, Total D (7440-22-4)

ND1 12M. Thallium, N Total (7440-28-0)

ND 1 13M. Zinc, Total 0 (7440-66-6) 0.05 <0.01- 1 mg/L Ibs/d 14M. Cyanide, 1 Total (57-12-5)

ND 15M. P.henols, Total h 0.20 <0.01 1 mg/L lbs/d DIOXIN 2,3,7x8-Tetra-DESCRIBE RESULTS chlorodibenzo-P-Diosin (1764-01-6)

EPA Form 3510-2C (8-90)PAGE V-3 Outfall #024 CONTINUE ON REVERSE CONTINUED FROM THE FRONT2. MARK 'X 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c LONGTERMAVRG.

a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavaailable)

VALUE (ifavailable) j AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED (1) No. (OF.N.O .COCN 1n ()MS NLS (ifavailable) .REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CO(2) M ASR CONCENTRATION (2) MASS(ANALYS GCIMS FRACTION -VOLATILE COMPOUNDS 1V. Accroteln N (107-02-8)

ND 1 2V. Acrylonitnle 1 (107-13-1) x ND 3V. Benzene (71-43-2)

ND 1 4V. Bis (Chiolo-methyl) Ether ND 1 (542-88-1) x 5V. Brornoform (75-25-2)

ND 1 6V. Carbon Tetrachloride ND 1 (56-23-5) x 7V. Chlorobenzene N (108-90-7) x ND 1 8V. Chlorodi-bromomethane ND 1 (124-48-1) 9V. Chloroethane 1 (75-00-3)

_ ND 10V. 2-Chloro-ethylvinyl Ether X ND 1 (110-75-8) x 1 IV. Chloroform

'\/(67-66-3).

5.9 0.01 1 mg/L lbs/d 12V. Dichloro-bromomethane

>" ND 1 (75-27-4) x 13V. Dichloro-difluoromethane ND 1 (75-71-8) x 14V. I,1-Dichloro-N ethane (75-34-3) 1 ND.15V. 1,2-Dichloro-N ethane (107-06-2) x ND 16V. 1,1-Dichloro-x ethylene (75-354) ND 1 17V. 1.2-Dichloro-N propane (78-87-5)

ND 1 18V. 1,3-Dichloro-propyXene ND 1 (542-75-6) 19V. Ethylbenzene ND (100-414)

ND 1 20V. Methyl NBromide (74-83-9)

ND 121V. Methyl Chloride (74-87-3)

NDEPA Form 3510-2C (8-90)PAGE V-4 Outfall #024 CONTINUE ON PAGE V-5 CONTINUED FROM PAGE V-4 2. MARK X_ _ 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND b. a .MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

.AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED 1 ((1) d. NO. OF a. CONCEN- (b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRAMASS CONCEASS CONCENTRATION (2)

MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -VOLATILE COMPOUNDS (continued) 22V. Methylene 1 Chloride (75-09-2) 1 23V. 1,1,2,2-Tetrachloroethane ND 1 179-34-51 24V. Tetrachloro-N ethylene (127-18-4)

ND 1 25V. Toluene x (108-88-3)

_ 1 26V. 1,2-Trans-Dichloroethylene ND 1 (156-60-5) x 27V. 1l,l,-Trichloro-ND ethane (71-55-6) xD 1 28V. 1.1,2-Trichloro-X ethane (79-00-5)29V Trichloro-ethylene (79-01-6) xN 1 30V. Trichioro-fluoromethane ND (75-69-4}x 31V. Vinyl Chloride 1 (75-01-4)

ND GCIMS FRACTION -ACID COMPOUNDS 1A. 2-Chlorophenol ND 1 (95-57-8) x 2A. 2,4-Dichloro-N1 phenol (120-83-2)

ND 3A. 2,4-Dimethyl-1 phenol (105-67-9)

ND 4A. 4,6-Dinitro-O-ND 1 Cresol (534-52-1)

N 5A. 2,4-Dinitro-ND 1 phenol (51-28-5)

N 6A. 2-Nitrophenol ND (88-75-5) _ _ 1 7A. 4-Nitrophenol ND (100-02-7) fD_1 8A. P-Chloro-M-ND Cresol (59-50-7) x1 9A. Pentachloro-ND1 phenol (87-86-5)

ND 1 (108-95-2)A.

Phenol 0.084 <0.01 1 mg/L lbs/d 11 A. 2,4,6-Trichloro-ND phenol (88-05-2)

ND I EPA Form 3510-2C (8-90)PAGE V-5 CONTINUE ON REVERSE Outfall #024 CONTINUED FROM THE FRONT 2. MARK X 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c a. MAXIMUM DAILY VALUE (if available)

VALUE (if available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) (1) I(1) 1d. NO. OF a. CONCEN-()b N.O (((available)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2)

MASS (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS 1B. Acenaphthene

\/(83-32-9) 1D 2B. Acenaphtylene (208-96-8) x ND i 3B. Anthracene (120-12-7)

NDi 4B. Benzidine N (92-87-5)

ND 5B. Benzo (a)Anthracene ND 1 (56-55-3) x 68. Benzo (a)Pyrene (50-32-8)

ND 1 7. 3,4-8enzo-fluoranthene ND (205-99-2)

D 88. 8enzo (ghi) ND Perylene (191-24-2)

ND 1 98. Benzo (k)Fluoranthene ND 1 (207-08-9) x D 108. Bis (2-Chloro-elhay) Methane ND 1 (111-91-1) x 11. Bis (2-Chloro-ehy) Ether ND 1 (111-44-4) 128. Bis (2-Chloroisopropyl)

X ND 1 Ether (102-80.1) l\138. Bis (2-Ethyl-hexyl) Phthalate ND 1 (117-81-7) x_14B. 4-Bromophenyl Phenyl Ether NO (101-55-3)

ND 1 158, Butyl Benzyl ND Phthalate (85-68-7) , ND1 168. 2-Chloro-naphthalene

". ND 1 (91-58-7)17B. 4-Chloro-phenyl Phenyl Ether ND (7005-72-3) x 188. Chrysene ND (218-01-9)

ND 1 19B. Dibenzo (ah)Anthracene ND 1 (53-70-3) x ND 208. 1,2-Dichloro-1 benzene (95-50-1)

ND 218. 1,3-Di-chloro-x benzene (541-73-1)

ND 1EPA Form 3510-2C (8-90)PAGE V-6 Outfall #024 CONTINUE ON PAGE V-7 0 CONTINUED FROM PAGE V-6 2. MARK "X' 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. a. MAXIMUM DAiLY VALUE (if available)

VALUE (Qfavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED jjj ( ( dM NO. OF a. CONCEN- (1) b. NO. OF (if available)

REQUIRED' PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS MATS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 22B. 1,4-Dichloro-N benzene (106-46-7)

ND 1 231. 3,3-Dichloro-N benzldine (91-94-1)

ND 1 24S. Diethyl N Phthalate (84-66.2)

ND 1 25B. Dimethyl Phthalate ND (131 3) ND 1 268. Di-N-Butyl N Phthalate (84-74-2)

ND 1 27B. 2.4-Dinitro-NDtoluene (121.14-2)

ND ' 1 288. 2,6-Dinitro-1 toluene (606-20-2) xND 298. Di-N-Octyl N Phthalate (117-84-0)

ND 130B. 1,2-Diphenyl-hydrazine (as Azo- xND benzene) (122-66-7)

ND 1 31B. Fluoranthene

\(206-44-0)

ND 1 32B. Fluorene N (86-73-7)

ND 1 338. Hexachloro-N benzene (118-74-1)

ND 1 34B. Hexachloro-ND butadiene (87-68-3) f\35B. Hexachloro-cyclopentadiene ND 1 (77-47-4)36B Hexachloro-1 ethane (67-72-1)

ND 378. Indeno (1,2,3-cd)

Pyrene " ND 1 (193-39-5) x 38B. Isophorone N (78-59-1) x ND 398. Naphthalene N (91-20-3)

ND 1 408. Nitrobenzene ND (98-95-3)

ND 1 41B. N-Nitro-sodimethylamlne ND (62-75-9)428. N-Nitrosodl-N-Propylamlne

'. ND (621-64-7) x EPA Form 3510-2C (8-90)PAGE V-7 CONTINUE ON REVERSE Outfall #024 CONTINUED FROM THE FRONT 1 2. MARK X"3. EFFLUENT 1 4. UNITS 1 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavoilable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF.(ifailable)

REQUIRED PRESENT ABSENT CONCENTRATION1 (2)MASS CONCENTRATON (2)MASS CONCENTRATION (2)MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 43B. N-Nilro-sodiphenylamlne ND 1 (86-30-6)

/,_448. Phenanthrene ND (85-01-8)

ND 1 458. Pyrene N (129-00-0)

ND 1 468. 1,2,4-Tri-chlorobenzene ND (120-82-1)

ND 1 GC/MS FRACTION -PESTICIDES IP. Addnin (309-00-2) x 2P. a-BHC (319-84-6) x 3P. 1-BHC (319-85-7) x 4P. y-BHC (58-89-9) x 5P. 6-RHC (319-86-8) x 6P. Chlordane X (57-74-9) x 7P. 4,4'-DODT (50-29-3) x 8P. 4,4'-DDE (72-55-9) x 9P. 4,4'-DDD (72-54-8) x loP. Dieldrin (60-57-1) x IIP. a-Enosulfan (115-29-7) r I x 12P. P-Endosulfan (115-29-7)

_13P. Endosulfan Sulfate (1031-07-8) x 14P. Endfn (72-20-8)

_15P. Enddn Aldehyde (7421-93-4) x16P. Heptachlor (7644-8) xEPA Form 3510-2C (8-90)PAGE V-8 CONTINUE ON PAGE V-9 Outfall #024 EPA I.D. NUMBER (copyfrom Iem I of Form I) OUTFALL NUMBER NHD081257446 024CONTINUED FROM PAGE V-82. MARK "X" 3. EFFLUENT I 4. UNITS I 5. INTAKE aotion all 1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (if available)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED*

() UM I d. NO. OF a. CONCEN- (1) b. NO. OF (i[available)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION (2) MASS ANALYSEGCIMS FRACTION

-PESTICIDES (continued) 17P. Hleptachlor Epoxide (1024-57-3) x____18P. PCB-1 242 (53469-21-9) 19P. PCB-1 254x (11097-69-1)20P. PCB-1221

.>(11104-28-2)

_____________________________

21P. PCB-1232X (11141-16-5) 22P. PCB-1248X

____________

__________

__ ____(12672-29-6)

_______________

_____ _____________

23P. PCB-1 260X (11096-62-5) 24P. PCB-1016X (1 2674-11-2) x____ ___25P. Toxaphene ((80021-35-2) x__ ________ _____ ________________

___________

_________________________________

EPA Form 3510-2C (8-90)PAGE V-9 Outfall #024 P PLEASE PRINT OR TYPE IN THE UNSHADED AREAS ONLY. You may report some or asi of this information EPA I.D. NUMBER (copyfrom Item ! ofForm 1)on separate sheets (use the same format) Instead of completing these pages. NHD081257446 SEE INSTRUCTIONS.II V. INTAKE AND EFFLUENT CHARACTERISTICS (continued from page 3 of Form 2-C)OUTFALL NO.025A PART A -You must provide the results of at least one analysis for every pollutant in this table. Complete one table for each outfall. See instructions for additional details.3. UNITS 4. INTAKE 2. EFFLUENT (specify i(blank) (opfional)

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM a. MAXIMUM DAILY VALUE (ifavailable) (if available)

AVERAGE VALUE (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF 1. POLLUTANT CONCENTRATION (2) MASS CONCENTRATION (2) MASS (1) CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES a. Biochemical Oxygen ND 1 Demand (BOD)b. Chemical Oxygen Demand (COD) 10 15.7 1 mg/L ibs/d c. Total Organic Carbon (TOC) 3.2 5.0 1 mg/L Ibs/dd. Total Suspended Solids (TSS) ND 1 e. Ammonia (a N) ND 1 VALUE VALUE VALUE VALUE f. Flow 187,8011GD

g. Temperature VALUE VALUE VALUE VALUE (winter) I h. Temperature VALUE VALUE VALUE VALUE (summer) 27 MINIMUM MAXIMUM MINIMUM MAXIMUM 1. pH' 9.5 9.5 1 STANDARD UNITS PART B -Mark "X in column 2-a for each pollutant you know or have reason to believe is present. Mark "X" in column 2-b for each pollutant you believe to be absent. If you mark column 2a for any pollutant which is limited either directly, or indirectly but expressly, in an effluent limitations guideline, you must provide the results of at least one analysis for that pollutant.

For other pollutants for which you mark column 2a, you must provide quantitative data or an explanation of their presence in your discharge.

Complete one table for each outfall. See the instructions for additional details and requirements.

2. MARK"X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AVERAGE AND a. b. a. MAXIMUM DAILY VALUE (ifavailable) (ifavailable)

VALUE CAS NO. BELIEVED BELIEVED (I) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION (2) MASS ANALYSES a. Bromide (24959-67-9)

X b. Chlorine, Total Residual X c. Color X d. Fecal Coliform e. Fluoride (16984-48-8)

X .f. Nitrate-Nitrite (as N) X EPA Form 3510-2C (8-90)PAGE V-1 Outfall #025A CONTINUE ON REVERS ITEM V-B CONTINUED FROM FRONT 2. MARK X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AND 8. b. a. MAXIMUM DAILY VALUE (If-ailable) (if available)

AVERAGE VALUE CAS NO. BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- b. NO: OF (ifavailable)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES g. Nitrogen, 1 Total Organic (as ND N) __ I h. Oil and ND Grease N I. Phosphorus (as P), Total (7723-14-0) x J. Radioactivity (1) Alpha. Total x ND 1 pCi/kg (2) Beta, Total x1 pCi/kg (3) Radium, Total x (4) Radium 226, Total k. Sulfate (-oJ ND I (sSOW)1 (14808-79-8)

ND I. Sulfide XD (as) N_ _ _m. Sulfite (as SOA)(14265-45-3) x n. Surfactants x ND o. Aluminum, Total (7429-90-5) x p. Barium. Total (7440-39-3) x q. Boron, Total (7440-42-8) x ND 1 r. Cobalt, Total 1 (7440-48-4)

._ 1 I s. Iron, Total ND t. Magnesium, Total X ND (7439-95-4) x u. Molybdenum, Total (7439-98-7) x v. Manganese, Total ND (7439-96-5)

w. Tin, Total (7440-31-5)

_x x. Titanium, Total x (7440-32-6)

____ ______________

______________

________ ____________

EPA Form 3510-2C (8-90)PAGE V-2 CONTINUE ON PAGE V-3 0 EPA I.D. NUMBER (copy from Item I of Form 1) OUTFALL NUMBER NHD081257446 025A CONTINUED FROM PAGE 3 OF FORM 2-C PART C -If you are a primary industry and this outfall contains process wastewater.

refer to Table 2c-2 in the instructions to determine which of the GC/MS fractions you must test for. Mark "X" in column 2-a for all such GC/MS fractions that apply to your industry and for ALL toxic metals, cyanides, and total phenols. If you are not required to mark column 2-a (secondary industries, nonprocess wastewater outfal/s, and nonrequired GC/MS fractions), mark "X" in column 2-b for each pollutant you know or have reason to believe is present. Mark "X" in column 2-c for each pollutant you believe is absent. If you mark column 2a for any pollutant, you mus provide the results of at least one analysis for that pollutant.

If you mark column 2b for any pollutant, you must provide the results of at least one analysis for that pollutant if you know or have reason to believe it will be discharged in concentrations of 10 ppb or greater. If you mark column 2b for acrolein, acrylonitrile.

2,4 dinitrophenol.

or 2-methyl-4, 6 dinitrophenol, you must provide the results of at least one analysis for each of these pollutants which you know or have reason to believe that you discharge in concentrations of 100 ppb or greater. Otherwise, for pollutants for which you mark column 2b, you must either submit at least one analysis or briefly describe the reasons the pollutant is expected to be discharged.

Note that there are 7 pages to this part; please review each carefully.

Complete one table (all 7 pages) for each outfall. See instructions for additional details and requirements.

