ML19350F139
| ML19350F139 | |
| Person / Time | |
|---|---|
| Site: | Wolf Creek  |
| Issue date: | 06/22/1981 |
| From: | KANSAS GAS & ELECTRIC CO. |
| To: | |
| Shared Package | |
| ML19350F136 | List: |
| References | |
| ENVR-810622, NUDOCS 8106240258 | |
| Download: ML19350F139 (125) | |
Text
{{#Wiki_filter:WCGS-ER(OLS) ' (q 1 g WOLF CREEK GENERATING STATION, UNIT NO. 1 ENVIRONMENTAL REPORT OPERATING LICENSE STAGE REVISION 2 INSTRUCTIONS FOR INSERTING REVISION 2 Remove and insert the pages, tables, figures, and tabs listed below. Dashes (--) in the remove or insert column of the instructions indicate no action required. The Revi-sion 2 tab, transmittal letter, and these instructions should be placed at the end of Revision 1 Insertion Instruc-tions. Tab 1 should be placed as per instructions in the Revision 1 Insertion Instructions. Tab NRC Q &A should be placed before the Revision 1 Insertion Instructions. REMOVE INSERT VOLUME 1 CHAPTER 1 Pages 1.1-27/27a Pages 1.1-27/27a Tables 1.1-29/30 Tables 1.1-29/30
) CHAPTER 2
(/
'N_
Pages 2.0-xiii/xiv Pages 2.0-xiii/xiv Page 2.0-xiv(a) Page 2.0-xiv(a) Pages 2.1-1/2 Pages 2.1-1/2 and 2.1-2a Pages 2.1-5/6 through 2.1-9/10 Pages 2.1-5/6 through 2.1-9/10 Pages 2.1-21/22 and 2.1-23/24 Pages 2.1-21/22 and 2.1-23/24 Tables 2.1-2 (Sheet 1 of 3)/ Tables 2.1-2 (Sheet 1 of 3)/ (Sheet 2 of 3) and 2.1-2 (Sheet 2 of 3) and 2.1-2 (Sheet 3 of 3)/2.1-3 (Sheet 3 of 3)/2.1-3 Table 2.1-18a Figure 2.1-4 Figure 2.1-4 Figure 2.1-6 Figure 2.1-6 Figure 2.1-10 Figure 2.1-10 Figure 2.1-23a VOLUME 2 CHAPTER 2 i Table 2.4-3/4 Table 2.4-3/4 Pages 2.8-5/6 Pages 2.8-5/6 CHAPTER 3 Pages 3.1-1/2 Pages 3.1-1/2 i f N -- Figures 3.1-2a/b Tables 3.2-1/(Sheet 2) Tables 3.2-1/(Sheet 2) Figure 3.3-l' Figure 3.3-1 Pages 3.4-1/2 through 3.4-4/5 Pages 3.4-1/2 through 3.4-4/5
~1-
'810624O M. -- .
WCGS-ER(OLS) I REMOVE INSERT k CHAPTER 3 (cont'd) Tables 3.5-1 (Sheet 3)/2 Tables 3.5-1 (Sheet 3)/2 Table 3.5-6 and Table 3.5-7 Table-3.5-6/(Sheet 2) through Table 3.5-7/(Sheet 2) . Pages 3.6-5/6 and 3.6-7/8 Pages 3.6-5/6 and 3.6-7/8 Tables 3.6-1/2 and 3.6-3/4 Tables 3.6-1/2 and 3.6-3/4 Pages 3.9-1/2 and 3.9-3 Pages 3.9-1/2 and 3.9-3 Table 3.9-1 - Table 3.9-1 Figure 3.9-1 Figure 3.9-1 i Figure 3.9-2 Figure 3.9-2 Table 3A-1/(Sheet 2) Table 3A-1/(Sheet 2) Table 3A-2/(Sheet 2) Table 3A-2/ Sheet 2) Tables 3A-4 (Sheet 2)/5 Tables 3A-4 (Sheet 2)/5 Figure 3A-2 (Sheet 1)/ Figure 3A-2 (Sheet 1)/ (Sheet :2) through Figure (Sheet 2) through Figure 3A-2 (Sheet 5)/(Sheet 6) 3A-2 (Sheet 5)/(Sheet 6) CHAPTER 5 t Pages 5.0-i/ii through 5.0-v/vi Pages 5.0-i/ii through 5.0-v/vi Pages 5.1-5/6 Pages 5.1-5/6
/N Pages 5.2-1/2 turough 5.2-11/12 Pages 5.2-1/2 through 5.2-9 ,
(N' ) Tables 5.2-1/2 through 5.2-11/12 Tables 5.2-1 (Sheet 1 of 3)/ .' (Sheet 2 of 3) through 5.2-12 Figures 5.2-1/2 Figures 5.2-1/2
- Pages 5.7-1/2 Pages 5.7-1/2 Pages 5A-1/2 Pages 5A-1/2 and 5A-3/4 Tables SA-1/2 Tables SA-1 (Sheet 1 of 4)/
l (Sheet 2 of 4) through SA-2/3 CHAPTER 7 Pages 7.3-1/2 Pages 7.3-1/2 CHAPTER 10 Pages 10.0-1/2 and 10.0-3 Pages 10.0-1/2 and 10.0-3 CHAPTER 12 u l Pages 12.1-1/2 Pages 12.1-1/2 ! NRC Q & R
-- Pages 240-1/ Table 240.1-1 through Figures 240.14/240.15-2
-- Pages 290-1/2 through 290-13/14 l l l . - _ _ _ _ . . _ _ _ _ _ _ . - _ . _ _ _ _ . . _ _ _ _ _ _ . _ _ _ _
WCGS-ER(OLS) 4 l REMOVE INSERT NRC Q & A
- (cont'd) :
-- Pages 291-1/2 through 291-26/27
, -- Pages 310-1/2'through Table i 310.7-2/Page 310-6 l l -- Pages 311-1/2 and 311-3 l
-- Pages 320-1/2 through 320-9/10
-- Pages 450-1/2 through Figure 450.2-1/Page 450-3
-- Pages 470-1/2 REVISION 2
-- Revision 2 tab (directly behind Revision 1 tab)
-- Place transmittal letter and these instructions behind Revision 2 tab l
1 I 1 j-l. l i i I l l I l i l-i 1
w d S
.r. ,
WCGS-ER(OLS)'
...fQ 1 \
[ cDEPENDENT_ VARIABLE: ' T MIKWH 4 Right_ Hand Ectimated' -Standard "T" Variable . Coefficient Error Statistic
,, 3 t
19.988 _C- .933 21.4
-LSFRE-
- :. 522 .083 6.3 PZ .200 .050 -4.0 7 SEAS . 068 .008 2.0 DDCUS . 037 .013 2.8 PPZ .006 .001. -4.1 R = .968 li 2 = .957
- j. .
DW =_2.00 C- = Constant-R = Coefficient of. Determination R =R Adjusted a fO DW = Durbin/ Watson coefficient l
- R
)
V' LMIKWH = LogL(Mjssouri Industrial Sales Excluding
! Armco)
LSFRB = Log (FRB Production Index) PZ = Log-(Real Price'of Electricity /Real Price of Gac Fuels)
; SEAS- = Seasonal Production Variable i DDCUS = Dummy to Account for Customer Reclassification 4
in 1970 I PPZ = PZ Subsequent to 1973 Oil Embargo, O Otherwisc (Test for changing price elasticity) 1
- J All Log values referenced in this documentation are natural logs
. The variable PZ is the ratio of electric price to gas price
! and as such represents a combined price elasticity for both .
t gas and electricity. i A rmco Steel is involved in the production of wire, wire j rope, steel products and ingots. Future yearly estimates t of electric -usages to 1983 were obtained from Armco and reflect greater intensity of future use. Alternative modeling efforts were undertaken to analyze the relation of Armco usage to external production indices. These models { showed that there has bcen a historical relationship between v' the_ FRB durable index and Armco usage, but because of the na tu re of che la rge discrete Armco load additions, the Rev. 2 1.1-27 6/81 i. n 7 y 9 - - - -e..---p--e.p + .o -p.-r%ww,y -rw y.- ,.-mmy -p.,, .-.-?vr pp pp4m, .*,.-q -w. esp es W m ..p.4woggu..-.W*-pft-+ve-w:w-=w
i I WCGS-ER(OLS) models were judged to have relatively low explanatory ! power. Afer analyzing a detailed survey questionnaire answered by Armco, the forecast supplied by Armco, and applying judgment, it was concluded that subsequent to 1983 Armco usage would increase by 2 percent per year. G ' O 1.1-27a *)g3 g
+' %
WCGS-ER(OLS) TABLE 1.1-29 KCPL MONTHLY LOADS AND INTERCHANGE, FIRST TWO YEARS WITH WCGS IN SERVICE f Year Month Peak (MW) Energy (1000 MWH) Purchases (1000 MWH) Sales (1000 M4H) ! 1984 Apr 1541 809 25.08 10.04 May 1793 857 37.39 14.86 Jun 2305 981 32.01 22.48 Jul 2460 1205 88.51 14.97 Aug 2485 1140 54.24 30.19 ! Sep 2269 918 29.91 41.03 i Oct 1584 872 57.74 41.32 l Nov 1573 872 49.73 46.34 Dec 1694 925 45.68 19.28 1985 Jan 1723 986 17.35 21.98 ' Feb 1702 898 17.00 14.00 l Mar 1615 905 21.89 28.78 l; Apr 1606 843 37.28 10.29 ? May 1864 889 16.25 32.88 , i i Jun 2397 1025 25.19 26.96 k Jul 2574 1257 81.27 12.50 ! I ] Aug 2574 1181 101.44 15.65 l Sep 2358 954 60.24 32.43 i i Oct 1547 907 45.17 18.79 ! Nov 1663 910 20.45 13.00 Dec 1762 961 21.22 15.46 , I
; Rev. 1 4/81 i
i I 1 i !O l \ - _ _ _ - _ _ _ _ - _ _ _ _ l
WCGS-ER(OLS) TABLE 1.1-30 PROJECTED FUEL MIX FIRST THREE YEARS OF PLANNED OPERATIONS WITH AND WITHOUT WCGS (TOTAL GENERATION) IN PERCENT High Capacity Factor" Low Capacity Factor" 1984 1985 1986 1984 1985 1986 Fuel Type With Without With Without With Without With Without With without kith Without WCGS WCGS WCGS WCGS WCGS WCGS WCGS WCGS WCGS WCGS WCGS WCGS KG&E Coal 61.7 61.7 57.4 57.4 60.4 60.4 61.7 61.7 57.4 57.4 60.4 60.4 Oil 0.3 0.3 1.7 5.4 1 2 4.9 0.3 0.3 2.3 5.4 1.8 4.9 38.0 13.4 37.2 9.7 34.7 19.9 38.0 17.4 37.2 13.5 3 4 . ~, Gas 16.3 Nuclear 21.7 - 27.5 - 28.7 - 18.1 - 22.9 - 24.3 - Total 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 l KCPL Coal 82.3 97.3 78.1 97.0 75.3 93.2 84.5 97.3 80.8 97.0 78.7 93.2 Oil 1.9 2.6 1.9 2.9 3.6 6.8 1.8 2.6 1.9 2.9 3.9 6.8 Gas 0.1 C.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 Nuclear 15.7 - 19.9 - 21.0 - 13.6 - 17.2 - 17.4 - Total 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 NOTE: May not add due to rounding. " Represents the fuel mix for high and low capacity factors of the WCGS expected operating range. G 9 Gw
- .WCGS-ER(OLS)-
( LIST OF' FIGURES N g)
-CilAPTER 2.0 - Tile ~ SITE AND ENVIRONMENTAL INTERFACES _
Figure No. Title 2.1-1 Location of Site Within the State of Kansas e
- 2.1-2 Location of Site Within Cof fey County
; 2.1-3 Property-Owned by' Applicant 2.1-4 ' Plant Site Features 2.1-5 Layout of Dams, Dikes, Spillways, and Outlet
- Works 2.1-6 Site Features 2.1-7 ' Transportation Network Near'the Site 2.1-8 Cities and Towns hithin 50 Miles of the Site i 2.1-9 _1970 Resident Population 0 to 10 Miles g ,) 2.1-10
- 1980 Resident Population 0 to 10 Miles i
2.1-11 1990 Re,sident Population 0 to 10 Miles 2.1-12 2000 Resident Population 0 to 10 Miles 2.1-13 2010 Resident Population 0 to 10 Miles 2.1-14 2020 Resident Population 0 to 10 Miles 2.1-15 1970 Resident Population 10 to 50 Miles j 2.1-16 1980 Residant Population 10 to 50 Miles . 2.1-17 1990 Resident Population 10 to 50 Miles 1 2.1 2000 Resident Population 10 to 50 Miles
'2.1-19 2010 Resident Population 10 to 50 Miles 2.1-20 2020 Resident Population 10 to 50 Miles 2.1-21 Public Facilities and Institutions Within 5 Miles
. of the Site f 1 2.0-xiii
10GS-ER(OLS) LIST OF FIGURES -(continued) Figure No. Title 2.1-22 Cmulative Population Density,1970 to 2020, Within 50 miles of the Site 2.1-23 Land Use Within 5 Milos 2.1-23a Quarry Locations l 2.1-24 Zoning Within 5 Miles 2.1-25 Water Withdrawal Points on the Neosho River in Kansas Downstream of the Site 2.1-26 Municipal Ground-Water Supplies Within 20 Miles of the Site 2.1-27 Well Inventory Within 5 Miles 2.2-1 Terrestrial Ecology Sampling locations 2.2-2 Average Bimonthly Chorophyll a and Bimnss Values for Periphyton Collected frcm Natural Substrates, 1973-78 2.2-? Average Binonthly Density and Biovolume Values for Periphytm Collected frcm Natural Substrates, 1973-78 2.3-1 Regional Climatological Stations 2.3-2 Topographic Features Within 5 Miles of the Plant Site 2.3-3 Topographic Features Within 50 Miles of the Plant Site 2.3-4 'Iepographic cross Sections Within a 5-Mile Radius of the Site 2.3-5 Topographic Cross Sections Within a 50-Mile Radius of the Site 2.3-6 Meteorological Tower Plot Plan 2.3-7 Hail Reports, 1955-1967 2.3-7a Tornado Reports by One-Degree Squares, 1955-1967 2.3-8 Wind Gusts, 1955-1967 2.0-xiv Rev. 2 6/81
WCGS-ER(OLS) i. I LIST OF FIGURES (continued) Figure No. Title ~ f , 2.3-9 Wind Storms by One-Degree Squares, 1955-1967 4 l 2.3-10 Wind Storns by ho-Cegree Ws, 1955-1967 I i l 1 i 4 I Ii ; l 1 i \ a 9 4 l 1 .i i i l 1 l l i O Pev. 2 1 2.0-xiv(a) 6/81 i i I
WCGS-ER(OLS)
/ ') CHAPTER 2.0 T '"
THE SITE AND' ENVIRONMENTAL INTERFACES , 2 2.1 GEOGRAPHY AND DEMOGRAPHY-2.1.1 ' SITE LOCATION AND DESCRIPTION 2.1.1.1 Specification of Location The Wolf Creek Generating Station, Unit No. 1 (WCGS) is located in eastern Kansas approximately 75 miles southwest of Kansas City, 53 miles south of Topeka, and 100 miles east-northeast of Wichita, Kansas. The plant site is near the center of Coffey. County in Hampden Township, 3.5 miles northeast of the city of Burlington and 3.5 miles east l of the Neosho River and the main dam at John Redmond Reser-voir. ~ Figure 2.1-1 shows the location of.the site in Kansas, and Figure ~2.1-2 locates it in Coffey County. l The plant site is located in Townsnip 21 South, Range 16 j East of the Sixth Principal Meridian, and~ Townships 20 and 21 South, Range 15 East of the Sixth Principal Meridian. The reactor is located 4,235,500 meters north and 264,600 y'"N meters east within zone 15 at Universal Transverse Mercator
) Coordinates Latitude 38 14'20" North aad Longitude 95 41'20" x- '
West. The WCGS is a Standardized Nuclear Unit Power Plant System (SNUPPS) plant, which locates the reactor centerline at hypothetical SNUPPS coordinates Latitude 100 ^90 North and Longitude 100,000 East. The Kansas State plane coordi-
. nates corresponding to these hypothetical coordinates are Latitude 584,670 North and Longitude 2,807,250 East.
2.1.1.2 Site Area /.
?
Of the 11,882 acres owned by the applicant on and near to the WCGS site, 9,818 acres are occupied by the site, and 1,976 acres lie outside of the site boundary. The acreage beyond the site boundary is leased as farmland and pastureland. The railroad right-of-way to the site boundary occupies about 148 acres, 88 acres of which are owned by the applicant. Figure 2.1-3 shows the lands owned i by the applicant. The station property lines include both the land inside the site boundary and the leased land out-side the boundary. Areas modified by construction of the plant include 135 acres for the station, 60 acres for the cooling lake dams and dikes, and 5,090 acres for the cooling [ lake at a normal elevation of 1,087 feet above mean sea level (MSL). Figure 2.1-4 shows the location and orienta-tion of principal plant structures, and Figure 2.1-5 shows [\j the layout for the cooling lake, dams, dikes, and spillways.
\s / !
3 Rev. 2 2.1-1 6/81
WCGS-ER(OLS) The plant exclusion area, shown on Figure 2.1-6, lies within the site boundary and encompasses approximately 1,118 acres, which are owned by the applicant. This area is traversed only by the access road to the plant. There are no residential, commercial, or industrial struc-tures within either the exclusion area or the plant site area. The effects of the Wolf Creek cooling lake are dis-cussed in Section 2.8. (see note below) ! The transportation network in the site vicinity is shown on Figure 2.1-7. The main highway artery in the plant site area is U.S. Highway 75, which runs in a north-south direction about 0.25 mile west of the site boundary and 2.8 miles west of the reactor location at its closest point. The four other major roads within a 5-mile radius of the plant are the federal-aid secondary routes 10, 149, 153, and 1472. There is no commercial water traffic on the Neosho River or the John Redmond Reservoir. The nearest existing railroad to the site is the Missouri Pacific Railroad located 9.5 miles southeast of the site boundary. l A spur connecting the site with this track was constructed to provide rail access to the site. Another railroad, (Santa Fe Railroad) and right-of-way, running in a north-south direction, located 0.3 mile west of the plant site is abandoned. By Interstate Commerce Commission Order in Finance Docket No. 26591, dated February 4, 1972, caption-ed Atchinson, Topeka, and Santa Fe Railroad Company Abandonment, B.H. Junction and Gridley, Franklin and Coffey Countics, it was ordered that the branch line of the rail-road extending between milepost 0.0 at B.H. Junction, Kansas, and milepost 52 plus 1,518 feet at Gridley, Kansas, be abandoned. With this abandonment, title of the right-of-way property reverted to the fee simple title owners. Of fsite activities which may be considered as possible con-tributors to the risk associated with WCGS are transportation, mining and mineral exploration and operations, industrial activities and military activities. Air transportation does not pose any undue risk to the safe operation of WCGS (FSAR Addendum Section 3.5.1.6). Water transportation poses no hazards to WCGS since there is no commercial water traffic Note: For consistency the term " cooling lake" is used in this Environmental Report to designate the entire body of impounded cooling water and its related structures and appurtenances. This use is not necessarily consistent with the definition of
" cooling lake" found in 40 CPR 423.11 or any sub-sequent specialized definitions, but is used in the context of prior WCGS documentation as portrayed in that context.
Rev. 2 2.1-2 6/81
WCGS-ER(OLS)
/N. on John Redmond Reservoir or Neosho River (FSAR Addendum
}
Section 2.2.1.5). Land transportation routes are of a sufficient distance from WCGS that they do not pose any hazard to the plant (FSAR Addendum Sections 2.2.1.4, 2.2.3.1, and 2.2.3.2). Gas pipelines and petroleum storage facil-ities were evaluated and determined not to present a hazard to WCGS (FSAR Addendum Sections 2.2.1.6 and 2.2.3). Indus-trial and military activites do not pose a hazard to WCGS operation due to the distance between WCGS and any indus-trial or military facility (FSAR Sections 2.2.1.1, 2.2.1.2, and 2.2.3). FSAR Section 2.2.1.2.3 discusses mining activities which are small and pose no hazard to WCGS. In summary, no external activities pose a threat or hazard to WCGS operation. ' 2.1.1.3 Boundaries for Establishing Effluent Release Limits The restricted area, which is used for establishing effluent release limits, enable the applicant to fulfill their obligations with respect to the requirements of 10 CFR Part 20. This area and the distance from the station vent stack to the boundary line of the restricted area is shown on Figure 2.1-6. The restricted area boundary coincides with the exclusion area boundary. (
\ / %/
l l /N (N/ i l Rev. 2 2.1-2a 6/81
WCGS-ER(OLS)
) continued to 2020 for each MCD. County sums derived from \_ 4 these divisions were then reproportioned to county totals derived from the step-down procedure (Greenberg and others, 1973). Thus, if .an area had grown in the past, it was assumed it would continue to grow. The MCD projections were allocated to variots segments in the 0- to 50-mile area with the area-distribution method previously described.
In casec where new residential developments occurred within the 0- to 5-mile area and historic population trends were not reliable, projections were based on the number of planned home sites within each development. An occupancy f actor of i 2.9 people per dwelling (determined from a field survey and verified by the 1970 census data) was.used to derive a total population for each new residential area. This approach provides a conservative or high population projection for these areas. It is assumed that no permanent residents would live within < 1 mile of the plant site or within the area occupied by the cooling lake beyond 1980. Demographic surveys' performed in
; 1980 have confirmcd these assumptions.
2.1.2.1 Population Within 10 Miles s The total 1970 population within the 10-mile area was 4,059, [ T which results in a density of 13 people per square mile (_,/ and clearly depicts the area's rural nature (Table 2.1-2). Within 5 miles of the plant site, the 2,537 residents provide a density of 32 people per' square mile. However, when Burlington with its population of 2,099 is excluded, the area within 5 miles of the plant site then has a density of six people oer square mile. The 2020 population projection for the area within 10 miles of the plant site indicates a decline in nearly all segments except 'in those which encompass Burlington and New Strawn. These communities are located principally in the 3- to 4- and-4- to 5-mile segments described in Table 2.1-2 and on Figure 2.1-8. However, the 2020 projection is not the maximum. As shown in Table 2.1-2, the 10-mile population increases very slowly from 4,059 in 1970 to 6,120 in 2000. After the year 2000 the 10-mile population declines to 5,370 in 2020. The increase and decline is related to the age-structure of the
- population and the out-migration history of the area. Figures 2.1-9 through 2.1-14 present the projected populations in the 0- to 10-mile area from 1970 to 2020.
The only incorporated communities within 10 miles of the pl an t site are at Burlington, 3.5 miles to the southwest, and New Strawn, 3 miles to the west-northwest of the plant )
N r site (Table 2.1-1). \ Rev. 2 2.1-5 6/81
WCGS-ER(OLS) Burlington had a 1970 population of 2,099, a January 1979 populat ion o f 2,511, and is expected to undergo only mod-erate g rowth by 2023. New Strawn was created when the U.S. Army Co rps o f Engi-neers relocated Strawn (an unincorporated settlement) from the area to be inundated by the John Redmond Reservoir, and was incorporated in 1971 (Brown, 1979). The town did not appear in the 1970 U.S. Census. Therefore, in the absence of historic population trends, estimates for the future have been based on the r umber of planned lot sites. New Strawn is currently g rowing, and has the capability to accommodate significant new residential development. Within New Strawn 668 home and trailer lots have been subdivided, with approximately 150 single family homes and 63 trailers presently occupied within the town (Jones, 1979, Boyce, 1979). Present growth in New Strawn is estimated at 12 to 15 single family homes per year (Jone s , 1979). Assuming development of an additional 30 single family residences and 22 trailers (remaining capacity in the Arrow-head Park Trailer Camp) , the 1980 population of New Strawn could be as high as 800 residents (assuming about 2.9 people per dwelling unit) . As New Strawn occupies parts of two of the geographic sectors, approximately 534 of these people would live in the west-northwest segment from 3 to 4 miles from the site, and 266 residents would live in the northwest segment from 3 to 4 miles from the site. In addition to incorporated New Strawn, there are two adjacent d ev el o pm en ts , Remer's Point and Hillview, in an unincorporated area west of New Strawn. Presently, there are a total of 11 homes and 2 mobile homes in the two developments - 7 homes and 2 trailers in Hillview, and 4 homes in Remer's Point. It is estimated that there exists space for approximately 40 addi-tional dwelling units within the two developments (Remer, 1979; Harris, 1979). Full development of these two areas would result in a total population of approximately 150 residents (assuming 2.9 persons per dwelling unit). However, this development is unlikely to occur until well after 1980 (Remer, 1979; Harris, 1979). Of this potential total of 150 residents in Remer's Point and Hillview, 10 would locate in the west-northwest segment, 5 to 10 miles from the plant, and the remainder would locate in west-northwest segment, 4 to 5 miles from the site. It should be noted that, as the historic g rowth trends for the reg ion suggest decreased population g rowth for most communities, the above increased projections are therefore 2.1-6
WCGS-ER(OLS)
.,m.
] j' likely to,be conservative or high-estimates of future popu-
\_,/ 1ations for these communities.