12. MARK X 3. EFFLUENT 4. UNITS 5. INTAKE (optional) 1.1POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. C. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (if available)

AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED (1) 1)I )d. NO. OF a. CONCEN- (1b. NO. OF (((available)

REQLIIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSEMETALS, CYANIDE, AND TOTAL PHENOLS IM. Antimony, Total ND (7440-36-0)

ND 1 2M. Arsenic, Total ND (7440-38-2)

ND 1 3M. Beryllium, Total N.(7440-41-7)

ND 1 4M. Cadmium, Total >(7440-43-9)

ND1 5M. Chromium, N1 Total (7440-47-3)

ND 6M. Copper, Total X (7440-50-8)

ND 1 7M. Lead, Total ND (7439-92-1)

__ 1 8M, Mercury, Total ND (7439-97-6)

X ND 1 9M. Nickel, Total 1 (7440-02-0) 7 N.10M. Selenium, N1 Total (7782-49-2)

XD 1 11M. Silver, Total 1 (7440-22-4)

ND i 12M. Thallium, Total (7440-28-0)

ND1 13M. Zinc, Total 0.02 0.03 1 mg/L lbs/d (7440-66-6)

__0.02 0.03 i _ g/L ibs/d 14M. Cyanide, N Total (57-12-5)

ND 15M. Phenols, Total ND 1 DIOXIN 2,3,7,8-Tetra-DESCRIBE RESULTS chlorodibenzo-P-> ( ESRERSUT Dioxin (1764-01-6)EPA Form 3510-2C (8-90)PAGE V-3 Outfall #025A CONTINUE ON REVERSE CONTINUED FROM THE FRONT 2. MARK X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional) 1.POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (if available)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) YJ c lt :1_OId NO, OF a, CONCEN- b. NO. OF (if available)

REQUIRED PRESENT ABSENT CONCENTRATION )MASS CONCENTRATION (2)MASS CONCENTRATIN (2) MASS TRATION b. MASS CONCENTRATION (2) MASS [ANALYSEGCIMS FRACTION

-VOLATILE COMPOUNDS 1V. Accrolein (107-02-8) 1ND 2V. Acrylonitrile (107-13-1)

,/x ND 1 3V. Benzene (71-43-2)

ND 1 4V. Bis (Chloro-,,ethyl) Ether ND (542-88-1) x 5V. Bromoform 1 (75-25-2)

ND1 6V. Carbon Tetrachlorde ND 1 (56-23-5) x 7V. Chlorobenzene ND (108-90-7) x"- 1 BV. Chlorodi-bromomethane ND 1 (124-48-1)

)9V. Chloroethane 1 (75-00-3) x ND 10V. 2-Chloro-ethylvinyl Ether ND 1 (110-75-8) x_1 1V. Chloroform (67-66-3) , ND 1 12V. Dichloro-bromomethane ND 1 (75-27-4) x ND 13V. Dichloro-difluoromethane ND 1 (75-71-8)

N-D 14V. 1,1-Dichloro-1 ethane (75-34-3) x ND 15V. 1,2-Dichloro-ethane (107-06-2)

.ND 1 16V. 1.1-Dichloro-1 ethylene (75-35-4)

ND 1TV. 1.2-Dichloro-propane (78-87-5)

ND 1 18V. 1,3-Dichloro-propylene .D 1 (542-75-6) x 19V. Ethylbenzene

\/ND (100-41-4) x 20V. Methyl 1 Bromide (74-83-9)

ND 1 21V. Methyl ND Chloride (74-87-3)

ND EPA Form 3510-2C (8-90)PAGE V4 CONTINUE.ON PAGE V-5 Outfall #025A CONTINUED FROM PAGE V-4 1 2. MARK "X" 3. EFFLUENT 4. UNITS 1 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. C. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (f available)

AVERAGE VALUE CAS NUMBER TESTING 1BELIEVED BELIEVED (1) (1) I() J d. NO. OF a. CONCEN- ( b. NO. OF (uiavailab/l REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (t ZMASS CONCENTRATION (Z ,MASS ANALYSES TRATION

b. MASS CONCENTRATtON (21 MASS ANALYSE GCIMS FRACTION -VOLATILE COMPOUNDS (continued) 22V. Methylene N Chloride (75-09-2)

ND 1 23V. 1,1,2,2-Tetrachloroethane ND 1 (79-34-5)24V. Tetrachloro-N ethylene (127-18-4)

ND 1 25V. Toluene N (108.88-3)

ND 1 26V. 1,2-Trans-

, Dichloroethylene ND 1 (156-60-5)

" 27V. lll-Trichloro-ND 1 ethane (71-55-6)

ND l 28V. 1,1,2-Trichloro-X ND 1 ethane (79-00-5)29V Trichloro-N ethylene (79-01-6)

ND 130V. Trichloro-fluoromethane ND "1 (75-69-4)31V. Vinyl Chloride 7 ND (75-01-4)

ND GC/MS FRACTION -ACID COMPOUNDS 1A. 2-Chlorophenol ND (95-57-8)

ND 1 2A. 2,4-Dichloro-N phenol (120-83-2)

ND 1 3A. 2,4-Dimethyl-1 phenol (105-67-9)

ND 4A. 4.6-Dinitro-o-NI Cresol (534-52-1)

N 1 5A. 2,4-Dinitro-N1 phenol (51-28-5)

ND 6A. 2-Nitrophenol ND (88-75-5)

ND 1 7A. 4-Nitrophenol ND (100-02-7)

.ND 1 8A. P-Chloro-M-N Cresol (59-50-7)

ND 1 9A Pentachloro-ND phenol (87-86-5) x 1 110A. Phenol ND (108-95-2)

ND ,1 11A. 2,4,6-Trichloro-X ND 1 phhenol (88-05-2)EPA Form 3510-2C (8-90)PAGE V-5 CONTINUE ON REVERSE Outfall #025A 0 CONTINUED FROM THE FRONT r -r -1 2. MARK X" 3. EFFLUENT 1 4. UNITS 1 5. INTAKE (optional)

1. POLLUTANT 1 b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a LONG TERM AND a. b. c. a, MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavai/able)

REQ)tREO PRESENT ABSENT CONCENTRATION (2)MASS CONCENTRATIONJ (2)MASS CONCENTRATION (2)Ms ANALY MASS CONCENTRATION 2)MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS 1B. Acenaphthene ND (83-32-9)__

ND 1 2B. Acenaphtylene ND (208-96-8) x ND 1 3B. Anthracene D (120,12-7)

ND 1 4B. Benzidine N (92-87-5)

ND 1 5B. Benzo (a)Anthracene XND (56-55-3)

ND 1 68. Benzo (a)Pyrene (50-32-8) x ND 7B. 3,4-Benzo-fluoranthene

> ND 1 (205-99-2) 8B. Benzo (ghi) N Perylene (191-24-2)

N 9B. Benzo (k)Fluoranthene ND1 (207-08-9)

N 10B. Bis (2-Chloro-ethoxy) Methane ND 1 (111-91-1) x 1 1B. Bis (2-Chioro-ethyl) Ether ND1 (111-44-4) x 12B. Bis (2-ChloroiXopropyo ND 1 Ether (102-80-1)

,-\13B. Bis (2-Ethyl.hetyl) Phthalate ND 1 (117-81-7) x _14B. 4-BromophenylPhenyl Ether ND 1 (101-55-3) x 15B. Butyl Benzyl ND Phthalate (85-68-7)

ND 16B. 2-Chloro-naphthalene X ND 1 (91-58-7)17B. 4-Chloro-phenyl Phenyl Ether ND (7005-72-3) x I 188. Chrysene ND (218-01-9) x ND 1 19B. Oibenzo (ah)Anthracene ND (53-70-3)

ND 1 20B. 1,2-Dichloro-1 benzene (95-50-1)

.ND 121B. 1,3-Di-chloro-X benzene (541-73-1)

ND .EPA Form 3510-2C (8-90)PAGE V-6 Outfall #025A CONTINUE ON PAGE V-7 CONTINUED FROM PAGE V-6 TAKE__ _ _ _ _ _ _ _ _2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional) 1.POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (if'available)

VALUE (ifavailable)

] AVERAGE VALUE CAS NUMBER TETN EIVED BELIEVED ()()()d O Fa OCN 1 .N.O (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS MASS ANALYSE GCIMS FRACTION -BASE/NEUTRAL COMPOUNDS (conrinued)22B. 1,4-Dichloro-x ND benzene (106-46-7)

ND 1 238. 3,3-Dichloro-)

benzidine (91-94-1)

ND 1 24B. Diethyl 1 Phthalate (84-66-2)

ND 25B. Dimethyl Phthalate ND 1 (131-11-3)

_26B. Di-N-Butyl N Phthalate (84-74-2)

ND 1 27B. 2,4-Dinitro-N toluene (121.14-2)

ND 1 288. 2,6-Dinitro-N toluene (606-20-2)

ND 1 29B. Di-N-Octyl N Phthalate (117-84.0)

ND 130B. 1,2-Diphenyl-hydrazine (as Azo- N1 benzene) (122-66-7) x 31B. Fluoranthene ND1 (206-44-0)

ND 1 328. Fluorene x ND (86-73-7)

ND 1 338. Hexachloro-N benzene (118-74-1)

ND 1 348. Hexachloro-ND butadiene (87-68-3)

/\358. Hexachloro-cyclopentadiene X ND1 (77-47-4)36B Hexachloro-N ethane (67-72-1)

ND 1 37B. Indano (1.2.3-cd)

Pyrene ND 1 (193-39-5) x 388. Isophorone ND (78-59-1)

ND 1 39B. Naphthalene N1 (91-20-3)

ND 40B. NItrobenzene IND (98-95-3)

N 41B. N-Nitro-sodimethylamine (62-75-9)

N1 42B. N-Nitrosodi-N-Propylamlne X (621-64-7) 1x i EPA Form 3510-2C (8-90)

PAG E ,V-7 CONTINUE ON REVERSE Outfall #025A CONTINUED FROM THE FRONT2. MARK "X" 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE C. LONG TERM AVRG.

a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (i(available) d NO. O AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED () 1(1) J(1) d NO. OF a. CONCEN- ()b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION1 (2)MAS C (2)MASS ANALYSES TRATION b. MASS CONCENTRATION (2)MASS ANALYSE GCIMS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 43B. N-Nitro-sodiphenylamine ND 1 (86-30-6)44B. Phenanthrene 1 (85-01-8)

ND .458. Pyrene N (129-00-0)

ND 1 46B. 1,2,4.Tri.

chlorobenzene ND (120-82-1 ) N I GC/MS FRACTION -PESTICIDES 1 P. Aldrin (309-00-2) x 2P. a-BHC X (319-84-6) 3P. P-BHC (319-85-7) x 4P. y-BHC X (58-89-9) x 5P. 8-BHC (319-86-8) x 6P. Chlordane X (57-74-9) x 7P. 4,4'-DDT (50-29-3) x 8P. 4,4'-DDE (72-55-9) x 9P. 4,4'-DOD (72-54-8) x 1OP: Dieldrin (60-57-1) x 11P. a-Enosulfan (115-29-7)

_x 12P. p-Endosulfan (115-29-7)

_x 13P. Endosulfan Sulfate (1031-07-8) x 14P. Enddn (72-20-8) x 15P. Endrin Aldehyde (7421-93-4) x 16P. Heplachlor x(76-44-.8)

_L EPA Form 3510-2C (8-90)PAGE V-8 CONTINUE ON PAGE V-9 Outfall #025A EPA I.D. NUMBER (copy from Item I of Form 1) OUTFALL NUMBER NHD081257446 025A CONTINUED FROM PAGE V-8 2. MARK X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable) j AVERAGE VALUE CAS NUMBER TESTIN BEIVED. BELIEVED (1) (1) OC(N1)rTONdN.OFaCNE-(1)b.N.F (ifavoilable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION

12) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -PESTICIDES (continued) 17P. Haptachlor Epoxide (1024-57-3) x 18P. PCB- 1242 (53469-21-9) x 19P. PCB-1254 (11097-69-1) x 20P. PCB-1221 (11104-28-2)

A 21P. PCB-1232 (11141-16-5)

_x 22P. PCB-1248 (12672-29-6)

X 23P. PCB-1260 (11096-82-5) x 24P. (12674-11-2)

, 25P. Toxaphene (8001-35-2) xEPA Form 3510-2C (8-90)PAGE V-9 Outfall 4025A F PLEASE PRINT OR TYPE IN THE UNSHADED AREAS ONLY. You may report some or all of this information EPA ID. NUMBER (copyfrom Item I of Form1)on separate sheets (use the same format) instead of completing these pages. NHD081257446 SEE INSTRUCTIONS.

I I V. INTAKE AND EFFLUENT CHARACTERISTICS (continued from page 3 of Form 2-C)OUTFALL NO.025B PART A -You must provide the results of at least one analysis for every pollutant In this table. Complete one table for each outfall. See instructions for additional details.3. UNITS 4. INTAKE 2. EFFLUENT (specify ihblank) (optional)

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM a. MAXIMUM DAILY VALUE (ifavailable) (ifavailable)

AVERAGE VALUE (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF 1. POLLUTANT CONCENTRATION (2) MASS CONCENTRATION (2) MASS (I) CONCENTRATION (2)

MASS ANALYSES TRATION b. MASS CONCENTRATION (2)

MASS ANALYSES a. Biochemical Oxygen Demand (BOD) ND b. Chemical Oxygen Demand (COD) ND c. Total Organic Carbon (TOC) ND d. Total Suspended Solids (7SS) ND 1 e. Ammonia (as N) 1.6 1.1 1 mg/L lbs/d VALUE VALUE VALUE VALUE f. Flow 85,019 1 GPD g. Temperature VALUE VALUE VALUE VALUE (winter)h. Temperature VALUE VALUE VALUE VALUE (summer) 28 1 MINIMUM MAXIMUM MINIMUM MAXIMUM i. pH 5.9 5.9 1 STANDARD UNITS PART B -Mark "X" in column 2-a for each pollutant you know or have reason to believe is presenl. Mark "X" in column 2-b for each pollutant you believe to be absent. If you mark column 2a for any pollutant which is limited either directly, or indirectly but expressly, in an effluent limitations guideline, you must provide the results of at least one analysis for that pollutant.

For other pollutants for which you mark column 2a, you must provide quantitative data or an explanation of their presence in your discharge.

Complete one table for each ouffall. See the instructions for additional details and requirements.

2. MARK 'X" 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

VALUE a. LONG TERM AVERAGE AND a. b. a. MAXIMUM DAILY VALUE (i.available) (if available) -VALUE CAS NO. BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES a. Bromide (24959-67-9)

X b. Chlorine, Total Residual x c. Color X d. Fecal Coliform X e. Fluoride (16984-48-8)

X f. Nitrate-Nitrite (as N) X EPA Form 3510-2C (8-90)PAGE V-1 Outfall #025B CONTINUE ON REVERS ITEM V-B CONTINUED FROM FRONT 2. MARK X" 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AND a. b. a. MAXIMUM DAILY VALUE (([available) (i[available)

AVERAGE VALUE CAS NO. BELIEVED BELIEVED (1) (1) ('I d. NO. OF a. CONCEN- (1) b. NO. OF (([available)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES g. Nitrogen, Total Organic (as ND N) ____ I___ __ ______h. Oil and ND1 Grease 1 I. Phosphorus (as P), Total (7723-14-0) x J. Radioactivity (1) Alpha. Total x ND 1 pCi/kg (2) Beta, Total x ND 1 pCi/kg (3) Radium, Total x (4) Radium 226, Total x k. Sulfate (,WSO,) ND 1 (14808-79-8) x I I. Sulfide ND 1 (as S) ND_ _m. Sulfite (as SO,) k (-So))(14265-45-3) x n. Surfactants x ND ,1 o. Aluminum, Total (7429-90-5) x p. Barium, Total (7440-39-3) x q. Boron, Total 1D (744042-8)

ND r. Cobalt, Total NT)(7440-48-4)

/\a. Iron, Total. ND (7439-89-6)

..ND 1 L. Magnesium, Total ND (7439-95-4) x u. Molybdenum, Total V (7439-98-7) x v. Manganese, Total ND 1 (7439-96-5) x w. Tin, Total (7440-31-5)

.x x. Titanium, Total EPA Form 3510-2C (8-90)PAGE V-2 CONTINUE ON PAGE V-3 0 EPA I.D. NUMBER (copyfrom Item I ofForm I) OUTFALL NUMBER NHD081257446 025B CONTINUED FROM PAGE 3 OF FORM 2-C PART C -If you are a primary industry and this outfall contains process wastewater, refer to Table 2c-2 in the instructions to determine which of the GCMS fractions you must test for. Mark WX' in column 2-a for alt such GC/MS fractions that apply to your industry and for ALL toxic metals, cyanides, and total phenols. If you are not required to mark column 2-a (secondary industries, nonprocess wastewater outfalls, and nonrequired GC/MS fractions), mark "X" in column 2-b for each pollutant you know or have reason to believe is present. Mark "X" in column 2-c for each pollutant you believe is absent. If you mark column 2a for any pollutant, you mus provide the results of at least one analysis for that pollutant.

If you mark column 2b for any pollutant, you must provide the results of at least one analysis for that pollutant if you know or have reason to believe it will be discharged in concentrations of 10 ppb or greater. If you mark column 2b for acrolein, acrylonitrile, 2,4 dinitrophenol, or 2-methyl-4, 6 dinitrophenol, you must provide the results of at least one analysis for each of these pollutants which you know or have reason to believe that you discharge in concentrations of 100 ppb or greater. Otherwise, for pollutants for which you mark column 2b, you must either submit at least one analysis or briefly describe the reasons the pollutant is expected to be discharged.

Note that there are 7 pages to this pari; please review each carefully.

Complete one table (all 7 pages) for each outfall. See instructions for additional details and requirements.

_2. MARK "X" 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. C. a. MAXIMUM DAILY VALUE (ifa~vailable)

VALUE (if~amilable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED[ (1)

(1) (1d. NO. OF a. CONCEN- 1Ib. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION1 (2) MASS CONCENTRATION (2)MSS ANALYSES TRATION b. MASS CONCENTRATION (21 MASS ANALYSE METALS, CYANIDE, AND TOTAL PHENOLS 1M. Antimony, Total 1 (7440-36-0)

X 1 2M. Arsenic, Total \,/(7440-38-2) 1 3M. Beryllium.

Total NO (7440-41-7) 1 4M. Cadmium, Total X (7440-43-9)

ND 1 5M. Chromium.