The midpoint of station' operating life, rounded to the nearest census date, is 2000. The distribution for age categories 0 to 12, 12 to 18, and over 18 is shown in Table 2.1-3. The U.S. . projected age distributon for 2000 was used because the 1970 age distribution for Coffey County did not dif fer signif-
. icantly f rom the 197010.S. age distribution. Appendix D o f
, Regulatory Guide 4.2' Revision 2, Preparation of Environmental-Reports for Nuclear Power Stations, defines a "significant difference" as more than a 10 percent difference of the age distribution of the county in which,the proposed station is'to be located from the U.S. age distribution in the 1970 decen-nial census. The 10-percent difference cri'.erion is to be applied to any^ of the three age g roups . Table 2.1-3 shows the 1970 age distribution for the U.S., Coffey County (the county in which the plant is located), and the counties in which all
-or a pcrtion are located within 50 miles of the plant. None of the age categories differ significantly f rom the 1970 U.S.
age distribution. The year 2000 age distributions for 0 to 10 miles from the site and 10 to 50 miles are the same. 2.1.2.2 Population Between 10 and 50 Miles [( ) _,,1 Cities and towns within 10 to 50 miles of the plant site are shown on Figure 2.1-8 and their 1960 and 1970 census popu-lations are listed in Table 2.1-1. Many of these incorporated places experienced a decline in population from 1960 to 1970. Emporia, Kansas, with 23,327 residents in 1970 and 26.174 l residents in 1978 is the largest city in the 10- to 50-mile region, while the next largest is Ottawa with 11,036 people in 1970.and 10,693 people in January 1978 (Kn ig ht , 1979). The majority of the incorporated places contain less than 1,000 peo pl e . The population rose for the area from 10-to-50 miles is divided into 64 segments ranging in size from 59 to 177 square miles. The current and projected population distri-bution from 10 to 50 miles is listed in Table 2.1-4. The 1970 ' through 2020 population distributions are compared on Figures 2.1-15 through 2.1-20. The total cumulative 1970 population within the entire 50-mile area surrounding the site was 163,834 or about 21 persons per square mile. In the region within 10 to 50 miles of the plant site, the projections clearly depict a decline in the rural areas with moderate growth occurring only in the vicinities of major j e~' cities and towns (Figure 2.1-8 and Table 2.1-1). A net
/ Rev. 2
, 2.1-7 6/81 i i
r-WCGS-ER (OLS ) population decline of 4 percent over the entire 0- to 50-mile area is projected for the 50-year period from 1970 to 2020. The year 2000 age distribution for the 10 to 50 mile area around the site is shown in Table 2.1-3. The means by which this distribution was generated is discussed in Section 2.1.3.1. 2.1.2.3 Transient Population Transient population within 10 miles of the site is low. Most seasonal or daily shifts in population are associated with public facilities such as the John Redmond Reservoir, schools, and parks. Figure 2.1-21, Public Facilities and Institutions, illus-trates the geographic location of the transient population centers within 5 miles. Tables 2.1-5 through 2.1-8 provide a description of the faci.ities shown on Figure 2.1-21. The Flint Hills National Wildlife Refuge (Table 2.1-8) is pri-marily outside the 10-mile study area. By comparing the population statistics (enrollment and usage) on Tables 2.1-5 through 2.1-8 with the geographic locations (Figure 2.1-21), current transient concentrations can be identified in relation to the plant location. Fo r , future projections, there were no anticipated expansions to public facilities within 5 miles of the site. There is presently no commitment by the Applicants to public uce of the WCGS cooling lake or surrounding land (see Section 2.8). If this commitment is made in the future, an increase in the transient population within 5 miles of the site would result. One Federal-Aid Primary highway (FAP 75) and four Federal-Aid Secondary highways (FAS 10, FAS 149, FAS 153, and FAS 1472) occur witnin 5 miles of the site (Figure 2.1-21). Based on the 1978 annual average daily traffic (ADT) count for FAP 75 and the 1975 ADT counts for the secondary highways, the following ranges of traffic volumes were recorded within 5 miles of the site (Ijans, 1978): Range o f ADT Route Orientation (vehicles per day) FAP 75 N-S 2810 - 3800 FAS 10 E-W 485 - 875 FAS 149 N-S 95 - 110 FAS 153 E-W 75 - 225 FAS 1472 E-W 90 - 125 1 2.1-8 01 '
1 1
^
WCGS-ER(OLS) ( ) The most' important source of transient seasonal population in
. is_,,/ the general area is the recreational usage of John Redmond Reservoir. The conservation pool of John Redmond Reservoir ex tends 3. 5 to 7.2 miles west of the site. The facilities that attract a transient population are boat launching ramps, fishing, picnic facilities, and campgrounds. The peak monthly
-usage was 79,400 during July 1978 (Duncan, 1979). The yearly visitation at John Redmond Dam and Reservoir averages about 380,000 (yearly change in visitation is largely dependent on weather conditions [Chester, 1979]). Actual 1972 visitation was r epo r ted to tue 692,300 (Kansas Park and Resources Author-
- ity, - and ~ 0bl inger-Smith Co rpo ration , 1975, Table IX.1). The recreational season is year round, but the peak months are during the summer. Major . sources of transient or seasonal populations, sucn as that experienced during recreational use of John Redmond Reservoir, have established visitor trends which can be utilized as a guide for future usage of these areas.
With the exception of visitation at-Kansas reserviors and state parks, transient populations at distances of 5 to 50 miles are miniral due to the absence of major industrial facilities or recreational attractions. The Pomona , Melvern , Toronto , and Fall River reservoirs and state parks are located within 50 miles of'the site. The s
'-) - recreational f acilities available at each of ttese reservoirs consist o f. boat launching ramps, picnic shelter s, sanitary facilities, campgrounds and swimming beaches. Location and actual 1978 visitation for each of these reservoirs are given below (Herndon, 1979):
f Reservoir and State Park Location 1978 Visitation Pomona 29 miles north 885,380 Malvern 19 miles north 896,054 Toronto 34 miles south- 419,900 southwest Fall River 45 miles south- 433,500 southwest The two largest cit! , althin 50 miles are Emporia (28 miles wes t-no r th wes t) and -awa (32.5 miles northeast). The 1978 populations of the 3e cities, 26,174 and 10,693, respectively, l reflect the absence of a large population-industrial source in the 16-county area surrounding the site. Transient population in the area is-not expected to increase due to the projected 2.1-9 Rev. 2 6/81
WCGS-ER(OLS) population decline (4 percent, Section 2.1.2.2) in the next 50 years. 2.1.2.4 Low Population Zone The low population zone (LPZ) is defined as the area within 2.5 miles (4,023 meters) from the reactor center as shown on Figures 2.1-6 and 2.1-21. The LPZ meets the requirements as stated in 10 CFR Part 100. The LPZ does not include Burling ton, New Strawn, or Highway 75, nor does it contain any areas of heavy residential use. The 1970 population of the 20-square mile area of the LPZ was 101 people. By 1980, the permanent resident population should be about 130 people. Table 2.1-9 presents the estimated distribution of noculation in 1970 and 1980 within the LPZ. All exit routes sithin the LPZ are presently unsurfaced two-lane county roads. Some of these roads may be impassable during periods of rainy weather except for tracked vehicles, four-wheel drive vehic1cs, and farm tractors. Detailed evacuation provisions will be . ; dressed in the detailed emergency procedures (Section 13.3 of the Final Sa fety Anal-ysis Repor t) . Two improved access roads (one all-weather) will be constructed which will provide exit routes within tha site property boundary and from the .PZ area. There are no sources of transient population within the LPZ. [There is presently no commitment by the Applicants to public use of the cooling lake or surrounding land (Section 2.8)] With the exception of residential traffic, there is na transient population in the LPZ, neither during the working day nor seasonally. No data are available on the frequency of residential traffic within the LPZ. The roads are not i major highways but are unsurfaced country roads which serve scattered residences. The ra lroad passing through the site i area was abandoned, and the rails have been removed. There are no commercial facilities within 2.5 miles of the site. 2.1.2.5 Population Center The population center or city closest to the site with a population g reater than 25,000 persons, is Emporia, Kansas, 28 miles west-northwest of the site. In 1975 its popula-tion was estimated to be 26,145 persons (DeMott, 1979). The next city eligible for designation as a population center is Topeka, Kansas, 53 miles north of the site. To pe k a 's reported populations for 1970 and 1978 were 155,322 and 144,221 persons, respectively (Schlicher, 1979). 2.1-10 O
WCGS-ER(OLS)
/j . 2.1.3.3.3 Land Use Capabilities A description of the soils on the site and their capabilities
- regarding agricultural potential, wildlife habitat and general construction characteristics are. presented in Section 2.2.2.8 of the ER (CPS) .
Since -the ER(CPS) several of the soil units mapped on the site have been designated as prine farmland by the Soil Conservation Service
-(Swanson,- 1979). These prime farmland soil-types are listed below:
4-41B - Bates loam, 1 to 4 percent slopes 41C - Bates loam, 4 to 7 percent slopes 428 - Dennis silt loam, 1 to 4 perc.nt slopes 32 - Kenoma silt loam, 1 to 3 percent slopes 32B3 - Kenoma silt loam, 1 to 4 percent slopes, eroded 15 - Lanton silty clay loam. This is a new name; previously mapped as Oakwood silty clay loam.
'~N 16 - Leanna silt loam \- / 21(23) - Lula silt loam. This is a new designation; it includes Labette silt loams, O to 2 percent slopes that were mapped previously 18 - Osage silty clay loam.
14 - Osage silty clay 22B - Summit silty clay loam, 1 to 4 percenc slopes 12 - Verdigris silt loam. This has been changed to also include the Mason silt loam tha: was mapped previously 31 - Woodson silt loam These prime farmland designations are subject to change prior to publishing the Coffey County Soil Survey, which , is expected to be completed in 1981. There are no designated unique farmlands or farmlands of state or local significance in Coffey County (Swanson, 1979). b =V l 2.1-21
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WCGS-ER(OLS) 2.1.3.3.4 Projected Land Use and Visitors Center A lake use study was conducted to determine the feasibility of allowing public use of the WCGS cooling lake for recreational purposes. Currently, there are to plans for public use of the cooling lake or lands within the site boundary adjacent to the cooling lake not needed during operation of the station and related facilities (see Section 2.8). At present the only area of the site which will be open for public use will be the visitor center. The visitors center is locatea in the Emer-gency Operations Facility Complex. (See Figure 2.1-6) 2.1.3. Water Use Within 50 Miles 2.1.3.4.1 Municipal, Ind us t r i al , Irrigation and Recreation Uses This section discusses the regional ground-water use and the principal surface-water users of the Neosho River downstream of the WCGS site to the Kansas-Oklahoma state line (approxi-mately 170 river miles) . Regarding surface-water use, only users downstream of the plant discharge are described since these are most likely to be affected by plant effluent relecses. Descriptions of the Neosho River and its major tributaries, streamflow gauging stations, major reservoirs and g round-water g radients are presented in Section 2.4. The effects of regional consumptive water use by the plant on water supplies are discussed in Sections 2.4, 3.3 and 5.7. Water and sewage treatment processes of the plant are d isc us sed in Sections 3.6, 3.7, 5.3 and 5.4. The water use estimates presented herein are based primarily on unpublished data which consisted primarily of estimated annual totals. Little information was available for monthly or seasonal variations, or for past and proj ec tcd water use. The principal water withdrawal from the Neosho River down-stream of the site is for municipal use, followed by indus-trial, irrigation and recreational uses. Listed in Tables 2.1-19 and 2.1-20 are the major water users and dischargers on the Neosho River downstraam of the site. The locations of the major water users are indicated on Figure 2.1-25. The City of LeRoy is the nearest municipal water user downstream o f Wol f Creek (13.5 miles). More detail regarding the incorporated municipal water supply systems downstream of the site is presented in Table 2.1-21. These municipal systems supply water for domestic, commercial, industrial and public-water requirements. Rural water districts (RWD) utilizing the Neosho River, either directly or indirectly, are also listed in Table 2.1-21. 2.1-22 Rev. 2 6/81
WCGS-ER(OLS)
,m The RWDs have been formed in those areas where ground-water
, resources are limited.
L
/
flunicipal ground-water supplies within a 20-mile radius of the site are listed in Table 2.1-22; their locations are shown on !/igure 2.1-26. Many rural residences rely on individual w<,lls for domestic needs and livestock watering. There is no commercial water traffic on either the Neosho River or on the John Redmond Reservior. 2.1.3.4.2 Commcreial and Recreational Fish Harvest The principal fishing waters that are contiguous with the WCGS discharge and that may be influenced by the station effluents include the Neosho River downstream from the John Redmond Daa and tributary streams to the Neosho River. Within 50 miles of the plant site this includes approximately 100 anglable river miles of the Neosho River and approximately 24 tributaries with 240 stream miles of anglable waters. Fish cannot move upstream on the Neosho River past the John Redmond Dam. Therefore, fisheries upstream of the John Redmond Dam would not be influenced by station effluents. Although numerous city and county lakes, farm and ranch ponds, and other small lakes may also be considered contig-uous with waters receiving station effluents (since their / % waters eventually flow into the Neosho River) , they are ( ) not considered in the following discussion since many small dams block continuous flow during dry seasons and are also barriers to fish moving upstream. Commercial Fishing - Commercial fishing on the Neosho River and John Redmond and other reservoirs in Kansas began in 1978. This Kansas Fish and Game Commission controlled program only allows the hIrvesting of large rough fish. The catch in the John Redmond vicinity in 1980 was 421,000 pounds. Mussels are also commercially harvested from the Neosho River, l but none of the catch is used for human consumption. The shells are exported for seeding pearls in clams. The most recent annual mussel harvest estimate was for the 1969-1970 season and included both the Neosho and Verdigris rivers; total harvest was 600,000 pounds (272 metric tons) and was valued at $21,000. The annual harvest for the three previous seasons was 32,000 pounds (14.5 metric tons) in 1966-1967, 24,000 pounds (10.9 metric tons) in 1967-1968, and 8,750 pounds (3.9 metric tons) in 1968-1969 (Hartmann, 1979). Recreational Fishing - The Neosho River and many of its tributaries within 50 miles of the WCGS provide good sport-fishing, primarily for panfish and catfish. The species l 7e'y of fish caught by anglers in these waters are listed below l g j (Ray, 1976): Rev. 2 2.1-23 6/81
WCGS-ER(OLS) channel catfish bullheads walleye l flathead catfish largemouth bass spotted bass carp white bass paddlefish white crappie sunfish blue catfish freshwater drum buffalo The principal fishing areas on the Neosho River are generally restricted to adjacent towns, road crossings, low water or overflow dams and reservoir tailwaters. The most popular areas within 100 river miles downstream of the John Redmond Dam are the John Redmond Dam stilling basin area and dams at the cities of Burlington, LeRoy, Neosho Falls, Iola, Humboldt, Erie and Chanute (Jirak, 1979; Ray, 1976). Although recreational fish harvest estimates for the Neosho River and its tributaries are not available, angler utiliza-tion of these waters has been reported (Ray, 1976). The estimated angler use for the 100 miles of the Neosho River below the John Redmond Dam and for the 24 anglable tributaries is estimated to be approximately 54,0 ) man-days per year. The catch rate from these waters is expected to be similar to the regional lake harvest objective of approximately two fish per man-day, each weighing 1/2 pound (Brunson, 1979). Based on these estimates the annual harvest from these waters was determined to be approximately 54,000 pounds (24.5 metric tons). No data were available concerning the amount of sport fish cons um ed locally. Fishermen residing beyond the 50-mile radius area from the WCGS will likely fish within the area and, therefore, only a portion of the harvest would be expected to be consumed locally. 2.1.3.5 Water Use Within 5 Miles 2.1.3.5.1 Municipal, Ind us t r i al , Irrigation and Recreation Uses All sur face wa ter rights within 5 miles of the site, except for two, are located on the Neosho River upstream.of the confluence with Wolf Creek. Of the two remaining water rights, one is located on Long Creek, in the adjacent water-shed east of the site; the other water right is held by the Applicants for storage of natural flows on Wolf Creek. The water rights on the Neosho River between Wolf Creek and the John Redmond Dam are held for municipal, ind us t r ial , irrigation and recreation use. The municipal water rights are for the City of Burlington and Coffey County Rural Water Districts 2 and 3; the industri.. water rights are held by 2.1-24
Y a f WCGS-ER(OLS) i ~~
!-~/ }' TABLE 2.1-2 Sheet 1 of 3 i \d RESIDENT POPULATION DISTRIBUTION ,
BY SECTOR AND RADIAL DISTANCE UP.TO 10 Miles j Radial Distance from Reactor (Miles) 10-Mile-Sector Year 0-1 1-2 2-3 3-4 4-5 ,5-10 Total
! , N 1970 0 3 2 9 1 75 90 i 1980 0 2 5 0 5 108 120 1 1990 0 10 10 10 10 60 100 4
2000 0 10 10 10 10 60 100 l.' 2010 0 10 10 10 0 40 70
'2020 0 10 10 10 0 30 60
)' NNE 1970 0 1 1 5 18 147 172 j' 1980 0 0 6 9 16 73 104 l 1 1990 0 10 10 10 20 140 190 l 2000 0 10 10 10 20 140 190 l 2010 0 10 10 10 10 110 150 2020 0 0 0 10 10 90 110 I NE 1970 0 1 4 11 6 74 96 l 1980 0 2 6 12 6 90 116 l l 1990 0 10 10 30 10 70 110 1 2000 0 10 10 J.0 10 60 100 j 2010 0 0 10 10 10 50 80
~
2020 0 0 10 10 10 40 70 ~ j ENE 1970 0 0 7 3 4 77 91 4 1980 0 2 5 2 5 60 74 1 1990 0 -0 10 10 10 70 100 j 2000 0 0 10 10 10 00 90 i 1 2010 0 0 10 10 10 50 80 2020 0 0 10 10 10 40 70 i E 1970 0 3 1 1 1 61 67 I 1980 0 8 3 2 4 63 80 I i 1990 0 10 10 10 10 50 90 2000 0 10 10 10 id 40 80 2010 0 10 0 0 0 30 40 2020 0 10 0 0 0 20 30 i i- If the projected population is less than 10, the projections i have been rounded upward. Thus, if there are 2 persons l I projected, tha number has been rounded to 10. !O Rev. 2 6/81 l
WCGS-ER(OLS) TABLE 2.1-2 (continued) Sheet 2 of 3 l (Miles) Radial Distance from Reactor 10-Mile sector Year 0-1 1-2 2-3 3-4 4-5 5-10 Total ESE 1970 0 9 7 3 18 90 127 1980 0 4 4 5 5 103 121 l 1990 0 10 10 10 10 80 120 2000 0 10 10 10 10 70 110 2010 0 10 10 10 10 50 90 2020 0 10 10 10 10 40 80 SE 1970 0 4 7 7 8 107 133 1980 0 10 5 14 7 199 235 l 1990 0 10 10 10 10 90 130 2000 0 10 10 10 10 90 130 2010 0 10 10 10 10 70 110 2020 0 10 10 10 10 50 90 SSE 1970 2 7 7 1 9 260 286 1980 0 0 1 8 16 144 169 l 1990 0 0 0 10 10 250 270 2000 0 0 0 0 10 240 250 2010 0 0 0 0 10 200 210 2020 0 0 0 0 10 150 160 S 1970 0 4 7 14 8 84 117 1980 0 0 0 14 7 57 78 l 1990 0 0 0 10 10 70 90 2000 0 0 0 10 10 60 80 2010 0 0 0 10 10 50 70 2020 0 0 0 10 10 30 50 SSW 1970 0 0 0 0 7 89 96 1980 0 0 0 0 12 87 99 l 1990 0 0 0 0 10 80 90 2000 0 0 0 0 10 80 90 2010 0 0 0 0 10 60 70 2020 0 0 0 0 10 50 60 SW 1970 2 0 6 652 1,431 211 2,302 1980 0 0 12 854 1,857 377 3,100 l 1990 0 0 10 790 1,730 230 2,760 200J 0 0 10 860 1,880 230 2,980 2010 0 0 10 780 1,700 200 2,690 2020 0 0 10 690 1,500 170 2,370 0 Rev. 2 6/81
WCGS-ER(OLS) [ ) TABLE 2.1-2 (continued) Sheet 3 of 3 v Radial Distance from Reactor (Miles) 10-Mile Sector Year 0-1 1-2 2-3 3-4 4-5 5-10 Total WSW 1970 0 0 11 29 13 66 119 1980 0 0 11 10 26 76 123 l 1990 0 0 10 30 10 50 100 2000 0 0 10 30 10 50 100 2010 0 0 10 20 10 40 80 2020 0 0 10 20 10 30 70 W 1970 1 0 13 1 0 43 58 1980 0 0 11 2 0 44 57 l 1990 0 0 10 10 0 30 50 2000 0 0 10 10 0 30 50 2010 0 0 10 10 0 20 40 2020 0 0 10 10 0 10 30 WNW 1970 0 0 3 49 14 24 90 1980 0 0 9 362 11 118 500 l 1990 0 0 10 760 90 20 880 [~'; 2000 0 0 10 990 100 20 1,120 ( / 2010 0 0 10 1,220 110 10 1,350
' 2020 0 0 10 1,240 120 10 1,380 NW 1970 1 0 22 46 9 54 132 1980 0 8 2 4 14 71 99 l 1990 0 0 20 390 10 40 460 2000 0 0 20 510 10 40 580 2010 0 0 10 630 10 30 680 2020 0 0 10 650 10 20 690 NNW 1970 0 0 13 5 5 60 83 1980 0 0 4 3 0 84 91 l 1990 0 0 10 10 10 50 80 2000 0 0 10 10 10 40 70 2010 0 0 10 10 10 30 60 2020 0 0 10 10 10 20 50 Total 1970 6 32 111 836 1,552 1,522 4,059 1980 0 36 84 1,301 1,991 1,754 5,166 l 1990 0 60 140 2,080 1,960 1,380 5,620 20J0 0 60 140 2,490 2,120 1,310 6,120 2010 0 50 120 2,740 1,920 1,040 5,870 2020 0 40 110 2,690 1,730 800 5,370 ,
V Rev. 2 6/81
TABLE 2.1-3 AGE DISTRIBUTIONS FOR THE SITE AREA FOR 1970 and 2000 II 1970 U.S. Coffey Counties Within 2000 U.S. Age Category Population County II 50 Miles Of Site (b) Population (c) O to 12 24% 19% 23% 19% 12 to 18 12% 10% 12% 9% Over 18 64% 71% 65% 72%
- t
" Year 2000 is the midpoint (rounded to the nearest census date) of the @
station operating life. y m b " 1970 U.S. Census of Population, General Population Character- g istics, Kansas g
" Projections of the Population of the United States: 1977 to 2050", Population Estimates and Projections, Current Population Reports, Series P-25, No. 704: Bureau of the Census.
Note: The 0- to 10-mile 1970 distribution is represented by the "Coffey County" column, and the 10- to 50-mile 1970 distribution by the
" Counties within 50 miles of the Site" column. The projected age dis';ribution for 2000 for 0-to-10 miles and 10-to-50 miles is found in the "2000 U.S. Population" column.
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v -m/ hCGS-ER(OIS) TABLE 2.1-18a DIS'IANCE 'IO NEAREST PLANT BOUNDAIN, RESIDENCE, VIIETABLE GARDEN AND LIVESTOCK WITHIN 5 MILES Distance From Reactor (Miles) i Nearest Nearest Nearest Nearest Nearest Plant Nearest Vegetable Meat Dairy Dairy Sector Boundary Residence Garden Animal Cow Goat Milk Consuners N 1.1 1.4 1.4 1.1 None None 2 adults NNE 1.1 2.6 2.7 0.8 4.7 None 3 adults /2 children NE 1.3 1.8 2.1 0.8 None None ) ENE 1.5 2.0 2.2 0.3 None None E 1.2 1.8 1.8 1.2 1.8 None 2 adults ESE 1.2 1.6 1.6 1.2 1.7 None 2 adults SE 1.2 1.4 1.4 1.2 1.4 None 2 adults /2 teens /2 children SSE 3.0 3.0 3.2 3.2 5.0 None 2 adults /1 infant S 3.3 3.5 3.5 3.3 None None i SSW 1.7 4.6 4.6 4.6 None Ibne SW 1.5 2.2 2.2 1.6 None None WSW 1.5 2.7 2.7 1.5 4.7 None Various local families W 1.8 2.2 2.2 2.8 None None i WNW 2.1 2.9 2.9 2.1 None Ibne NW 2.6 1.3 1.4 2.2 3.5 None- Various local families NNW 1.5 2.2 2.2 2.0 lbne Ibne i j Sour : Field Investigation, Kansas Gas and Electric Company,1980. Rev. 2 I ' 6/81 _
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/ b WOLF CREEK GENERATING STATiv;J l ,
UNIT NO. I y I (, , ENVIRONMENTAL REPORT (OPERATING LICENSE STAGE j s ) l ' l
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l l l v l l ___ _ _o - - WOLF CREEK GENERATING STATION UNIT NO. I NOTE: DMRONMENTAL REPORT CPERATING LK:ENSE STE e MAP BASED OrJ DIMES S MOORE FIELD INVESTIGATICN AND AERtAL Figure 2.1-23a PHOTO INTERPRETATION,1973. BUILT UP LAND AROUND SITE UPDAiED IN 1979. Quarry Locations Rev. 2 l REV 2 6-81 6/81 !
-____]
WOGS-ER(OLS) TABLE 2.4-3
\
V
/ REGUIATED STREAM FIDE OF THE NEOSHO RIVER FROM 1964 TO 1977 (All Values in Cubic Feet Per Secorrl)
RECORDED DISCHARGES AT RECORDED DISCHARGES AT BURLI!CION, KANSAS IOIA, KANSAS ' (RM 338.4) (RM 284.4) Monthly Maxinum Mininum Date of Monthly Maxinum Mininum Date of m nth Average Daily Daily Min. Flow Average Daily Daily Min. Flow Oct. 1,774 13,400 2.8 10/2/74 2,284 29,500 25 10/16/66 Nov. 1,397 13,400 29 11/30/66 1,897 24,900 27 11/2/66 Dec. 1,005 6,240 14 12/31/66 1,316 15,200 21 12/31/66 Jan. 951 7,180 14 1/10/67 1,339 12,800 14 1/12-13/67 Feb. 1,024 12,400 21 2/11/67 1,299 14,200 18 2/24-25/67 Mar. 1,461 15,300 20 3/18/67 2,035 22,100 15 3/16-17/67 Apr. 2,002 14,'000 30 4/2/67 2,633 30,200 38 4/12/77 p May 2,433 12,200 21 5/24/70 2,758 15,100 40 5/23-28/67 June 4,080 14,700 31 5/22/70 5,314 26,100 LS 6/30/66 July 2,884 13,000 18 7/19/73 3,412 29,500 37 7/15/66 Aug. 532 9,750 2.0 8/31/76 698 11,100 31 8/31/66 Sep. 930 11,900 5.9 9/30/74 1,495 24,100 19 9/4/76 Scuroes: U.S. Geological Survey (1969) and U.S. Department of the Interior (1 % 6-1977). Note: Period of record is frcan September 1,1964 through September 30, 1977. Regulated storage of the John Redmond Reservoir began on September 1,1964; flow at the Burlington gauge has been cmpletely regulated by the reservoir since 1%3; flow at the gauge near Iola has reflected considerable regulation since 1963. ( , Rev. 2 I 6/81 1
l WCGS-ER (OLS ) 1 TABLE 2.4-4 IN-CHANNEL !!YDRAULIC PARAMETERS FOR Tile NEOSIIO RIVER (1) Near Iola: D.A. - 3,818 sq. mi. Discharge Width Average Depth Velocity (cfs)a (feet) (feet) (fps) 050 140 1.6 1.6 0 80 88 .90 1.1 Qa 220 3.2 2.5 (2) Near Parsons: D.A. - 4,905 sq. mi. 0 50 130 2.1 1.5 080 82 1.1 .9 Qa 220 4.0 2.5 (3) Near Chanute: D.A. - 4,195 sq. mi. Qa 254 3.52 2.87 a 050, &080 are those discharges which are exceeded 50 and 80 percent of the time, respectively. Qa is average discharge. b 050 and 080 information are not available. Source: Kansas Water Resources Board, 1971, Kansas Streamflow characteristics, Part 8, In-channel hydraulic goemetry of streams in Kansas: Technical Report no. 8. l l 9 1
4 L a c
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WCGS-ER(OLS) ) V The total costs for the various scenarios and the benefits derived from the use of the lake are summarized in Table 2.8-1. The benefit-cost ratios developed in that table show - that the public would benefit from the use of the WCGS cool-ing lake for only scenario three. 2.8.3 USE OF WCGS LAND The applicants have purchased 11,882 acres in association with the WCGS project. Property actually necessary for the project within the site boundary totals 9818 acres. Several farmers would only sell their property within the site boundary by selling their entire farm or. would only allow right-of-way access if the entire acreage through which right-of-way was desired was purchased. The acres outside the site boundary are being utilized to the extent possible
- as they were prior to their purchase.
2.8.3.1 Exclusion Area The applicants own all land within the 1200 meter exclusion l area surrounding the WCGS reactor and have the authority to determine all activities inside the area. The majority of x the 1118 acre exclusion area is water surface extending over the cooling lake and station structures occupy a large portion of the remainder.- See Figure 2.1-6. The ' balance of the land within the exclusion a,ea will not be utilized for agricultural purposes. Selective land management practices will be utilized as necessary to con-trol vegetation growth for plant security areas and the remaining land in the exclusion area. 2.8.3.2 Land Outside of the Exclusion Area
! Approximately 4200 acres are within the WCGS site boundary but outside of areas occupied by the lake, dam and exclusion area. To the extent practical, this land will be used for agricultural purposes.
A buffer zone of natural vegetation will be retained eround the lake. The remaining 3700 acres of cropland and range-land will be continued in agricultural production if prac-tical. 2.8.4 WCGS LAND USE
SUMMARY
AND CONCLUSIONS The 9818 acres of Coffey County, Kansas land within the WCGS site boundary is comprised of 5090 acres of water at the cooling lake normal pool elevation of 1087 feet and 4728 l (, / acres of land. 1 Rev. 2 2.8-5 6/81
WCGS.En(OLS) 2.8.4.1 Cooling Lake Public use of the WCGS cooling lake hnd evacuation, security and operational considerations for the use of the lake are discussed in Section 2.8.2. The henefit-cost ratios devel-oped for public use of the lake show that it is beneficial to develop the lake into a recreational facility for only one of the evaluated scenarios. This scenario assumes public boating is allowed on the lake and also assumes the fishery is developed with State assistance. A significant portion of that benefit (42%) is derived from using the lake as a fishery with State stocking of trophy fish increasing use by the public. Only about 33% of the benefit of the lake use is derived from uses for which there is a demand in the region-swimming, boating, camping, and picnicking. As stated in Appendix 2A there is a surplus of fishing opportunities in the region surrounding WCGS, as well as for the state, and this surplus will persist well into the fu-ture. Additionally, although the Appendix 2A citing of a Kansas fish preference survey says the results must be interpreted with caution, there is an apparent low prefer-ence for trophy fishing in Kansas. Consequently, the Appli-cants will not commit to a long term use of the cooling lake whose main benefit will be derived from fishing by the Kansas public that already have an abundance of fishing available and exhibit a low preference for the additional trophy fishing that would develop in the lake. The Applicants are continuing with their fish stocking program to establish desirable fish species in the lake. 2.8.4.2 Land Land outside the exclusion area and above the cooling lake normal pool level, but inside the WCGS site property, will be utilized to the extent practical as it was prior to its pur-chase for the WCGS site. O 2.8-6
WCGS-ER (OLS) l CHAPTER 3.0 THE STATION ( ) v ' 3.1 EXTERNAL APPEARANCE 3.1.1 STRUCTURES'AND ARRANGEMENT The principal building complex at Wolf Creek Generating Station, -Unit No. 1, (WCGS) is a group of interconnected buildings oriented in a generally north-south direction as shown in' Figure 2.1-4. This complex comprises the central structures and forms the visual foundation for the power block as reflected in the artist's conception, which is included as the frontispiece for this document. Figure 3.1.1 is an oblique aerial photograph of the site looking to the east'and Figure 3.1-2 is an overhead aerial photograph of the site. These photos were taken in April 1979. Figures 3.1-2a and 3.1-2b are aerial photographs taken in February 1981. Lake filling began in November 1980 and Figure 3.1-2b shows an impoundment of about 1200 surface acres of water. The main vertical element in the composition of the power
~
block is the reactor building. The reactor building houses a pressurized water reactor (PWR) and associated reactor coolant and ventilation systems. Interconnecting structures include the fuel building, control building, auxiliary
-~s building, the diesel generator building, and the turbine
( )
\s_,/ building. The radwaste building is located nearby, facing the fuel building. The turbine building, a horizontal structure, has a lower profile than the reactor building.
Its steel structure has metal siding. Also included among the power block structures are the condensate storage tank, the refueling water storage tank, the reactor makeup water storage tank, the demineralized water tank, the emergency fuel oil storage tanks, and several transformer vaults which are located around the power block structures as shown in Figure 2.1-4. The major non-power block structures include the ad-ministration building, the Technical Support Center, the switchyard, the shop building, the security building, the sewage treatment plant, the warehouse, the circulating water pumphouse, the circulating water discharge structure, and the essential service water pumphouse. Also located around the site complex are several storage tanks and small buildings for storage of acid, compressed gases, water, and fuel oil. These items are shown on Figure 2.1-4. The Emergency Operations Facility, Simulator, Vistors Center complex is located about 2 3/4 miles northwest of the station as shown in Figure 2.1-6. Railroad sidings are installed to serve the fuel and turbine buildings. The main access rail-
/T road leads into the site from the north and branches into i\- 'j several spurs which provide access to the outlying structures and encircle the principal building complex. Designations of the plant perimeter and exclusion area boundary are shown in Figure 2.1-6 Rev. 2 3.1-1 6/81
l wCcS-rR(Or.S) 3.1.2 ARCHITECTURAT. FEATURPS AND AESTHPTIC CONSIDPRATIOFS The layout of the facility was planned to achieve a blend of functional and aesthetic considerations. The plant arrangenent and structural design are coordinated to establish continuity and to provide both a balance and symmetry of design and a pleasing appearance. The various site components such as structures, equipment, parking, and railroad spurs are organized in a neat, functional nanner with a minimum of visual clutter. Land-scaping is planned where possible, to complement plant appearance. In summary, this is an industrial facility whose plant facilities and grounds have been designed to be visually pleasing and compatible with the surrounding environment. 3.1.3 GASEOUS AND LIOUID PELEASE POINTS There are two potential rel ea se points for radioactive gaseous effluents from the station: the reactor building and the radwaste building. The vents fo r these buildinos through which the ef fluents exhaust extend 10 feet above the roofs of these buildings and stand 218 feet and 64 feet above the plant grade elevation. Liquid radioactive wastes disch arged from the plant are released from the station into the cooling lake via the circulating water discharge structure. The locations of the release points are shown in Figure 3.1-3. O 3.1-2
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WCGS-ER (OLS)
- +
g ' TABLE-3.2-1 ! REACTOR 4AND STEAM - ELECTRIC' SYSTEM DESIGN AND OPERATING PARAMETERS A.- Reactor Coolant System Nominal operating pressure, psig 2,235 Total system volume, including j pressurizer and surge line, fta 12,135 System liquid volume, including . pressurizer. water'at maximum guaranteed power, fta
! 11,393
_ Pressurizer spray rate, maximum, gpm 900 Pressurizer heater capacity, kW 1,800 System Thermal and Hydraulic Data NSSS power, PNt 3:425 I Reactor power, MWt 3,411
- - Ultimate reactor power, MWt .
3,565 Thermal design flows, 'gpm Per loop 94,400 . Total .
'377,600 f'~' Total' reactor flow, 106 lb/hr 140.3
( Temperatures, F: Reactor vessel outlet 618.5 Reactor vessel inlet 558.4 Steam generator outlet 558.2 1 Steam generator inlet 544.6 Feedwater 440.0 i Pressurizer 653.0 Pressure, psia Design 2,500 Normal 2,250 Average velocity along fuel rods, ft/sec 16.7 Active heat transfer, surface area, ft 2 59,700 Average heat flux, Btu /hr-ft 2
~ ! 189,800 Maximum heat flux for normal operation, Btu /hr-ft 2 440,300 Average linear power, kW/ft 5.44 (
Peak linear power for normal operation, kW/ft 12.6 Peak linear power resulting from overpower
, transients / operator errors, assuming a maximum overpower of 118%, kW/ft 18.0 Heat flux hot channel factor, F Q 2.32 Peak fuel central temperature at peak linear l power for prevention of centerline melt, F 4,700
WCGS-ER(OLS) TABLE 3.2-1 (Sheet 2) B. Core Mechanical Design Parameters Design RCC canless
. 17 x 17 Number of fuel assemblies 193 UO 2 rods per assembly 264 Rod pitch, in. 0.496 Overall dimensions, in. 8.426 x 8.426 Fuel weight, as UO 2 , Ib 222,739 Clad weight, lb 45,296 Number of grids per issembly 8 - Type R Loading technique 3 region nonuniform Fuel Rods Number 50,952 Outside diameter, in. 0.374 Fuel to cladding gap, in. 0.0065 Cladding thickness, in. 0.0225 Cladding material Zircaloy-4 Fuel Pellets Material UO 2 sintered Density, % of theoretical 95 Diameter, in. 0.3225 Length, in. 0.530 Rod Cluster Control Assemblies Neutron absorber Ag-In-Cd or Hafnium l Cladding material Type 304 SS-cold worked Clad thickness, in. 0.0185 Number of clusters, full length 53 Number of absorber rods per cluster 24 Core Structure Core barrel, I.D./O.D., in. 148.0/152.5 Thermal shield Neutron pad design Baffle thickness, in. 0.88 Structure Characteristics Core diameter, equivalent, in. 132.7 Core height, active fuel, in. 143.7 Rev. 2 6/81
JOHN , EV APOR A Tl0N-4 9.3 ( REDMOND i RESERVOIR RAINFALL AND RUNOFF-27.3 1 WOLF CREZj 1r M AKEUP -46.9 COOLING I LAKE l O.0428 : Cl 2 1r 0.0009 LIME LIME SOFTENER SLUDGE POND C l, --* H2S O, y a n H,SO --> CLEAR WELL O.00395 g 1r CIRCULATING 0.0022 WATER CARBON I AND SAND l FILTERS 111 4 . 0 m y 0.0397 0.0298 D E MIN E R A LIZ E D PROCESS Na0CL WATER O O.009871r
- POTABLE o RADj y WATER O.0258 MC (F0k 0.00987 1r 1r WATE Il lf if if lf O.00755 S; AUXILIARY STEAM RADIOACTIVE OTHER 0.010 0 Ml BOILER GENERATOR PLANT PLANT O.00232 W)
BLOWDOWN BLOWDOWN WASTE SYSTEMS
. i A
0.0l18 0.0021 i 0.00186 COOLING LAKE D IS C H A R G E -21.7 l 'I I s
3 SEEPAGE -3.5 ) l JL
~
if ESSENTIAL SERVICE WATER 1 c CI: PUMPHOUSE 33.5 f if SERVICE WATER WATER 90.0 0.0223 U JL if
' ^
OlLY SITE NITORS 0.0223 * ' .0365 m
- WASTE -
OIL - SERVICE DRAIN SEPARATOR R SYSTEM ) h 0.01418 S ANIT ARY SEWAGE O.00755 L NIT A RY W ATER (POT ABLE) '
; TREATMENT SC. WASTES SYSTEM h PN J ASHWATER (POT ABLE) _
m z O.013 9 RADWASTE SYSTEM SOLIDS SHIPPED OFF SITE 1f REV. 2 6/81 NOTE: WOLF CREEK GENERATING STATION 3' UNIT NO. I ALL FL0W RATES ARE CFS ENVIRONMENTAL REPORT OPERATING LICENSE STAGE) j FIGURE 3.3-1 ANNUAL AVERAGE WCGS-1 WATER USE FLOW DIACRAM
WCCS-EP(OLS) 3.4 IIEAT DISSIPATION SYSTEM k ,
) 3.4.1 GENERAL The Wolf Creek Generating Stat. ion, Unit No. 1,(WCCS) coolinq l system is designed to support two 1150-MWe pressurized water reactors (PWR) operating at a 100 percent average annual load factorg for normal conditions. At this rate, a maximum of 8.0 X 10 Btu of beat per hour per unit will be dissipated g in the cooling lake. The heat will be dissipated through evaporation, convection, and radiation for the systems shown on Figure 3.4-1.
3.4.2 COOLING LAKE The station cooling lake is formed by one main earth-rolled dam across Wolf Creek and five perimeter saddle dams. The cooling lake, peripheral dams, dikes, intornal canals, and outlet works are shown on Figure 2.1-5. Llans cf the service spillway and the outlet works are shown on Figures 3.4-2 and 3.4-3. The top of the main dam is at elevation 1100 feet above mean sea level- (MSL) . Each dam has a 3 to 1 (horizontal to vertical) slope on both the upstream and downstream faces. The upstream slope of each dam is riprapped for /N protection against wind-generated wave erosion while the downstream slope is seeded. The top of the main dam is l (N -) riprapped to prevent erosion. A service spillway and an auxiliary spillway on the east abutment of the main dam are designed to accommodate the probable maximum flood. The service spillway is an uncon-trolled, concrete, ogee-crested semicircular spillway. The auxiliary spillway is located about 1500 feet east of the service spillway and is an open-cut type. A low-level outlet works is located near the west abutment of the main dam. The outlet works is provided with a 60-inch diameter outlet pipe. A 30-inch diameter blowdown pipe branches from the outlet pipe. The low-level outlet works is designed to blowdown water (from 0 to 60 cfs) to regulate the water quality of the cooling lake. In addition, the low-level outlet works enable drainage of the cooling lake to permit inspection and repairs of the main dam. 3.4.3 INTAKE AND DISCl!ARGE STRUCTURES 3.4.3.1 Makeup Fater s Makeup water for the WCGS cooling lake is drawn from the j Neosho River immediately downstream from the John Redmond y ,/ Reservoir. A makeup water screen house is situated on j Rev. 2 3.4-1 6/81
WCGS-ER(OLS) the east bank of the river downstream of John Redmond Reservoir and contains one bar grill, three vertical travel-ing screens, and three vertical wet-pit pumps, each with a normal operation capacity of 40 to 60 cfs. The three pumps in parallel have a maximum capacity of 170 cfs when the river elevation at the pumphouse is at flood stage. Two auxiliary raw water pumps, each with a capacity of 400 gpm, are located in the makeup screen house to provide makeup to the plant, potable water and demineralizer water systems when the makeup water pumps are not operating. A general arrangement of the makeup water screen house is shown in Figures 3.4-4 and 3.4-5. The existing Corps of Engineers low-flow channel located on the west side of the river has not been altered and will continue to function as it does at the present time. A recently excavated channel downstream of the stilling basin (see Figure 3.4-6) on the east side of the river suptties makeup water to the screen house during normal coniitions. This channel can be fed by a 42-inch diameter pipe connected with John Redmond Dam during times the still-ing basin is under repair. The screen house bar grill, located at the inlet of the intake bays, is composed of 1-inch vertical bars spaced at 3-inch intervals. Each intake bay is approximately 11 feet 2 inches wide. Each screen is 10 feet wide. The intake structure floor is located at an elevation of 995 feet MSL. The vertical screens, operated intermittently, are back-washed with water drawn from the Neosho River. This screen wash system is activated normally by a timer or automatically from a high-differential pressure switch. Screen mesh size is 0.375 inch. Trash collected on the traveling screens is backwashed to a trash basket where it is strained and collected. The trash is manually disposed of offsite. There are no provisions for returning fish that survive impingement to the Neosho River, but the intake velocity of 0.5 feet per second at the low water-level minimizes fish impingement. Makeup water from the screen house is pumped through a 54-inch diameter pipe and discharges into the Wolf Creek cooling lake at the makeup water discharge structure located on the western shore of the cooling lake (see Figure 2.1-5). A plan and section view of the discharge structure is shown on Figure 3.4-7. Two raw water pumps located in this dis-charge structure supply water to the steam cycle makeup system and the potable water system. O 3.4-2 1
WCGS-ER(OLS) [ } 3.4.3.2 Circulating Water NJ The locat. ion of the circulating water screen house at the WCGS is shown on Figure 2.1-5. Plan and elevati~on' drawings of this structure are shown on Figures 3.4-8 and 3.4-9. The circulating water screen house structure for Unit 1 houses three circulating water pumps. Under normal con-ditions all three pumps will be operating at a total capacicy of 1114 cfs. Three service wrter pumps are also housed in the circulating water screen house structure. Normally, two service water pumps will be operating at a total capacity of 90 cfs, with one pump serving as a standby. A low-flow and startup pump with a capacity of 14.5 cfs is also provided for the service water system. The Circulating Water screenhouse sump floor is located at an elevation fo 1058 feet MSL. A steel plate is provided at the sump inlet of the Screenhouse as a weather protection device (Figure 3.4-9). This steel plate extends from elevation 1075 feet MSL, upwards to the operating floor, 1092 feet MSL. The velocitics of circulating water and service water flow downstream of
/'"N the steel plate are essentially independent of cooling lake water level. %( /)
Based on a total (circulating water and service water combined) flow rate of 1204 cfs for one unit, the average inlet water velocities are calculated to be: Approach velocity to the 0.87 feet Screenhouse: per second Velocity through the bar 1.06 feet grill: per second Approach velocity to the 1.06 feet traveling screens: per second Velocity through the 1.95 feet traveling screens: per second The circulating water screen house contains a bar grill, conventional traveling screens, strainers, and fire pumps (one diesel and one electric motor driven). The traveling screens will operate the same as the makeup water screen house traveling screens described _in Section 3.4.3.1. l
<- g After passing through the condenser, the circulating water i(dN
) discharges into the cooling lake from the circulating water discharge structure, shown on Figure 3.4-10. The water Rev. 2 3.4-3 6/81
WCC.S-ER(OLS) takes approximately 38 days to travel from the discharge to tiie intake, based on an effective cooling volume of 91,000 acre-feet and a total flow rate of 1204 cfs (the total volume of circulating water and service water required for one-unit operation at 100 percent average annual load factor). O i l i l O Rev. 2 3.4-3a 6/81
I, WCGS-ER (OLS)
.( \ There:areftwo essential' service: water' pumps'for Unit 1,
~
's /' each ofTwhichLhas a.capacityLof 33.5 cfs; One of the~two
~
l pumps serves as:the redundant? backup?pum'p. The pumps are l located-in a. seismic Category.I" structure that is separate - . from the circulating water screen house.
- 3.4.4 THERMAL CONSIDERATIONS The1 temperature rise across the condenser for each 1150 MWe unit'is.31.5.F based on9 the circulating water heat rejection. rate of 7.87 x 10 Btu /hr and circulating water flow rate of 1114 cfs at 100 percent average ar.nual load
' factor. The condenser has three sections: low pressure, i
intermediate pressure,.and high pressure. Total effective tube length for the-three sections in series is approx-imately 140 feet.- With a tube flow velocity of 8.0 feet i per second, the travel time for water across the condenser is about 18 seconds. Sargent & Lundy's LAKET computer model has been used to calculate the cooling lake temperature distribution. This-model simulates the effects of varying weather conditions and plant heated-water discharge on the surface temperature and evaporation rates of a lake. The time-varying tempera-4 .ture distribution along the water body's central axis is [ computed against time, and the natural and forced evaporation (, rates and the variation in the lake level are also computed. !~ At the normal operating pool elevation of 1087 feet MSL, the gross surface area of the cooling lake is 5090 acres, and the' effective cooling area is 4330 acres. Elevation / area-capacity information for the Wolf Creek cooling lake 4 is shown on Figure 3.3-2. Hy'draulic and thermal balances are used together with the
- energy budget method to determine evaporation from the lake. The energy budget method takes into account such factors as solar radiation, reflected solar radiation,
~ andlenergy transferred from the lake to the atmosphere. i Maximum temperatures at various locations in the cooling lake with one unit operating at 100 and two units operating at 88.5 percent average annual load factor are shown in Figures 3.4-11 and 3.4-12. The location points are shown in Figure 3.4-13 along with the distances from the plant discharge point along the circulating water flow path line to 'each location point. These maximum temperatures corre-4 spond to lake temperatures that occurred less than 1 percent of the time during the 16 years of analysis (1949-1964). A cumulative profile of temperature distributio.. for various 1 O locations in the cooling lake is presented in Taale 3.4-1. For each location, the table gives the maximum temperature i ! 3.4-4
1 WCGS-ER(OLS) l l and the temperatures that occurred at a frequency of 1, 5 and 50 percent of the time based on the 16 years of calculated data. The temperature provided at N percent (where N is 1, 5, or 50) frequency is interpreted as a base temperature where N percent of all temperatures calcu-lated were higher than this temperature. (For example, at 5 percent occurrence, 5 percent of all temperatures calculated were higher than the base temperature.) Con-versely, 95 percent of all temperatures recorded were lower than the base temperature. Seasonal upper 1 percentile and 50 percentile temperature distributions in the cooling lake at the locations identified in Figure 3.4-13 are given in Tables 3.4-2 and 3.4-3. Table 3.4-1 shows that the maximum plant nlet temperatur^s for one-unit operation at 100 percent average annual load factor do not exceed the design maximum plant inlet temper-ature of 95 F established by essential service water intake requirements. Table 3.4-1 also shows the same result for two-unit operation at 38.5 percent average annual load factor. The maximum natural cooling lake temperature simulated for the 16-year data period is 87.2 F for one-unit operation and 87.4 F for two-unit operation. Natural temperatures are the cooling lake temperatures that would exist at zero load and are assumed to be constant throughout the cooling lake. They differ for one- and two-unit operation because the water mass following 16 years of operation differs. Because natural temperatures are dependent on the total mass of water in the cooling lake, the natural temperatures on an aggregate time basis are indirectly dependent on load, and the recorded maximum natural lake temperatures for one- and twc-unit operation are not identical. Figure 3.4-14 presents the simulated natural ter perature variation in the cooling lake for one-unit operation. The total dissolved solids (TDS) concentration in the cooling lake increases as the water evaporates. Tables 3.4-4 and 3.4-5 show the evaporation rates for one- and two-unit operation. A balance between consumptive water losses (such as evaporation) and replenishment sources (such as
- makeup, rainfall, and runoff), which vary with seasonal l and operational characteristics, determines the extent of the TDS buildup and reduction. A complete discussion of total dissolved solids is presented in Section 3.6.
3.4-5
l l WCGS-ER(OLS)
, TABLE 3.5-1 (Sheet 3) l \- Reactor Coolant Secondary Coolant (2)
Class 6 pCi/gm pCi/gm Ce-141 7.00E-5 'l.81E-9 ! Ce-143 4.00E-5 4.79E-10 Ce-144 3.30E-5 9.03E-10 Pr-143 5.00E-5 9.08E-10 Pr-144 3.30E 1.97E-9 2.90E-1 5.78E-6 (3) (1) Refer to Table 3A-1 for assumptions. . (2) For the secondary side, the noble gas activities are for the steam phase; all other activities are'for steam generator water activities. (3) Lower blowdown rates result in higher secondary system activities. A 60-gpm blowdown will result in a total of 5.35E-5 pCi/gm (excluding noble gases, N-16, and tritium) in the steam generator. A maximum blowdown rate was used in this table. O V 1 J l
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~7 1 x 10 (4) Isniates 0-errRE-9 Capsert Liquid Nat (TI) 10 to 10' 1 x 10 Co-137 1 x 10'$(3) 1-5 CH D-RE-10 cooling guns air vents water metrailla- m omtment monitor tion coolirst water surge tanks on hi a? arms (HiJ-iE-2 Steam gener- Liquid (2) Na1 (TI) 10'I to 10-2 1 x 10 Cs-137 1 x 10'$(3) 1 x 10 (4) 1-5 Closes ator lujuid gusan blowiwn ratioactiv- scirtille. isolaticri ity sonitor tion valves on hi alarm O-leHtE-25 Steam gener- Liquid (2) Na! (TI) 10' to 10' 1 x 10 Co-137 . I x 10'$(3) 1 x 10'4(4) 1-5 Closes ator bacnakasa gesus blowdtwn 5xucessirs; acistille. isolation systm munitor tion valve on hi alarns
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"/ trol systm let&wn scirtilla-tion sonitor 0 e-RE-35 Essertial Liquid NaI (?!) 10' to Aw' 1 x 10 Cs-137 1 x 10 (3) 1 x 10'4(4) 1-5 Alarwa 0-EP-it-36 service water 9 mum '
.syntem. meint illa-nonitor tim 0-f1 HIE-50 Auxiliary Liquid (2) Nm! (71) 10' to 10-2 1 x 10 Ce-137 1 x 10' (3) 1 x 10 (4) 1-5 Hi alarm steam syst m gauna is3lates coruternata acirtilla- auxiliary reconery tion steam sigply ponitor to radwaste building and trip = auxil-iary steam c m densate transfer purps 040-se-1 Rahanate Liquid Na! (TI) 0.1 - 10 r/hr 0.1 r/hr la PA IA -A IA (NC-RE-2 11dificat game optm scirtilla-sursitor tion (1) PEC - mininsa estactable concertration.