N Total (7440-47-3)

NX 1 6M. Copper, Total 0 (7440-50-8) 0.01 0.01 1 tg/L ibs/d 7M. Lead, Total ND 1 (7439-92-1)

ND 1 8M. Mercury, Total 1 (7439-97-6)

NO 1 9M. Nickel, Total N (7440-02-0)

X_ _1 10M. Selenium, 1 Total (7782-49-2)

ND1IM. Silver, Total 1 (7440-22-4)

X __1 12M. Thallium, Total (7440-28-0) 1 13M. Zinc, Total xND (7440-66-6)

ND _14M. Cyanide, ND Total (57-12-5)

ND 15M. Phenols, ND Total ND 1 DIOXIN 2,3,7,8-Tetra-DESCRIBE RESULTS chlorodlbenzo-P-Dioxin (1764-01-6)

EPA Form 3510-2C (8-90)PAGE V-3 CONTINUE ON REVERSE Outfall No. 025B CONTINUED FROM THE FRONT 2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (i[available)

VALUE (i/available)

AVERAGE VALUE CAS NUMBER TESTfrNG BELIEVED (1) { 1(1) 1) d. NO. OF a. CONCEN- (1) {b. NO.' OF, (i[available)

REQUIRED PRESENT ABSENT CONCENTRATION[

(21 MASS CONCENTRATION 121 MASS CONCENTRATION (2t MASS ANALYSES TRATION

b. MASS CONCENTRATION 1(2) MASS ANALYSE GC/MS FRACTION -VOLATILE COMPOUNDS IV, Aocrolein 1 (107-02-8)

.ND 1 2V. Acrylonitrile ND (107-13-1)

ND 1 3V. Benzene (71-43-2)

ND1 4V. Bis (Chloro- .methyl) Ether ND 1 (542-88-1) x 5V. Bromoform (75-25-2) 1ND 6V. Carbon Tetrachloride NT 1 (56-23-5)1 x ND 7V. Chlorobenzene 1 (108-90-7) 1 N BV. Chlorodi-bromomethane ND 1 (124-48-1) x 9V. Chloroethane D (75-00-3)

ND 1OV. 2-Chloro-ethylvinyl Ether ND 1 (110-75-8) 1 IV. Chloroform

\/(67-66-3)_

x ND 12V. Dichloro-bromomrelhane X ND 1 (75)-27-4) x, 13V. Dichloro-difluoromethane ND 1 (75-71-8)14V. 1.1-Dichloro-ND ethane (75-34-3)

ND l 15V. 1,2-Dichloro-ethane (107-06-2c) x ND1 16V. 1.1-Dichloro-N ethylene (75-35-4)

ND'1 17V. 1,2-Dichloro-1 propane (78-87-5)

-ND.118V. 1.3-Dichloro-propylene ND (542-75-6) 19V. Ethylbenzene ND (100-41-4)

N) 1 20V. Methyl Bromide (74-83-9)

ND 1 21V. Methyl ND 1 Chloride (74-87-3)

N1 EPA.Form 3510-2C (8-90)PAGEV4 Outfall #025B CONTINUE ON PAGE V-5 CONTINUED FROM PAGE V-4 2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (if available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELICE'VO

-(1) I (1) -.-O. -_ g. CONCErt- (1) b, NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS TRAT1ON b MASS CONCENTRATION (2IMASS ANALYSE GCIMS FRACTION -VOLATILE COMPOUNDS (continued) 22V. Methylene 1 Chloride (75-09-2) xND 23V. 1,1,2,2-Tetrachloroethane

' ND (79-34-5)24V. Tetrachloro.

1 ethylene (127-18-4)

ND 25V. Toluene N1 (108-88-3) x 1 26V. 1,2-Trans-Dlchloroethylene ND 1 (156-60-5) 27V. 1,1,1-Trlchloro-ND ethane (71-55-6)

ND 1 28V. 1,1,2-Trichloro-ND ethane (79-00-5)

ND 1 29V Trichloro-N ethylene (79-01-68).

ND30V. Trichloro-fluoromethane ND 1 (75-69..4) 31V. Vinyl Chloride ND (75-01 -4) _______ I__ I___________

_______ __ ______ _______GCIMS FRACTION -ACID COMPOUNDS 1A. 2-Chlorophenol ND (95-57-8)

ND_1 2A. 2,4-Dichloro-XND phenol (120-83-2)

ND 1 3A. 2.4-Dimethyl-X ND1 phenol (105-67-9)

N 4A. 4,6-Dinitro-O-ND Cresol (534-52-1)

ND 5A. 2,4-Dinitro-1 phenol (51-28-5)

ND 6A. 2-Nitrophenol ND (88-75-5)

ND 1 7A. 4-Nitrophenol ND (100-02-7)

ND 1 8A. P-Chloro-M-N Cresol (59-50-7)

ND 1 9A. Pentachloro-ND phenol (87-86-5)

ND 1 10A. Phenol ND (108-95-2)

ND 1 11 A. 2,4,6-Tdchloro-ND 1phhenol (88-05-2) xD EPA Form 3510-2C (8-90)PAGE V-5 CONTINUE ON REVERSE Outfall #025B CONTINUED FROM THE FRONT2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c LONG TERM AVRG. a. LONG TERM AND a. b. c a. MAXIMUM DAILY VALUE (if available)

VALUE (ifavailable) d AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED -(1) I()1)dNOOF .CONCEN- (1) b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATON (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION

12) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS IB. Acenaphthene 1 (83-32-9)

ND1 2B. Acenaphtylene D (208-96-8)

ND 1 3B. Anthracene (120-12-7) , ND 1 4B. Benzidine N (92-8-5)ND 1 58. Benzo (a)Anthracene , _ ND 1 (56-55-3) xN 68. Benzo (a) ND Pyrene (50-32-8) xND 1 7B. 3.4-Benzo-fluoranthene ND 1 (205-99-2)

88. Benzo (ghi)Perylene (191-24-2) xND 1 9B. Benzo (k)Fluoranthene ND (207-08-9) 10B. Bis (2-Chloro.

cilhoxy) Methane 1 (111-91-1)

\ ND 11 1B. 8is (2.Ch/oro ethyl) Ether ,,ND (111-44-4) 1 128. Bis (2-Chloroisopropyl)

ND Ether (102-80-1) x 138. Bis (2-Ethyl-hexyl) Phthalate ND (117-81-7) " /x 14B. 4-Bromophenyl Phenyl Ether N.D 1 (101-55-3) x 15B. Butyl Benzyl 1 Phthalate (85-68-7) x ND 16B. 2-Chloro-naphthalene ND (91-58-7) x 17B. 4-Chloro-phenyl Phenyl Ether ND (7005-72-3)

ND 18B. Chrysene N (218-01-9) x ND 19B. Dibenzo (a~h)Anthracene ND (53-70-3)

ND i 208. 1,2-Dichloro-

\ ND benzene (95-50-1)

/ _ __121B. 1,3-Di-chloro-N benzene (541-73-1) 1ND 1i EPA Form 3510-2C (8-90)PAGE V-6 Outfall #025B CONTINUE ON PAGE V-7 CONTINUED FROM PAGE V-6 2. MARK "X' 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT I b MAXIMUM 30 DAY VALUE c LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) d. NO. OF a. CONCEN- _1)_ b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 22B. 1,4-Dichloro-N benzene (106-46-7) ,D 1 238. 3,3-Dichloro-1 benzidine (91-94-1)

ND 24B. Diethyl N Phthalate (84-66-2)

ND 1 25B. Dimethyl Phthalate ND 1 (131 3) ND 1 26B. DI-N-ButA D Phthalate (84-74ý2) xND 1 27B. 2,4-Dinitro-Ntoluene (121-14-2) x 1 28B. 2,6-Dinitro-1toluene (606-20-2)

ND 29B. Di-N-Octyl N Phthalate (117-84.0)

ND 1 30B. 1,2-Diphenyl-hydrazine (as Azo- ND 1 benzene) (122-66-7)

N 31B. Fluoranthene N (206-44-0) x ND 1 32B. Fluorene ND (86-73-7)

ND 1 33B. Hexachloro-N benzene (118-74-1)

ND 1 34B. Hexachloro-Nbutadiene (87-68-3)

ND 1 35B. Hexachloro-cyclopentadiene X ND 1 (77-47-4) x 36B Hexachloro-x ethane (67-72-1)

ND 1 37B. Indeno (1,2,3-cd)

Pyrene ND 1 (193-39-5) x 38B. Isophorone ND (78-59-1)

ND i 398. Naphthalene ND (91-20-3) 1x 1 408. Nitrobenzene ND (98-95-3) x I 41B. N-Nitro-sodimethylamine ND 1 (62-75-9)428. N-Nitrosodi-(621-64-7)

X ND EPA Form 3510-2C (8-90)PAGE V-7 Outfall #025B CONTINUE ON REVERSE CONTINUED FROM THE FRONT.2. MARK "X 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (if available)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) (T(1) 1d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MAS MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS 1ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 43B. N-Nitro-sodiphenylamine ND 1 (86-30-6) x 44B. Phenanthrene ND (85-01-8)

ND 1 45B. Pyrene N (129-00-0) , ND 1 468. 1,2,4-Td-chlorobenzene xND ('120-82-1)

ND GC/MS FRACTION -PESTICIDES 1P. Aldnin (309-00-2) 2P. a-BHC (319-84-6) x 3P. "BHC (319-85-7) x 4P. y-BHC (58-89-9) x 5P. 8-BHC (319-86-8) x 6P. Chlordane (57-74-9) x 7P. 4,4'-DDT (50-29-3) x 8P. 4,4'-DDE (72-55-9) x 9P. 4,4'-DDD (72-54-8) x loP. Dieldrin (60-57-1) x I1P. a-Enosulfan (115-29-7) ix 12P. O-Endosulfan (115-29-7) x __13P. Endosulfan Sulfate (1031-07-8) x 14P. Endrin (72-20-8)

• x 15P. Endrin Aldehyde (7421-93-4) 16P. Heptachlor (76-44-8) x EPA Form 3510-2C (8-90)

PAGE V-8 CONTINUE ON PAGE V-9 Outfall #025B EPA I.D. NUMBER (copy from Item I of Form 1) OUTFALL NUMBER NI-HD081257446 025B CONTINUED FROM PAGE V-82. MARK X" 3. EFFLUENT 1 4. UNITS 1 5. INTAKE (oviioantl

1. POLLUTANT

b. MAXIMUM 30 DAY VALUET c. LONG TERM AVRG. a. LONG TERM AND a. b. c, a. MAXIMUM DABLY VALUE: (available)

VALUE (ifNavailabO ) AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED (1a M U I LaeU d. NO. OF (af. CONCEN- [b. NO. OF (available)

REQUIRED PRESENT ABSENT CONCENTRATION (2)MASS CONCETRON (2)MMASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -PESTICIDES (continued)

Epoxide (1024-57-3) x___________

1l8P. P08-1 242x (53469-21-9) x _______1 9P. PCB-l 254 (11097-69-1) x 20P. PCB-1221X (11104-28-2) x___21P. PCB-1232X (11141-16-5)

F22P. PCB-1248X (12672-29-6) 23P. PCB-1260X_____

______(11096-82-5) 24P. PCB-1016X___________

(12674-11-2) x____ _______25P. ToxapheneX

_______ ____________

____ _______ ____ ___________

____ _______ ___ __ ____(8001-35-2)

_____ ____ ___________

EPA Form 3510-2C (8-90)PAGE V-9 Outfall #025B

]- I PLEASE PRINT OR TYPE IN THE UNSHADED AREAS ONLY. You may report some or all of this information EPA I.D. NUMBER (copy from Item I of Form1))on separate sheets (use the same format) instead of completing these pages. NHD08125'7446 SEE INSTRUCTIONS.

V. INTAKE AND EFFLUENT CHARACTERISTICS (continued from page 3 of Form 2-C)OUTFALL NO.

025C PART A -You must provide the results of at least one analysis for every pollutant in this table. Complete one table for each outfall. See instructions for additional details.3. UNITS 4. INTAKE 2. EFFLUENT (specify (f blank) (optional)

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM a. MAXIMUM DAILY VALUE (if available) (if available)

d. NO. OFAVERAGE VALUE b. NO. OF 11) (1) d O F a OCN 1 .N.O 1. POLLUTANT CONCENTRATION (2) MASS CONCENTRATION (2) MASS (1) CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES a. Biochemical Oxygen Demand (BOD) 10 1.6 1 mg/L ibs/d b. Chemical Oxygen 5.3 1 mg/L lbs/d Demand (COD).c. Total Organic Carbon 10 1.6 1 ng/L lbs/d (TOC)d. Total Suspended Solids(TSS) 1.4 0.2 1 mg/L lbs/d e. Ammonia (as N) 2.3 0.4 1 mg/L lbs/d VALUE VALUE VALUE VALUE f. Flow 18,616 1 GPD g. Temperature VALUE VALUE VALUE VALUE (winter) "C h. Temperature VALUE VALUE VALUE VALUE (summer) 28 1 MINIMUM MAXIMUM MINIMUM MAXIMUM 1. pH 7.0 7.0 1 STANDARD UNITS PART B -Mark "X" in column 2-a for each pollutant you know or have reason to believe is present. Mark "X" in column 2-b for each pollutant you believe to be absent. If you mark column 2a for any pollutant which is limited either directly, or indirectly but expressly, in an effluent limitations guideline, you must provide the results of at least one analysis for that pollutant.

For other pollutants for which you mark column 2a, you must provide quantitative data or an explanation of their presence in your discharge.

Complete one table for each outfall. See the instructions for additional details and requirements.

2. MARK "X" 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AVERAGE AND a. b. a. MAXIMUM DAILY VALUE (ifavailable) (ifavailable)

VALUE CAS NO. BELIEVED BELIEVED ( 1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (if available)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES a. Bromide (24959-67-9)

X b. Chlorine, Total Residual _X c. Color X d. Fecal Coliform X e. FluordeX (16984-48,-8)

____ _____ _____ _____ ____ ____f. Nitrate-Nitrite (a( ) ________ ___________________________ ____ _____

______________________

____EPA Form 3510-2C (8-90)PAGE V-1 Outfall #025C CONTINUE ON REVERS ITEM V-B CONTINUED FROM FRONT

2. MARK "X 3. EFFLUENT 4. UNITS 5. INTAKE (qwjio"aI)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AND a. b. a. MAXIMUM DAILY VALUE (if available) (if available)

AVERAGE VALUE CAS NO. BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (if available)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES g. Nitrogen, Total Organic (as 5.1 0.79 mg/L lbs/d ,N)h. Oil and ND Grease X ND1 i. Phosphorus (as P), Total (7723-14-0) x J. Radioactivity (1) Alpha, Total x ND pCi/kg (2) Beta, Total x 5.20 i pCi/kg (3) Radium.Total x (4) Radium 226, Total x k. Sulfate (ay SO,) 240 383 1 mg/L lbs/d (14808-79-8) 2 1. Sulfide ND (a S) ND 1 m. Sulfite (as SO,)(14265-45-3) x n. Surfactants x ND o. Aluminum, Total (7429-90-5) x p. Barium, Total (7440-39-3) x q. Boron, Total \N (7440-42-8)

ND 1 r. Cobalt, Total 1 (7 4 4 0 -4 8 -4 ). N D a. Iron, Total 1 mg/L lbs/d (7439-89-6)0.12 0.02m I. Magnesium, Total 2.5 0.39 1 mg/L lbs/d (7439-95-4) x I u. Molybdenum, Total (7439-98-7)

_v, Manganese, Total 1 mg/L lbs/d (7439-96-5) 0 w. Tin, Total (7440-31-5) x x. Titanium, Total x 1(7440-32-6)

EPA Form 3510-2C (8-90)PAGE V-2 CONTINUE ON PAGE V-3 EPA I.D. NUMBER (copy/mrm Item I ofFonn I) OUTFALL NUMBER NHD081257446 025CCONTINUED FROM PAGE 3 OF FORM 2-CPART C -If you are a primary industry and this outfall contains process wastewater, refer to Table 2c-2 in the instructions to determine which of the GC/MS fractions you must test for. Mark "X" in column 2-a for all such GCIMS fractions that apply to your industry and for ALL toxic metals, cyanides, and total phenols. If you are not required to mark column 2-a (secondary industries, nonprocess wastewater outfalls, and nonrequired GC/MS fractions), mark "X" in column 2-b for each pollutant you know or have reason to believe is present. Mark "X' in column 2-c for each pollutant you believe is absent. If you mark column 2a for any pollutant, you mus provide the results of at least one analysis for that pollutant.

If you mark column 2b for any pollutant, you must provide the results of at least one analysis for that pollutant if you know or have reason to believe it will be discharged in concentrations of 10 ppb or greater. If you mark column 2b for acrolein, acryfonitrile, 2,4 dinitrophenol, or 2-methyl-4, 6 dinitrophanol, you must provide the results of at least one analysis for each of these pollutants which you know or have reason to believe that you discharge in concentrations of 100 ppb or greater. Otherwise, for pollutants for which you mark column 2b, you must either submit at least one analysis or briefly describe the reasons the pollutant is expected to be discharged.

Note that there are 7 pages to this part; please review each carefully.

Complete one table (all 7 pages) for each outfall. See instructions for additional details and requirements.

2. MARK XX" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. C. a. MAXIMUM DAILY VALUE (ifavai/able)

VALUE (ifavailable)

AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED (1) 1 )d. NO. OF a. CONCEN- 1 b. NO. OF (i avaloble)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS (2) MASS ANALYSES TRATION b. MASS CONCENTRTION (2) MASS ANALYSE METALS, CYANIDE, AND TOTAL PHENOLS IM. Antimony, Total \/(7440-36-0)

ND 2M. Arsenic, Total ND 1 (7440-38-2) 3M. Beryllum, Total \ ND .(7440-41-7)

/\4M. Cadmium, Total N (7440.43-9)

ND 5M. Chromium, ND Total (7440-.47-3)

_____ _____________

_______BM. Copper, Total ND (7440-50-68)

.ND 1 7M. Lead. Total ND (7439-92-1)

X.8M. Mercury, Total ND (7439-97-6) ..ND X 9M. Nickel, Total ND 1 (7440-02-0)

X 10M. Selenium, ND Total (7782-49-2)

\N j11M. Silver, Total \/(7440-22.4)

X 12M. Thallium, ND Total (7440-28-0)

X 13M. Zinc, Total X ND 1 (7440-66-6)

X 14M. Cyanide, 1 Total (57-1 2-5) ND____ ______ ________15M. Phenols, NDND DIOXIN 2.3,78-Tetra-DE chlarodibenzo-P.