(2) neun in geration. (3) Cre onsor cd magsitaakt above DEC to avoid spurious alame and to indicate the taalraga cf radioactivity into an otherwise rumradioactive systan. . (4) Ttso ontors of eng11tude abcme stC to indicate sigtificant in1=*aga cd radioactivity. (5) Only tater clearer than this will be sort to the reactor sukann noter storage tank. (1) Hidt activity may indicate sweporator cperating Irelen. (7) Hidt activity may indioste a crud burst or iodine spiking. (8) High activity may irtitcate a crud burst, ioline spiking, or failed fuel. taboratory analyses will be garformed to determine cause. Rev. 2 6/81 A G t
.h 200R bud!E
iCG-ER(OIS) nBIZ 3.5-6 (Sheet 2) LIQUID PN9 AND EFERENT RADIOACTIVITY KNITORS LIQUID DTLENT RADIOhCTIVITY KNITORS Sample (bntrol- Alert Hi Flow Mmitor tenitor . . Type Range M r (1) lirg Alarm Alam Rate (bntrol Number Descriptim (cortinuous) Detectice ( u Ci/cc) (uCi/cc) Isot@e (uCi/cc) ( u Ci/cc) g Functim o-HP-RE-45 W ry Liquid (4) NaI (TI) 10' to 10-2 1 x 10 ~0 Cs-137 (3) (2) 1-5 Closes liquid waste pues discharge systen scirtilla- valves on monitor tien hi alam
-2
(>fB-RE-18 Liquid rad- Liquid (4) NaI (TI) 10' to 10 1 x 10 Cs-137 (3) (2) 1-5 Closes weste dis- genen dim iarge marge scirtilla- valw on monitor tion hi alam 10 to 10~2
~
0-tz-RE-59 Turbine Liqu2d 6) NaI (TI) 1 x 10 Cs-137 (3) (2) 1-5 C1cune buildirg gamma dis & arge drain sonitor scirtilla- valve on tica Hi alam Chan-RE-52 Steam genera- Liquid (4) NaI (TI) 10-7to 10-2 3 x 10 4 Cs-137 (3) (2) 1-5 C1 cees dis-ator blow- gamme & arge ard dows discharge scirtilla- blowdown monitor tim im lation valves en hi alarm' (1) P0C = mininsn &u+ahle con 2rtration. (2) High alam is set to ermure that Technical Specification limits (the 10 CIR 20 general population MPCs for the contro111rq isotge at the bcundary of the restrictai area) are not exceeded ard to initiate isolation before the limit can be exceeded. (3) Alert alam is et cne order cf macpituch below the w&nical S;ecification limits to alert qmrators cf alert radioactivity levels. (4) Normally, all of this liquid will be recycled. me nonitor is to prevert inadvertert discharge valve openirg ard to ensure that any rel- that might become necessary are within limits. In accordance with the wchnical Specifications, batd analyses will be performed before any releases are made. (5) Normally, not radioactive since Ictertially radioactive drains are segregated frczn this ard recycled. Rev. 2 6/81 O . O O
ICGi-ER(OIE) TAatz 3.5-7
./% AIRIKsedE penrvsut NO EFfLWWF MD10hCTIVITY KNItutS N- AJMOIRE PIO2SS RADluhCTIVITY KNITORS Minim m 02ntrol- Alert 11 1 tutal Ruquired a mator Alarm Alarm Ventilation Sensitivity Omtzn1 Tyge Range sec (1) ling Flow (cfm) (UC1/ce) nswt_ica, I oC1/ce) ( DC1/ce) Intcge ( WC1/m) ( N C1/cc) mmitor (cnrt anmus)
-12 to 10' 1 x 10'8(8) 1 x 10' (7) 420,000 1 x 10' (7) Inol.ites non-0-CT-NE-31 Particulate (3) 10 1 x 10'II Cs-137 tatrwet gursp, 0 CT-HE-32 -10 9 x 10'8(7) 420,000 9 x 10'8(7) aurryizes Ostainment laditar (4) 10' to 10 1 x 10 1-131 9 x 10(8) m fans on etsom5J erv ~ -7 -2 -7 1 x 10-5(8) 1 x 10-4(7) 420,000 1 x 10-4(7) high giums munators Gauxus (3) 10 to 10 2 x IC 6 85 activity via the ESFAS 1 x 10 (8) 1 x 10~7(7) 20,000/4000 1 x 10' (7) Isolatcm un-O-CP-RE-22 Particulate (3) 10'I to 20' 1 x 10'II Cs-137 t'I " "' N '
0 Cr-RE-33 4 -10 -9 9 x 10-8(7) 20,000/4000 9 x 10-8(7) derergizes Omtatisent luttne (4) 10'11 to 10 1 x 10 1-131 9 x to (8) I"#9' I'"' ** Ew ys systen 2 x 10
-7 kr-85 1 x 10-5(8) 1 x 104(7) 20,0000/4000 1 x 104(7) high gaseous sonitors ca== um (3) 10-7 to 10-2 activity via the ESPAS 0 4ff-RE-3 m E E (Mill-RE-4 Gansna (5) 1 to 108 rals/hr 1 rad /hr m m NR Cortantse rt High Activity a matorn 2 x 10 (9) 2 x 10' (10) 1000 Nh Closes blow-0 GE-RE-92 Gaarwms 10' to 10' 2 x 10 Er-85 down isolaticm
@ndener (continuuus) valve on air dis- (3), (6) hi alarve dary) sonator Particulate (lab analysis) (6)
\ Itzitne (lab g analysis) (6) f Initiates OHTrRE-27 Particulate (3) 10'I to 10' 1 x 10'II Cs-137 1 x 10' (8) 1 x 10' (7) 20,000 1 x 10' (7) nwits to fia 1 O GreRE-29 ledirm- (4) 10'II to 10 1 x 10'I 1-131 9 x 10(8) 9 x 10' (7) 20,000 9 x 10-8(7) teil.hrq Fuel build- "N M "'
im t
-7 -2 2 x 10
~7 Kr-85 1 x 10-5(8) 1 x 10-4(7) 20,000 1 x 10-4(7) tilation esi sonitors Gamms (3) 10 to 10 hicfi gueum III activity via the EsFAS Particulate (3) 10'I to 10 1 x 10'II Cs-137 1 x 10'8(8) 1' .0* (7) 1950 1 x 10' (7) Initiates 043-RE44 switch to am-0-G-RE-05 Omtrol lodine (4) 10
*II to 10 1 x 10 -10 1-131 9 x 10(8) 9 x 10'8(7) 1950 9 x 10-8(7) trol rtxJn
"*M
rexa air -7 -2 -7 Er-85 1 x 10-5(8) 1 x 10-4(7) 1950 1 x 10-4(7) tilaticm on staply Gasmus (3) 10 to 10 2 x 10 high gaseous nonstors activity via the ESF 3 Sappio flow for usuft danrwl is 3 cfm. (1) Mc = marumm detectable azumntration. (2) nden fwl is in the building. (3) Reta scartillatica chtector. (4) Ganse scintillaticm &tettor. (5) Gama meruttivu ion easear. (6) When in geration. (7) 10 MC. (8) PTC. (91 om ortkr of mapittudi dx)we MC to avoid snutricus alarius ard to irdicate primary to secordary leakage. (10) Tw oreru of magrutu& atine Mc to indioste ricp11ticant inloakage of radioactivity. lev. 2 6/81 1 o)
\
v l P00RDRGEL
MXE-ER(CIS) TABIE 3.5-7 (Sheet 2) AIRBOP E PIOCESS AND IFEI,UEFC RADIQACTIVITY KUTIORS AIRBOPfE IFFLUE2R RADIQACTIVITY KhTIORS Minim a Control- Alert Hi Total Required Penitor Type Range MX' (1) ling Alarm Alarm Ventilation Diluticm Sensitivity Otritrol 6txiitor (cont 2nuous) ( u Ci/cc) (uCi/ce) Isotore ( u Ci/ce) ( u C1/ce) Flow (cfm) Factor ( D Ci/ce) Ebneticri
-12 ^I 0-CT-RE-21 Particulate (2) 10 to 10' 1 x 10 Cs-137 (8) (7) 66,000 (4) (5) Alanns Plant -11 -6 ~10 unit vent Icxiine (3) 10 to 10 1 x 10 I-131 (8) (7) 66,000 (4) (5) (6) nonitor
-7 -2 -7 casecus (2) 10 to 10 2 x 10 Kr-85 (8) (7) 66,000 (4) (5)
-12 -11 0-G-RE-10 Particulate (2) 10 to 10' 1 x 10 Cs-137 (8) (7) 12,000 (4) (5) High alann te
-11 -6 -10 isolates the building Iodine (3) 10 to 10 1 x 10 I-131 (8) (7) 12,000 (4) (5) waste cyts exhaust ,7 ,y ,7 decay tank annitor ca - (2) 10 to 10 2 x 10 Kr-85 (8) (7) 12,000 (4) (5) discharge line O-GL-RE-60 Auxiliary ParticuD te (3) 10 -12 to 10
~7 1 x 10~I1 Cs-137 (8) (7) 20,000 (4) (7) Alarms Ventilation Exhaust tenitor 0 G-RE-41 Acx:ess Particulate (3) 10 -12 to 10~ 1 x 10
-11 Cs-137 (8) (7) 1950 (4) (7) ' Alarms Control Area Ventilation Exhaust Monitor Sarple flow for each channel is 3 cfm.
(1) POC = mininn detectable ocmoentration. (2) Beta scintillation detector. D (3) G&ma scintillation chtector. 3 X Q (4) Dilution factor = vent flow rate in m /sec g (annual average). (5) Mininn . unird sensitivity of nonitor in Ci/cc at naxunn allowable annual averacy concentration of controa41ng imtepe at monitor which will result in annual average Agendix I (bse at the site boundary = pcpulation MEC for controlling i mtope x 1~ x 1 x 1 where the bioacceulation factor is 1 for 106 bwilation factor dilution factor ed ncble gases and 1,000 lu ; .adines and particulates. See Offsite Doss: Calculation Manual. py (6) Grab sanples will be analyzed in the laboratory, and low iodine concw. rations will be calculated, i
./ using previously mt&lishM ratim.
o (7) High alann is set to ersure that TVdinical Specification limits (the 10 CER 20 general pcpulation j MPCs for the controlling isotopes at the boundtry of the restricted area) are not exceedecf. - (8) Alert alarm is set to alert cperators to that average concentration which, if maintained for a full
- year, would result un the 10 CTR 50 Appendix I annual dose guidelines beiry reached.
D" See Offsite Dose Cal ulation Manual. Rev. 2 6/81
. . ~ . . . - - - - . - - -- -. - ..., . -- -
+
I WCGS-ER (O'LS) w .\ lf
\s,j/ plant.. Pretreated water (11.6 gpm/ unit) ~is.-further . processed
. throughiweak-base, strong base, strong acid,-and mixed bed
- lon.exchangers and then pumped to a cycled condensate-storage
- tank where it'is.added to the condensate feed as required.
;- The following sections discuss the chemicals.used in these
- water treatment-systems.
T . 3. 6. 3.1. Pretreatment System The pretreatment system for the potable. water and demineral-ized water systems consists of'one chlorinator,la chlorine 4- retention tank, two ferric sulfate pre-mix tanks, two lime softeners (one.a spare), one acid feed (pH adjustment) system, one clear well', three' sand-filters (one-a. spare), three carbon' filters (one a spare), and one filtered water storage tank.
- During normal plant operation, the system operates inter-1 .mittently.
~
The chlor'inator, lime' softener, and acid feed system operate u at 1000 gpm'for approximately 30 min / day.- The two carbon I filters (one a spare) and two sand filters (one a spare) ! each operate at 167.to 250 gpm for approximately180 min / day. i- Blowdown from the lime softener and the carbon and sand filter 1 produces all of the waste generated in the pretreatment system. The lime-softener blowdown rate is 50 gpm for 4 minutes for
- each 20 minutes of operation. Blowdown consists of 3 percent solids by' weight. Solids are composed of 97.8 percent' calcium
- carbonate (CACO ), 0.36 percent magnesium hydroxide
- 3 and 1.8_ percent ferric hydroxide (Fe [OH] . The blowdown (Mg[OH)2)'l 1 is discharged-into the lime sludge pond, w$)ich is sized to , contain all the influent for one-unit operation. l l .The carbon and sand filters are backflushed for about 10
- minutes once every 7 days. Each carbon filter requires 5660 - ;
j- gallons of backwash water, and each sand filter requires ! 3410 gallons of backwash water. The backwash is discharged [ into the lime sludge pond. i L 3.6.3.2 Demineralizer System The demineralizer system consists of two parallel deminer-l alizer~ trains (one a spare), each designed to produce a min-4 imum of 216,000 gallons of demineralized water in a 24-hour . period. Each' train operates at 150 gpm and requires regen-eration every 13 days. During normal operation, one train l . is used approximately 2 hr/ day. Each demineralizer train consists of a strong acid cation unit, weak base and strong base anion units, and a mixed bed polisher. The mixed bed polisher requires one regener-ation for every 14 regenerations of the train. The chemicals Rev. 2 3.6-5 6/81 l l p ---,-m , ,-,.nn-,.,,--w,--,. - -- , -,.e --n., v ,r,,,.e.,w-wm- -r,.,,,.,re-,,,w, ,,,-,-a,-,., _-...wnv,..- -,,,--,-,-r,-e-v--
WCGS-E R (OLS ) used to regenerate a train and a mixed bed polisher are given in Table 3.6-2. The amount of water used to regenerate the primary unite is 35,600 gallons per regeneration. The mixed bed units require 7,523 gallons per regeneration. Impurities removed by the demineralizers are listed in Table 3.6-6. Waste produced during regeneration (regenerates anC impuri-ties) is discharged to the lime sludge pond. 3.6.4 SERVICE WATER SYSTEM Service water used to cool plant equipment is withdrawn from the cooling lake at a flow rate of 90 cfs per unit. Of the total flow, 83 cfs is circulated through the plant, and re-turned to the cooling lake; the remaining 7 cfs is used as backwash water for traveling screens and strainers and is also returned to the cooling lake. The service water is chlorinated in the same manner and for the same reasons as the circulating water (see Section 3.6.2.1). The feed rate is carefully monitored so that the amount of chlorine added is only slightly greater than the chlorine demand of the water. The free chlorine residual concentra-tion is maintained between 0.1 and 0.5 mg/ liter at the service water discharge. Free chlorine residual dissipates rapidly when discharged to the cooling lake and will therefore have little effect on the lake. The predicted chlorine usage for the service water system is approximately 100 lb/ day per unit 3.6.5 ESSENTIAL SERVICE WATER SYSTEM Essential service water is withdrawn from the cooling lake at a flow rate of 33.5 cfs per unit, circulated through the plant, and returned to the cooling lake. There is no chem-ical treatment of the essential service water. 3.6.6 SANITARY WATER SYSTEM Water used for plant sanitary purposes is treated in a sewage treatment system, and the effluent is treated with sodium hypochlorite. The sodium hypochlorite is added as a 15% solution with water with a maximum free chlorine residual of 1 mg/ liter. 3.6.7 AUXILIARY STEAM SYSTEM Blowdown from the auxiliary steam system is discharged to the oily waste system sump. The typical chemicals added for boiler water treatment of the auxiliary steam system are described in Table 3.6-3. t 3.6-6
w .- , . . . - , - . ~ L o WCGS-?R(OLS). [7s 3.6.8- PLANT DECONTAMINATION SYSTEM.
~
Chemically treated water in the p1 ant ~ decontamination' system is not -directly discharged to the -' lake but. treat'ed in the radwaste system and then discharged. _ Typical chemicals.used inithe' decontamination system are Turco Decon 4521, and Turco.
- Decon 4502 (see Table'3.6-3) The resulting decontamination solutions are sent.to the' chemical waste tank. -These wastes are then' transferred to the solid radwasteJsystem and solidified for burial.
t 3.6.9 RADWASTE' SYSTEM ' Waste systems such as those from floor drains,-power block equipment drains, laundry wastes, steam generator blowdown, and other wastes'are processed through the radwaste system - (see~Section 3.5). , a 3.6.10 OTilER. WASTE STREAMS
- 3. 6 .~ 10.1 Oily Wastes i
. Wastes leaving the' power block, collectively known as the oily waste. system effluent, are discharges to the site oil
- separator. These wastes consist of a mixture of the follow-LO \ i ing liquids:
G a. IIVAC condensates; j
- b. lube oil (vapor extractors);
- c. radiation monitor effluent (circulating water) ;
{ 1 !- d. ~ miscellaneous sources (valve stem leakoffs, com- [ pressed air condensate, equipment seal leakage); i e. ~ domestic water (washdown); I
- f. fire protection; and-
]' - g. auxiliary boiler' blowdown. The actual amount of effluent from any one liquid source is dependent on equipment condition .(seals, packing, etc. ) i and power block operation phase (plant shutdown, normal oper- _ ation, maintenance, etc.). These effluents are discharged
- , from power block sumps to the oil separator via-centrifugal
. sump pumps. They have a batch flow rate of approximately 100 gpm. The average duration and frequency of discharge
- is 1 minute, 9 times per hour during normal operation and l 15 times'per hour during plant shutdown. The effluent could 3 f. consist of all, a combination of, or a single component of
- ,r '
i Rev. 2 3.6-7 6/81
--...--,--,,-y-, .-c,w,.---,--. - , . - , , , - , , _ . . - - ,....-,-w. , . - , . . _ _ . ~ - . . - , - - , - - ..--...,--#%-,,my, ,.-w.%, ,yr-emy-,-wy.w.,..,9,mm,,ew.9.w
WCGS-ER (OLS) these liquids. The oily waste separator receives these ef-fluents, along with drainage frcm various yard and equip-ment drains. The oily waste separator separates the oils from the water using their density difference. The condensate /feedwater leakage is normally routed to the secondary liquid radwaste system for internal processing and recycling. In the event of a fire and subsequent fire protection system actuation, the sprinkler discharge water and a condensate / feed-water mixture will be discharged to the cite collection system, but 10 hours of flow (approximately 2000 gpm) can be held if it is not possible to discharge to the site collection system immediately. The fire protection water discharged during a fire will contain an increased amount of contam-inants (solids and dissolved products of combustion), the composition and quantity of which are general.ly undeter-minable. The domestic water source (washdown) is normally zero but may increase to as much as 10 to 50 gpm during power block shutdown-maintenance operations. Closed cooling uater has not been included because all pumps have mechanical seals (zero leakage anticipated) and all drains are capped. Any closed cooling water maintenance drainage is collected ir, portable containers for recycling or disposal. The amounts of effluents during normal, design, and worst conditions are indicated in Table 3.6-7. Worst condition refers to occurrences such as tank overflows. The miscellaneous sources previously mentioned are approxi-mately 75% c.irculating water and 25% domestic water. To prevent corrosion in the power block system, potassiuna chro-mate is added to the component cooling water and closed cool-ino water systems. A similar inhibitor is added to the chilled water system. With good maintenance and housekeeping, none of the corrosion inhibitor fluid will be discharged (see Table 3.6-3). 3.6.10.2 " ansformer Vault Effluents Transformer ffluents could be discharged from the service station ano engineered safety feature (ESP) transformer, the main and unit auxiliary transformer, and the start-up transformer. Normally, effluent release will be due to rainwater accumulation in the vaulta and is controlled by normally closing a manual valve. Should an oil spill occur, the oil can be pumped out with a portable pump in lieu of draining it out through the valve. The amounts of effluents during normal, design, and worst conditions are indicated in Table 3.6-7. 3.6-8
t
'WCGS-ER(OLS)-
i
\ -
TABLE 3.6 l WATER' ANALYSES (All Values in.mg/ liter as Substance Except Where Noted) COOLING LAKE JOHN REDMOND '1WO UNITS ONE UNIT RESERVOIR (88.5 percent load) (100 percent load) SUBSTANCE- NORMAL DROUGHT NORMAL"' DROUGHTD NORMAL DROUGHTb Calcium 89 125 214 389' 172- 218 Magnesium- 22 31 53 96 43 54 Sodium 24- 34 58 '106 46 59 Bicarbonate 233 326 80 52 129 74 (as CACO3 ). Sulfates 89 125 674 1329 480 701 Chlorides 28 40 67 124 54 70
. b TDS 400 560 1133 2089 888 1153 i
I J pli 8.0 8.0 7.7 7.1 7.5 7.3 i i a t a
~
- "Averace values during the post drought years.
I Maximum values. Adjusted for acid addition.
ad TABLE 3.6-2 CHEMICALS USED AT WOLF CREEK GENERATI!$ STATION SITE - UNIT 1
~ ' !C *A 7ECJW 7 A*T *A*I ' 9 FSI 3C 'XT eV;tTTY NP 17e AKAL ?r**v %eu-ds)
'i*CM Sadia ?fdr's11e 6:W) -eastie *Jsed to regene nte pringry ced It/ redes once every 13 dvs demi-erallre-s. 625 g ap* g
'le ?M SMia ? /dromite 13%) Coustie Used to regenerete timed tet 2 C lt/ regen ove every ;*2 inyt kSO deziner=11:ers.
32S0h fulfurie Acid *; W 1 M
- Pe 1 sed to regenergte primery bei 1.125 !!/*eges o*se every 13 $ays 31,590 temine-alizers.
- tS-Jk Sulfurie Acta (1008) C' He Used t3 resenerete mixed het 320:t/reses sv e every 19l? days (50 dominere11rers.
J5Ch Eu. Parte Ac12 IJOT) M' Pe Feduce scalins teMevy of circulating 6.'5 m l E ;b/iny C ntinuous .N Ur.it 3ernal - 2.2L z 1C7 I O weter. o.63 x l'* It/s.y Two t. git F.ernal . 3.51 x 107 5.h6 m 1 7 1:/s,y Q One l'ait Irs-ht - 2.36 a 107 m 7.& 3 11" i:/da7 % *.htt Irought - 2.53 x IC7 l 2 nlorine es revent tio:ogies; fouliv -f %;2 le/tcec 3/dey f r 30 minuten 5 M coMe ser. k 51 s 10 /mit . y C'p Chlorine *ns *revent biol3gieel fouling ?f rw - 33 3 lb/bse 3/ day for N minutes esse st ia.' service eter system. 3.6b a l h/unit g
*( .Jtig Calcitan it.iroxide (95) Line Used to es* ten influent to the 2.h it/13CC gal.:n M minutes /dey v
2b,25 deminerali ed *M PSteble w9ter syst ems. hCCh Suitarie Acid (lW.) 4 ' P, pr! Adhstme7t of the line softened 3 % lb/dey Int ermitt ent ;,l'X) water. 01; rnlorine Oes Prevent biols.-ieal fouling of pretreatment system. 2. M lt/dsy !stermittent 9;c Fep(SCg,1'3 Ferrie sulfate toegu'ont Als 'Ised to soften influent to the At lb/ day F3 minutes / day 1,680 1enineralized a.M pot =ble wvter systems. Ne0Cl Soditus Hypochlorite (IM) Tertiary sewge treatment. C.26 gellsna per day Continuous 960
%0rl Soditus Hypxhlorite (15') 1%teb'e water disinfectiwa.
- o o.085 gallons Per dey continuom 3;5 ss_
M t-1
ii % 4 l t 1 TABLE 3.6-3 f 5 CHEMICALS USED IN POWER BLOCK ONLY t 6 i 1 1 4 I > 4 CET4!* M VE *WE VW _ _ - CO*"fF3l g F0E*.A F3TS! 'U YHTS imiM.ie. 33 Adfast p51 cf sus 111ery boiler
, );)t)* r:
- 1 Rydresime 'N2Ti2 Raume cuygen fra botier veter.
I
~
1 fi 7, P ) * ? hree Decon h521 Oustete, eitrate, emmenten ions, inhititore, For decontamination of eculpment - Dispneed of la redweste syst e. l 3,,,,' surfectent, and a foam suppressant. and plant fee 111 ties.
. 43 f* e ,'. - ho Mos Fotassima permangenste, potessia hydraaide, Predecorr mainetton oxidiser end Elsposed of in redweste system.
end e wetting egent. conditioner. l
.g ,
' $stesolum Chrtunate EgCrOt. ; ' Corrosion inhibitor for the No 11guid discherge' to environ-j c=ponent cooling water end closed ecoling veter systeem.
ment is antiespeted. 3 @, ! - , . M
- o ,
j
* .n of L-e -
l (n -
.e I v 1
l I T l Q - l C - I g - I J Q" M Rev. 2 i W es%. 6/81 D - i: r--- 1 1
- y TABLE 3.6-4 WOLF CREEK COOLING LAKE I PREDICTED MONTHLY TDS CONCENTRATIONS (1949-1964) FOR TWO-UNIT OPERATION l
(All Values in ag/ liter) l l JUL AUG SEP OCT _ NOV DEC YRAR JAN_ FEB MAR _ APR MAY JUN _ 394.0 401 0 408.5 4 15.3 428.0 437.7 447.3 457.5 466.0 1949 385.8 384.6 387.3 482.8 492.0 500.3 505.7 508.9 511.7 519.5 532.4 545.6 553.6l 1950 470.6 476.0 571.9 577.6i 565.8 570.0 573.2 575.6 552.8 549.7 , 549.2 561.3 1951 558.5 562.3 702.0 721.1 727.2 581.7 5 86.2 588.5 592.3 601.7 616.2 633.0 651.9 675.9 1952 934.7 944.9
- 739.6 743.2 756.3 763.6 786.6 808.8 846.2 882.8 918.6 1953 .733.3 1157.0 1179.2 1193.0 1207.6 0 955.5 %2.9 977.5 990.4 980.2 999.4 1047.5 1103.7 1954 1207.0 1220.5 1226.6 1253.8 1309.2 1355.1 1358.0 1390.2 1399.2 y 1955 1204.1 1199.7 1200.1 1434.4 1452.6 1458.9 1504.6 1564.7 1643.3 1710.6 1726.3 1735.2 tis 1401.3 1393.3 1409.1 1956 1711.1 1680.5 D
1574.7 1518.1 1506.6 1479.1 1427.2 1357.4 1300.3 3 1957 1737.0 1721.8 1724.2 1085.9 1057.9 1034.0 1000.9 992.8 990.4 990.4 990.1 985.3 @ 1958 1245.2 1199.3 1138.0 967.2 $ 969.6 966.6 965.1 965.7 963.7 969.4 978.2 967.5 970.0 1959 978.2 972.6 934.1 945.3 938.1 933.4 932.1 935.1 937.0 943.2 941.2 936.4 1960 961.5 953.5 909.6 906.9 929.5 925.0 920.8 914.6 893.6 .898.3 907.7 916.4 908.7 908.2 1961 862.4 859.5 852.3
$91.7 885.0 880.0 881.1 873.5 872.0 875.3 868.0 1962 900.9 855.3 855.9 849.3 844.8 837.7 829,7 827.6 82 8.4 828.0 833.9 841.9 847.5 1963 835.8 832.8 841.7 839.6 835.7 832.8 826.3 830.7 839.3 834.5 836.8 1964 845.5 Note: Values are based on two units operating at 88.5 percent average annual load factor. " Start of design drought period.
End of n drought period.
1 WCGS-ER(OLS):
- ^ \j 3.9 TRANSMISSION FACILITIES ^ TT . .; ,
3.9.1 GENERAL DESCRIPTION -
+ c Except for minor modifications noted in the following dis- !
cussions, the routes, stru;tures and clearing methods are as originally described. in Section '3.9 of the Environmental Report - Construction Permit Stage (ER(CPS)). The transmis-sion lines described herein are the preferred routes defined in that original document. The WCGS required construction of transmission line inter-connections to +he.KG&E and KCPL systems (Figures 3.9-1 and 3.9-2). The connection to the KG&E system is'a 345-kV line extending 97.6 miles in a west-southwest direction from the generating station substation to the existing KG&E Rose Hill Substation. The interconnection!to the KCPL-system is a 345-kV line extending northeast 49.2 miles to where it enters an l l existing transmission line' corridor which was widened to ' accomodate the additional line. The' transmission line then continues along this dual corridor for 7.2 miles 'to ~ West I Gardner Substation. ( The KEPCo system will continue to be served by existing 'O interconnections at KG&E an'd' KCPL- substations with the F/ exception of the construction'by-the Coffe'y County REC of a' [, V 69-kV line from WCGS to the Phillips Petroleum Company pipeline pumping station near Sharpe, Kansas, KG&E constructed a four mile long 69-kV tap from the Athens-Burling, ton line to the WCGS. 3.
9.2 DESCRIPTION
OF TRANSMISSION RIGHTS-OF-WAY 3.9.2.1 Wolf Creek-Rose Hill Transmission Line The right-of-way for the Wolf Creek-Rose Hill transmission line shown in Figure 3.9-1 extends 97.6 mile's from the Wolf Creek Substation to the Rose Hill Substation. The 345-kV the single circuit line is carried for the maj ority of transmission route on wooden H frame structures. Transmis-sion line structures are discussed in more detail in Section
~~
3.9.3. The width of 'the Wolf Creek-Rose Hill right-of-way required to accomodate the 345-kV line is 150 feet. To construct the Wolf' Creek-Rose Hill line, right-of-way agree-ments for access to 1775 acres are required. The total acreagc required for the Wolf Creek Substation is 10.3 acres. T T %. . Cs) Rev. 2 3.9-1 ' 6/81
WCGS-ER(OLS) l 3.9.2.2 Wolf Creek-West Gardner Transmission Line l The right-of-way for the Wolf Creek-West Gardner .transmis-sion line shown in Figure 3.9-1 extends 49.2 miles from Wolf Creek Substation in a 160 foot wide right-of-way corridor where it enters a dual transmission line corridor 260 feet wide with the LaCygne-Craig 345-kV transmission line for 7.2 miles. The 7.2 mile dual transmission line corridor was widened from 160 feet to accommodate the additional line. The 345-kV single circuit line will be carried on wooden H frame structures for the majority of the transmission route. Transmission line structures are discussed in more detail in Section 3.9.3. To construct the 56.4 mile Wolf Creek-West Gardner transmission line, right-of-way agreements for access to 1041 acres are required. 3.9.2.3 Wolf Creek Tap of Athens-Burlington Transmission Line The right-of-way for the 69-kV Wolf Creek tap of the Athens-
.Burlington line (F.igure 3.9-2) extends east out of the Wolf Creek Substation, then south and east along the cooling lake to connect to the existing Athens-Burlington line. The total length of this line is 4.05 miles. The width.of the right-of-way to accommodate -the 69-kV line is 50 feet. Only one-quarter mile of the line is outside the site property boundary requiring right-of-way agreements for access to 1.51 acres.
3.9.2.4 Wolf Creek to Coffey County REC Transmission Line The right-of-way for the 69-kV line from Wolf Creek to the Coffey County REC extends east out of the Wolf Creek Substa-tion, then north to connect with the ahillips Petroleum Company pipeline pumping station near Sharpe, Kansas. The total length of this line is .approximately three miles. The width of the right-of-way for :the 69-kV line is 100 feet. Right-of-way agreements were obtained with KG&E and other property owners along the line right-of-way. 3.9.2.5 Land Use Classifications l The land classification types crossed .by the transmission lines are those described in the :ER(CPS) . . Additional land classification has been accomplished since then by the United States Department of Agriculture Soil Conservation Service-(SCS) for the national program of inventorying prime and unique farmland .(SCS, .1979) . Transmission lines from WCGS pass through seven counties of Kansas. Soil types classified as prime farmland by the Rev. 2 3.9-2 6/81
WCGS-ER(OLS)
. SCS are ' found within the transmission line corridors. Table ;
3.9-1 provides- a quantification of the percentage of the The transmission line corridor which is prime farmland. percentage of ' prime farmland which is within the Wolf Creek-Rose Hill ' transmission line right-of-way is 47% and 68% for the Wolf. Creek-West Gardner'right-of-way. Only land that is required for the foundations of the trans-mission towers will be removed from production. Therefore, the majority of the transmission corridor 'will continue to ~
- be used for agricultural-purposes and no significant removal
' of prime farmland from production will result
- 3.9.3' GENERAL DESIGN AND SELECTION OF STRUCTURES i
l Transmission tower structures are planned for use as de-scribed in the ER(CPS) Section 3.9.3. The wooden H frame ' structures are used to support nearly all of the transmis-sion lines and are treated with pentachlorophenol oil in l lieu of cellon asfdescribed in theThus, ER(CPS). The oil treated I structures age less rapidly. the potential for en-vironmental disturbance is reduced due to less required tower repair and replacement after the lines are initially put into service. Cellon was originally chosen because it was felt that the structures treated with cellon, which -age f' to a natural gray, would more readily - blend into the sky-line. However, the actual difference in the ability of either pole to blend into the environment is not markedly l different. The visible impact of the transmission lines ! has, however, been reduced where feasible ' by routing the lines so that they are screened by trees and hills. ! 3.9.4 GENERAL TREATMENT OF RIGHTS-OF-WAY Access, treatments at highway and river crossings and main-tenance practices for the. transmission lines are as dis-cussed in the ER(CPS) Section 3.9.3 except as noted below. Herbicides used to maintain transmission rights-of-way will be only those herbicides approved for use at the time of such maintenance by the EPA and the Kansas Weed and Pesticide Division of the Kansas State Department of Agriculture. Rev. 2 3.9-3 6/81
. , , , - . . . - . _ ~ _ . - - - - - _,.,-,, -,-,
~
1 WCGS-ER(OLS) l l TABLE 3.9-1 PRIME FARMLAND CROSSED BY TRANSMISSION LINES
- i
, Wolf Creek-Rose Hill Wolf Creek-West Gardner l 4 Miles Percent Miles Percent i Total Prime Prime Total Prime Prime County Miles Farmland Farmland Miles Farmland Farmland Butler 35 15 43 -- -- -- Greenwood 38 12 32 -- -- -- Coffey 25 19 76 11.9 7 59 l 1 Anderson -- -- -- 7 6 86 il -- 24 14 58 l Franklin ** -- -- i Miami -- -- -- 10 8 80 1 4 Johnson -- -- -- 3.5 3.3 94 l ' Total 98 46 47 56.4 38.3 68 l 4 l l 1
- Source: US Soil Conservation Service data, 1979.
** Partially estimated.
] I Rev. 2 } 6/81 1 I i
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. . 2" j((-
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,_lf;#. _._.
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34s Kv une 1 -~. - F* . Wolf Creek-Rose Hill 345 KV Line.] . =l m } ,. *l , l ,, l ) LaCygne-Eenton 345 KV Line Rev. 2 6/e1 ) WOLF CREEK GENERATING STATION l UNIT NO. I j
} hAthens-Burlington69KVLine ENVIRONMENTAL REPORT (OPERATING LICENSE STAGE) y Wolf Creek Tap
. Wolf Creek-Sharpe 69 KV Line FIGURE 3.9-2 I TRANSMISSION LINE Scale: 1/2" = 1 Mile RIGHT-OF-WAY ALIGNMENT Dr. GLS Date 1-3-75 1
WCGS-ER (OLS ) (o)
%d TABLE 3A-1 PLANT DATA FOR SOURCE TERM CALCULATIONS A. General
- 1. The maximum core thermal power 3,565 evaluated for safety considerations in the SAR (ultimate rating), MW(t)
- 2. Plant capacity factor, percent 80
- 3. Core properties (a) The total mass of uranium 196,000 in an equilibrium core, lb (b) The total mass of plutonium N/A in an equilibrium core, lb (c)' Enrichment of uranium in 3.5 l reload fuel (max.), percent (d) Fissile plutonium in reload 0.0 fuel (max.), percent
(\' (e) Fuel cladding defects number of rods, percent 0.12 (f) Cladding material Zircaloy-4 (g) Escape rate coefficients Same as R.G. 1.112 B. Reactor Coolant System Properties
- 1. Mass of primary coolant, 5.3 l x 105 lb(1)
- 2. Mass of primary coolant less 5.04 pressurizer volume, x 10 5 lb
- 3. Mass of primary coolant in 2.1 reactor, x 10 5 lb
- 4. Primary coolant flowrate, 142 x 108 lb/hr
- 5. Number of loops 4 j Rev. 2 6/81
l WCG S-ER (OLS) TABLE 3A-1 (Sheet 2)
- 6. Average primary letdown rate 75 to CVCS, gpm
- 7. Average primary letdown rate 7.5 to CVCS cation demineralizer, gpm
- 8. Average shim bleed flowrate, gpm 1.3
- 9. Chemical and volume control See Figure system parameter 3A-2 (Sheet 1) and Table 3A-2.
- 10. Boron recycle system parameters See Figure 3A-2 (Sheet 2)
&nd Table 3A-2.
- 11. Reactor coolant degassing Continuous in VCT (CVCS) or recycle evaporator (BRS)
- 12. Reactor coolant leakage to con-tainment, percent of inventory per day Noble gases 1.0 Iodine 0.001 C. Secondary System
- 1. Steam Generator Number 4 Type Recirculation U-tube Carryover, percent 0.25 Iodine partition factor 0.01 Nonvolatile partition factor 0.ra' Type of chemistry AVi Operating temperature, F 554.6 Operating pressure, psia 1000 1 Mass of steam each, (2) lb 8000 ;
Mass of liquid each, (2) lb 104,000 i O1
( { 1- # Q \ Q) TABLE 3A-2 PARAMETERS USED IN THE CALCULATION OF ESTIMATED ACTIVITY IN LIQUID WASTES Collection & Decay l Collector Tank Volume'of Specific Period Assumed , With Sources . Liquid wastes Activity Basis Before Discharge Comments i A. Reactor coolant drain 300 gal / day 1.0 PCA(1)' O.05 gpm/R.C. pump #2 None 10 percent assumed tank seal leak and other discharged. Balance miscellaneous leakage recycled to BRS. B. Letdown shim bleed 1,840 gal / day 1.0 PCA(1) CVCS inventory control None 10 percent assumed . discharged. Balance-t recycled to BRS. , C. Waste holdup tant 400-gal / day 0.5 PCA(1) None Recycled to RMWST l
- 1. Equipment drains Tank drains, filter drains, heat exchanger drains, demineralizer 1
drains 5 n
- 2. Excess samples Miscellaneous pre- h.
purges sample I tn
- D. Floor drain tank 1,140 gal / day 0.06 PCA(1) None Recycled to RMWST or l[
l discharged O t*
- 1. Decontamination Fuel cask, vessel head Nominal discharge. ~$
water system component flushing, will be 5,000 gallons j floor washdown, etc. at 35 gpm, approxi-mately twice a week. Annual release is given in FSAR Table 11.1-2. 1
- 2. Laboratory Washing and rinsing of
, equipment laboratory equipment.
Reactor grade drains which are aerated. Maintenance drains for filters, H. Er., demin-eralizers, etc. a j E. Chemical drain tanks 7,000 gal /yr Samples plus sample 90 days Drummed' rinse water 1 1
) Rev. 2 j 6/81' i
TABLE 3A-2 (Sheet 2) Collection & Decay period Assumed Collector Tank volume of Specific Liquid Wastes Activity Basis Before Discharge cmments With Sources _ NUREG-0017 None Recycled within F. Laundry and hot 450 gal / day closed laundry sys-shower tank tem or discharged. Nominal discharge will be 5,000 gal-lons at 35 gpa, approximately twice per month. Annual release is given in FSAR Table 11.1-2. Continuous blowdown None Normally recycled to G. Steam generator 86,400- 1.0 SCA (2) condensate /feedwater 518,400 gal / of 60-360 gpm day system None Discharged or re-H. Secondary liquid 7,200 gal / day (3) Floor drains cycled to con- lE: waste drain and equipment O drains densate storage collector tank tank. Annual release is given Oe in FSAR Ta51e trj 11.1-2. ] O Condensate deminer- 4,286 gal / day (3) 15,000 gal /high None Processing options e I. are: CD alizer regeneration TDS regeneration
- waste - per 1. Neutralize and waste discharge regeneration
- 2. Process and recycle to con-denser
- 3. Evaporate and discharge 12,857 gal / day (3) 45,000 gal / low Recycled to second-TDS regeneration ary cycle or dis-waste - per charge regeneration (1) PCA - Primary coolant specific activity (2) SCA - Secondary coolant specific activity (3) Fraction of SCA internally calculated by GALE Code.
Rev. 2 6/81 9 9 9
_ - . . _ _ _ . - - . . . _ - _ _ _ _ ~ . _ , _ . _ _ - _. - _ . . , _ . _ - . _ . . . - - - - -. >- - - - - - d T b TABLE 3A-4 (Shaet 2) ; Physical Characteristics of Effluent Building Streams Free tolume Point of Shape of Flow rate Temperature Velocity Source (cu. ft.) Release _(1) Filters (2) Exhaust Vent g (cfa) (F) (fam) H. Access control 208,000 Unit vent Exhaust - Continuous 6,000 104 max. - area .! P-H-C-H { I. Main steam 166,000 Unit vent None - Continuous 23,000 120 max. ~ enclosure $ l l 5 o O Us i M 30 O h w
+
(1) Grade elevation is 2000'-0" (2) P = prefilter or roughing filter, H = HEPA filter, C = charcoal adsorber _m - . _ _ _ _ _ _ _ _ _ . l
TABLE 3A-5 GALE CODE INPUT DATA SNUPPS Nuclear Unit IVR Parameters value Thermal power level (megawatts) 3565.000 Plant capacity factor 0.800 Mass of primary coolant (thousands Ibs) 530.000 Percent fuel with cladding defects 0.120 Primary system letdown rate (gpm) 75.000 Letdown cation demineralizer flow (gpm) 7.500 Number of steam generators 4.000 Total steam flow (millions lbs/hr) 15.850 Mass of steam in each steam generator (thousands Ibs) 8.000 Mass of liquid in each steam generator (thousands lbs) 104.000 Cass of water i.i steam generators (thousands Ib.;) 416.000 Total tass of secondary coolant (thousands lbs) 3570.000 Steam generator blowdown rate (thousands lbs/hr) 176.000 Primary to secondary leak rate (lbs/ day) 100.000 Condensate demineralizar regeneration time (days) 17.500 g Fission product carry-over fraction 0.001 O Halogen carry-over fraction 0.010 @ Condensate demineralizer flow fraction 0.684 : Radwaste dilution flow (thousands gpm) 5.000 trj
;c O
t* tn Liquid Waste Inputs Collection Decay Flow Rate Fraction Fraction Time Time Decontamination Factors Steam (gal / day) of PCA Discharged (days) (days) I Cs others Shim bleed rate 1.84E+03 1.000 .1 0.0 0.0 1.00E+ 06 4.00E+03 1.00E+05 Equipment drains 3.00E+02 1.000 .1 0.0 0.0 1.00E+05 2.00E+03 1.00E+04 Clean waste input 4.00E+02 .500 .1 0.0 0.0 1.00E+04 1.00E+05 1.00E+05
.058 0.0 0.0 1.00E+04 1.00E+05 1.00E+05 Dirty waste input 1.14E+03 1.0 S.C. blowdown 3.80E+05 (1) .0 .0 .000 1.00E+03 1.00E+02 1.00E+03 Untreated blowdown 1.27E+05 (1) 1.0 0.0 .000 1.00E+00 1.00E+00 1.00E+00 Regenerant solutions 4.71E+04 (1) .0 .0 0.0 1.33E+02 2.67E+02 1.33E+02 (1) Fraction of SCA internally calculated by GALE Code Gaseous Waste Inputs There is continuous low vol, purge of vol. control tk Holdup time for xenon (days) 9.0E+1 Holdup time for krypton (days) 9.0E+1 Fill time of decay tanks for the gas stripper (days) 0.0E+0 1
5 i N g (7.5 gpm) - Divert to Boron Recycle System (1,840 gpd @ 1.0 PCA) num 2 mumm ; Vent to Gaseous Radwaste System Return to Letdown (75 gpm @ 1.0 PCA)
; 1 3 mumm - 4 % Reactor Coolant System DECONTAMINATION FACTORS Cesium & Other lodit3 Rubidium, Nuclides
- 1. Mixed Bed Demineralizers 10 2 10
- 2. Cation Bed Demineralizer 1 10 10
- 3. Reacte,. Coolant Filter 1 1 1
- 4. Volume Control Tank (a) _ _ _
System DF 10 20 10 2 (a) For noble gases, a value of 0.25 is built into the GALE code for the y parameter for the case of continuous VCT purging. Chemical and Volume Controi System WOLF CREEK GENERATING STATION UNIT NO.1 ENVIRONMENTAL REPORT (OPERATING L. CENSE STAGE) Figure 3A-2 (Sheet 1) System Decontamination Factors _ _ . -. . . - _ - . . -- _ . . - . - . . ~ . _ _ _ _ _ _ _
Plant Discharge R. C. Dr Tank ent to juk Via Liquid Radwaste (300 gpd @ 1.0 PCA) Gaseous Radwaste System i (Equipment Drains) Rer hg Letdown 1 2 mummmma 3 mummmmmmu 4 mmmmmmmu 5 -umm. 6 - 2 Water Tank I ; (2,140 gpd) (1,840 gpd - shim bleed)A a n----------- n DECONTAMINATION FACTORS Cesium & Other lodine Rubidium Nuclides
- 1. Recycle Evaporator Demineralizer (a) 10 2 10
- 2. Recycle Evaporator Feed Filter 1 1 1
- 3. Recycle Holdup Tank - - -
- 4. Recycle Evaporator 102 103 103
- 5. Recycle Evaporator Condensate Demineralizer (b) 102 1 1
- 6. Recycle Evaporator Condensate Filter 1 1 1 System DF 105 2 x 103 104 Boron Recycle System ReV- 2 b, S i WOLF CREEK GENERATING STATION UNIT NO.1 ENVIRONMENTAL REPORT (OPERATING LICENSE STAGE)
- a. Mixed Bed Figure 3A-2
- b. Anion Bed (Sheet 2)
System Decontamination Factors
N A ( N- (O
%)
\
gask Plant Discharge p : Reactor Makeup Clean Wastes W 1 - 2 - 3 - 4 - 5 - 6 @ Water Tank (400 gpd) (400 gpd @ 0.5 PCA) DECONTAMINATION FACTORS Cesium & Other lodine Rubidium Nuclides
- 1. Waste Holdup Tank 1
- 2. Waste Evaporator Feed Filter 1 1 Waste Evaporator 103 104 104 3.
1 1
- 4. Liquid Waste Charcoal Adsorber 1 Waste Evaporator Condensate Demineralizer 10 10 10 5.
1 1
- 6. Waste Evaporator Condensate Filter 1 System DF 104 105 105 Liquid Radwaste Rev. 2 Train "A"- C! ear Waste 6/E,1 WOLF CREEK GENERATING STATION UNIT NO.1 ENVIRONMENTAL REPORT (OPERATING LICENSE STAGE)
Figure 3A 2 (Sheet 3) System Oecontamination Factors
zum 3 4 2 Discharge Dirty Waste (1,140 gpd ; 1 2 - === 5 - 6 =' 7 - 8 4 Reactor Makeup Water System
@ 0.058 PCA)
DECONTAMINATION FACTORS Cesium & Other lodine fiubidium Nuclides
- 1. Floor Drain Tank - - -
- 2. Floor Drain Tank Filter 1 1 1
- 3. Waste Monitor Tank Demineralizer (a) _ , _ _ _
- 4. Waste Monitor Tank Filter (a) 1 1 1
- 5. Waste Evaporator (b) 103 104 104
- 6. Liquid Waste Charcoal Adsorber 1 1 1
- 7. Waste Evaporator Condensate Demineralizer 10 10 10
- 8. Waste Evaporator Condensate Filter 1 1 1 System DF (c) 104 105 105 Liquid Radwaste Rev. 2 l
Train B" - Dirty Waste 6/81 l WOLF CREEK GENERATING STATION UNIT NO.1 ENVIRONMENTAL REPORT (OPERATING LICENSE STAGE) a) Used only when influent activity (10-Se Ci/cc Figure 3A-2 b) Used when influent activity!:10-SpCi/cc (Sheet 4) c) Assumes evaporator path . . System Decontamination Factors 9 9
a a
; Recycle Laundry & Hot Showers '
2 - 3 4 - 5 : Plant Discharge (450 gpd) __ (Built into the GALE code) DECONTAMINATION FACTORS Cesium & Other lodine Rubidium Nuclides
- 1. Laundry and Hot Shower Tank
- 2. Laundry and Hot Shower Filter 1 1 1
- 3. Laundry and Hot Shower Reverse Osmosis 10 10 10
- 4. Laundry and Hot Shower Charcoal Adsorber 1 1 1
- 5. Laundry and Hot Shower Storage Tank System DF 10 10 10 Liquid Radwaste. Rev. 2 Laundry Train 6/81 WOLF CREEK GENERATING STATION UNIT NO.1 ENVIRONMENTAL REPORT (OPERATING LICENSE STAGE)
Figure 3A-2 (Sheet 5) System Decontamination Factors
.-- --------__I
m Vent to = 5 Feedwater Heater 25% flash 2 - 3 -- 4 - 5 : Secondary Blowdown : 1 - Cycle Max. 4.2 x 106 lb/ day Min. 0.7 x 106 lb/ day DECONTAMINATION FACTORS Cesium & Other lodine Rubidium Nuclides
- 1. Steam Generator Blowdown Flashtank
- 2. Steam Generator Blowdown Regenerative Heat Exchanger -
- 3. S.G. Blowdown Nonregenerative Heat Exchanger _ ._
1 1
- 4. S.G. Blowdown Filters 1
- 5. S.G. Blowdown Demineralizers 102(10) 1o(10) __
1o2(10) System DF 103 102 103 Steam Generator Blowdown WOLF CREEK GENERATING STATION ... UNIT NO.1 ENVIRONMENTAL REPORTIOPERATING UCENSE STAGE) Figure 3A-2 (Sheet 6) System Decontamination Factors
7y WCGS-ER(OLS) f i kj TABLE OF CONTENTS CHAPTER 5.0 ENVIRONMENTAL EFFECTS ~OF STATION OPERATION Title Page i Section 5.1 EFFECTS OF OPEPATION OF HEAT DISSIPATION SYSTEM 5.1-1 5.1.1 EFFLUENT LIMITATIONS AND WATER QUALITY STANDARDS 5.1-1 5.1.2 PHYSICAL EFFECTS 5.1-3 5.1.2.1 Blowdown Design and Flow Rates 5.1-3 5.1.2.2 Neosho River Flow Rates -5.1-3 5.1.2.3 Kansas Water Quality Criteria 5.1-3 5.1.2.4 Temperature of the BlowdCwn Water and Neosho River 5.1-4 5.1.2.5 conclusion 5.1-5 5.1.3 BIOLOGICAL EFFECTS 5.1-6 I (jb 5.1.3.1 5.1.3.2 introduction Effects of Released Heat 5.1-6 5.1-6 5.1.3.2.1 Cooling Lake 5.1-6 5.1.3.2.1.1 Phytoplankton 5.1-7 5.1.3.2.1.2 Zooplankton 5.1-7 5.1.3.2.1.3 Periphyton 5.1-8 5.1.3.2.1.4 Macrophytes 5.1-9 5.1.3.2.1.5 Macroinvertebrates 5.1-9 5.1.3.2.1.6 Fish 5.1-10 1 5.1.3.2.2 Wolf Creek and Neosho River 5.1-14 5.1.3.3 Effects of Condenser Passage (Entrainment) 5.1-14 5.1.3.3.1 Phytoplankton 5.1-14 5.1.3.3.2 Zooplankton 5.1-15 5.1.3.3.3 Fish 5.1-16 5.1.3.4 T'rects of Reactor Shutdown 5.1-17 5.1.3.4.1 ., umber of Shutdowns per Year 5.1-17 5.1.3.4.2 Cold Shock 5.1-17 b 5.0-i
I WCGS-ER(OLS) TABLE OF CONTENTS (Continued) Section Title Page 5.1.3.5 Effects of Circulating Water and Makeup l Water Screen House (Impingement) 5.1-18 5.1.3.5.1 Circulating Water Screen House 5.1-18 5.1.3.5.2 Makeup Water Screen House 5.1-19 5.1.*.5.2.1 a Entrainment 5.1-19 5.1.3.5.2.2 Impingement 5.1-20 5.1.4 EFFECTS OF HEAT DISSIPATION FACILITIES - METEOROLOGY 5.1-22 5.
1.5 REFERENCES
5.1-23 5.2 RADIOLOGICAL IMPACT FROM ROUTINE OPERAminN 5.2-1 5.2.1 EXPOSURE PATHWAYS 5.2.1.1 Exposure Pathways For Radiation Exposure of Biota Other Than Man 5.2-1 l 5.2.1.2 Exposure Pathways to Man 5.2-2 5.2.2 RADIOACTIVITY IN THE ENVIRONMENT 5.2-4 5.2.3 DOSE RATE ESTIMATES FOR BIOTA OTHER THAN MAN 5.2-5 5.2.4 DOSE RATE ESTIMATES FOR MAN 5.2-5 5.2.4.1 Liquid Pathways 5.2-5 5.2.4.2 Gaseous Pathways 5.2-6 5.2.4.3 Direct Hadiation From Facility 5.2-7 5.2.4.4 Annual Population Doses 5.2-7 5.2.5
SUMMARY
OF ANNUAL RADIATION DOSES 5.2-7 5.
2.6 REFERENCES
5.2-8 5.3 - EFFECTS OF CHEMICAL AND BIOCIDE DISCHARGE 5.3-1 Rev. 2 5.0-ii 6/81
WCGS-ER(OLS) g'~s-( TABLE OF CONTENTS (Continued) Section Title Page 2 5.3.1 COOLING LAKE 5.3-1 5.3.2 NEOSilO RIVER 5.3-2 5.
3.3 REFERENCES
5.3-4 5.4 EFFECTS OF SANITARY WASTE DISCHARGES 5.4-1 5.
4.1 REFERENCES
5.4-3 5.5 EFFECTS OF OPERATION AND MAINTENANCE OF THE TRANSMISSION SYSTEM 5.5-1 5.6 OTHER EFFECTS 5.6-1 5.7 RESOURCES COMMITTED 5.7-1 5.7.1 URANIUM RESOURCES 5.7-1 5.7.2 OTHER RESOURCES 5.7-2 5.
7.3 REFERENCES
5.7-2 5.8 DECOMMISSIONING AND DISMANTLING 5.8-1 (O_,) 5.8.1 DECOMMISSIONING REQUIREMENTS AND ALTERNATIVES 5.8-1 5.8-2 5.8.2 LONG-TERM USE OF THE LAND 5.8.3 ENVIRONMENTAL CONSEQUENCES OF DECOMMISSIONING 5.8-2 5.8.4 DECOMMISSIONING COSTS 5.8-3 5.8.5 PLANS AND POLICIES OF THE APPLICANTS 5.8-4 5.
8.6 REFERENCES
5.8-4 Appendix SA DOSE CALCULATION MODELS AND ASSUMPTIONS SA-1 5.0-iii a i I
WCGS-ER(OLS) TABLE OF CONTENTS (Continued) LIST OF TABLES Number Title 5.1-1 Upper Avoidance and Final Preferendum Temperatures of Fishes Expected to Inhabit the Cooling Lake at Wolf Creek Generating Station. 5.1-2 List of Fish Species Which May be Established in Wolf Creek Cooling Lake 5.1-3 Hours of Fogging and Icing Due to the Cooling Lake at Selected Receptors for Data Period: 6/1/73 - 5/31/74 5.1-4 Hours of Fogging and Icing Duc to the Cooling Lake at Selected Receptors for Data Period: 6/1/74 - 5/31/75 5.1-5 Hours of Fogging and Icing Due to the Cooling Lake at Selected Receptors for Data Period: 3/5/79 - 3/4/80 5.1-6 Hours of Fog Per Month Due to Cooling Lake at Selected Receptors for Data Period: 6/1/74 - 5/31/75 5.1-7 Frequency of Temperature Change > 2oC 5.1-8 Change in Vapor Density Distribution Due to Cooling Lake at Selected Receptors for Data Period: 6/1/73 - 5/31/74 5.1-9 Change in Vapor Density Distribution Due to Cooling Lake at Selected Receptors for Data Period: 6/1/74 - 5/31/75 5.1-10 Change in Vapor Density Distribution Due to Cooling Lake at Selected Receptors for Data Period: 3/5/79 - 3/4/80 5.2-1 Average Meteorological Relative Concentration Analysis l l 5.2-2 Calculated Liquid Effluent Discharge Ccncentrations From Routine Operation O Rev. 2 5.0-iv 6/81
WCGS-ER(OLS)
.O ,, TABLE OF CONTENTS (Continued)
LIST OF TABLES Number Title 5.2-3 Bioaccumulation Factors l 5.2-4 Maximum Internal and External Dose Rates to Biota Other Than Man At the Circulating Water Discharge Point 5.2-5 Estinated Dose Rates to Maximum Individuals From Liquid Effluents Residing in the Town of Le Roy 5.2-6 Estimated Dose Rates to Maximum Individuals From l Liquid Effluent Concentrations at Circulating Water Discharge Point 5.2-7 Estimated Dose From Liquid Effluents to Population of Le Roy 5.2-8 Calculated Population Dose Rates From Submersion in Gaseous Effluents
/ 5.2-9a Calculated Radioactive Iodine and Particulate
( Gaseous Pathway Doses (Hypothetical Worst Case) 5.2-9b Calculated Radioactive Iodine and Particulate Gaseous Pathway Doses (Centrolling Existing Rasident) 5.2-10 Annual Dose from Noble Gases l 5.2-11 Summary of Calculated Total-Body and Thyroid Dese Rates From Liquid and Gaseous Effluents 5.2-12 Appendix I Conformance Summary Table for Liquid ard Gaseous Effluents Rev. 2 5._.0-v 6/81
WCGS-ER(OLS) TABLE OF CONTENTS (Continued) LIST OF FIGURES Number. Title 5.1-1 Comparison of Blowdown and Neosho River Temperatures for One Unit Operation 5.1- 2 Comparison of Blowdown and Neosho River Temperatures fot Two Unit Operation 5.1-3 Fogging and Icing Analysis Grid 5.2-1 Exposure Pathways to Organisms Other Than Humans 5.2-2 Exposure Pathways for Humans O i O\ Rev. 1 ; 5.0-vi 4/81 l
)
WCGS-ER(OLS) [ 7 ,h to dissipate the excess heat (1. 29 F) . The Kansas Water x~j Quality Criteria for absolute temperature is also met, as illustrated on Figures 5.1-1 and 5.1-2, since the blow-down temperature is calculated to be cooler than the river during the warm months of the year and elevates the river temperature to less than 90 F.- Since the monthly Neosho River flow varies substantially from year to year, monitoring the Neosho-River flow and tem-perature and regulating the blowdown flow are used to ensure that the Kansas Water Quality Criteria are not exceeded during any operating conditions, f 5.1.2.5 Conclusion The Wolf Creek blowdown complies with the Kansas Water Quality Criteria under all conditions. During post-drought conditions with a maximum blowdown of 40 cfs for one- and two-unit operation, the monthly. average blowdown temperature difference between the blowdown and the natural Neosho River temperature at the confluence of Wolf Creek and the Neosho River is sufficiently small that (1) the resultant river temperature is less than 90 F and (2) the increase in tem-perature is less than 5 F except during February when both units are operating at 88.5 percent average annual load (N factor. A negligible mixing zone may be required during s this February discharge condition to comply with the Kansas Water Quality Criteria. i. f J 5.1-5
WCGS-ER(OLS) 5.1.3 BIOLOGICAL EFFECTS 4 5.1.3.1 Introduction The ef f ects of station operation on aquatic biota in the vicinity of the WCGS site were discussed in Section 5.1 ^: the Environ-mental Report Construction Permit State (ER(CPLJ). That discus-sion was based on the limited amount of baseline data available then and projected cooling lake inundation effects based on taat limited data. Substantially more biological data are available now from our aquatic ecology monitoring programs (Section 2.2.2) to evaluate what biota will inhabit the cooling lake. The effects of station operation discussed in Section 5.1 of the ER (CPS) were reexamined because the cooling lake temperature distributions pre-sented in Section 3.4.4 of this report vary from temperatures presented in the ER (CPS). The new temperature distributions resulted from higher plant capacity factors used in Sargent & Lundy's LAKET computer program (Section 3.4.4). The following sections discuss the effects of various operational features of the heat dissipation system on aquatic biota in the cooling lake, Wolf Creek, and the Neosho River. The effects of biocide and chemical discharges are discussed in Section 5.3. The discussions are based on current literature and available information on the biological composition of the cooling lake, Wolf Creek, and the Neosho River. 5.1.3.2 Effects of Released Heat 5.1.3.2.1 Cooling Lake The cooling lake will have an area of 5,090 acres of which 4,330 acres will be thermally altered. Temperatures at the plant inlet, discharge, and at various locations in the cooling lake are discussed in Section 3.4. The predicted temperatures repre-sent a range from the maximum to 50 percentile occurrence. Maximum temperatures will occur less than 1 percent of the time, or on an average of approximately four days per year, and are not indicative of normal conditions in the cooling lake. Fifty percentile, or median temperatures approximate what may actually be observed. The following discussions were based on two temper-ature values, those at the 50 percentile IcVel, as indicative of average conditions in the cooling lake, and maximum temperatures, as worst case. The cooling lake should provide suitable habitat for aquatic biota during operation of WCGS. An area near the immediate l discharge zone will be most affected by thermal input since the l predicted 1 percentile temperatures during spring, summer, and fall (104.1 - 116. 5 F) will exclude most aquatic organisms. The extent of the area / volume of the cooling lake affected by the thermal input will vary depending on meteorological factors (Section 3.4). Thermal stratification in the cooling lake Rev. 2 5.1-6 6/81
WCGS-ER(OLS)
/m
( ) to dissipate the excess heat (1.29 F). The Kansas Water N,/ Quality Criteria for absolute temperature is also met, as illustrated on Figures 5.1-1 and 5.1-2, since the blow-down temperature is calculated to be cooler than the river during the warm months of the year and elevates the' river temperature to.less than 90 F. Since.the monthly Neosho River flow varies substantially from year to year, monitoring the Neosho River flow and tem-perature and regulating the blowdown flow are used to ensure that the Kansas Water Quality Criteria are not exceeded during any operating conditions. 5.1.2.5 conclusion The Wolf Creek blowdown complies with the Kansas Water Quality Criteria under all conditions. During post-drought conditions with a maximum blowdown of 40 cfs for one- and two-unit operation, the monthly average blowdown temperature difference between the blowdown and the natural Neosho River temperature at the confluence of Wolf Creek and the Neosho River is sufficiently small that (1) the resultant river temperature is less than 90 F and (2) the increase in tem-perature is less than 5 F except during February when both units are operating at 88.5 percent average annual load
/~'N factor. A negligible mixing zone may be required during '( N this February discharge condition to comply with the Kansas Water Quality Criteria.