)Dioxin (1 764-1-6)If EPA Form 3510-2C (8-90)PAGE V-3 Outfall #025C CONTINUE ON REVERSE CONTJNUED FROM THE FRONT 2. MARK *X 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (if available)

[ AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1 1) (1 ) d.NO O a CN N (1)b.N.O (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS MASS CONCENTRATION (2)MASS ANALYSES TRATION b. MASS MASS ANALYSE GCIMS FRACTION -VOLATILE COMPOUNDS IV. Accroleln D (107-02-8) x ND I 2V. Acrylonitnle (107-13-1) x ND 1 3V. Benzene (71-43-2) x1 4V. Bls (Chlorm-methyl) Ether ND 1 (542-88-1)

_5V. Bromoform ND (75-25-2)

ND 1.6V. Carbon Tetrachloride ND 1 (56-23-5) x 7V. Chlorobenzene ND (108-90-7)

ND 1 8V. Chlorodi-bromomethane ND 1 (124-48-1) x 9V. Chloroethane ND (75-00-3)

ND i 1iV. 2-ChIoro-ethyMnyl Ether ND 1 (110-75-8)

-1IV. Chloroform ND (67-66-3),ND 1 12V. Dichloro-bromomethane X _ND 1 (75-27-4) x'13V. Dichloro-difluoromethane ND (75-7148)

_____ _____ _______14V. 1,1-Dichloro-1 ethane (75-34-3) xD 1 15V. 1.2-Dichloro-ethane (107-06-2) xD 1 16V. 1.1-DIchloro-x ethylene (75-354) _ _ 1 17V. 1,2-Dichloro-propane (78-87-5) x ND 1 18V. 1,3-Dichloro-propylene ND1 (542-75-6) x 19V. Ethylbenzene ND (10041-4)

ND 1 20V. Methyl XND Bromide (74-83-9)

ND 1 21V. Methyl 1 Chloride (74-87-3)

NDEPA Form 3510-2C (8-90)

PAGE V-4 CONTINUE ON PAGE V-5 Outfall #025C CONTINUED FROM PAGE V-42. MARK "X 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

= b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM CAS NUMBER TESTING BELIEVED [BELIEVED (1) bd. NO. OF a. CONCEN- T b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2)

MASS 'ANALYSES RATRATION

• ATION (2) MASS ANALYSE GC/MS FRACTION -VOLATILE COMPOUNDS (continued) 22V. Methylene ND Chloride (75-09-2) xD 1 23V. 1,1.2.2-Tetrachloroethane ND 1 24V. Tetrachloro-1 ethylene (127-18-4) xD 1 25V. Toluene 1 (108-88-3) xD 1 26V. 1,2-Trans-Dichloroethylene ND 1 (156-60-5) x 27V. 1,1.1-Trichloro-1 ethane (71-55-6)

ND 1 28V. 1.1,2-Trichloro-X ethane (79-00-5)

___1 29V Trichloro-ethylene (79-01-6)

ND 1 30V. Trichloro-fluoromethane ND 1 (75-69-4)31V. Vinyl Chloride ND 1 (75-01-4)GC/MS FRACTION -ACID COMPOUNDS IA. 2-Chlorophenol ND (95-57-8)

N 2A. 2,4-Dichloro-phenol (120-83-2)

ND 1 3A. 2,4-Dimethyl-1 phenol (105-67-9)

ND 4A. 4.6-Dinitro-O-ND Cresol (534-52-1)

ND 1 5A. 2,4-Dinitro-phenol (51-28-5)

ND 1 6A. 2-Nitrophenol ND 1 (88-75-5) x 7A. 4-Nitrophenol

> ND 1 (100-02-7) x 8A. P-Chloro-M-N Cresol (59-50-7)

ND 1 9A. Pentachloro-ND phenol (87-86-5)

ND x 10A. Phenol ND (108-95-2) xD 1 I IA. 2,4,6-Trichloro-ND phenol (88-05-2) xD 1EPA Form 3510-2C (8-90)PAGE V-5 Outfall #025C CONTINUE ON REVERSE CONTINUED FROM THE FRONT2. MARK X 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (if avoilable)

VALUE (i(available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) (1) (1) 1 d. NO. OF a. CONCEN- (1) b. NO. OF (iavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2)MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS 18. Acenaphthene N (83-32-9) x ND 1 2B. Acenaphlylene (208-96-8) x ND 1 3B. Anthracene

\/(120-12-7)

/x ND _48. Benzidine (92-87-5) 1ND 5B. Benzo (a)Anthracene N (56-55-3) x ND 6B. Benzo (a) 1 Pyrene (50-32-8) x ND 1 7B. 3,4-Benzo-fluoranthene ND1 (205-99-2) x 8B. Benzo (ghi) 1 Perylene (191-24.2) xND 98. Benzo (k)Fluoranthene ND (207-08-9) x 108. Bis (2-Chloro-ethoxy) Methane ND (111-91-1)

ND 1 I IB. Bis (2-Chloro-ethyl) Ether ND (111-44-4) x 128. Bis (2-Chl-ori'opropyl)

ND Ether (102-80-1) x ND 13B. Bis (2-Ethyl-hexyl) Phthalate ND (117-81-7) 14B. 4-Bromophenyl Phenyl Ether ND (101-55-3) x 158. Butyl Benzyl 1 Phthalate (85-68-7)

_' ND1 16B. 2-Chloro-naphthalene ND 1 (91-58-7)17B. 4-Chloro-phenyl Phenyl Ether ND (7005-72-3) x 188. Chrysene ND (218-01-9)

ND 1 198. Dibenzo (a~h)Anthracene x ND 1 (53-70-3) x%20B. 1,2-Dichloro-ND benzene (95-50-1)

ND 1 21B. 1,3-Di-chlor0-1 benzene (541-73-1) x 1 EPA Form 3510-2C (8-90)PAGE V-6 Outfall #025C CONTINUE ON PAGE V-7 CONTINUED FROM PAGE V-62. MARK "X 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER ,ESTNG BELIEVEO 8ELItEVED ( d. NO. OF a. CONCEN- b. NO OF (if available)

REQUIRED 1 PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 22B. 1,4-Dichloro-ND benzene (106-46-7) 1 23B. 3,3-Dichloro-x benzidine (91-94-1)

ND 24B. Dlethyl ND Phthalate (84-66-2) x25B. Dimethyl Phthalate ND (131 3) ND 1 26B. Di-N-Butyl N Phthalate (114-74-2)

ND27B. 2,4-Dinitro-N toluene (121-14-2)

ND 1 28B. 2.6-Dinitro-1 toluene (606-20-2)

ND 29B. Di-N-Octy ND Phthalate (117-84-0)

ND_1 306. 1,2-Diphenyl-hydrazine (as Azo- N1 benzene) (122-66-7)

ND 31B. Fluoranthene ND (206-44-0)

ND 1 328. Fluorene ND (86-73-7)

ND 1 33B. Hexachioro-benzene (118-74-1)

ND 1 34B. Hexachloro-ND butadiene (87-68-3)

ND__358. Hexachloro-cyclopentadiene ND (77-47-4)

/'x 36B Hexachloro-1 ethane (67-72-1)

ND l 37B. Indeno (1,23-cd)

Pyrene N1 (193-39-5) 386. Isophomne ND 1 (78-59-1)

ND 1 39B. Naphthalene ND (91-20-3)

ND 1 408. Nitrobenzene ND (98-95-3)

ND 1 418. N-Nitro-sodimethylamlne ND (62-75-9)

/\42B. N-Nitrosodi.

N-Propylamine ND (621-64-7)

_EPA Form 3510-2C (8-90)

PAGE V-7 Outfall #025C CONTINUE ON REVERSE CONTINUED FROM THE FRONT2. MARK "X 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED (1) 0 (1) d.( N.O OF a. CONCEN- (1) b NO. OF (Wf available)

REQUIRED PRESENT ABSENT CONCENTRATION (2)

MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 430. N-Nltro-sodiphenylamine ND 1 (86-30-6)44B. Phenanthrene D (85-01-8)

ND 1 458. Pyrena N (129-00-0)

ND 1 468. 1.2,4-Tr-chlorobenzene ND (120-82-1)

ND GC/MS FRACTION -PESTICIDES 1P. Aldrin (309-00-2)

_2P. a-BHC (319-84-6) x 3P. IP-BHC (319-85-7) x 4P. y-BHC (58-89-9) x 5P. -BHC (319-86-8) 6P. Chlordane X (57-74-9) x 7P. 4,4'-DDT (50-29-3) x 8P. 4,4'-DDE (72-55-9) x 9P. 4,4'-DDD (72-54-8) x 10P. Dieldrin (60-57-1) x 11P. a-Enosulfan (115-29-7) x 12P. I-Endosulfan (115-29-7) 13P. Endosulfan Sulfate (1031-07-8) x 14P. Endrin (72-20-8) x 15P. Endrin Aldehyde (7421-93.4) x 16P. Heptachlor (76-44-8) x EPA Form 3510-2C (8-90)PAGE V-8 Outfall 025C CONTINUE ON PAGE V-9 EPA I.D. NUMBER (copyfirom Item I of Form I) OUTFALL NUMBER INHD081257446 025C CONTINUED FROM PAGE V-8 I T 1 2. MARK"X"3. EFFLUENT i 4. UNITS 1 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30DAYVALUE c, LONGTERM AVRG. t a. LONG TERM o AND a. b. c. a. MAXIMUM DAILY VALUE (if available)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) [ d. NO. OF a. CONCEN- (1) b. NO. OF (([available)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GCIMS FRACTION -PESTICIDES (cotiued)17P. Heptachlor /Epoxide ,><, (1024-57-3) 18P. PCB-1242 (53469-21-9)

X 19P. PCB-1254 k/(11097-69-1) 20P. PCB-1221 X/(11 !04-28,2) 21P. PCB-1232 (11141-16-5)

X 22P. PCB-1248 %/(12672-29-6)

A 23P. PCB-1260 (11096-82-5)

X 24P. PCB-1016 (12874-11-2) 25P, Toxaphene (8001-35-2)

X GCIMS FRACTION -PESTICIDES (continued) 17P. Heptachlor Epoxide (1024-57-3) 18P. PCB-1 242 (53469-21-9) 19P. PCB-1254 (11097-69-1) 20P- PCB-1221 (11104-28-2) 21P PCB-1232 (11141-16-5) 22P. PCB-1248 (12672-29-6) x_ __23P. PCB-1260 (11096-82-5) x _ __ _24P. PCB-1016 (12674-11.2) x _25P. Toxaphene EPA0Form35-2) 2 (89)PGx-EPA Form 3510-2C (8-90)

PAGE V-9 Out fall 025C PLEASE PRINT OR TYPE IN THE UNSHADED AREAS ONLY. You may report some or all of this information EPA I.D. NUMBER (copy from Item I of Form I)on separate sheets (use the same format) instead of completing these pages.SEE INSTRUCTIONS.

NHD081257446 V. INTAKE AND EFFLUENT CHARACTERISTICS (continued from page 3 of Form 2-C)OUTFALL NO.

025D PART A -You must provide the results of at least one analysis for every pollutant in this table. Complete one table for each outfall. See instructions for additional details.3. UNITS 4. INTAKE 2. EFFLUENT (specify if blank) (optional)

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM a. MAXIMUM DAILY VALUE (if available) (if available)

AVERAGE VALUE[11 (1) d. ND. OF a. CONCEN- (l) b. NO. OF 1. POLLUTANT CONCENTRATION (2) MASS CONCENTRATION (2) MASS (1) CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES a. Biochemical Oxygen ND1 Demand (BOD)b. Chemical Oxygen ND 1 Demand (COD)c. Total Organic Carbon (TOC) 1.1 0.11 i 1 mg/L ibs/d d. Total Suspended Solids (TSS) ND e. Ammonia (as N) 0.72 0.07 1 mg/L lbs/d VALUE VALUE VALUE VALUE f. Flow 12,307 1 GPD g. Temperature VALUE VALUE VALUE VALUE (winter) IC h. Temperature VALUE VALUE VALUE VALUE (summer) 32 1 MINIMUM MAXIMUM MINIMUM MAXIMUM i.pH 75 7.5 1 STANDARD UNITS PART B -Mark "X" in column 2-a for each pollutant you know or have reason to believe is present. Mark "X" in column 2-b for each pollutant you believe to be absent. If you mark column 2a for any pollutant which is limited either directly, or indirectly but expressly, in an effluent limitations guideline, you must provide the results of at least one analysis for that pollutant.

For other pollutants for which you mark column 2a, you must provide quantitative data or an explanation of their presence in your discharge.

Complete one table for each outfall. See the instructions for additional details and requirements.2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

VALUE a. LONG TERM AVERAGE AND a. b. a. MAXIMUM DAILY VALUE (ifavailable) (ifavailable)

VALUE CAS NO. BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2)

MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES a. Bromide (24959-67-9)

X b. Chlorine, Total Residual _ X c. Color X d. Fecal Coliform e. Fluoride (16984-48-8)

_f. Nitrate-Nitrite (as All EPA Form 3510-2C (8-90)PAGE V-1 Outfall #025D CONTINUE ON REVERS ITEM V-8 CONTINUED FROM FRONT2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional 1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AND b. a. MAXIMUM DAILY VALUE (ifavailable) (ifavailable)

AVERAGE VALUE CAS NO. BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES g. Nitrogen, 1 Total Organic (as ND N) __ I _ _ _ __ _ _ _ _h. Oil and X 1 Grease xD i. Phosphorus (as P). Total (7723-14-0)

X j. Radioactivity (1) Alpha, Total x ND 1 pCi/kg (2) Beta, Total X 1199 1 pCi/kg (3) Radium, Total X (4) Radium 226, Total ___k. Sulfate (as SO,) 36 ND 1 (14808-79-8)

_I. Sulfide ND (as) _-__D_1 m. Sulfite (as SOA)(14265-45-3) x n. Surfactants; ND o. Aluminum, Total (7429-90-5) x p. Barium, Total (7440-39-3) x q. Boron, Total N220 22.6 1 Mg/L lbs/d (744042-8)

.220 22.6 1 mg/_ ibs/d r. Cobalt. Total ND (7440-48-4) ..xD 1 S. Iron, Total 0.05 0.01 1 g/L lbs/d (7439-89-6)

__0.05 0.01 1 mg/L ibs/d t. Magnesium.

Total _(7439-95-4)

u. Molybdenum, Total (7439-98-7) x v. Manganese.

Total > ND (7439-96-5)

w. Tin, Total (7440-31-5)

_x x. Titanium, Total _(7440-32-6) x I EPA Form 3510-2C (8-90)PAGE V-2 Outfall #025D CONTINUE ON PAGE V-3 0 EPA I.D. NUMBER (copy from hem I of Form 1) OUTFALL NUMBER NHD081257446 025D I CONTINUED FROM PAGE 3 OF FORM 2-C PART C -If you are a primary industry and this outfall contains process wastewaler, refer to Table 2c-2 in the instructions to determine which of the GC/MS fractions you must test for. Mark "X" in column 2-a for all such GC/MS fractions that apply to your industry and for ALL toxic metals, cyanides, and total phenols. If you are not required to mark column 2-a (secondary industries, nonprocess wastewater outfalls, and nonrequired GC/MS fractions), mark "X" In column 2-b for each pollutant you know or have reason to believe is present. Mark "X in column 2-c for each pollutant you believe is absent. If you mark column 2a for any pollutant, you mus provide the results of at least one analysis for that pollutant.

If you mark column 2b for any pollutant, you must provide the results of at least one analysis for that pollutant if you know or have reason to believe it will be discharged in concentrations of 10 ppb or greater. It you mark columrn 2b for acrofein, acrylonitrile, 2,4 dinitrophenol, or 2-methyl.4, 8 dinitrophenol, you must provide the results of at least one analysis for each of these pollutants which you know or have reason to believe that you discharge in concentrations of 100 ppb or greater. Otherwise, for pollutants for which you mark column 2b, you must either submit at least one analysis or briefly describe the reasons the pollutant is expected to be discharged.

Note that there are 7 pages to this part; please review each carefully.

Complete one table (all 7 pages) for each outfall. See instructions for additional details and requirements.2. MARK "X 3. EFFLUENT 4. UNITS 5. INTAKE (oprional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c LONG TERM AVRG. a. LONG TERM AND b. a. MAXIMUM DAILY VALUE (ifavilable)

VALUE (i1available)

AVERAGE VALUE CA NMBR TESTING BELIEVED BELIEVED (1 1 1 I d O Fa OCN (1) Ib.O.F (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS T O (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE METALS, CYANIDE, AND TOTAL PHENOLS IM. Antimony.

Total ND 1 (7440-36-0)

X ND 1 2M. Arsenic, Total ND (7440-38-2)

.ND 1 3M. Beryllium, Total XND (7440-41-7) ..ND 1 4M. Cadmium, Total ND 1 (7440-43-9)

.5M. Chromium, N1 Total (7440-47-3)

ND1 6M. Copper, Total (7440-50-8)

X ND 1 7M. Lead, Total ND (7439-92-1)

X 8M. Mercury, Total 1 N (7439-97.6)

ND 1 9M. Nickel, Total ND (7440-02-0)

/\10M. Selenium, 1 Total (7782-49-2)

ND 11M. Silver, Total ND (7440-22-4)

.ND 1 12M. Thallium,V Total (7440-28-0)

A ND 1 13M. Zinc, Total 0.04 <0.01 1 mg/L lbs/d (7440-66-6)

._ 0.04 <0.01 1 mg/L ibs/d 14M. Cyanide, ND Total (57-12-5)

ND 15M. Phenols, Total -1 DIOXIN I X DESCRI1BE RESULTS chlorodibenzo-P-Dioxin (1764-01-6)

EPA Form 3510-2C (8-90)PAGE V-3 Outfall #025D CONTINUE ON REVERSE CONTINUED FROM THE FRONT 2. MARK 'X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE C. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (if available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED C NBELICEOVED MASSCONENTd.

NO( OF a. CONCEN (1) M C E T NO. OF (if available)

REQUIREDI PRESENT ABETCONCENTRATIONI (2) MASS COCNRTO (2) MASS NLSS TRATION 1b. MASS CONCENTRATION1 (2) MASS GC/MS FRACTION -VOLATILE COMPOUNDS IV. Accrolein (107-02-8)

ND .2V. Acrylonitrile (107-13-1) x ND 1 3V. Benzene (71.43-2)

ND 4V. Bis (Chloro-methyl) Ether ND 1 (542-88-1)

_5V. Bromoform N (75-25-2)

ND 1 6V. Carbon Tetrachloride ND 1 (56-23-5) x 7V. Chlorobenzene N (108-90-7) x ND 1 8V. Chlorodi-bromomethane ND 1 (124-48-1) x 9V. Chloroethane (75-00-3)

ND 1 1OV. 2-Chloro-ethylvinyl Ether ND 1 (110-75-8)

ND 1 IV. Chloroform

\(67-66-3)

ND 1 12V. Dichloro-bromomethane ND 1 (75-27-4) x ND 13V. Dichloro-difluommethane A ND 1 (75-71-8)14V. 1,1-Dichloro-N ethane (75-34-3)

ND I 15V. 1,2-Dichloro-ND ethane (107-06-2) x ND 1 16V. 1,1-Dlchloro-.

ND ethylene (75-35-4) x __ _17V. 1,2-Dlchloro-ND 1 propane (78-87-5)

ND 1 18V. 1,3-Dichloro-propylene ND 1 (542-75-6)

_19V. Ethylbenzene (100_41-4) x " ND 1 20V. Methyl ND Bromide (74-83-9)

ND 21V. Methyl ND Chloride (74-87-3)EPA Form 3510-2C (8-90)PAGE V-4 Outfall #25DCONTINUE ON PAGE V-5 CONTINUED FROM PAGE V-4 2. MARK X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE C. LONG TERM AVRG. e. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (i[available)

VALUE ([available)

AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED d.(1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATIONI (2) MASS CONCENTRATIONI

2) MASS CONCENTRATION (2) MASS ANALYSES TRATIONMASS ASS CONCENTRATIONI (2) MASS ANALYSE GC/MS FRACTION -VOLATILE COMPOUNDS (continued) 22V. Methylene 1 Chloride (75-09-2)

ND 23V. 1,1,2.2-Tetrachloroethane ND 1 (79-34-5)24V. Tetrachloro-ethylene (127-1 B-4) ND 1 25V. Toluene D (108-88-3) xND1 26V. 1,2-Trans-Dichloroethylene x ND 1 (156-60-5) 27V. 1,1,I-Trichloro-ethane (71-55-6)

ND 1 28V. 1,1,2-Trichloro-ND 1 ethane (79-00-5)

ND 29V Trichloro-ethylene (79-01-6)

ND 1 30V. Trichloro-fluoromethane ND 1 (75-69-.4) 31V. Vinyl Chloride N (75-01-4) xND GC/MS FRACTION -ACID COMPOUNDS 1A. 2-Chlorophenol ND (95-57-8)

ND 1 2A. 2,4-Dichloro-N phenol (120-83-2)

ND 1 3A. 2,4-Dimethyl-1 phenol (105-67-9)

N ND 4A. 4,6-Dinitro-O-Cresol (534-52-1)

ND 1 5A. 2,4-Dinitro-ND phenol (51-28-5)

Nx__6A. 2-Nitrophenol ND (88-75-5) x ND i 7A. 4-Nitrophenol ND (100-02-7)

NDi 8A. P-Chloro-M-NDCresol (59-50-7)

ND 9A. Pentachloro-N phenol (87-86-5) x ND 10A, Phenol ND (108-95-2)

ND 1 11 A. 2.4,6-Trichloro-N phenol (88-05-2)

ND 1 EPA Form 3510-2C (8-90)PAGE V-5 Out fal~l #025D CONTINUE ON REVERSE CONTINUED FROM THE FRONT 2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a. LONG TERM AND a. b. c a. MAXIMUM DAILY VALUE (tfavailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) [ (1) (1) d. NO. OF a. CONCEN- (1) b NO. OF (ifavailable)

REQUIRED PRESENT ASSENT CONCENTRATION1 (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2)MASS ANALYSES TRATION

b. MASS CONCENTRATION1 (2) MASS ANALYSEGCIMS FRACTION

-BASE/NEUTRAL COMPOUNDS 1B. Acenaphthene (83-32-9) x NOD128. Acenaphtylene (208-96-8) x ND 1 38. Anthracene

\(120-12-7)

ND 1 48. Benzidine (92-87-5)

ND 1 58. Benzo (a)Anthracene X ND 1 (56-55-3)68. Benzo (a)Pyrene (50-32-8) x ND 1 78. 3,4-Benzo-fluoranthene ND 1 (205-99-2) xN 88. Benzo (ghi)Perylene (191-24-2)

.ND 1 98. Benzo (k)Fluoranthene ND 1 (207-08-9) x ND 10B. Bis (2-Chloro-ethoxy) Methane ND 1 (111-91-I)

__ND 118. Bis (2-Chloro-ethyl) Ether (111-44-4) x NO 128. Bis (2-Chloroisopropyl)

X ND 1 Ether (102-80-1)

_ ND13B. BIs (2-Ethyl-hexyl) Phthalate ND (117-81-7) x 14B. 4-Bromophenyl Phenyl Ether ND 1 (101-55-3) 158. Butyl 8enzyl 1 Phthalate (85-68-7) x ND 168. 2-Chloro-naphthalene ND 1 (91-58-7)178. 4-Chloro-phenyl Phenyl Ether ND 1 (7005-72-3)

ND 188. Chrysene N1 (218-01-9) x ND 198. Dibenzo (ah)Anthracene N (53-70-3) xND1 208. 1,2-Dichloro-ND benzene (95-50-1)

.ND 1 21B. 1,3-Di-chloro-1 benzene (541-73-1)

NDEPA Form 3510-2C (8-90)

PAGE V-6 Outfall #025DCONTINUE ON PAGE V-7 CONTINUED FROM PAGE V-62. MARK "X_ 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT lb. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM CAS NUMBER TESTING BELIEVED BELIEVED (1) (1) [.d. NO. OF a. CONCEN- (1)b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2)

MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 22B. 1,4-Dichloro-benzene (106-46-7) xN 1 23B. 3,3-Dichloro-N benzidine (91-94-1)

N 1 24B. Diathyl N Phthalate (84-66-2)

ND 125B. Dimethyl Phthalate ND 1 (131 3) x 26B. Di-N-Butyl N Phthalate (84-74-2)

ND 1 27B. 2,4-Dinitro-N toluene (121-14-2)

ND 1 28B. 2,6-Dinitro-N toluene (606-20-2)

ND 1 29B. Di-N-Octyl N Phthalate (117-84-0)

ND 1 30B. 1,2-Diphenyl-hydrazine (as Azo- ND benzene) (122-66-7) xD 1 31B. Fluoranthene ND (206-44-0)

ND x.32B. Fluorene IND (86-73-7)

ND 1 338. Hexachloro-N benzene (118-74-1)

ND 1 34B. Hexachloro-1 butadiene (87-68-3)

ND 35B. Hexachloro-cyclopentadiene N1 (77-47-4) x 368 Hexachloro-ethane (67-72-1)

ND 137B. Indeno (1,2,3-cd)

Pyrene ND 1 (193-39-5) x 38B. Isophorone ND (78-59-1)

ND 1 39B. Naphthalene ND (91-20-3)

ND x 40B. Nitrobenzene 1 (98-95-3) x 1 41B. N-Nitro-sodimethylamine ND (62-75-9)42B. N-Nitrosodi-N-Propylarnine ND (621-64-7) xNIID EPA Form 3510-2C (8-90)PAGE V-7 CONTINUE ON REVERSE Outfall #02SD CONTINUED FROM THE FRONT A T 2. MARK "X 3..EFFLUENT

4. UNITS 5. INTAKE (optional) 1.POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. C. a. MAXIMUM DAILY VALUE (ifaalbe VALUE (ifavailable)

AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED (11 1 d. NO. OF a. CONCEN- b. NO. OF AN(aM 1IU DILVAU (i1a)iabe VALU (faalbl)AE)G AU (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION1 (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued) 43B. N-Nitro-sodiphenylamine X ND .(86-30-6)44B. Phenanthrene

\(85-01-8)

ND 1 45B. Pyrene N (129-00-0)

ND 1 46B. 1.2,4-Tri-chlorobenzene ND 1 (120-82-1)

NDx1 GC/MS FRACTION -PESTICIDES I P. Aldrin (309-00-2) x _, 2P. a-BHC (319-84-6)

/x 3P. p-BHC (319-85-7) x 4P. T-BHC (58-89-9) x 5P. 6-BHC (319-86-8) x 6P. Chlordane (57-74-9) x7P. 4,4'-DDT (50-29-3)

__x BP. 4,4'-DDE (72-55-9) x 9P. 4.4'-DDD (72-54-8) x loP. Dieddnin (60-57-1) x I 1P. a-Enosulfan (115-29-7)

/x 12P. f3-Endosulfan (115-29-7)

/x 13P. Endosulfan Sulfate (1031-07-8)

_14P. Endrin (72-20-8)

_15P. Endrin Aldehyde (7421-93-4) x 16P. Heptachlor (76-44-8)

_EPA Form 3510-2C (8-90)PAGE V-8 CONTINUE ON PAGE V-9 Outfall #025D EPA I.D. NUMBER (copyfroin Item I ofForm 1) OUTFALL NUMBER NHD081257446 025D CONTINUED FROM PAGE V-8 2. MARK "X" 3. EFFLUENT I 4 UNITS I 5 INTAKF tim~l1 3.EF L EN. UNITTAN .. .........

IN AK -r ......I.POLLUTANT

.b. MAXIMUM 30 DAY VALUEI C. LONG TERM AVRG.

a. LONG TERM AND C. a. MAXIMUM DAILY VALUE (if available)

VALUE (if available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION1 (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSEGCIMS FRACTION

-PESTICIDES (continued) 1 7P. Heptachlor Epoxide (1024-57-3) 18P. PCB-1242 (53469-21-9) x19P. PCB-1254 (11097-69-1) 20P. PCB-1221 (11104-28-2) x 21P. PCB-1232 (11141-16-5) 22P. PCB-1 248 (12672-29-6) x 23P. PCB-1260 (11096-82-5) x 24P. PCB-1016 (12674-11-2) 25P Toxaphene (8001-35-2) x EPA Form 3510-2C (8-90)PAGE V-9 Outfall #025D r ,11 PLEASE PRINT OR TYPE IN THE UNSHADED AREAS ONLY. You may report some or all of this information EPA I.D. NUMBER (copyfrom Item I of Fora, I)on separate sheets (use the same format) instead of completing these pages.

NHD81257446 SEE INSTRUCTIONS.

I 8I V. INTAKE AND EFFLUENT CHARACTERISTICS (continued from page 3 of Form 2-C))UTFALL NO.027 PART A -You must provide the results of at least one analysis for every pollutant in this table. Complete one table for each outfall. See instructions for additional details.3. UNITS 4. INTAKE 2. EFFLUENT (specify ((blank) (optional)

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

VALUE a. LONG TERM a. MAXIMUM DAILY VALUE (Jravailable)

(1(available)

AVERAGE VALUE (1) (1) d. NO. OF a. CONCEN-(1) b. NO. OF 1. POLLUTANT CONCENTRATION (21 MASS CONCENTRATION (2) MASS (1) CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSES a. Biochemical Oxygen ND 1 Demand (BOD)b. Chemical Oxygen 14 10.0 1 mg/L lbs/d Demand (COD)c. Total Organic Carbon (TOC) 1.1_ 0.78 1 mg/L ibs/d d. Total Suspended Solids (TS) 1.6 1.14 1 mg/L lbs/d e. Ammonia (as M) ND 1 VALUE VALUE VALUE VALUE f.Flow 85,276* 1 GPD g. Temperature VALUE VALUE VALUE VALUE (winter) I h. Temperature VALUE VALUE VALUE VALUE (summer) 22 C MINIMUM MAXIMUM MINIMUM MAXIMUM i. pH 8.2 8.2 1 STANDARD UNITS PART B -Mark "X" in column 2-a for each pollutant you know or have reason to believe is present. Mark X In column 2-b for each pollutant you believe to be absent. It you mark column 2a for any pollutant which is limited either directly, or indirectly but expressly, in an effluent limitations guideline, you must provide the results of at least one analysis for that pollutant. For other pollutants for which you mark column 2a, you must provide quantitative data or an explanation of their presence in your discharge.

Complete one table for each outfall. See the instructions for additional details and requirements.

2. MARK "X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AVERAGE AND a. b. a. MAXIMUM DAILY VALUE (ifavailable)

((.available)

VALUE CAS NO. BELIEVED BELIEVED (1) (1) (11 d. NO. OF a. CONCEN- b. NO. OF (i(available)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION (2) MASS ANALYSES a. Bromide 5.0 3.6 1 mg/L lbs/d (24959-67-9)

b. Chlorine, Total X Residual ND 1 c. Color X d. Fecal Coliform X e. Fluoride (16984-48-8) 1f. NitT'ate-Nitrite 0.61 1 mg/L lbs/d (asN) 0 0.43 I IbI/d EPA Form 3510-2C.(8-90)

• Average monthly flow; no discharge during sampling.PAGE V-i Outfall #027 CONTINUE ON REVERS ITEM V-B CONTINUED FROM FRONT 2. MARK"X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

I. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. VALUE a. LONG TERM AND a. b. a. MAXIMUM DAILY VALUE (ifavailable) (Qf available)

AVERAGE VALUE CAS NO. BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (if available)

PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION

b. MASS CONCENTRATION (2) MASS ANALYSES g. Nitrogen, \Total Organic (as ND 1 N)GrOland 1.0 0.71 1 mg/L lbs/d I. Phosphorus (as P), Total 0.22 0.16 1 mg/L ibs/d (7723-14-0) x J. Radioactivity (1) Alpha, Total x1 (2) Beta, total x (3) Radium, Total x_(4) Radium 226, Total x k. Sulfate (as SO,) 170 121 1 rg/ lbs/d (14808-79-8) 1 I. Sulfide ND (as S) ND__m. Sulfite (a" SO,) Ix (14265-45-3)

/\n. Surfactants x o. Aluminum, Total (7429-90-5)

p. Barium, Total (7440-39-3) x q. Boron, Total (7440-42-8) x r. Cobalt, Total (7440-48-4) x s. Iron, Total 0.5 00 'M/ b/(7439-89-6)

X 0.05 0.04 1 mg/L ibs/d t. Magnesium.

Total X 120 85.4 1 mg/L lbs/d (7439-954) x u. Molybdenum.

Total (7439-98-7) x v. Manganese, Totlx 0.01 0.01 1 Mg/ lbs/d w. Tin, Total (7440-31-5)

/x x. Titanium, Total x (7440-32-6) 8 EPA Form 3510-2C (8-90)PAGE V-2 CONTINUE ON PAGE V-3 EPA I.D. NUMBER (copyfrom Item I of Form I) OUTFALL NUMBER NHD081257446 027CONTINUED FROM PAGE 3 OF FORM 2-C PART C -If you are a primary industry and this outfall contains process wastewater, refer to Table 2c-2 in the instructions to determine which of the GC/MS fractions you must test for. Mark "X" in column 2-a for all such GCIMSfractions that apply to your industry and for ALL toxic metals, cyanides, and total phenols. If you are not required to mark column 2-a (secondary industries, nonprocess wastewater ouffalls, and nonrequired GG/MS fractions), mark "X" in column 2-b for each pollutant you know or have reason to believe is present. Mark "X" in column 2-c for each pollutant you believe is absent. If you mark column 2a for any pollutant, you mus provide the results of at least one analysis for that pollutant.

If you mark column 2b for any pollutant, you must provide the results of at least one analysis for that pollutant if you know or have reason to believe it will be discharged in concentrations of 10 ppb or greater. If you mark column 2b for acrolein, acrytonitrile, 2.4 dinitrophenol, or 2-methyl-4, 8 dinitrophenol, you must provide the results of at least one analysis for each of these pollutants which you know or have reason to believe that you discharge in concentrations of 100 ppb or greater. Otherwise, for pollutants for which you mark column 2b, you must either submit at least one analysis or briefly describe the reasons the pollutant Is expected to be discharged.

Note that there are 7 pages to this part; please review each carefully.