N. 5.1-5
WCGS-ER(OLS) 5.1.3 BIOLOGICAL EFFECTS 5.1.3.1 Introduction The ef fects of station operation on aquatic biota in the vicinity of the WCGS site were discussed in Section 5.1 of the Environ ' mental Report Construction Permit State (ER(CPS} ) . That discus-sion was based on the limited amount of baseline data availabic then and projected cooling lake inundation effects based on that limited data. Substantially more biological data are available now from our aquatic ecology monitoring programs (Section 2.2.2) to evaluate what biota will inhabit the cooling lake. The of?ects of station operation discussed in Section 5.1 of the ER (CPS) were reexamined because the cooling lake temperature distributions pre-sented in Section 3.4.4 of this report vary from temperatures presented in the ER (CPS). The new tempe>ature distributions resulted from higher plant capacity factors used in Sargent & Lundy's LAKET computer program (Section 3.4.4). The following sections discuss the effects of various operational features of the heat dissipation system on aquatic biota in the cooling lake, Wolf Creek, and the Neosho River. The effects of biocide and chemical discharges are discussed in Section 5.3. The discussions are based on current literature and available information on the biological composition of the cooling lake, Wolf Creek, and the Neosho River. 5.1.3.2 Effects of Released Heat 5.1.3.2.1 Cooling Lake The cooling lake will have an area of 5,090 acres of which 4,330 acres will be thermally altered. Temperatures at the plant inlet, discharge, and at various locations in the cooling lake are discussed in Section 3.4. The predicted temperatures repre-sent a range from the maximum to 50 percentile occurrence. Maximum temperatures will occur less than 1 percent of the time, or on an average of approximately four days per year, and are not indicative of normal conditions in the cooling lake. Fifty percentile, or median temperatures approximate what may actually be observed. The following discussions were based on two temper-ature values, those at the 50 percentile level, as indicative of average conditions in the cooling lake, and maximum temperatures, as worst case. The cooling lake should provide suitable habitat for aquatic biota during operation of WCGS. An area near the immediate discharge zone will be most affected by thermal input since the l predicted 1 percentile temperatures during spring, summer, and l fall (104.1 - 116.5 F) will exclude most aquatic organisms. The ( extent of the area / volume of the cooling lake affected by the ' thermal input will vary depending on meteorological factors (Section 3.4). Thermal stratification in the cooling lake Rev. 2 5.1-6 6/81
. - _ _ = . .
WCGS-ER(OLS)- ( 5.2 RADIOLOGICAL IMPACT FROM ROUTINE OPERATION L- .
. Normal operation of. the Wolf Creek Generating Station (WCGS) will result in the release of only very low level liquid and gaseous . radioactive discharges. In order to evaluate any potential impact from these releases, the dose contribution i of the radioactive materials in the environment was predict-ed on the basis of terrestrial and aquatic pathways dis-cussed in this section and in Sections 5.2 and 5.3 of the Environmental . Repo rt-Cons truction Permit Stage (ER(CPS)).
In summary, negligible radiological impact is expected on man and the aquatic biota or terrestrial mammals as a result of .the quantity of radionuclides to be released from the WCGS. A detailed discussion of important dose pathways and resultant exposure rates was presented in Sections 5.2 and 5.3 ~ of the EF(CPS) and is updated below. An update of this section was necessitated to reevaluate the potential impact from liquid and gaseous radioactive effluent discharges using the -NRC computer codes GASPAR and LADTAP II. This i update is based on a full three years of meteorological data collected at WCGS and a revised set of liquid source terms which are being incorporated into Section 3.5 at this time. The NRC computer codes used in this revision are based on
/Q the methods and model s outlined in Regulatory Guides 1.109, 1.111 and 1.113.
5.2.1 EXPOSURS PATHWAYS 5.2.1.1 Exposure Pathways for Radiation Exposure of Biota Other Than Man Dose rate estimates to biota as herein presented should be considered extremely conservative since they are predicated on the following assumptions:
- 1. Liquid discharges are diluted only by the circulating cooling water. No credit was 4
taken for further reduction of radionuclide i concentrations in the cooling lake;
- 2. Buildup of the radionuclides in the cooling lake over the period of the life of the plant; i
- 3. Aquatic organisms are continuously submerged at the point of discharge to the cooling lake;
- 4. Predatory species obtain their entire diet
( ) from primary organisms in equilibrium with water at effluent concentrations. Rev. 2 5.2-1 6/81 i
. _ . . _ _ _ _ _ . , _ __ . . , _ . _ _ . _ , , .- . ~ .
WCGS-ER(OLS) Liq uid and gaseous releases will result in radiation coses to aquatic and terrestrial biota through pathways summarized in Figure 5.2-1. Many of the pathways of exposure for biota are similar to those for man. These pathways include inges-tion of water and aquatic foods, submersion in air, immer-sion in water and exposure to sediments and shorelines. Other pathways such as inhalation and direct radiation from air deposition of radionuclides on soils are not considered significant fo r inclusion in the total dose to such organ-isms. Pathways of expoaure from liquid ef fluents are gener-ally the most significant contributors Because to radiation aquatic dosecan organisms to organisms other than man. actively concentrate some radionuclides, these food chain components are potentially the most important contributors The impact to radiation dose to terrestrial animals. through the food chain pathway is expected to reach a maxi-mum in predatory species such as muskrats, raccoons and herons which could conceivably obtain their total diet from aquatic organisms in equilibrium with water at ef fluent con-centrations. The dose rate estimates for biota other than man are discussed in Section 5.2.3. 5.2.1.2 Exposure Pathways to Man Radioactive effluents from the WCGS will become distributed throughout the
- 3rrestrial ecosystem by dispe rsion of gas-cous releases, deposition of radioactive particulates and dilution of liquid radioactive discharges. Liquid and gas-cous releases will result in radiation doses to man through pathways summarized in Figure 5.2-2.
Gaseous exposure pathways to man include:
- 1. Submersion in the cloud of gaseous effluents;
- 2. Inhalation of gaseous effluents;
- 3. Direct radiation exposure from radionuclide deposition on vegetation, soil and exposed surfaces; and
- 4. Ingestion of contaminated food chain compon-ents.
The annual individual dose from nob le gases was evaluated in each of the 16 directional secto rs around the plant at the Exclusion-Restricted Area Boundary (.75 miles), to evaluate cloud subme rsion and air dose from beta and gamma radiations. Also the calculated population dose rates from subme rsion in gaseous effluents were evaluated within a 50 mile radius of the plant. Radioactive iodine and pa r-ticulate gaseous pathway doses were evaluated for a hypo-thetical wors t case and fo r the controlling existing resi-dont in the prevailing X/O sector which is north. The l Rev. 2 5.2-2 6/81 l
WCGS-UR(OLS) [ hypothetical wors t case assumes a resident lives in the Q] north sector at _ the Exclusion-Restricted Area Boundary ( .75
-miles) with members of each age group present and all path-ways present. The controlling existing resident lives 1.4 miles north of the plant and was evaluated as the maximum existing case. The dose rate estimates for man are pre-sented in Section 5.2.4.
Liquid exposure pathways to man include: 1
- 1. Internal exposure from ingestion of water or contaminated food chain components;
- 2. External exposure from contaminated water or shoreline sediment.
Dose rate estimates to maximum individuals from liquid effluent concentrations were evaluated at the circulating
' water discharge point.
Water is not available for public consumption at the plant site and no population or individual exposure is expected from this pathway. Although recreational uses of the cool-ing lake are not planned it is conservatively assumed that individual exposures from swimming, boating, fishing or ps ingestion of fish could result. t ) (/ Discharge water concentrations, bioaccumulation factors, and ingestion rates were used to estimate internal dose rates. Although such activities may not be allowed on the lake, external dose rates were estimated for individuals boating or swimming in the vicinity of the discharge. The exposure rate from contaminated shorelice sediments was also calcu-lated. Evaluation of each pathway is based on maximizing condi-tions. No credit was taken for dilution of the effluents in the cooling lake; buildup of the radionuclides in the lake over the life of the plant is assumed; all interactions are assumed to occur with radionuclido concentrations as they will occur at the point of discharge. Aquatic food chain elements are assumed to be in equilibrium with discharge concentrations prior to consumption. Since any swimming, boating, or fishing activities, if allowed, would be expected to be conducted in places in the cooling lake other than at the discharge point, evaluation of this path-way provides an upper estimate of the potential dose. Dose rate estimates to maximum individuals and the popula-tion of the town of Le Roy were also evaluated for exposure from liquid ef fluent concentrations. I t / Important aquatic pathways for consideration are summarized V in Figure 5.2-2. Rev. 2 5.2-3 6/81
WCGS-CR(OLS) 5.2.2 RADIOACTIVITY IN TiiE ENVIRONMENT Estimated gaseous and l iquid effluents from the WCGS are l presented in Section 3.5. On-site meteorological data collected over three full years l was used to predict gaseous effluent distribution in the environment. Both the PUFF and straight-line Gaussian dis-persion models, described in Regulatory Guide 1.111, were used for determination of ground level and mixed mode annua) average diffusion estimates. Resultant CllI/Q values are summarized fo r each sector in Table 5.2-1. For estimation of offluent dispersion a combination of both a mixed mode and ground-level release was assumed. The meteorological data indicates that maximum concentrations would Im expected to occur in the north sector. Gaseous dose calculations were done using GASPAR computer code. Dose calculation models used in GASPAR are outlined in Regulatory Guides 1.109 and 1.111. Assumptions used were either site specific or default values taken from the Regulatory Guides. These assumptions are presented in Appendix 5A. Liquid dose calculations were done using LADTAP II computer code. Dose calculation models used in LADTAP II a re out-lined in Regulatory Guides 1.109 and 1.113 for doses to man and USAEC Report WASII-1258 for doses to biota other than man. Site specific va lues were used when available. Default values used were either recommended in Regulatory Guide 1.109 or taken from HERMES USAEC Report HEDL-TME-71-168. The assumptions used in LADTAP II are presented in Appen-dix 5A. Liq uid radioactive releases will be diluted by cooling water with a flow rate of 1114 cfs and service water with a flow rate of 90 cfs for a total discharge of 1204 cfs. This is the only dilution assumed for dose calculations to the max-imum individual interacting with the cooling lake environ-ment. Buildup or reconcentration of the radionuclides in the cooling lake and at the circulating water discharge is taken into consideration over a 40 year plant life expect-ancy. The last five of these years are conside red to be during a drought. The model used for calculating buildup of the radionuclidea in the lake is presented in Appendix SA. The models were taken f rom Regulatory Guide 1.113 and USEPA EPA-520 Radionuclide Accumulation in a Reactor Cooling Lake. The town of Le Roy, Kansas, is the nearest downstream water user intake from WCGS. Dose rates to an individual residing in Le Roy and to the population at Le Roy have been eval-uated. These dcse rates take into consideration a 40 year buildup of radionuclides in the lake and then a further dilution in the Neosho Rive r. No credit is take n for the l radionuclides decay during transition from the lake to Rev. 2 5.2-4 6/81
WCGS-ER(OLS)
- Le Roy. Estimated radionuclide concentrations in the of flu-
' v' i
ent water at the discharge to the cooling lake and at Le Roy are listed in Table 5.2-2. Bioaccumulation factors used to predict uptake of radionuclides by fish and invertebrates I are listed in Table 5.2-3. 5.2.3 DOSE RATE ESTIMATES FOR BIOTA OTIIER TIIAN MAN The 1athways for radiation exposure of biota other than man were discussed in Section 5.2.1.1. For calculation of these dose rates it was assumed that aquatic organisms and terres-trial species live at the circulating water discharge point. Buildup of radionuclides was considered over the 40 year plant life. All food consumed has been grown or has lived in the liquid ef fluent at discharge concentrations. Inter-nal and external dose rates to biota are summarized in Table 5.2-4. The primary aquatic organism, fish, receive an estimated maximum internal exposure of 13.6 mrad /yr and a maximum external exposure of 9.41 mrad /yr. The muskrat is a terrestrial animal which could receive an estimated maximum internal exposure of 51.6 mrad /yr and a maximum external exposure of 6.42 mrad /yr. According to information presented in USAEC report WASil-1258 doses to biota at WCGS are well within expected annuc1 doses / when assuming the organisms live at the discharge point in (v]/ effluent concentrations. While these doses may be experienced by a few organisms which live at the discharge point of the station, the doses received by an entire impulation of aquatic or terrestrial organisms would be significantly less. 5.2.4 DOSE RATE ESTIMATES FOR MAN 5.2.4.1 Liquid Pathways Radionuclide concentrations in the discharge water were calculated based on a total discharge of 1204 cfs. Release rates and resultant radionuclide concentrations are listed in Table 5.2-2. Dose rate estimates to maximum individuals from liquid effluent concentrations were evaluated at the circulating water discharge point. No credit was taken for dilution of the effluents in the cooling lake; buildup of the radionuclides in the lake over a 40 year life expectancy are assumed to occur with radionuclide concentrations as they will occur at the discharge point. Pathways to man are discussed in Section 5.2.1.2. Assumptions used in dose cal-culations are given in Appendix SA. Dose rate estimates were calculated for maximum individuals ' [m) and to the population residing at Le Roy. No credit was (,/ taken for the radionuclides decay during transition between discharge from the lake and Le Roy. Rev. . 5.2-5 6/81 l l
WCGS-ER(OLS) Dose rates to maximum individuals from liquid of fluents are listed in Tables 5.2-5 and 5.2-6. Population doses at Le Roy are listed in Table 5.2-7. The maximum organ and total body doses to individuals re-siding in Le Roy were calculated to be 1.96E-001 mrem /yr to the liver of a child and 1.49E-001 mrem /yr to the total body of an adult, Tab le 5. 2-5. The most significant intern-al doses will be from eating fish (1.29E-001 mrem /yr to the liver of a teenager and 8.92E-002 mrem /yr to the total body of an adult). The most significant external dose rate will be to the skin of a teenager from exposure to radionuclide deposits in shoreline sediments 5.19E-004 mrem /yr. Estimated dose from liquid effluents to the population of Le Roy are presented in Tabic 5.2-7. The maximum organ and total body doses to individuals at the circulating water discharge point were calculated to be 4.27 mrem /yr to the liver of a teenager and 2.95 mrem /yr to the total body of an adult, Table 5.2-6. The most signifi-cant internal doses will be from eating fish (4.19 mrem /yr to the live r of a teenager and 2.90 mrem /yr to the total body of an adult). The most significant external dose ra'.e will be to the skin of a teenager from exposure to radio-nuclide deposits in shoreline sediments 2.52E-002 mrem /yr. 5.2.4.2 Gaseous Pathways The doses from gaseous effluents were calculated assuming intermittent purge operation. Intermittent purge mode re-lease rates were taken from Table 3.5-3. The values of the dispersion and deposition coefficients, X/Q (non-decayed), X/Q (depleted and non-decayed) and D/Q used in the calcula-tions are listed in Table 5.2-1. The north sector was determined to be the prevailing X/O sector for calculating annual dose from noble gases as well as from particulates and iodines. Exposure pathways to man are discussed in Section 5.2.1.2. Assumptions used in these dose calculations are given in Appendix 5A. The annual doses due to normal gaseous effluents from WCGS are listed in Tables 5.2-9a, b and 5.2-10. Doses attribu-table to radioactive iodines and particulates at the con-trolling sector Exclusion-Restricted Area Boundary are Doses con-tained within Table 5.2-9a (Hypothetical Worst Case). from iodines and pa rticula tes at the controlling residence are contained within Table 5.2-9b (Controlling Existing Res ide nt ) . T6ala 5.2-10 contains doses from noble gases at the Exclusian-Restricted Area Boundary. O Rev. 2 5.2-6 6/81
L WCGS-ER(OLS) j noble gas at the Exclusion-
) Results of calculdtions Restricted Area Boundary (.75 miles) show the cloud submer-V sion dose to the total body to be 2.2E-002 mrem /yr and 7.24E-002 mrem /yr to the skin in the north sector. The air dose resulted in exposure rates of 3.55E-002 mrad /yr gamma and 1.00E-001 mrad /yr from beta.
Doses attributable to radioactive particulates and iodines-were evaluated at the north sector Exclusion-Restricted Area Bounda ry. A hypothetical worst case assumed members of each age group were present and all pathways were present at the boundary. Members of each age group were assumed - to ingest goat milk rather than cow milk to consider the worst case milk ingestion pathway. The maximum organ and total body dose was 6.51 mrem /yr to the thyroid of an infant and 4.66E-001 mrem /yr to the total body of a child. Doses attributa-ble to the actual controlling existing resident (1.4 miles north sector) for the maximum organ and total body dose were 3.07 mrem /yr to an infants thyroid and 1.94E-001 to the total body of an adult. Calculated population dose rates from submersion in gaseous effluents were predicted based on the population in the year 2000- The results of these calculations are presented in Table 5.2-8. A I 5.2.4.3 Direct Radiation From Facility This_ subject was discussed in Section 5.3.4 of the ER(CPS). Although the source strengths involved have changed slight-ly, the conclusion reached-that negligible annual population exposure would be received in direct radiation from WCGS-has not changed. 5.2.4.4 Annual Population Doses Population dose rates at radial distances are summarized in Table 5.2-8. From these calculations, the average person within_p0 miles of the site would receive an annual dose of 2.9x10 mrem. The actual doses would be much lower due to shielding effects of housing. 5.2.5
SUMMARY
OF ANNUAL RADIATION DOSES Tne design of the WCGS will assure that gaseous and liquid ef fluent concentrations are within the guidelines stated in 10 CPR 20. During reactor operation, actual radionuclide concentrations in the environment will be determined by continuous environmental monitorino. A series of previously discussed tables from Sections 5.2.3 i
\ and 5.2.4 estimate individual, population and biota annual l\j doses from liquid and gaseous ef fluents. A brief summary of Rev. 2 5.2-7 6/81
WCGS-ER(OLS) calculated total body and thyroid dose rates from liquid and gaseous effluents is presented in Table 5.2-11 for max-imum individual exposures and population exposures. The exposure pathways considered for calculation of doses to man and biota are outlined in Sections 5.2.1.1 and 5.2.1.2. A conformance summary with 10 CPR 50, Appendix I, is out- I lined in Table 5.2-12. 5.
2.6 REFERENCES
Attachment to concluding Statement of Position of theNumer- Reg-ulatory Staf f. Public Rule-making Hearing on: ical Guides for Design Objectives and Limiting Condi-tions for Operation to Meet the criterion "As Low As Practicable" for Radioactive Material in Light-Water-USAEC, s Docket No. Cooled Nuclear Power Stations, RM-50-2, February 20, 1974. Eckerman, K. F. and Lash, D. G., 1978 GASPAR version marked
" revised 8/19/77": US Nuclear Regulatory Commission, Radiological Assessment Branch.
Eckerman, K. F., Congel, F. J., Roccklein, A. K. and Pasciak, W. J., 1980, NUREG-0597 Users Guide to GASPAR Code: U.S.N.R.C. Radiological Assessment Branch. 8 Environmental Statement Concerning Proposed Rule Final Making Action: Numerical Guides for Design Objectives and Liraiting Conditions for Operation to Meet the Cri-terion "As Low as Practicable" for RadioactiveEffluents, Material in Light-Water-Cooled Nuclear Powe r ReactorD.C., July 1973. USAEC Report WASH-1258- Washington, F., and Dotson, W. L. (compilers), HERMES-A Fletcher, J. Digital Computer Code for Estimating Regional Radiolo-gical Effects from the Nuclear Power Industry, USAEC Report HEDL-TME-71-168, Hanford Engineering Development Laboratory, 1971. Lyon, R. J., Shearin, R. L., 1976, EPA-520 Radionuclide Accumulation in a Reactor Cooling Lake: USEPA, Office of Radiation Programs. Regulatory Guide 1.109, Calculation of Annual Doses to Man from Routine Releases of Reactor Ef fluents for the Pur-pose of Evaluating CompliaNe with 10 CFR 50, Appen-dix I, Office of Standards Development. Regula to ry Guide 1.111, Me thods fo r Estimating Atmospheric Transport and Dispersion of Gaseous Effluents in Rou-tine Releases f rom Light-Water-Cooled Reactors, Office of Standards Development. Rev. 2 5.2-8 6/81
1 i - WCGS-ER(OLS) i Regulatory _ Guide 1.113, Estimating Aquatic Dispersion of Effluents from Accidental and Routine Reactor Releases
~
for the Purpose of Implementing Appendix I, Office of Standards Development. Simpson, D. B., McGill, E. L., 1980, NUREG/CR-1276 User's Manual for LADTAP II Computer Program: U.S.N.R.C. and Oak Ridge National Laboratory. Warminski, N. C., 1979, Horticulture Agent for the Sedgwick
' County Extension Of fice of the Kansas State University Cooperative Extension Service, Wichita, Kansas, tele-phone conversation (25, 26 January), written cominunica-tion (29 January).