Complete one table (afl 7 pages) for each outfall. See instructions for additional details and requirements.

2. MARK "X" 3. EFFLUENT I 4. UNITS I 5. INTAKE

2. MARK"X` 3. EFFLUENT 1 4. UNITS 5 INTAKE (opt at)1. POLLUTANT AND CASNUMBER a.TESTING REQUIRED b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG.

a. LONG TERM b. c. a. MAXIMUM DAILY VALUE (if available)

VALUE (if available)

AVERAGE VALUE BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN-(1) b. NO. OF PRESENT ABSENT CONCENTRATION 1(2) MASS CONCENTRATION1 (2) MASS CONCENTRATION 1(2) MASS ANALYSES TRATION b. MASS CONCENTRATION1 (2) MASS ANALYSE LDIOXIN 2,3,.8-Ttra-X IDESCRIBE RESULTS chlorodibenzo-P-Dioxin (1764-01-61 EPA Form 3510-2C (8-90)PAGE V-3 Outfall #027 CONTINUE ON REVERSE CONTINUED FROM THE FRONT 2. MARK X 3. EFFLUENT

4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (if available)

VALUE (ifavailable)

AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED (1) (1) (1) d. NO. OF a. CONCEN- (1) b. NO. OF (if available)

REQUIRED PRESE=NT A13SENT CONCENTRATION (2) MASS CONCENTRATION

('2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -VOLATILE COMPOUNDS 1V. Accroleln (107-02-8)

ND 1 2V. Acrylonitnle

\(107-13-1)

ND 1 3V. Benzene N (71x43-2)

N_ _4V. Bis (Chloro-methyl) Ether > ND 1 (542-88-1)

)5V. Bromoform ND 1 (75-25-2)

ND 1 6V. Carbon Tetrachloride X ND 1 (56-23-5) x 7V. Chlorobenzene 1 (108-90-7)

ND BV. Chlorodi-bromomethane ND 1 (124-48-1)

I 9V. Chloroethane N (75-00-3)

ND1 IOV. 2-Chloro-ethylvinyl Ether ND 1 (110-75-8)

.I11 V. Chloroform (67-66-3) x ND 1 12V. Dichloro-bromomethane ND 1 (75-27-4)13V. Dichtoro-difluoromethane ND 1 (75-71-8) x 14V. 1.1-Dichloro-D ethane (75-34-3) _ __ _15V. 1.2-Dichloro-ND1 ethane (107-06-2) x ND 1 16V. 1,1-Dichloro-1ethylene (75-35-4)

ND 17V. 1,2-Dichloro-1propane (78-87-5)

ND 18V. 1,3-Dichloro-propylene ND 1 (542-75-6) x 19V. Ethylbenzene ND1 (100-41-4) x.20V. Methyl ND Bromide (74-83-9)

ND 1 21V. Methyl ND Chloride (74-87-3)

N DEPA Form 3510-2C (8-90)

PAGE V4 Outfall #027 CONTINUE ON PAGE V-5 0CONTINUED FROM PAGE V4 r I 2. MARK "X 3. EFFLUJENT I lIIIJT.5 I INTAI(F Intn~l 1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND b. c. a. MAXIMUM DAILY VALUE (ifavoilable)

VALUE (i(available)

AVERAGE VALUECAS NUMBER TESTING BELIEVED BELIEVED (1 (1)d. NO. OF a. CONCEN- b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION

[2) MASS ANALYSE GC/MS FRACTION -VOLATILE COMPOUNDS (continued) 22V. Methylene X Chloride (75-09-2)

ND 23V. 1.1,2,2-Tetrachloroethane ND 1 (79-34-5)24V. Tetrachloroz N ethylene (127-18-4)

N) 1 25V. Toluene (108-88-3) xD 1 26V. 1,2-Trans-Dichloroethylene ND 1 (156-60-5) x 27V. 1.1,1-Trichloro.

1 ethane (71-55-6)

ND 1 28V. 1,1,2-Trichloro-1 ethane (79-00-5)

ND 29V Trichloro-ethylene (79-01-6)

ND 1 30V. Trichloro-fluoromethane ND 1 (75-69-4)31V. Vinyl Chloride \ ND 1 (75-01-4)

_GC/MS FRACTION -ACID COMPOUNDS IA. 2-Chlorophenol X ND 1 (95-57-8) x 2A. 2,4-Dichloro-phenol (120-83-2)

ND 1 3A, 2,4-Dimethyl-Nphenol (105-67-9)

ND 1 4A. 4,6-Dinitro-O-N Cresol (534-52-1)

ND 1 5A. 2,4-Dinitro-ND 1 phenol (51-28-5)

ND 1 6A. 2-Nitrophenol ND (88-75-5) xD 1 7A. 4-Nitrophenol D (100-02-7)

ND SA. P-Chloro-M-NCresol (59-50-7)

ND 1 9A. Pentachloro-ND 1 phenol (87-86-5) x__1 10A. Phenol ND (108-95-2)

ND 1 1 1A. 2,4,6-Trichloro-N phenol (88-05-2)

ND EPA Form 3510-2C (8-90)PAGE V-5 CONTINUE ON REVERSE Outfall #027 CONTINUED FROM THE FRONT2. MARK X 3. EFFLUENT 4. UNITS 5. INTAKE (oplional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (if available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED B3ELIEVED (1 1 1 .N.O .CNEN-' (): NO. OF (iavailable)

RE PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS CONCENTRATION (2) MASS ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS 1B. Acenaphthene

\/(83-32-9)

ND 2B. Acenaphtylene (208-96-8) x ND 1 36. Anthracene (120-12-7) x ND 1 46. Benzidine (92-87-5)

ND 1 56. Benzo (a)Anthracene ND 1 (56-55-3) x ND 6B. Benzo (a)Pyrene (50-32-8) x ND 7B. 3,4-Benzo-fluoranthene ND (205-99-2) x 8B. Benzo (ghi) N1 Perylene (191,-24-2) xND 9B. Benzo (k)Fluoranthene ND 1 (207-08-9) 10B. Bis (2-Chloro-elhoxy) Methane X ND (111-91-1) x ND 1 116. Bis (2-Chloro-ethyl) Ether N (111-44-4) x ND I 12B. Bis (2-Chloroisopropyl.

X ND 1 Ether (102-80-1) x ND 13B. Bis (2-Ethyl-hexyl) Phthalate ND 1 (117-81-7) x 148. 4-Bnomophenyl Phenyl Ether ND 1 (101-55-3) x 15B. Butyl Benzyt 1 Phthalate (85-68-7)

ND 168. 2-Chloro-1 naphthalene ND 1 (91-58-7)17B. 4-Chloro-phenyl Phenyl Ether ND (7005-72-3) x 18B. Chrysene (218-01-9) x ND 19B. Dibenzo (ah)Anthracene ND (53-70-3) x20B. 1,2-Dichloro-N benzene (95-50-1)

ND 1 21B. 1.3-Di-chloro-1 benzene (541-73-1)

ND 1 EPA Form 3510-2C (8-90)PAGE V-6 Outfall #027 CONTINUE ON PAGE V-7 0 0 CONTINUED FROM PAGE V-6 2. MARK X" 3. EFFLUENT 4. UNITS 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (if available)

VALUE (if available)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED (1) (1) 112 d. NO. OF a. CONCEN- (1) b. NO. OF (iavaiable)

REQUJRED PRESENT ABSENT CONCENTRATION1

2) MASS CONCENTRATJON (2) MASS CONCENTRATIONd 2)MASS ANALYSES TRATION b.CMASS CONCENTRATION 21M) ANALYSE GC/MS FRACTION -BASE/NEUTRAL COMPOUNDS (continued)22B, 1.4-Dichloro-ND benzene (106-46-7) 1 23B. 3,3-Dichloro-1 benzidine (91-94.1) x ND 24B. Diethyl Phthalate (84-66-2)

ND .1 258. Dimethyl Phthalate 1 (131-11-3) xNDi 26B. Di-N-Bulyl 1 Phthalate (84-74-2) , ND 27B. 2,4-Dinitro.-

toluene (121-14-2)

ND 1 288. 2,6-Dinitro-toluene (606-20-2)

ND 29B. Di-N-Octyl 1 Phthalate (117-84-0)

ND 30B. 1,2-Diphenyl-hydrazine (as Azo- ND benzene) (122-66-7)

ND 31 B. Fluoranthene

\/(206-44-0) x ND i 328. Fluorene (86-73-7)

ND 1 33B. Hexachloro-benzene (I118-74-1) x 1 34B. Hexachloro-butadiene (87-66-3)

ND 35B. Hexachloro-cyclopentadiene X (77-47-4)

NDi 368 Hexachloro-1 ethane (67-72-1) x ND 378. Indeno (1,2,3-cd)

Pyrene ND (193-39-5)

ND 1 38B. Isophorone ND (78-59-1)

ND 1 39B. Naphthalene (91-20-3)

ND 1 408. Nitrobenzene D (98-95-3)

ND 418 N-Nitro-sodimethylamine ND (62-75-9)

ND 42B. N-Nitrosodi-N-Propylamine ND (621-64-7) xD EPA Form 3510-2C (8-90)PAGE V-7 Outfall #027 CONTINUE ON REVERSE CONTINUED FROM THE FRONT 2. MARK XX" 3. EFFLUENT 4. UNITS 5. INTAKE (optional) 1.POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING BELIEVED BELIEVED 0) c (1) (1) d. NO. OF a. CONCEN- b. NO. OF (ifavailable)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATION b. MASS ONC TI71 ASS ANALYSE GC/MS FRACTION -BASEINEUTRAL COMPOUNDS (continued) 43B. N-Nitro-sodiphenylamine ND (86-30-6) 1 448. Phenanthrene (85-01-8)

ND 1 45B. Pyrene N (129-00-0)

ND 46B. 1,2,4-Tri-chlorobenzene (120-82-1) x GC/MS FRACTION -PESTICIDES 1P. Aldrin (309-00-2) x 2P. a-BHC (319-84-6)

_3P. )1-BHC (319-85-7) x 4P. y-BHC (58-89-9) x 5P. 6-BHC (319-86-8) x 6P. Chlordane (57-74-9) x 7P. 4,4'-DDT (50-29-3)

./\8P. 4,4'-DDE (72-55-9) , x 9P. 4,4'-DDD (72-54-8) x 10P. Dieldrin (60-57-1) x 11P. a-Enosulfan (115-29-7) x 12P. 1-Endosulfan (115-29-7) x 13P. Endosulfan Sulfate (1031-07-8)

_14P. Endrin (72-20-8) x 15P. Endrin Aldehyde (7421-93-4) x 16P. Heptachlor (76-44-8) tX EPA Form 3510-2C (8-90)PAGE V-8 Outfall #027 CONTINUE ON PAGE V-9 EPA I.D. NUMBER (copyfrom Item 1 ofForm 1) OUTFALL NUMBER NHD081257446 027 CONTINUED FROM PAGE V-8 2. MARK "X*3. EFFLUENT i 4. UNITS i 5. INTAKE (optional)

1. POLLUTANT

b. MAXIMUM 30 DAY VALUE c. LONG TERM AVRG. a. LONG TERM AND a. b. c. a. MAXIMUM DAILY VALUE (ifavailable)

VALUE (ifavailable)

AVERAGE VALUE CAS NUMBER TESTING [BELIEVED1BEL`E'VED (1 t 1 d. NO. OF a.TRToCONCEN-b.MS () "ANLsb"N.O (i(available)

REQUIRED PRESENT ABSENT CONCENTRATION (2) MASS CONCENTRATION (2) MASS CONCENTRATION (2) MASS ANALYSES TRATIONCONCENTRATION (2) MASS GC/MS FRACTION -PESTICIDES (continued)

C E A N SS_17P. Heptachlor Epoxlde (1024-57-3) x 18P. PCB-1 242 (53469-21-9) 19P. PCB-1 254 X_(11097-69-1) x 20P. PCB-1221 (11104-28-2) x 21P. PCB-1232 (11141-16-5) x 22P. PCB-1248 (12672-29-6)

,,x 23P. PCB-1260 (11096-82-5)

_24P. PCB-1016 (12674-11-2)

,,_25P. Toxaphene (O001-35-2)

.I i EPA Form 3510-2C (8-90)PAGE V-9 Outfall #027 FPL Energy Seabrook proposes the following changes to the current NPDES Permit requirements.

Annotated NPDES Permit pages reflecting the proposed changes are attached following the change descriptions:

• Condensate Polishing System Outfalls 028A, 028B and 028C (Proposed new addition to Permit)FPL Energy Seabrook proposes to add three new outfalls to the NPDES Permit to establishMonitoring Requirements and Effluent Limitations for the Condensate Polishing System (CPS).The CPS was completed and initially operated in 2005 during the term of the current NPDES Permit as documented in the renewal application for the current NPDES Permit submitted in April 1998. It is an integral part of the Condensate System. The CPS is designed to remove dissolved and suspended impurities from the Condensate System that can cause corrosion and fouling of secondary components.

The system is normally maintained in a standby condition and is placed in operation to remove secondary system contaminants to support plant start up or to remove impurities introduced by a condenser tube leak.The CPS and the three proposed outfalls (028A, 028B and 028C) are described comprehensively in Tab 2 with the Form 2C information.

The proposed Monitoring Requirements and EffluentLimitations for the Condensate Polishing System (CPS) are attached with the annotated NPDES Permit pages.Toxicity Testing Frequency Adjustment (Ref. Permit pages 19, 20, 21, 29)FPL Energy Seabrook has performed quarterly Whole Effluent Toxicity testing since theeffective date of the current NPDES Permit. Toxicity test results have been submitted each quarter with the Discharge Monitoring Reports.

A table summarizing the results of toxicity testing 2002 -2006 is attached.

It is requested that the frequency of toxicity testing be adjusted from the current quarterly frequency to a semiannual frequency in accordance with Permit Part I.E. 1 "Special Conditions, Whole Effluent Toxicity Test Frequency Adjustment" which states the following:

The permittee may submit a written request to the EPA requesting a reduction in the frequency (to not less than twice per year) of required toxicity testing, after completion of a minimum of eight (8) successive toxicity tests of effluent all of which must be valid tests and must demonstrate acceptable toxicity.

Until written notice is received by certified mail from the EPA indicating that the Whole Effluent Testing requirement has been changed, the permittee is required to continue testing at the frequency specified'in the respective permit.Permit Changes, p. 1 Seabrook Station believes that the required condition for a frequency adjustment has been satisfied: "eight (8) successive toxicity tests of effluent all of which must be valid tests and must demonstrate acceptable toxicity':

The attached table summarizes the results of 17 consecutive quarterly Whole Effluent Toxicity Tests, including 168 chronic and acute assays.Approximately 95% (of the reported assays (159/168) exhibit no toxicity in either acute orchronic tests, while 9\ assays or approximately 5% indicate some degree of toxicity to the test species. The permit does not establish the threshold for acceptable toxicity; those valuesrequiring reporting are "Report" only. While there have not been eight successive tests with no observed toxicity the data in total supports a general conclusion that the effluent is not toxic.Seabrook Station proposes that the Whole Effluent Toxicity test frequency be adjusted to semiannual.

The four quarterly discharge scenarios for Outfalls 025 A, B, C and D are proposed to be applied to the semiannual tests thus each of the four specified discharge scenarios will be tested every two years versus every year.9 Chlorine Transit Study (Ref. Permit page 21)FPL Energy Seabrook performed six Chlorine Transit Studies during the term of the current NPDES Permit ("a minimum of twice per year for the first three years of the permit").

It isproposed that the current NPDES Permit requirement to perform Chlorine Transit Studies be removed based on the satisfactory completion and results of the six studies performed.

The results of each of the six studies were reported individually and were summarized in a final report submitted on May 16, 2005. The final report concluded: "the overall results of sixchlorine transit studies demonstrates that the NPDES Permit Total Residual Oxidant (chlorine) limits, as measured at the Circulating Water System Discharge Transition Structure (Outfall 001), are sufficiently stringent to ensure that the New Hampshire chronic and acute water-quality standards for chlorine are met in the receiving waters. The six studies demonstrated that theresidual chlorine concentration at a distance of ten feet from the diffuser nozzle was below the minimum detection level (0.05 mg/L) with one exception at 0.06 mg/L. At a distance beyond tenfeet further significant reduction in chlorine concentration can be expected in the buoyant rapid mixing conditions of the thermal plume." The six Chlorine Transit Study dates were: November 12, 2002 March 26, 2003 October 9, 2003 April 19, 2004 October 14, 2004 March 17, 2005 Evaluation of Screen Wash Efficiency (Ref. Permit page 22)FPL Energy Seabrook conducted a screen wash efficiency study on May 18, 2006 using dead fish as required by the current NPDES Permit. The results of the Screen Collection Efficiency Study are provided below. The study results indicate that the collection efficiency of the travelling screens and impingement sample collection process is very high consistent withimpingement monitoring program assumptions.

It is proposed that the current NPDES PermitPermit Changes, p. 2 requirement to perform screen wash efficiency studies be removed based on the results of this study.* Outfalls 025C and 025D Oil and Grease Monitoring Requirement (Ref.Permit pages 13, 14)FPL Energy Seabrook proposes to revise the current NPDES Permit Monitoring requirement for Outfalls 025C and 025D oil and grease from the current "l/Batch" to "1/Quarter".

The proposed change to quarterly oil and grease monitoring will make the oil and grease monitoring frequency for Outfalls 025C and 025D consistent with Outfalls 025A and 025B, currently monitored on a quarterly frequency.