I 1 i l j d 1 i i j ] 4 i 1 4 1 f
' Rev. 2 5.2-9 6/81 i
' WCGS ER(OLS)
TABLE 5.2 1 Sheet 1 of 3 (x \ AVERAE ETfXHOIKIC/L l<!2ATIVE (DfCENTRATION ANALYSIS 1Y (j IWA Period 3 years: (6/1/73 - 5/31/75, Dams and Moore 7691-062-07 7/12/80 (Gruru!) 3/5/79 - 3/4/80) 7/19/80 (Mixed McAo) MIX W EDE Gmq Nearest Plant Sector Bourulary X/Q Rel. X/Q Depl. X/Q Depos. X/Q Rel. X/Q Dtpl. X/Q Depos. NE 1.1 2.8E-07 2.5E47 4.lE-09 5.9E-07 5.lE-07 5.lE-09 E 1.3 9.3E-38 W.2E-08 1.lE-09 2.4E-07 2.0E-07 1.5E-09 DE 1.5 5.4E-08 4.8E-(8 4.3E-10 1.7E-07 1.5E-07 7.3E-10 E 1.2 8.0E-08 7. lE-0,1 ?.5E-10 2.8E-07 2.4E-07 1.4E-09 ESE 1.2 1.2E-07 1. lE-0*.' 1.lE-09 3.3E-07 -2.9E-07 1.7E-09 SE 1.2 1.5E-07 1.3E-07 1.6E-C9 3.8E-07 3.3E-07 2.3E-09 SSE 3.0 4.8E-08 4.0E-08 4.7E-10 1.0E-07 7.9E-08 6.3E-10 S 3.3 4.6E-08 3.8f'W8 3.9E-10 8.5E-08 6.6E-08 4.9E-10 3SW l.7 1.0E-07 8. '/E-48 1.0E-09 2.5E-07 2.lE-07 1.5E-09 SW l.5 8.lE-08 7.2E-08 6.3E-10 2.5E-07 2.1E-07 1.2E-09 EW l.5 8.3E-08 7.3E-08 6.5E-10 2.6E-07 2.2E-07 1.2E-09 W 1.8 9.0E-O's 7.8E-08 5.9E-10 2.3E-07 1.9E-07 1.0E-09 ENW 2.1 7.5E 08 6.4E-08 4.9E-10 1.8E-07 1.5E-97 8.5E-10 NW 2.6 8.5E-08 7.0E-08 4.lE-10 2.0E-07 1.SE-07 7.0E-10 NtM 1.5 2.5E-07 2.lE-07 . 6E-09 6.3E-07 5.3E-07 3.0E-09 N 1.1 5.6E-07 4.9E-07 6.4E-09 1.0E-06 8.8E-07 8.0E-09 , Nearest < Reaidence n g NNt 3.l* 7.9E-08 6.60-08 7.7E-10 1.4E-07 1.lE-07 9.3E-10 [ } NE 1.8 5.8E-08 5.0E-08 6.1E-10 1.5E-07 1.2E-07 8.60-10 ( ! ENE E 2.0 1.8 3.7E-08 4.7E-08 3.2E-08 4.lE-0E 2.7E-10 3.9E-10 1.lE-07 1.6E-07 9.0E-08 1.3E-07 4.3E-10 7.lE-10 ESE 1.7* 9.4 E-08 8.lE-08 7.7E-10 2.4E-07 2.0E-07 1.2E-09 SE 1.4 1.lE-07 9.8E-08 1.2E-09 3.lE-07 2.6E-07 1.8E-09 SSE 3.0 4.8E-Oo 4.0E-03 4.7E-10 1.0E-07 7.9E-08 6.3E-10 S 3.5 4.3E-08 3.5E-08 3.5E-10 7.8E-08 6.lE-08 4.4E-10 SSW 2.5* 6.2C-08 5.3E-08 5.3E-10 1.5E-07 1.2E-07 7.6E-10 SW 2.1 5.0E-08 4.4E-08 3.5E-10 1.5E-07 1.2E-07 6.5E-10 W5W 2.7* 5.3E-08 5.5E-08 3.4E-10 1.6E-07 1.3E-07 7.3E-10 W 2.2 7.3E-08 6.2E-08 4.5E-10 1.7E-07 1.4E-07 7.lE-10 WNW 2.9 5.2C-08 4.4E-08 3.0E-10 1.2E-07 9.2E-08 4.8C-10 PM 1.3* 2.9E-07 3.3E-07 1.9E-09 8.3E-07 7.3E-07 3.7E-09 NNW 2.2* 1.7r-07 1.9E-07 1.0E-09 4.3E-07 3.6E-07 1.9E-09 N 1.4 4.lE-07 3.5E-07 4.4E-09 7.3E-07 6.2E-07 5.5E-09 Nearest Vog. Garden NNE 3.6* 6.3E-08 5.2E-Od 5.7E-10 1.2E-07 9.2E-08 7.6E-10 a NC 2.l* 5.lE-08 4.4E-08 5.lE-10 1.3E-07 1.0E-07 7.3E-10 INE 2.2* 3.8E-08 3.3E-08 2.7E-10 1.lC-07 9.2E-O'o 4.4E-10 E 1.9 4.7E-08 4.lE-08 3.9E-10 1.6E-07 1.3E-07 7.1E-10 ESE 1.7* 9.4 E-08 8.1E-08 7.7I-10 2.4E-07 2.0E-07 1.2E-09 SE 1.4 1.lE-07 9.8E-08 1.2E-09 3.lE-07 2.6E-07 1.8E-09 SSE 3.2* 4.8E-08 4.0E-08 4.7E-10 1.0E-07 8.0E-08 6.4E-10 S 3.5 4.3E-08 3.5E-08 3.5E-10 7.8E-08 6.lE-08 4.4E-10 SSW 4.6* 2.5E-08 2.0E-08 1.7E-10 6.2E-08 4.6E-08 2.6E-10 SW 3.0* 3.3E-08 2. 8E-08 1.9E-10 8.9E-08 7.0E-08 3.5E-10 EW 2.7* 5.3E-08 5.5E-08 3.4E-10 1.4E-07 1.lE-07 5.8E-10 C W 2.2 7.3E-08 6.2E-08 4.5E-10 1.7E-07 1.4E-07 7.lE-10 ( WNW 2.9 5.2E-08 4.4E-08 3.0E-10 1.2E-07 9.2E-08 4.8E-10 ( NW 1.4* 2.9E-07 3.3E-07 1.9E-09 8.3E-07 7.3E-07 3.7E-09 tem 2.2 1.5E-07 1.3E-07 8.4E-10 3.8E-07 3.lE-07 1.6E-09 N 1.4 4.1E-07 3.5E-07 4.4E-09 7.3E-07 6.2E-07 5.5E-09
- 1he clasest mnaervative distance X/QS were used for these distances.
WCGS-ER(OLS) TABIE 5.2-1 sheet 2 of 3 AVF3W:E PETED40 LOGICAL Rf2ATIVE (DC12frPATIOi MW.YSIS Tw es and Moore 7699-062-07 [Mta Period 3 pars: (6/1/73 - 5/31/75, 7/12/80 (Ground) 7/19/80 (Mbasi et>))) 1/5/79 - 3/4/80) MIX m PYDE GOUND Exclur. ion-Restricted X/Q Depl. X/O Depos. kctor Area Doundary X/O Pol. X/Q Depl. X/O Depoo. X/Q Rel. 4.7E-07 4.2E-07 7.5E-09 1.0E-06 8.9E-07 9.lE-09 NNE .75 3.6E-09 1.9E-07 1.7E-07 2.8E-09 5.2E-07 4.7E-07 NE .75 4.0E-07 2.lE-09
.75 9.2E-08 8.3E-08 8.6E-10 4.5E-07 UNE 3.0E-09 1.6E-07 1.5E-07 1.6E-09 5.8E-07 5.2E-07 E .75 6.4E-07 3.8 E-09
.75 2.2E-07 2.0E-07 2.10-09 7.1E-07 ESE 4.7E-09 2.5E-07 2.3E-07 3.0E-09 7.5E-07 6.6D-07 SE .75 6.30-09 2.9E-07 2.6E-07 4.2E-09 7.6E-07 6.8E-07 SSE .75 6.7E-07 5.8E-09
.75 3.4E-07 3.0E-07 4.4E-09 7.5E-07 S 5.4E-09 2.9L-07 2.6E-07 3. 4 E-09 8.4E-07 7.5E-07 SS3d .75 3.7E-09 2.2E-07 2.0E-07 2.0E-09 7.0E-07 6.2E-07 SW .75 4.2E-09
.75 2.0E-07 1.8E-07 1.8E-09 8.0E-07 7.lE-07 WUW 5.2E-09 3.0E-07 2.7E-07 2.4E-09 1.0E-06 9.07-07 W .75 4.2E-09 2.5E-07 2.2E-07 2.lE-09 7.6E-07 6.8E-07 64 54 .75 5.9E-09 4.2E-07 3.8E-07 2.8E-09 1.3E-06 1.2E-06 tAJ .75 6.2E-07 5.5E-07 4. 4 E-09 1. 8E-06 1.6E-06 9.7E-09 t&54 .75 1.6E-08
.75 9.2E-07 8.2E-07 1,3E-08 1.9E-06 1.7E-06 N
L.P. Zone 1.0E-07 8.6E-08 1.1E-09 1.8E-07 1.5E-07 1.3E-09 NNE 2.5 3.6E-08 3.1E-08 3.2E-10 8.5E-08 6.8E-08 4.6E-10 NE 2.5 2.8E-10 2.5 2.8E-08 2.4E-08 1.8E-10 7.8E-08 6.2E-08 ILE 4.0E-10 E 2.5 3.30-08 2.8E-08 2.3E-10 9.6E-08 7.7E-08 4.8E-08 4.0E-08 3.3E-10 1.3E-07 1.0E-07 5.3E-10 ESE 2.5 6.0E-08 5.0E-08 5.2C-10 1.3E-07 1.0E-07 6.3D-10 SC 2.5 6.10-08 5.lE-08 6.4E-10 1. 4 E-07 1.1E-07 9.3E-10 SSE 2.5 7.9E-10 2.5 6.4E-08 5. 4 E-08 6 lE-10 1.30-07 1.0E-07 S
- 6. lE-08 5.2E-08 S.2E-10 1.5E-01 1.2E-07 7.9E-10 SSE1 2.5 3.9E-08 3. 4 E-08 2.5E-10 1. 2 E-07 9.4E-08 4.9E-10 SW 2.5 5.7E-10 2.5 5.2E-08 4.40-08 3.4 E-10 1.4E-07 1.10-07 WCW 6.4E-08 5.40-08 3.7E-10 1.40-07 1.lE-07 5.5C-10 W 2.5 6.4E-10 2.5 6.0E-08 5.0E-08 3.7E-10 1.5E-07 1.2E-07 v2AJ 9.0E-08 7.5E-08 4.4E-10 2.1E-07 1.70-07 7.5E-10 tAf 2.5 1.3E-09 2.5 1.3E-07 1.lE-07 6.8E-10 3.2C-07 2.6E-07 t#AI 2.lE-09 2.5 1.9E-07 1.6E-07 1.6E-09 3.2E-07 2.6E-07 N
th1 rest Heat Anim!
.8 4.3E-07 3.9E-07 6.8E-09 9.1E-07 8.lE-07 8.2E-09 NNE 1.7E-07 1.5E-07 2. 4 E-09 4.8E-07 4.3E-07 3.3E-09 NE .8 1.9E-09
.8 9.5E-08 8.5E-08 8.8E-10 4.1E-07 3.6E-07 E2E 8.0E-08 7.lE-08 7.5E-10 2.8E-07 2.4E-07 1.4E-09 E 1.2 1.2E-07 1.lE-07 1.lE-09 3.3E-07 2.9E-07 1.7E-09 ESE 1.2 1.5E-07 1.3E-07 1.6E-09 3. 8 E-07 3.3E-07 2.3E-09 SE 1.2 4.5E-08 3.7E-08 4.2E-10 9.3E-08 7.2E-08 5.7E-10 SSE 3.2 3.3 4.6E-08 3.8E-08 3.9E-10 8.5E-08 6.6E-08 4.9t-10 S
3.8E-08 3.2E ^8 2.9E-10 1.1E-07 8.2E-08 5.0E-10 SSW 3.3 7.4E-08 6.6E-08 5.6E-10 2.2E-07 1.8E-07 1.0E-09 SW l.6 1.2E-09 8.3E-08 7.3E-08 6.5E-10 2.6E-07 2.2E-07 WSW l.5 9.5E-08 8.2E-08 6.4E-10 2.6E-07 2.2E-07 1.2E-09 W l.7 4.6E-10 3.0* 5.lE-08 5.2E-08 2.9E-10 1.lE-07 8.9E-08 64A4 2.3* 1.2E-07 1.3E-07 6.5E-10 3.0E-07 2.5E-07 1.]E-09 tad 1.7E-07 1.4E-07 9.9E-10 4.3E-07 3.5E-07 1.9E-09 NNW 2.0 1.1 5.6E-07 4.9E-07 6. 4 E-09 1.0E-06 8.8E-07 8.0E-09 N
- h closest conservative distancxs X/CS were used for these distances.
Pcv. 2 6/81
7"y t, f \ l
\s' WCGS ER(OLS) ' TABLE 5.2-1 Sheet 3 of 3 AVCACE ETEORDIDGICAL Rf2ATIVE (DfCEfffRATION ANALYSIS 1f Dames and Moore 7699-062-07 Data Period 3 yrers: 7/12/80 (Ground)
(6/1/73 - 5/31/75, 7/19/80 (Mixed Mode) 3/5/79 - 3/4/80) GRXND MIXID MBE Nearest Dairy X/O Rel. X/O Dep1. X/O Depos. X/Q Rel. X/Q Depl. X/0 Depos. Sector coat 2.8E-10 6.7E-08 5.0E-08 3.8E-10 5.0 3.6E-08 2.9E-08 1.2C-10 NNE 1.3C-08 9.6E-Il 2.8E-08 2.0E-08 5.0 1.6E-08 5.8E-11 NE 9.0E-09 7.5E-09 4.0E-11 2.lE-08 1.5E-08 ENE 5.0 2.8E-08 2.0E-08 8.8E-11 5.0 1.4E-08 1.lE-08 7.0E-Il E 9.0E-11 4.6E-00 3.4E-08 1.5E-10 5.0 1.8E-08 1.4E-08 ESE 1.4E-10 4.0E-08 2.9E-08 1.5E-10 4
'i .0 ' 2.2E-08 1.7E-08 SE 1.8E-08 1.8E-10 4.5E-08 3.4E-08 2.4E-10 SSE .0 2.2E-08 3.5c-08 -2.4E-10 2.9E-08 2.3E-08 2.lE-10 4.8E-08 S 5.0 5.lE-08 3.8E-08 2.lE-10 5.0* 2.lE-08 1.7E-08 1.3E-10 SSi 8.2E-11 4.3E-08 1.2C-08 1.4E-10 91 5.0* 1.8E-08 1.5c-08 1.8E-08 1.0E-10 5.2E-08 3.8E-08 1.7E-10 RAI 5.0 2.2E-08 4.2C-08 1.8E-10 2.4E-08 1.9E-08 1.0E-10 5.7E-08 51 5.0 5.5E-08 4.0E-08 1.8E-10 5.0 . 2.3E-08 1.8E-08 1.0E-10 leM 1.2E-10 8.lE-08 6.0E-08 2.2E-10 NW 5.0 3.4E-08 2.7E-08 1.3C-07 9.4E-08 4.0E-10
.[m\
\ /
PHI H 5.0 5.0 6.lE-08 7.4E-08 4.7E-08 5.8E-08 2.4E-10 4.9E-10 1.lE-07 1.0E-06 8.2E-08 8.8E-07 5.7E-10 8.0E-09 V 1.1 5.;,E-07 4.9E-07 6.4E-09 r Nearest Dairy Cow 3.2C-08 3.2E-10 7.3E-08 5.5E-08 4.2E-10 NNE 4.7 3.9E-08 2.4E-08 2.3E-10 5.8E-08 4.6E-08 3.0E-10 3.0* 2.8E-08 NE 9.0E-09 7.5E-09 4.0E-ll 2.lE-08 1.5E-08 5.8E-ll DE 5.0/None 1.6E-07 1.3E-07 7.1E-10 1.8 4.7E-08 4.1E-08 3.9E-10 E 4.5E-07 4.0E-07 2.3E-09 1.3* 1.5E-07 1.4E-07 1.4E-09 ESE 1.8E-07 1.6E-07 2.0E-09 5.0E-07 4.3E-07 3.lE-09 SC 1.2* 6.5E-08 5.0E-08 3.7E-10 4.0* 3.3E-08 2.6E-08 2.8E-10 SSE 4.8E 08 3.5E-08 2.4E-10 S 5.0/None 2.9E-08 2.3E-08 2.lE-10 1.7E-08 1.4E-10 5.1EH.9 3.8E-08 2.1E-10 SSW 5.0/None 2.1E-08 1.4E-10 1.8E-08 1.5E-08 8.2C-ll 4.3E-08 1.2E-08 SW 5.0*/None 5.7E-08 4.3E-08 1.9E-10 4.7 2.4E-08 2.0E-08 1.2E-10 isi 5.7E-08 4.3E-08 1.8E-10 5.0/None 2.4E-08 1.9E-08 1.0E-10 , il 1.8E-08 1.0E-10 5.5E-08 4.0E-08 1.8E-10 INI 5.0/None 2.3E-08 6.0E-08 2.4E-10 1.3E-07 1.0E-07 4.2E-10 NW 3.5* 5.9E-08 1.9E-07 1.0E-09 4.3E-07 3.6E-07 1.9E-09 NNW 2.0* 1.7EH)7 6.lE-08 4.7E-10 1.lE-07 8.3E-08 5.8E-10 N 5.0*/None 7.7E-08 8.0E-09 5.6EH)7 4.9E-07 6.4E-09 1.0E-06 8.8E-07 N 1.1 s.
- The closest conservative distanen X/OS were used for these distan
.Vv ]
Rev. 2 6/81 l- ,
WCGS-ER(OLS) TAlaLE 5.2-2 CALCULATED LIQUID EFFLUENT DISCHARGE CONCENTRATIONS FROM ROUTINE OPERATION pCi/1 Reicase Circulaging Cooligg d Isotope Ci/yr Water Lake LeRoy H-3 4.10E+002 2.38E+004 2.34E+004 7.38E+002 Cr-51 7.00E-005 1.26E-004 6.09E-005 1.92E-006 Mn-54 1.10E-004 1.12E-003 1.01E-003 3.19E-005 Fe-55 6.00E-005 1.59E-003 1.53E-003 4.82E-005 Fe-59 4.00E-005 9.34E-005 5.62E-005 1.77E-006 Co-58 9.90E-004 3.11E-003 2.19E-003 6.91E-005 Co 60 9.40E-004 3.91E-002 3.82E-002 1.21E-003 Br4B3 3.80E-004 3.53E-004 1.19E-006 3.76E-008 Mo- 9 9 a a.10E-003 3.17E-003 2.88E-004 9.09E-006 Tc-99M 1.80E-003 1.69E-003 1.41E-005 4.45E-007 TE-129M 5.00E-005 9.95C-005 5.30E-003 1.67E-006 I-131 2.40E-002 2.84E-002 A.07E-003 1.92C-004 Te-132 9.80E-004 1.01E-003 9.94C-005 3.14E-006 I-132 7.90E-003 7.35E-003 2.37E-005 7.48E-007 I-373 3.20E-002 3.07E-002 8.78E-004 2.77E-005 Cs-134 9.80E-003 2.16E-001 2.07E-001 6.53E-003 I-135 1.60E-002 1.50E-002 1.40E-004 4.42E-006 Cs-136 4.40E-003 5.89E-003 1.79E-003 5.65E-005 Cs-137 8.50E-003 5.85E-001 P.77E-001 1.82E-002 Zr-95 1.40E-004 4.14E-004 2.84E-004 8.98E-006 Nb-95 2.00E-004 4.06E-004 2.20E-00, 6.940-006 Rb-86 3.00E-005 4.55E-005 1.76E-005 5.55E-007 RL-103 2.00E-005 4.35E-005 2.49E-005 7.86E-007 Ru-106 2.40E-004 2.90E-003 2.68E-003 8.46C-005 Ag-110M 4.00E-005 3.46E-004 3.090-004 9.75E-006 Cc-144 5.20E-004 4.98E-003 4.50E-003 1.42E-004 Dr-84 2.00E-004 1.86E-004 1.39E-007 4.39E-009 Sr-89 1.00E-005 2.56E-005 1.63E-035 5.14E-007 Te-127M 1.00E-005 4.32E-005 3.39E-005 1.07E-006 Te-127 3.00E-005 2.82E-005 3.68E-007 1.16E-008 Te-129 6.00E-005 5.58E-005 8.99E-008 2.84E-009 I-130 1.80E-004 1.7]E-004 2.93E-006 9.25E-008 Te-131M 9.00E-005 8.71E-005 3.53E-006 1.!!E-007 Br-85 2.00E-005 1.86E-005 1.30E-009 4.10E-011 Rb-88 6.80E-002 6.33E-002 2.64E-005 8.33E-007 Sr-91 2.00E-00F 1.88E-005 2.51E-007 7.92E-009 Y-91M 1.00E-005 9.30E-006 1.09C-008 3.44E-010 Te-131 4.00E-005 3.72E-005 2.18E-008 6.88E-010 I-134 3.70E-003 3.44E-003 4.27E-006 1.35E-007 All Others 3.00E-005 - - - a b M = metastable Based solely on di4ution by the circulating water discharge and c buildup of radionuclides over 40 year plant life. Based on dilution by the circulating water discharge and build-d up of radionuclides in the cooling lake over 40 year plant life. Concentration of radionuclides at the LeRoy water works intake. Based on dilution by cit culating water discharge and build-up of radionuclides in the cooling lake over 40 year plant life and additional dilution in the Neosho River. Rev. 2 6/81
i}
) WCGS-ER(OLS)
TABLE 5.2-3'
' BIOACCUMULATION FACTORS (pCi/kg per pCi/ liter)
FRESHWATER SALTWATER ELEMENT FISH INVERTEBRATE FISH INVERTEBRATE H 9.0E-01 9.0E-01 9.0E-01 9.3E-01 C 4.6E 03 9.1E 03 1.8E 03 1.4E 03 NA 1.0E 02 2.0E 02 6.7E-02 1.9E-01 P 1.0E 05 2.0E 04 2.9E 04 3.0E 04. CR 2.0E 02 2.0E 03 4.0E 02 2.0E 03 MN 4.0E 02 9.0E 09 5.5E 02 4.0E 02 FE 1.0E 02 3.2E 03 3.0E 03 2.0E 04 CO 5.0E 01 2.0E 02 1.0E 02 1.0E 03 NI 1.0E 02 1.0E 02 1.0E 02 2.5E 02 CU 5.0E 01 4.0E 02 6.7E 02 1.7E 03 ZN 2.0E 03 1.0E 04 2.0E 03 5.0E 04 BR 4.2E 02 3.3E 02 1.5E-02 3.1E 00 RB 2.0E 03 1.0E 03 8.3E 00 1.7E 01
,/g SR 3.0E 01 1.0E 02 2.0E 00 2.0E 01
( ) Y 2.5E 01 1.0E 03 2.5E 01 1.0E 03
'd' ZR 3.3E 00 6.7E 00 2.0E 02 8.0E 01 NB 3.0E 04 1.0E 02 3.0E 04 1.0E 02 MO 1.0E 01 1.0E 01 1.0E 01 1.0E 01 TC 1.5E 01 5.0E 00 1.0E 01 5.0E 01 RU 1.0E 01 3.0E 02 3.0E 00 1.0E 03 RH 1.0E 01 3.0E 02 1.0E 01 2.0E 03 TE 4.0E 02 6.1E 03 1.0E 01 1.0E 02 I 1.5E 01 5.0E 00 1.0E 01 5.0E 01 l CS 2.0" 03 1.0E 03 4.0E 01 2.5E 01
- BA 4.0E 00 2.0E 02 1.0E 01 1. 0E 0.2
, LA 2.5E 01 1.0E 03 2.5E 01 1.0E 03 i CE 1.0E 00 1.0E 03 1.0E 01 6.0E 02 1 PR 2.5E 01 1.0E 03 2.5E 01 1.0E 03 ND 2.5E 01 1.0E 03 2.5E 01 1.0E 03 W 1.2E 03 1.0E 01 3.0E 01 3.0E 01 NP 1.0E 01 4.0E 02 1.0E 01 1.0E 01 Regulatory Guide 1.109 s> s , i Rev. 2 6/81
i I 1 l I 4 WCGS-ER(OLS) TABLE 5.2-4 MAXIMUM INTERNAL AND EXTERNAL DOSE RATES TO BIOTA OTHER THAN MAN AT THE CIRCULATING WATER DISCHARGE POINT Biotic Type Dose Rate (mrad /yr) Primary Organisms Internal External Total Fish 1.36E+001 9.41E+000 2.30E+001 Invertebrate 5.12E+000 1.88E+001 2.39E+001 Algae 5.72E+000 1.37E-002 5.73E+000 Secandary OtJanisms Muskrat 5.16E+001 6.42E+000 5.80E+001 Raccoon 2.80E+000 4.84E+000 7.64E+000 lieron 2.84E+002 6.41E+000 2.90E+002 Duck 4.64E+001 9.55E+000 5.60E+001 Assumes aquatic and terrestrial organisms and species live at the circulating water discharge point. Build-up of radionuclides is considered over the 40 year plant life. All food consumed is considered to be in equilibrium with water at effluent concentrations. l 1 l l O Rev. 2 6/81 1
y
- j iCGS-ER(OIS)
'\ !
~ b' . - TABLE 5.2-5 ESTimTID DLEE RATES 10 mXIM.M It0IVIDUAIS fh0M LIQUID EFFLUDfrS RESIDIPC IN T!!E TON OF IEinX 4
NA]LT PREM PER YEAR i PA112Y SKIN HONE LIVER TOTAL DODY TI!YIOID KIONEY _LUtG GI-LLI Fish- 7.80-002 1.25-001 8.92-002 1.57-003 4.29-002 1.52-002 3.94-003 Inwrtebrate 9.47-004 1.90-003 1.42-003 3.63-004 9.36-004 5.134)04 9.29-004 Drinking 1.36-003 5.87-002 5.80-002 5.68-002 5.72-002 5.67-002 5.66-002 + ' Shoreline 9.30-005 7.97-005 7.97-005 7.97-005 7.97-005 7.97-005 7.97-005 7.97-005 Swiming .00 3.38-007L 3.38-007 3.38-007 3.38-007 3.38-007 3.38-007 s.38-007 lbstiry .00 1.13-006 1.13-006 1.13-006 1.13-006 1.13-006 1.13-006 1.13-006 Total 9.30-005 8.03-002 1.86-001 1.49-001 5.88-002 1.01-001 7.25-002 6.16-002 TEENAGR PATIMY SKIN IOtE LIVER 1UTAL BODY 'I11YIOID KIDIEY -LDG GI-LLI
, Fish 8.27-002 1.29-001 5.05-002 1.23-003 4.37-002 1.76-002 2.98-003
. Inwrtebrate 1.00403 1.86-003 8.76-004 2.82-004 8.72-004 4.64-004 6.87-004 Drinking 1.32-003 4.1M)02 4.06-002 4.01-002 4.05-002 4.01-002 3.99-032 Shoreline 5.19-004 4.45-004 4.45-004 4.45-004 4.45-004 4.45-004 4.45-004 4.45-004 Swim ing '.00 1.95-006 1.95-006 1.95-006 1.95-006 1.95-006 1.95-006 1.95-006 Instity .00 1.13-006 1.13-006 1.13-006 1.13-006 1.13-006 1.13-006 1.13-006 1btal -5.19-004 8.55-002 1.73-001 9.24-002 4.20-002 8.56-002 5.86-002 4.40-002
,.p OIIID PATIMY . SKIN BONE LIVER 1UTAL DODY UlYHDID KIDNEY IDG GI-LLI Fish 1.03-001 1.14-001 1.99-002 1.03-003 3.73-002 1.4u-002 1.65-003 Inh-td rate 1.30-003 1.69-003 4.88-004 2.46-004 7.65-004 3.91-004 3.84-004 Drinking 3.82-003 8.05-002 7.70-002 7.69-002 7.77-002 7.68-002 7.64-002 Shorelire - 1.09-004 9.29-005 9.29-005 9.29-005 9.29-005 9.29-005 9.29-005 i.29-005 Swiming .00 1.21-006 1.21-006 1.21-006 1.21-006 1.21-006 1.21-006 . 21-006 Ibating .00 6.28-007 6.28-007 6.28407 6.28-007 6.28-007 6.28-007 6.28-007 Total 1.09-004 1.08-001 1. % -001 9.75-002 7.82-002 1.16-001 9.13-002 7.85-002 i ItF Ntr I PATIMY SKIN BONE LIVER 1UIAL BODY UlYlOID KIDhEY IDG GI-LLI Fish 00 .00 .00 .00 .00 .00 .00 4 Drinkirg 3.95-003 8.01-002 7.53-002 7.58-002 7.63-002 7.55-002 7.50-002 Shoreline .00 .00 .00 .00 .00 .00 .00 .00 Total .00 3.95-003 8.01-002 7.53-002 7.58-002 7.63-002 7.55-002 7.50-002 (1) Assim.s drinking water is tJe only liquid pattway an infant would receive expmure from.