Outfalls 025C and 025D are consistently below the detection level for oiland grease as documented in the Discharge Monitoring Reports. During the term of the current permit all but three oil and grease analyses for Outfalls 025C and 025D have been below the detection level. The three oil and grease analyses that were above the detection level were less than one half of the NPDES Permit limit.2006 025C and 025D oil and grease below detection level 2005 November 025D monthly average 2.0 mg/L (15 mg/L permit limit), daily maximum 9.6 mg/L (20 mg/L permit limit)2004 025C and 025D oil and grease below detection level 2003 025C and 025D oil and grease below detection level 2002 July 025C monthly average 5.6 mg/L (15 mg/L permit limit), daily maximum 6.0 mg/L (20 mg/L permit limit)2002 August 025C monthly average 1.3 mg/L (15 mg/L permit limit), daily maximum 3.1 mg/L (20 mg/L permit limit)The performance of oil and grease analyses on Outfalls 025C and 025D by EPA Method 1664 results in the generation of radioactively contaminated hexane, a mixed waste.

The oil and grease sample waste from these outfalls contains very low levels of radioactivity due to its presence in the outfall discharge at levels well within the effluent limits prescribed by theNuclear Regulatory Commission. Hexane is present in the sample waste as it is used as a solventin the analytical method. It is estimated that four gallons of mixed waste are generated annually.In the interest of minimizing the generation of waste and the associated storage/incineration environmental risk it is suggested that the quarterly frequency of analyses is appropriate commensurate with the very low risk of an oil & grease discharge from the outfalls.* Dynacool 1383 Antiscalant Concentration (Ref. EPA Letter dated January 27, 2004 and NIDES Letter dated January 30, 2004, NPDES Permit Attachment C, Bulk Chemicals)

FPL Energy Seabrook proposes to revise the current NPDES Permit concentration limit for the antiscalant product Dynacool 1383. The referenced EPA and NHDES letters approved the discharge of this product at a concentration of .1 mg/L at Outfall 001. The product is currently used to control scale formation in the Circulating Water Chlorination System and in groundwater removal systems designed to control groundwater infiltration in site buildings.

To further Permit Changes, p. 3 enhance scale formation control, FPL Energy Seabrook proposes to increase the allowed concentration of Dynacool 1383 from. 1 mg/L to 5.0 mg/L. The referenced letters document thevery low aquatic toxicity of this "essentially non-toxic" product (96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> LC-50 for mysid shrimp > 5,000 mg/L).

The recommended concentration (5.0 mg/L) is 0.1 percent of the mysid shrimp LC-50.Biological and Water Quality Monitoring Program (Ref. Permit Pages 22, 25)FPL Energy Seabrook proposes to revise the current NPDES Permit requirement to submit a description of the Biological and Water Quality Monitoring Program. A written description of the program was previously submitted on May 1, 2002. No changes to the monitoring program have been requested thus it is proposed that the NPDES Permit be revised to reference the current description of the monitoring program.

FPL Energy Seabrook proposes to revise the current NPDES Permit description of the report submittal requirements for the ongoing biological, hydrological and chlorination programs.

The proposed change is for clarity and consistency with the requirement to submit the annual Environmental Monitoring Report by September 1.Permit Changes, p. 4 Seabrook Station Whole Effluent "1'o-ty Test Results (2002-2006)

Jun04 Jul04 1Oct04 Feb5 Jun05 Aug05 Nov05 Feb06 I May01 Jul02 1 Nov02 Jan03 Apr03 Aug03 Dec03 Feb04 July06-l r. 1 1 I 1 I- t------l---l -----------+ I- I + I Amedcamysis bohla nysld shrimp)LC-50 "100% ! 100% > 100%

>100% >100% 0100%

10100 '100% , 10% l 100% '10100% 100% n10%

• 100% > 100% 1 100%A-NOEC 12.5% 100%

100% 100% 100% 100% 100%

100% 100% 100%

100% 100% 100% 100% 100%

100% 100%Menida beryllina I (inland sltverside)

______-;I -DD 107.% v1001% >100% __ _LC-50 '100% '100%

>100% '100% >100% >97.5%

• 10100 1 > 100% > 100%

>100% >100% >100% > 100% > 100% >100% >o100%A-NOEC 100% 100% T o0% 100% 100%

-7.5' 100% 100% 100% 100% 100% 100% 100% 100%

100% 100% I 100%Menlda boryina (inland silverside)

Survival C-NOEG 100% 100% 100% 100% 100% 97.5' 100% 100% 100% 100% 100% 100%

100% 100% 100% 100% 100%Survival LOEC >100% >100%

'100% >100% >100% '97.5% >100% >100% v 100% > 100% > 100% > 100% >v100%

>100% > 100% > 100% *100%Growth C-NOEC 100% 100% 100% 100% 100%

97.5% 100% 12.5-9 100% 100% 100% 100% 100% 12.5%

100% 100% 100%Growth LO.C >1100% 100% '0>100% 100% >97.5% >'100% 25%' > 100% > 100% .100% >v100% > 100% 25% > 100% > 100%

>

• 100%Aracla punclulato (purple sea urchin)C-NOEC 1100 100% 1 100% 100% 1 IOD_ 100% 100% 12.5% 100% 100% 100% 100% 100%

1 ND' 100% o 6.25% 100%LUOL>100% I >100% I >100% >100% 1 100% 1 >100%'100%25%>.100% I 100% I>100%>10% I>100% I NL- I >100%6.25% 1

• 100%efltntlons LC-50 Effluent concentration that kills 50% of the test organismsA-NOEC Acute No Observed Effect Concentration or the highest tested effluent concentration that causes no significant mortality.C-NOEC No Observed Effect Concentration or the highest concentration where no effect -es observed.LOEC Lowest Obsetved Effect ConcentraUton orthe lorest tested effluent concentration that had an effect.No toxicity was observed nany of the December 2003 ho4e Effluent Toxiity Tests. The first and second renewaf samples for the Mervdtia beeyina assay were salinity edjusled per EPA protocol.

As a resunt of the sagnlty adjustment, the highest actual test concentration used for the eniddia be wyfina assay wa 97.5%. Thererore, the ncote LC50 and chrenic NOEL (No Observed Effect Level) for Menodia betyqla "ere reported as 97.5%.4o toxiciy "as observed in any ol Ore Decemer 2003 Whole Effluret Toxicity Tests. The .rst and seond renewal usIaplenfs for the MeoAea betytia assay "ere oinity adjusted per EPA protocol.

As a result of the safinity adjustmnt, the highest actual test concentration used for the Mtenrdia beytVlna assay ", 97.5%. Therefore, the aclte LC50 and chronic NOEL (NO Observed Effect Level) for Mrenidia berytia were reported as 97.5%.0 The validity of Orese results is in question because the higher eMuent concentrations tested (50% and 100%) did no0 exhibit toicity'Arbaca assays nr e not performed in Nov 05 due to hadequste supply of viable tent organisms.rhacia essays owre not pertormed it Nov 05 due to hadoquate supply of viable test orgardnsms SCREEN COLLECTION EFFICIENCY STUDIES SEABROOK STATION MAY 2006

Introduction:

The efficiency of the traveling screens and impingement sample collection process in retaining fish impinged on the traveling screens was estimated through a directed study on 18 May 2006 as a requirement of Seabrook Station's NPDES Permit. The purpose of this study was to estimate the percentage recovery of fish impinged on the traveling screens at Seabrook Station.Seabrook Station makes use of a once-through circulating water system with an offshore cooling water intake for both the condenser cooling water and the plant service water. There are three offshore submerged intake structures which are located approximately

1.3 miles

offshore and draw water from the western Gulf of Maine. The 19-ft ID intake tunnel conveys the water approximately 3.22 miles to an inland termination point which consists of a 19-ft ID vertical shaft and the transition structure.

Adjacent to the transition structure is the circulating water pumphouse where the collection efficiency studies took place.The water from transition structure enters the circulating water pumphouse and separates into three screenwells (Figure 1). Each screenwell contains stop log guides, a flow-through traveling screen and a 130,000 gpm circulating water pump that supplies circulating water to the condensers.

The three screens are designated as l-CW-SR-1A, 1B, and IC. Each screen is 14-ft. wide and has 3/4-in. mesh baskets. The water depth at the screens is approximately 43-ft.below MSL. The screens have two operating speeds which are 5 feet per minute (fpm) and 20fpm. Debris and fish are removed from the upstream (ascending) side of the screens with water sprays and are sluiced via a trough to a metal collection basket, where the debris is removed and the water drains into the intake transition structure.

Fish impinged on the traveling screens are retained in the collection basket, which has the same mesh size as the traveling screens.Impingement samples are collected twice per week to estimate the number of fish impinged annually.All fish impinged on the traveling screens are assumed to be enumerated as part of the impingement enumeration process. However, there are several locations and processes where fish could be lost to the collection process. Although the nominal mesh size in the traveling screens is 3/8-in. it is possible that holes exist in the mesh that would allow fish to pass through into the cooling water system of the plant. Fish can also be lost to the system through"carryover" of fish over the top of the traveling screens. Fish also can become stuck in the trough that leads from the traveling screen to the collection basket. Finally, fish can be missed inthe sorting process where the fisheries technician removes fish from debris in the collection basket.Methods and Materials At 0650 hrs on 18 May, 100 fish were dropped through the stop log slots in the floor of the circulating water pumphouse to the surface of the water approximately 10 feet in front of traveling screen 1-CW-SR-1B (the middle screen). These fish were collected from previous impingement samples to ensure that they would be representative of the species composition and size of fish currently being impinged.

Each fish was marked with a caudal fin clip to distinguish it from fish that were being collected as part of the concurrent impingement sample. Lengths ranged from 66-348 mm and species used were: alewife, cunner, grubby, rainbow smelt, sea raven, and winter flounder.

The screens were washed at 0825 hrs and fish with caudal fin clipswere removed from the impingement sample and counted.

Results and Discussion Of the 100 fish released, 98 were recovered yielding a screen collection efficiency of 98%.Screen collection efficiency is often assumed to be near 100% and this study quantitativelyevaluated this assumption.

Screen collection efficiency is usually high at nuclear power plants where the traveling screens and associated troughs are well maintained and inspected as part of the cooling water system. The very good condition of the traveling screens and sluices at Seabrook Station contributed to the high screen collection efficiency.

Furthermore, the relativelyshort distance and straight run of the sluice connecting the traveling screens and the collection basket also contributed to the high screen collection efficiency.CO.UN. WATER INTAKE STRUCTURE DATA INTAKE TRANSITION STRUCTURE AND PUMPHOUSE 3-6 Figure 1. Seabrook Nuclear Power Station intake transition structure and pumphouse.

• 9. .9.PARTI A. Effluent Limitations, Conditions, and Monitoring Requirements (Continued)-ZO. During the period beginning on the Effective Date and lasting through the Expiration Date, the permittee is authorized to discharge from outfall number serial 26D, Wr * ...t.. ..... Y...L Tc T -4wik oze6j C@O"8-*US&W?O JL1St*G< .AokcrnAgZAno,,)

IrAr.JV)a. Such discharges shall be limited and monitored by the pertnittee as specified below: Effluent Characteristic Discharge Limitations Monitoring Requirements Measurement Sample Avg. Monthly Max. Daily Frequency Type Flow, gpd Report +9@9e c oooO 1/Batch Estimate Oiland Grease, mg/* 15 20. -rBabte Grab Total Suspended Solids, mg/I 30 100 /Batchrab b... Samples taken in compliance with the monitoring requiretlients specified above shall be taken it a representative point.prior to mixing with any other waste stream.--A-hi-4--4*- AEC Re.2

?H49*2338'Page 44of 9 PARTi* A. Effluent Limitations, Conditions, and Monitoring Requirements (Continued) 2.1. Je During the period beginning on the Effective Date and lasting through the Expiration Date, the permittee is authorized to discharge from outfall number serial D, -Wste Te.. or.....

Rz.... "-9A T--6o14 Tn-Ozeso (:J~y o~s~.L~ oAJ~uc~h."#,r~Y

);;Q K a. Such discharges shall be limited and monitored by the pertnittee as specilied below: Effluent Characteristic Discharge Limitations Monitoring Requirements Measurement Sample Avg. Monthly Max. Daily Frequency TFlow, gpd Report 4O "90 91,, oca 1/Batch Estimate Oil and Grease, mg/1 15 20. -e GrabTotal Suspended Solids, mg/1 30 100 1/Batch Grab

b. Samples taken in compliance with the monitoring requireulents specified above shall be taken at a representative point prior to mixing with any other wasfe stream.A-14~A44- 14A10 Rev~.23 Aege 12 of9 PART I A. Effluent Limitations, Conditions, and Monitoring Requirements (Continued) 22.. )A During the period beginning on the Effective Date and lasting through the Expiration Date, the penmittee is authorized to discharge from outfall serial number OMBf, S... G,. e-,m n,,;tr Bic, Demineralizer Rinse.02a. SuChishagW peitLeSfied

a. Such discharges shall be limited andmonitored by the permittee as specified below: Effluent Characteristic Discharge Limitations Monitoring Requirements Measurbment" Sample-Freguency "Tye Avg. MondivlMax. Daily Flow, gpd Report Oil and Grease, mg/1 15 Total Suspended Solids, mg/l 305boS coo0 Continuous, 20 1/Quarter' 100 l/Week'.Estimate Grab Grab'This discharge is considered continuous, although the frequency and duratibn may vary depending on plant operation.

Therefore the frequency of measurement for flow is continuous when in use. The measurement frequency for TSS is onCe per discharge, and weekly if the dischaige continues for more than seven days. The discharge may be interrupted and restarted b'ut will still bie considered continuous, as long asfthe discharge is reinitiated within four hours of interruption.Samples taken in compliance with the monitoring requirements spenified above shall be taken at a representative point prior to mixing with any other waste stream.b..?hA.EC Rev 23-Permit No. NH0020338 Page 13 of 30 PART I A. Effluent Limitations, Conditions, and Monitoring Requirements. (Continued)

15. During the period beginning on the Effective Date and lasting through the Expiration Date, the permittee is authorizedto discharge from outfall serial number 025C, Waste Holdup Sump.a. 'Such dischargesshall be limited and monitored by the permittee as specified below:.Effluent Characteristic.

Discharge Limitations M onitoring Requirements Measurement Sample Avg. Monthly Max. Daily Frequency Tyne Flow, gpd Report 60,000 l/Batch Estimate Oil and Grease, mg/l 15 20 Grab Solids,,mgl1...

,30 .00- "iBalV -rab" , .r'b. Samples taken in compliance with the monitoring requirements specified above shall be taken at a representhtive point prior to mixing with any other stream.

Permit No. NHU0?20338

'Page 14of30.PART I;:A. Effluent Limitations, Conditions, and Monitoring Requirements (Continued)

16. During the period beginning on the Effective Date and lasting through the Expiration Date, the permittee is authorized to discharge from outfall number serial 025D, Waste Test or Recovery Test Tanks.a. Such discharges shall be limited and monitored by the pertnittee as specified below:Effluent Characteristic Discharge Limitations Monitoring Requirements Measurement Sample Avg. Monthly Max. Daily Frequency Type Flow, gpd Report 100,000 l/Batch Estimate Oil 'and Grease, mg/1 -15 20. 1/Bat", GrabTotal Suspended Solids, mg/l -30 100 1/Batch Grab b. Samples taken in compliance with the monitoring requirements specified above shall be taken at a representative point prior to mixing with any other waste stream.

A-14 NAEC Rev. 23 Permit No. NH0020338 Page 19 of 30 20. The chemicals listeid in Attachment C are approved, with limits, for water discharge..

The permittee may propose to conduct feasibility st.dies involving new chemicals not currently approved f6r water discharge.

The permnittee shall gain approval from the Regional Administrator and the Director before any such stddies take place. A report summarizing the results of any such studies shall be submi.tted to the Regional Administrator and the Director regarding discharge frequency, concentration, and the impact, if any, on the indigenous populations of the receiving water. The Regional Administrator or the Director may require Whole Effluent Toxicity testing.as part of feasibility studies.The permittee may substitute or add laboratory chemicals that are discharged in de minimis amounts without conducting feasibility studies. The permittee shall submit, to the Regional Administrator and the Director, relevant information on the proposed addition/substitution regarding toxicity, frequency of discharge, concentration, and anticipated impacts.

'This'submittal shalt include a certifidation that the proposed chemical(s) is not carcinogenic, mutagenic, teratogenic or will bioaccumnulate..

Prior approval from the Regional Administrator and the Director is not necessary before any such addition/substitution of laboratory chemicals takes place. The permittee will continue to employ its Best Management Practice procedures entitled"Disposal of Laboratory Chemicals and Reagents" for laboratory chemicals.

The penmttee may not use any laboratory chemicals that are carcinogenic, mutagenic, teratogenic or that will bioaccumulate.

No increase in chemical discharge concentrations, chemical substitution, or the use of additional chemicals is allowed without written approval by the Regional Administrator and the Director or their designees.

Laboratory chemical use is excluded from this requirement No use of chemicals that bioaccumulate is allowed.21. There shall be no visible discharge of oil sheen, foam, or floating solids in the vicinity of the diffuser ports. Naturally occurring sea foam in the discharge transition structure is allowed. Except in cases of condenser leak seeking and* sealing, use of a reasonable amount of biodegradable and non-toxic material may be used to the extent necessary to locate and/or seal any condenser leak.

The permittee shall report in the appropriate monthly DMR the occasions wherein this material was used giving the date(s) of the incident, the type of materials used and the amount of materials discharged.22. The permittee is required to report the results of chronic (and modified acute)WET tests using Inland Silverside (Menidia bervllina), acute WET tests using Mysid Shrimp.(M ysidosis hahia) and chronic Sea Urchin (Arbacia punctulata)

WET tests on a quarterly basis. A 24-Hour composite sample is the required"sample type" for WET testing. if eAe----:z " c zo m5plin. ---Fods Et;v-A-19 1NAEC Rev. 23 Permit No. NH0020339"Page 20 of 30 59e"),. fi -44 fcund, t -mEny r-Buz-t T int -,-, per yzc, The permitte, shahl use the procedures arid protocols.

contained in AttAhcbnent D to this permit when conducting the WET testing.the toxicity tests shall be peýformed at times when various chemicals and waste tanks are discharged at the -facility.

The perrnittee shall docum.ent and submit to EPA the various scenarios under which the toxicity test has been performed.

The permittee shall conduct quarterly tokicity testing as outlined below: Administfative controli shall be in-place to control these discharges according to the following restrictions: (a) NPDES Permit Outfalls 025 (A, B, C & D) will not be discharged during EVAC, mollusicide applications (expected frequency to be twice per year with a duration of up to about two days).(b)" When Outfall 025B (Steam Generator Blowdown rinses) is being discharged, n6ne of the other Outfall 025 can be discharged..

T Testing ......- .....Day.l Day 3 Day S (Acute and sample #1 for chronic) (sample #2 for chronic) (sample #3 for chronic)Outfalls 025A and 025C and 025D Outfalls 025A and 025B Outfalls 025A and 025B or or or EVAC Outfalls 025C and 0251) Outfalls 025C and 0251D Note: If EVAC is not applied during the quarteF, then 025A, 025C, and 025D shall be discharged.mnd sampled_Day 3 and Day 5 cover both "or".conditions.

For example: if Day 3 samples w=re obtained with 025A and 025B being discharged, thin Day 5 simples should be obtained with 025C and 025D being discharged.

.'AL WET Testing (A ,-Day I Day 3 Day 5 (Acute and sample #1 for chronic) (sample #2 for chronic) (sample #3 foi chronic)Outfalls 025A and 025B. Outfalls 025C or 025D Outfalls 025C oi 025D CnTese discharges shall not be concurrent) or EVAC..Note: If EVAC is not applied during the quarter, then 025A and 025B shall be discharged and sampled. Day 3 and Day 5 6over both "or" conditions.

For example: if Day 3 samples v.ere obt.ined-with 025C being discharged, then Day 5 samples shall be obtained with 025D being discharged.

A-20 NAEC Rev. 23 Permit No. NH002033 8 Page 21 of 30'&utter-#3 WET Testing (jl September)

Day I Day 3 Day S (Acute and sample #1 for chronic) (sample #2 for chronic) (sample #3 for chronic)Outfalls 025A and 025C and 025D Outfalls 025A and 0253 Outfalls 025A and 025B or or or.EVAC Outfalls 025C and 025D. Outfalls 025C and 025D Note: IfEVAC is not applied during the quarter, then 025A, 025C, and 025D shall be discharged and sampled. Day 3 and Day 5 cover both "or" conditions.

For example: if Day 3 samples were obtained with 025A and 025B.being Sdischarged, then Day 5 samples should be obtained with 025C and 025D being discharged.

____ WE Testing (t rReebr Day I Day 3 Day S (Acute and sampli #1 for chronic) (sample #2 for chronic) (sample #3 for chronic)* Outfalls 025A and 025C and 025D Outfalls 025B and 025C Outfalls 025C and 025D or or EVAC Outfalls 025B and 025D (These discharges shall not be -concurrent)

Note:

• IfEVAC is not applied during the quarter, then'025A, 025C, and 025D shall be discharged and sampled." Chlorine Transit Stu 'The permittee shall con ta "chlorine transi dy" a* minimum of t per year for the first thre ears of the permit. s study shall be based on e 1993 Chlorine Transit y performed at S ook Station. The studish aI mesure the TR- c enration at the Disc ge Transition

,,,cture and the correspon (aig into account transit time) TRO e Discharge Diff-user No (DDN). The study s be conducted d periods of low chlorine de dof the cooling water least one of thes dies shallbe conducted en the plant is shut do ad the effluent is heated.A-21 NAEC Rev. 23 Permit No. NH0020338Page 22 of 30 Thep ittee p 1 submit a study propos the Regional to d the Directo 306 after the effective d f this permit and yar tereafter.

The study s ., to the maximum exte possible,'

represent "wo case" situations.,the facility shall be c ggTRO, asm dat the Discharge ransiti on Structure (D ,as close to the permitt diy maximum as po ;le and the cooling wat shall be exerting its low chlorine demand. Up approval frodm gional Administrato d the Director, the pe shall implement e study and submit the r ts to the 'egional A strator and the hould any of the Chlo Transit Study results in ate that the permitte 0 concenýtration, as m~e tteDS is not s ciently stringent to e e that the chronic and a e water-quality s~tandar or chlorine are met e'DDN, this permit be reopened to incorpo cter Eimits./4. Biological and Water Quality Monitoring Program 25 a. The Biological and Water Quality Monitoring Program (BP) eR-b" submitted to EPA fer ..prv.. v.... in 30. ""*":- -ffeetiwe "e of Ps-- nit. Upen appo4. .&"o- EP$, BP is an enforceable element of this permit. This BP shall be based on the 1996-Biological and Water Quality Monitoring Program, except for the following alternative regimes which will replace those previously employed: (1) Intertidal Monitoring only will be implemented if Seabrook Station decides to employ back flushing of the Cooling Water System to control macrofouling.

Any such Intertidal Monitoring Program* will begin at least one year prior to back. flushing.(2) The Impingement.

MonitorLg.Program will be-oahamcedto include: oollecting two 24-hour impingement samples each week,*thz cvcluctkz ef szre wash uffisionsieo using dead.&* and. a sampling protocol for high impingement events.(3) Ichthyoplankton Entrainment Sampling Program will allow greater understanding of diel variability in ichthyoplankton densities and will include more definitive day-night sampling (4 x 2-hour samplings/week:

morning, day, evening, ffight), increased sample volume, and decreased net mesh size.A-22 NAEC Rev. 23 Permit No. NH0020338 Page 25 of 30 Within 30 days of authorization of biological program improvements, the permittee shall update and resubmit the Biological and Water Quality Monitoring Program to include any such improvements.

• Examples of BP improvements include, but are not limited to:.1. Additional sampling stations, 2. Increased sampling frequency, 3. Changes demonstrated to reduce data variability or increased analysis sensitivity, 4. Changes demonstrated to increase the power to detect statistical significance, 5. Collection of additional data demonstrated to more definitively

• determine Seabrook Station impacts, 6. Additional plidictive models such as species-specific population,.community, and/or trophic level risk.CLd. .iologica hydrological, and chlorination study reports shall be submitted'W Ga aem GG nnua101 bas~r, "ith th- aMnnllk repGrA~main the previou 5.869 ý informaio

_;nd oocuin.:Tho rOPort is u in Fýebruary.

• ---The semi-annual mid-year%epcrt shall, be a letter report providing the" status of the on-going.programs, the expected effort in the ensuing six months, and a synopsis of the data and information obtained since the last annual report. This report shall be submitted in July.e. Fish Mortality Monitoring and Reporting.

Any incidence of fish mortality associated with the discharge plume or of unusual number of fish impinged on the Intake Traveling.

Screens shall be ieported to the Regional Administrator and the Director-within 24-Hours by telephone report as required in Paragraph Il.D.l.e of this permit. A written confirmation report is to be provided within five (5) days. This report should include the following:

I. The species, sizes, and approximate number of fish involved in the incident A-25 NAEC Rev. 23 Permit No. NH0020338 Page 27 of 30 Duplicate signed copies of these, and all other reports required herein, shall be submitted*to the Regional Administrator and one signed copy to the State at the following addresses:

Environmental Protection Agency NPDES Program Operation Section P. 0. Box 8127 Boston, MA 02114The State Agency is: New Hampshire DES Water Division Permits and Compliance Section-&Hazen Drive, P.O. Box 95 Concord, New Hampshire 03302-0095 C. 'NOTIFICATION

1. All existing manufacturing, commercial, mining, and silvicultural dischargers must notify the Director as soon as they know or have reason to believe (40 CFR § 122.42): a. That any activity has occurred or will occur wviich would result in the discharge, on a routine or frequent basis, of any toxic pollutant which is not limited in the permit, if that discharge will exceed the highest of the following "notification levels:" (1) One hundred micrograms per liter (100 /zg/1);(2) Two hundred micrograms per liter (200Dg/1) for acrolein and acrylonitrile; five hundred micrograms per liter (500 /2g/1) for 2,4-dinitrophenol and for 2-methyl-4,6-dinitrophenol; and one milligram per liter (mg/I) for antimony;(3) Five (5) times the maximum concentration value rep6rted for that pollutant in the permit application in accordance with 40 CFR§122.21(g)(7);

or (4) Any other notification level established by the Director in accordance with 40 CFR §122.44(f) and New Hampshire regulations.

A-27 NAEC Rev. 23 Permit No. NH0020338 Page 29 of 30 2. This NPDES Discharge Permit is issued by the U.S. Environmental Protection Agency (EPA) under Federal and State law. Upon final issuance by the federal EPA, the New H~Inpshire Department of Environmental Services, Water Division, may adopt this permit, including all terms and conditions, as a State discharge permit pursuant to RSA 485-A: 13.Each agency shall have the independent right to enforce the terms and conditions of this Permit. Any modification, suspension or revocation of this Permit shall be effective only with respect to the Agency taking such action, and shall not effect the validity or status of this Permit as issued by the other Agency, unless and until each Agency has concurred in writing with such modification, suspension or revocation.

In the event any portion of this Permit is declared invalid, illegal or otherwise issued in violation of State law, such permit shall reniain in full force and effect under Federal law as an NPDP-S permit issued by the U.S.Environmental Protection Agency. In the event this permit is declared invalid, illegal or otherwise issued in violation of Federal law, this Permit, if adopted as a state permit, shall remain in full force and effect under State law as a Pernit issued by the State of New Hampshire.

E. Special Conditions"Whole Effluent To Test Frequency A ent The perrni may submit a writie equest to the EPA esting a reducti in the fr ency (to not less th ce per year) of r d toxicity testin r pletion of a Mi -eight (9) successi oxicity tests of e ent all of w hch must be valid and must demo e acceptable to-' ..Until written notice is receive y certified mail fro e EPA indicatin at the Whole Effluent Te g requirement has n changed, the p ttee is required to continu esting at the freq specified in the ective permit., pH Range Adjustmernt The permittee may submit'a written request to the EPA requesting a change in the permitted pH limit range to no more than 6.0 to 9.0 Standard Units. The perrittee's written request must include the State's appro'Vral letter containing an original signature (no copies). The State's letter shall state that the permittee has demonstrated to the State's satisfaction that as long as discharges to the receiving water from a specific outfall are within a specific numeric pH range the naturally occurring receiving Water pH will be unaltered.

That letter must specify for each ouffall the associated numeric pH limit range.A-29 NAEC Rev. 23 Clean Water Act Section 316 (a) and (b)Certification FPL Energy Seabrook LLC has been authorized by the Environmental Protection Agency and the State of New Hampshire Department of Environmental Services (NHDES) to discharge from the facility, Seabrook Station, under the National Pollutant Discharge Elimination System, Permit No. NH0020338.

The Seabrook Station NPDES Permit became effective on April 1, 2002, with an expiration date five years from the effective date. The Seabrook Station NPDES Permit and Fact Sheet documented the amended determinations regarding the thermal component of the discharge and the location, design, construction and capacity of the cooling water system intake structures made pursuant to the Clean Water Act Sections 316 (a) and (b). The Fact Sheet specifies thefollowing requirement for amended determinations regarding Sections 316 (a) and (b) for permits being reissued.Each time the permit is reissued (not to exceed 5 years), the 316(a)and (b) determinations are reviewed.

The permittee must certifyany changes in: (1) the facility discharge characteristics, (2) the waterway characteristics, and (3) resident or transient aquatic community.

The permittee must then explain any differences identified and their impact on the local ecological community.FPL Energy Seabrook LLC has submitted an application to renew NPDES Permit NH0020338.

In support of an amended determination of compliance with Clean Water Act Sections 316 (a) and (b) FPL Energy Seabrook LLC certifies the following relative to the thermal component of the discharge and the location, design, construction and capacity of the cooling water system intake structures:

1) Clean Water Act Section 316 (a): The thermal component of the discharge from Seabrook Station has not changed nor does the NPDES Permit renewal application propose any change in the current thermal limits as specified in the permit. Compliance with the NPDES Permit thermal limits and monitoring requirements is documented and reported on an ongoing basis as required by the permit in the monthly Discharge Monitoring Reports and in the annual Hydrological Monitoring Reports. A thermal plume comparative evaluation was submitted to the EPA and NHDES in June 1991, concluding that there was satisfactory agreement between plume model predictions and field data in terms of surface temperature rise isotherms, thermocline depths and plume pattern.The impact of the thermal component of the discharge is rigorously assessed on an ongoing basis through implementation of the biological monitoring program required by the Seabrook Station NPDES Permit.

The preoperational phase of this program was initiated in 1976 followed by the operational phase of the program initiated at the time of C.W.A. Certification, p. I commercial operation of Seabrook Station in 1990. Annual reports documenting the biological monitoring program data, analyses and conclusions are submitted to the EPA, New Hampshire Department of Environmental Services and the National Oceanic and Atmospheric Administration, National Marine Fisheries Service.

The annual reports continue to demonstrate that the operation of Seabrook Station has not adversely impacted the balanced indigenous populations of aquatic biota in the vicinity of the cooling water system intake and discharge structures.

Seabrook Station increased its electrical generating capacity in May 2005 by approximately 60 megawatts electric to its current capacity of 1221 megawatts electricresulting in an incremental increase in the heat rejected through the station's condensers.

The thermal component of the discharge is monitored on an ongoing basis by temperature instruments in the discharge area and continues to remain in compliance with the NPDES Permit receiving water temperature rise limit (ref: 2005 Hydrological Monitoring Report, SBK-L-06015, January 26, 2006). An additional increase in electrical generating capacity of about 40 megawatts electric will commence in November 2006.

The ongoingmonitoring program for the thermal component of the discharge will ensure continued compliance with the NPDES Permit receiving water temperature rise limit.2) Clean Water Act Section 316 (b):The location, design, construction and capacity of the Seabrook Station cooling water.system intake structures has not changed nor does the NPDES Permit renewal application propose any change to these features of the cooling water system. Seabrook Station cooling water system flow is reported on an ongoing basis as required by the permit in themonthly Discharge Monitoring Reports.The impact of the operation of the cooling water system intake, structures is rigorously assessed on an ongoing basis through implementation of the biological monitoring program required by the Seabrook Station NPDES Permit.

The preoperational phase of this program was initiated in 1976 followed by the operational phase of the program initiated at the time of commercial operation of Seabrook Station in 1990. Annual reportsdocumenting the biological monitoring program data, analyses and conclusions are submitted to the EPA, New Hampshire Department of Environmental Services and the National Oceanic and Atmospheric Administration, National Marine Fisheries Service.The annual reports continue to demonstrate that the operation of Seabrook Station has not-adversely impacted the balanced indigenous populations of aquatic biota in the vicinity ofthe cooling water system intake and discharge structures.

Consultations with the National Oceanic and Atmospheric Administration, National Marine Fisheries Service were initiated in 1997 after a number of seals were taken in the Seabrook Station cooling water system. A Limited Take Permit application was filed by Seabrook Station in June 1997. Subsequently a Limited Take Permit and Letter ofAuthorization were issued by NMFS in July 1999. The provisions of the Limited Take Permit and LOA included enhanced monitoring, reporting and the requirement to design C.W.A. Certification, p. 2 and install a mitigation device to minimize or eliminate seal takes. Design and installation of a mitigation device was completed in August 1999. Additional vertical bars were installed on the intake velocity caps to reduce the bar spacing from approximately fourteen inches to five inches. The reduced bar spacing mitigation design has been completely successful in eliminating seal takes. In light of the proven effectiveness of the mitigation device design the Limited Take Permit was allowed toexpire in June 2004.FPL Energy Seabrook submitted on May 4, 2006, a Proposal for Information Collection (PIC) as required by CWA § 316 (b) Phase II Regulation, 40 CFR § 125.95 (b)(1). The Seabrook Station PIC is integral to this NPDES Permit renewal application.

The PIC demonstrates that Seabrook Station's Cooling Water Intake Structure design is "best technology available" and meets the National Performance Standards of 40 CFR § 125.94 (b). The PIG also includes the information required by 40 CFR §§ 122.21(r)(2), (3) and (5) describing the source water body, cooling water system intake structures and cooling water system operation respectively. FPL Energy Seabrook intends to submit a Comprehensive Demonstration Study (CDS) subsequent to receiving EPA reviewcomments on the PIC but not later than January 7, 2008. The CDS will supplement this NPDES Permit renewal application.

Certification pursuant to 40 CFR 122.22(d)I certify under penalty of law that this document and all attachments were prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gather and evaluate the information submitted.

Based on my inquiry of the person or persons who manage the system, or those persons directly responsible for gathering the information, the information submitted is, to the best of my knowledge and belief, true, accurate, and complete.

I am aware that there are significant penalties.

for submitting false information, including the possibility of fine and imprisonment forknowing violations.

Gene St. PierreSite Vice President~4A~Date Sworn and Subscribed Before me this aý, -day of V ,2006 Shirley A. Si My Commis.6,2009 C.W.A. Certification, p. 4