Rev. 2 6/81 i
. !v! ;
EGS-ER(OIS) TABLE 5.2-6 ESTImTID DOSE RATES '[O EXIMM It01VIDUAIS l'l0M LIQUID IFFLtJFNT CDONTRATIOtB AT 'IHE CIPCUIATItG WMER DISOIARE EUIffr-ADULT MtEN PER YEAR
'IUTAL KDY THYTOID KIDNEY LUtG GI-LLI PAD M Y SKIN ENE LIVER 2.90+000 6.47-002 1.39+000 4.94-001 1.31-001 Fish 2.52+000 4.07+000 6.27-002 4.66-002 1.36-002 3.75-002 1.66-002 3.19-002 C.25-002 .00 Inwrtebyate .00 .00 .00 .00 .00 Drinking .00 3.86-003 3.86-003 3.86-003 3.86-003 3.86-003 3.86-003 Shoreline 4.51-003 3.86-003 1.22-005 1.22-005 1.22-005 1.22-005 1.22-005 1.22-005 Swinning .00 1.22-005 4.08-005 4.08-005 4.08-005
.00 4.08-005 4.08-005 4.08-005 4.08-005 Bmtirg 8.22-002 1.43+000 5.14-001 1.98-001
'Ibtal 4.51-003 2.56+000 4.14+000 2.95+000 TEEtWER SKIN BONE LIVER '1UTAL BCOY *nflIOID KIINEY g GI-LLI PATlf*AY 1.64+000 5.28-002 1.42+000 5.7(H)01 9.88-002 Fish 2.67+000 4.19+000 4.53-002 6.13-002 2.91-002 1.09-002 3.57-002 1.50-002 Inwrtebrate 3.38-002 .00 .00
.00 .00 .00 .00 .00 Drinking 2.16-002 2.16-002 2.16-002 2.16-002 2.52-002 2.16-002 2.16-002 2.16-002 Shore 11m 7.06-005 7.06-005 7.06-005 7.06-005 Swiming .00 7.06-005 7.064)05 7.06-005 4.08-005 4.08405 4.08-005 4.08-005 4.08-005 Doatirg .00 4.08-005 4.08-005 1.66-001 4.27 +000 1.69+000 8.53-002 1.48+000 6.07-001 Total 2.52-002 2.73+000 OtIID
'IUTAL BnDY UfYIDIC KIDtEY Lt1C GI PATIM Y SKIN DONE LIVER 3.70+000 6 47-001 4.73-002 1.21+000 4.53-001 5.40- 6 Fish 3.34+000 1.96-002 5.55-002 1.66-002 1.01-002 3.14-002 1.26-002 Inwrtebrate 4.37-002 .00
.00 .00 .00 .00 .00 Drinking .00 4.51-003 4.51-003 4.51-003 4.51-003 4.51-003 4.51-003 4.51-003 Shoreline 5.26-003 4.39-005 4.39-005 4.39-005 4.30-005 4.39-005 4.39-005 4.39-005 Swiming .00 2.27-005 2.27-005 2.27-005
.00 2.27-005 2.27-005 2.27-005 2.27-005 Ikutirq 1.25+000 4.71-001 7.82-002 5.26-003 3.38 +000 3.76+000 6.68-001 6.19-002 Total
.s " sus the lake is not a source of drinkirn water.
Aad mns an 'rtfant wculd not be exposed to the existing pattways. Rev. 2 6/81 O l i
\ ~J WOGS-ER(OIS)
TABLE 5.2-7 ESTIBRTED DOSE FROM LIQUID EFFLUENTS
- 'IO POPUIATION OF IERN j
POPUIATION DOSE (person-rem /yr) { SKIN BONE LIVER TOI'AL BODY THYlOID KIDNEY LUPG GI-LLI - , IIGESTION Fish 3.06E-003 4.56E-003 2.68E-003 5.15E-005 1.55E-003 5.62E-004 1.26E-004 Invertebrate 2.27E-005 4.16E-005 2.67E-005 7.36E-006 1.97E-005 1.09E-005 1.65E-005 Drinking Water 5.69E-004 1.92E-002 1.88E-002 1.85E-002 1.87E-002 1.85E-002 1.85E-002 EXTERNAL EXPOSURE Shoreline 6.19E-005 5.30E-005 5.30E-005 5.30E-005 5.30E-005 5.30E-005 5.35E-005 5.35E-005 Swirmtmg 1.81E-007 1.81E-007 1.81E-007 1.81E-007 1.81E-007 1.81E-007- ' 1.81E-007 Boating 3.62E-007 3.62E-007 3.62 E-007 3.62E-007 3.62E-007 _3.62E-007 3.62E-007 Totals 6.19E-005 3.71E-003 2.39E-002 2.16E-002 1.86E-002 2.03E-002 1.91E-002 1.87E-002 { . Rev. 2 6/81
WCGS-ER(OLS) TABLE 5.2-8 CALCULATED POPULATION DOSE RATES PROM SUBMERSION IN GASE00S EFFLUENTS Cumulative Cumulative Cumulat.7e Average Radius 2000 Dose Annual Dose (miles) Populationa (person-rem /yr) (mrem /yr) 1 20 0.0024 0.12 2 100 0.0055 0.055 3 260 0.0076 0.029 4 2,750 0.021 0.008 5 4,870 0.026 0.0054 10 6,180 0.026 0.0043 20 12,100 0.026 0.0021 30 72,020 0.041 0.00058 40 114,630 0.046 0.0004 50 184,/70 0.054 0.00029 aDemographic data are presented in Section 2.1.2. Since population in the vicinity of the site will be reduced, the calculated doses are conservative. O I O
i Dx Y
' WCCS-ER(OIS) * \\~# /' TABLE 5.2-9a CAICUIATED RADIQ4CTIVE ICDINE AND PARTICUIATE g PATHNMf DOSES (Hypothetical Worst Case)
A0 9 location Group Pathay Critical Organ Dose Cbntributions (mrem /yr) 4 Adult Skin Thyroid Bone %tal Body Cortrolling . Ground Cbriamination 1.26 E-02* 1.08 E-02 1.08 E-02 1.08 E-02 Sector Exclusion- Air Irhalaticri 3.69 E-02 6.13 E-02* 9.63 E-05 3.69 E-02 Nstricted Area . Vegetable Ingestion 8.92 E-02 3.97 E-Ol* 1.78 E-01 9.35 E-02 Boundary .75 miles Cow Milk Ingestion = North Sector Goat Milk Ingestion 5.35 E-02 8.68 E-Ol* 7.98 E-02 6.13 E-02 Meat Ingestim 2.15 E-02 4.60 E-02 6.69 E-02* 2.18 E-02 Etal Dose (traem/yr) 2.14 E-01 1.38 E+00 3.36 E-01 2.24 E-01 Teen Skin Thyroid _ Bone Total Body Grourd Cortamination 1.26 E-02* 1.08 E-02 1.08 E-02 1.08 E-02 , Air Inhalation 3.71 E-02 6.75 E-02* 1.29 E-04 3.71 E-02 Vegetable Ingestion 1.20 E-01 3.78 E-Ol* 2.92 E-01 1.24 E-01 Cow Milk Ingestion Goat Milk Ingestion - 7.76 E-02 1.37 E+00* 1.47 E-01 8.60 E-02 Meat Ingestion 1.61 E-02 3.38 E-02 5.65 E-02* 1.63 E-02 Total Dose (mR m/yr) 2.63 E-01 1.86 E+00 5.06 E-01 2.74 E-01 Child Skin Thyroid Bone % tal Body
\' Grtual Cortamination 1.26 E-02* 1.08 E-02 1.08 E-02 1.08 E-02 Air Irhalation 3.28 E-02 6.73 E-02* 1.65 E-04 3.29 E-02 Vegetable Ingestion 2.37 E-01 6.30 E-01 7.05 E-Ol* 2.40 E-01 Cow Milk Ingestion Goat Milk Ingestion 1.46 E-01 2.69 E+00* 3.60 E-01 1.55 E-01 Heat Ingestion 2.70 E-02 5.38 E-02 1.06 E-Ol* 2.71 E-02 E tal Dose (mrem /yr) 4.55 E-01 3.45 E+00 1.18 E+00 4.66 E-01 Infant Skin Thyroid Bone Total Body Ground Cortamination 1.26 E-32* 1.08 E-02 1.08 E-02 1.08 E-02 3 Air Inhalation 1.89 E-02 5.05 E-02* 1.16 E-04 1.89 E-02 Vegetable Ingestion -
Cow Milk Ingestion - Goat Milk Ingestion 2.60 11-01 6.45 E+00* 6.98 E-01 2.72 E-01 Meat Ingestion - Total a we (mRom/yr) 2.92 E-01 6.51 E+00 7.09 E-01 3.02 E-01 Appndix I Limit (mRm/yr) 15.00 E+00 15.00 E+00 15.00 E+00 15.00 E+00 Notes (1) Asstanes menbers of each age group are present and all patNays are present at the Contro11ina Exclusion-Restricted Area Boundary. (2) Asstunes nenhers of each age grcup ingest goat milk rather than cow milk to consider the worst case milk ingestion patNay. (3) Asasnes no wgetable or meat ingestion by infants. Identifies the critical ortpn dose for each giwn pathway.
. (yi Rev. 2 6/81
MLS-ER(OIS) TABIE $.2-9b i CMEUIATfD RADICRCTIVE ICDINE AND PARTICUIATE pp PATfMY DOSES (Controlling Existing Resident) A90 location Group PatNay __ Critical Organ Ibse Contributions (mRm/yr) Skin 7tryroid Bone Total Body Adult Grm nd Contamination 4.78 E-03* 4.08 E-03 4.08 E-03 4.08 E-03 1.4 miles N 3.96 E-05 1.64 E-02 1.4 miles N Air Irhalation 1.64 E-02 2.67 E-02* Vegetable Ingestion 3.77 E-02 1.58 E-Ol* 6.91 E-02 3.94 E-02 1.4 miles N 4.05 E-Cl* 4.04 E-02 2.12 E-02 1.1 miles N Cow Milk Ingestion 1.94 E-02 Meat Irgestion 1.20 E-02 2.60 E-02 3.55 E-02* 1.22 E-02 1.1 miles N 1ctal Dose (mPm/yr) 9.03 E-02 6.20 E-01 1.49 E-01 9.33 E-02 Skin thyroid Bone 1btal Bcxfy Teen Ground Contamiraticn 4.78 E-03* 4.08 E-03 4.08 E-03 4.08 E-03 1.4 miles N 5.30 E-05 1.66 E-02 1.4 miles N Air Inhalation 1.65 E-02 2.94 E-02* Verptable Incystion 5.04 E-02 1.51 E-Ol* 1.13 E-01 5.19 E-02 1.4 miles N 7.45 E-02 3.17 E-02 1.1 miles N (bw Milk Ingestion 2.94 E-02 6.39 E-Ol* Meat Ingestion 8.93 E-03 1.90 E-02 3.00 E-02* 9.03 E-03 1.1 miles N Tbtal Dose (mRm/yr) 1.10 E-01 8.42 E-01 2.22 E-01 1.13 E-01 Child Skin Thyroid Bone 1btal Bcx]y Ground Contamination 4.78 E-03* 4.08 E-03 4.08 E-03 4.08 E-03 1.4 miles N 1.46 E-02 1.4 miles N Air Irhalation 1.46 E-02 2.92 E-02* 6.80 E-05 Vegetable Ingestion 9.76 E-02 2.51 E-01 2.74 E-Ol* 9.91 E-02 1.4 miles N 1.1 miles N Cow Milk Ingestion 5.89 E-02 1.27 E+00* 1.83 r-01 6.18 E-02 Meat Ingestion 1.48 E-02 3.00 E-02 5.64 E-02* 1.49 E-02 1.1 miles N Tctal Dose (mRm/yr) 1.91 E-01 1.58 C+00 5.18 E-01 1.94 E-01 Infant Skin thyroid Bone Total Body 1.4 miles N Ground Contamiration 4.78 E-03* 4.08 E-03 4.08 E-03 4.08 E-03 1.4 miles N Air Inhalation 8.41 E-03 2.17 E-02* 4.81 E-05 8.42 E-03 1.4 miles N Vecpt&le Ingestion 1.1 miles N Cow Milk Ingestion 1.10 E-01 3.04 E+00* 3.57 E-01 1.14 E-01 1.1 miles N Meat Ingestion Total Dose (mRm/yr) 1.23 E-01 3.07 E+00 3.61 E-01 1.27 E-01 Appendix I Limit (cre m /yr) 15.00 E+00 15.00 E+00 15.00 E+00 15.00 E+00 Note: (1) All patNays actually exist for this resident excxpt the cow milk ingestion patNay which is assuned. (2) Asaznes morters of each age group are present and that there is no wgetable or neat ingestion by infants.
- Identifies the critical organ dose for eac:h given patNay.
Rev. 2 6/81 0
WCGS- ER (OLS )
/~1 'x _, 'i TABLE 5.2 -10 ANNUAL DOSE FROM NOBLE GASES Exclusion-Restricted Cloud Submersion Air Dose Sector Area Boundary Total Body Skin Gamma Beta (miles) (mrem /yr) (mrem /yr) (mrad /yr) (mrad /yr)
NNE .75 1.12 E-02 3.74 E-02 1.83 E-02 5.17 E-02 NE .75 4.71 E-03 1.67 E-02 7.62 E-03 2.30 E-02 ENE .75 2.57 E-03 1.08 E-02 4.13 E-03 1.48 E-02 E .75 4.17 E-03 1.60 E-02 6.73 E-03 2.20 E-02 ESE .75 5.61 E-03 2.08 E-02 9.07 E-03 2.87 E-02 SE .75 6.30 E-03 2.28 E-02 1.02 E-02 3.16 E-02 SSE .75 7.14 E-03 2.51 E-02 1.16 E-02 3.45 E-02 /' S .75 8.17 E-03 2.74 E-02 1.32 E-02 3.79 E-02 (' SSW .75 7.26 E-03 2.62 E-02 1.17 E-02 3.60 E-02 SW .75 5.60 "-03 2.07 E-02 9.04 E-03 2.85 E-02 WSW .75 5.32 E-03 2.10 E-02 S.59 E-03 2.89 E-02 W .75 7.70 E-03 2.89 E-02 1.25 E-02 3.97 E-02 WNW .75 6.31 E-03 2.3u E-02 1.02 E-02 3.17 E-02 NW .75 1.06 E-02 3.90 E-02 1.72 E-02 5.37 E-02 NNW .75 1.55 E-02 5.59 E-02 2.52 E-02 7.71 E-02 N .75 2.20 E-02 7.24 E-02 3.55 E-02 1.00 E-01 Appendix I Limit 5.00 E+0 15.00 E+0 10.00 E+0 20.00 E+0 (7,) v Rev. 2 6/81
kCGS-ER(OLS) TABLE 5.2-11 SUNRIE OF CALCULATED TUfAL-BODY AND TINROID i DOSE RATES FIOM LIQUID AND GASEOUS EFFLUENTS Dose Rate Patlway Total Body Thyroid Maximun Irdividual Exposures: Liquid effluents" Ingestion fish 2.90E+000 mrem /yr 5.28E-002 mrem /yr inwrtebrate 4.66E-002 mrem /yr 1.09E-002 mrem /yr drinking watet 0.0 mrm/yr 0.0 mrem /yr External exlosuru shoreline 3.86E-003 mrem /yr 2.16E-002 mrm/yr swinnire 1.22E-005 mrem /yr 7.06E-005 mrem /yr boating 4.08E-005 mrem /yr 4.08E-005 mrem /yr Subtotal 2.95E+000 mrem /yr 8.53E-002 mrem /yr Gaseous offluents ncble gas subnersion 2.20E-002 mrem /yr -- particulate and iodine gases 1.27E-001 mrem /yr 3.07E+000 mrm/yr Subtotal 1.49E-001 mrem /yr 3.07E+000 mrm/yr Population Exposures: Liquid offluents c Ingestion fish 2.68E-003 person-rem /yr 5.15E-005 person-rm/yr inwrtebrate 2.67E-005 person-rem /yr 7.36E-006 person-rem /yr drinking water 1.88E-002 person-rm/yr 1.85E-002 person-rem /yr External exlosure storeline 5.30E-005 person-rm/yr 5.30E-005 person-rm/yr swinnity 1.81E-007 p2rson-rm/yr 1.81E-007 parson-rem /yr boati;.9 3.62E-007 person-rm/yr 3.62E-007 person-rm/yr Subtotal 2.16E-002 person-rm/yr '.86E-002 person-rem /yr Gaseous effluentsd subnersion 5.4E-002 person-rm/yr -- direct radiation 1.0E-003 person-rem /yr - Subtotal 5.5E-002 person-rem /yr -- l " Doses were calculatoj at the circulating water discharge for maxinum individm1 exlosures. Total body doses were for an adult and thryoid doses were to a teen es worn calculated at a point 1.4 miles frm the vent in the maximally exposed sector for an infant, c dTo tle population in the town of Le Roy. To the population within a 50 mile radius. Rev. 2 6/81
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. TABLE 5.2-12 *
- APPENDIX I CONFORMANCE
SUMMARY
TABLE FOR' LIQUID AND GASEOUS EFFLUENTS. Design Calculaged , Type of Dose Objective a -Dose Point of Dose
-Evaluation-Liquid Ef fluents 1' 2.95' mrem /yr b i
' Dose to total body 5 mrem /yr from-all pathways Point of Discharge-per site' ' Cooling Lake-Dose to.any organ 5 mrem /yr '4.27 mrem /yr from all pathways per site
' Same as above ~
Gaseous Effluents Dose to total body 5 mrem /yr 0.0220 mrem /yr of an individual per site .75 gi N of stack vent 4 Dose to skin of an 15 mrem /yr 0.0724 mrem /yr .75 mi N of stack- { individual per site vent Radiciodine and Particulates l Dose to any organ 15 mrem /yr 3.07 Inrem/yr* from all pathways per site _ Residence, 1.4 mi.. N' of stack vent. Milk cow 1.1 mi. N of stack. i I-131 releases 1 Ci/yr 0.0577 Ci/yr gaseous l per unit 0.0240 Ci/yr liquid Total 0.0817 Ci/yr i " Design objective as specified in the. commission's Appendix I Conformance bOption, 40 FR, 40816, September 4, 1975, RM-50-2. c Maximum dose to an individual from.all liquid pathways. Maximum dose to a teen liver from all liquid pathways. Maximally exposed sector. i
" Dose to an infant thyroid. ; ~
Rev. 2 6/81 .
i UI v GASEOUS EFFLUENTS b NUCLEAR FACILITY
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7d 6/31 WOLF CREEK GENERATING STATION UNIT NO. I ENVIRONMENTAL REPORT CPERATING LICENSE STAGE) FIGURE 5.2-1 U S At c Energy Comrnission,1973 EXPOSURE PATI { WAYS TO ORGANISMS q) OTilER TilAN llUMANS 1
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REFERENCE:
FIGURE 5.2-2 U. S. Atomic Energy Commission.1973 EXPOSURE PATilWAYS FOR llUMANS
l
'l WCGS-ER(OLS) .(v j 5.7 RESOURCES COMMITTED 5.7.1 URANIUM RESOURCES With the exception of uranium ore as fuel, operation of Wolf.
Creek Generating Station -(WCGS) is not expected to cause an
-irreversible commitment of resources beyond that resulting from construction of the plant.- Loss of habitat and effects on the terrestrial community are detailed in Section 4.3 of the Environmental Report-Construction Permit Stage (ER(CPS))
and the impact of thermal and chemical discharges on fish and other forms of aquatic biota is discussed in Section 5.1 and 5.3. Operation of the WCGS will involve irreversible consumption of a certain amount of uranium ore which represents a small fraction of the current- reserves and potential resources of the United States. Fuel consumption for Unit No. 1 of WCGS (operating at a 75 percent load factor) will total approxi-over the 30-year economic life of mately 7328 tons the plant. . Initial 16aof U,0[Ing and the first year of operation will require 545 tons of U O Annual fuel consumption in subsequent ~ years is estimade$. at approximately 219 to 238 tons of U 0 3 8* As of October 1, 1980, the estimate of the U.S. uranium ore l s reserves and potential resources recoverable at $50.00 or less per pound of U 038 is as follows (DOE, 1980): l Tons U 38 0
$/lb. U 0 Potential Resources Forward bokt Category Reserve Probable Possible Speculative
$30 645,000 885,000 346,000 311,000 I
$50 936,000 1,426,000 641,000 482,000
$100 1,122,000 2,080,000 1,005,000 696,000
! This estimate of rese rves does not include a possible pro-duction of 140,000 tons of U 0, as a byproduct of phost : tate l and coppe r production by the3Tear 2000 or other considera-tions that may also increase the estimates of U,0 8 resources available . By conside ring more expensively mined ore the reserves and potential resources of the U.S. are also in-creased.
~
Rev. 2 5.7-1 6/81
WCGS-ER(OLS) The total U.S. and foreign resources at $50.00 per pound or less excluding the Peop les Republic of China, USSR and associated countries, has been estimated by Working Group 1 of the International Nuclear Fuel C '/cle Evaluation spon-sored jointly by the OCED Nuclear Energy Agency and the International Atomic Energy Agency as of January 1, 1979, as 3,367,000 tons U02 g as Reasonably Assured and 3,185,000 0 as Estimatdd Additional. tons U 38 5.7.2 OTl!ER RESOURCES An auxiliary boiler system is installed within the power block to supply building heat and other services during plant outages. When this system is in continuous service at 50 percent load, 325,000 gallons per month of No. 2 distillate fuel oil will be committed. Assuming a 15 per-cent plant outage rate, the total yearly consumptive use at 50 percent load is not expected to exceed 585,000 gallons. 5.7.3 REFERENCE DOE, May/ June 1979, Update, Nuclear Power Program Informa-tion and Data: Division of Nuclear Power Development, U.S. Department of Energy. O O Rev. 2 5.7-2 6/81
WCGS-ER(OLS) f O s APPENDIX 5A DOSE CALCULATION MODELS AND ASSUMPTIONS All dose calculations have been revised by means of the NRC computer codes GASPAR and LADTAP II. Computer programs ARRG, CRITR,~GRONK, and FOOD developed at the Pacific North- 4 west Laboratory of Battelle Memorial Institute are no longer being used. The models and assumptions used in LADTAP II and GASPAR are identical or similar to those suggested in NRC Regula tory Guide 1.109. A list of assumptions and paramete rs used for the Wolf Creek site are presented in Table SA-1 for liquid ef fluents and Table SA-2 for gaseous effluents. 5A.1 INTERNAL DOSES TO AQUATIC ORGANISMS Doses to aquatic and terrestrial organisms other than man were calculated using NUREG/CR-1276 LADTAP II "A Computer Program for Calculating Radiation Exposure to Man from Routine Release of Nuclear Reactor Liquid Ef fluents. " The models used by this program are taken from Regulatory Guide 1.113, 1.109 and USAEC publication, WASH-1258. SA.2 DOSE TO HUMANS ( ,) Doses to man from liquid effluents were calculated using NUREG/CR-1276 LADTAP II computer program. The models used by this program are taken from Regulatory Guide 1.113 and 1.109. Doses to man from gaseous effluents were calculated using NUREG-0597 GASPAR - "A Computer Program for the Eval-uation of Radiological Impacts Due to the Release of Radio-active Material to the Atmosphere During Normal Operation of Light Water Reactors." The models used by this program are taken from Regulatory Guide 1.111 and 1.109. SA.3 RECONCENTRATION FORMULA USED TO CALCULATE RECONCENTRA-TION FACTORS FOR LIQUID EFFLUENTS ACCUMULATING IN A REACTOR COOLING LAKE Reconcentration models were based on Reg. Guide 1.113 and USEPA EPA-520 -
"Radionuclide Accumulation in a Reactor Cooling Lake." Calculated reconcentration factors for the lake and at the circulating water discharge are presented in Table SA-3, Reconcentration was determined as follows:
! I eg l [ h Lj' Rev. 2 5A-1 6/81 l
WCGS-ER(OLS) C=VT *If (1 - e - Acff t) + Co e
-A ff t uke Concentration O,
C = concentration of radionuclide in the lake at the end of the period Co = concentration in the lake at the beginning of time period t W = Ci/yr rate radioactivity is added to the lake 3 VT = lake volume ft Ob Aeff = A+7T A = the radionuclide decay constant *693 g T = radiological half life Qb = lake blowdown rate cfs t = time Q = plant pumping rate cfs R = reconcentration of radionuclide in the lake at the end of the period R = reconcentration in the lake at the beginning of time period t R= g C= therefore Q P
~
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+R o e cH t R=V T Aeff (1 - e ) Lake Reconcehdon Ccw = concentration at circulating water discharge point Ccw = C + S and C=E P P therefore (R + 1) b O
= Ccw Circulating Water ;
p Discharge Concentration R+ 1 = reconcentration of radionuclide at the circulating water discharge Rev. 2 SA-2 6/81
WCGS-ER(OLS) 77 i 5A.4 REFERENCES t
;V /
Attachment to Concluding Statement of Position of the Reg-ulatory Staf f. Public Rule-making Hearing on: Numer-ical Guides for Design Objectives and Limiting Condi-tions for Operation to Meet ' the Criterion "As Low As Practicable" for Radioactive Material in Light-Water-Cooled Nuclear Power Stations, USAEC, Docket No. RM-50-2, February 20, 1974. Eckerman, K. F. and Lash, D. G., 1978 GASPAR version marked
" revised 8/19/77": US Nuclear Regulatory Commission, Radiological Assessment Branch.
Eckerman, K. F., Congel, F. J., Roecklein, A. K. and Pasciak, W. J., 1980, NUREG-0597 Users Guide to GASPAR Code: U.S.N.R.C. Radiological Assessment Branch. Final Environmental Statement Concerning Proposed Rule Making Action: Numerical Guides for Design Objectives and Limiting Conditions for Operation to Meet the Cri-terion "As Low as Practicable" for Radioactive Material in Light-Water-Cooled Nuclear Power Reactor Ef fluents, USAEC Report WASH-1258, Washington, D.C., July 1973. F le tche r, J. F., and Dotson, W. L. (compilers). HERMES-A (O)
\
Digital Computer Code for Estimating Regional Radiolo-gical Effects from the Nuclear Power Industry, USAEC Report HEDL-TME-71-168, Hanford Engineering nevelopment Laboratory, 1971. Lyon, R. J., Shearin, R. L., 1976, EPA-520 Radionuclide Accumulation in a Reactor Cooling Lake: USEPA, Office of Radiation Programs. ! Regulatory Guide 1.109, Calculation of Annual Doses to Man from Routine Releases of Reactor Effluents for the Pur-i pose of Evaluating Compliance with 10 CPR 50, Appen-dix I, Office of Standards Development. I { Regulatory Guide 1.111, Methods for Estimating Atmospheric Transport and Dispersion of Gaseous Effluents in Rou-tine Releases f rom Light-Water-Cooled Reactors, Office of Standards Development. Regulatory Guide 1.113, Estimating Aquatic Dispersion of Effluents from Accidental and Routine Reactor Releases for the Purpose of Implementing Appendix I, Office of Standards Development. Simpson, D. B., McGill, B. L., 1980, NUREG/CR-1276 User's Manual for LADTAP II Computer Program: U.S.N.R.C. and lq
- v) Oak Ridge National Laboratory.
Rev. 2 SA-3 6/81
WCGS-ER(OLS) Warminski, N. C., 1979, Horticulture Agent for the Sedgwick County Extension Office of the Kansas State University Cooperative Extension Service, Wichita, Kansas, tele- l phone conversation (25, 26 January), written communica- ! tion (29 January). l l l O Rev. 2 SA-4 6/81
N C ' (.2 WCGS-ER(OLS) TABLE SA-1 (Sheet 1 of 4) The following assumptions and parameters were used in LADTAP II for ectimating doses at the Wolf Creek Generating Station site from liquid ef fluents: -
-PARAMETER INDIVIDUAL POPULATION REFERENCE Cooling Lake volume, Normal 4.847E+009 ft 3 4.847E+009 ft 3 3
CGS-ER(OLS) Pre-drought 4.649E+009 ft 33 4.649E+009 ft Page 3.4-3 Low-drought 4.451E+009 ft 4.451E+009 ft 3 3 Seepage 3.5 ft /sec 3.5 ft /sec WCGS-ER(OLS) page 3.3-3 l Blowdown Discharge Sargent & Lundy l Normal-post drought 40.0 ft /sec 40.0 ft /sec Report SL-3204 Revised Pre-drought 3.5 ft /sec 3.5 ft /sec March 26, 1976, on Drought 0.0 ft /sec 0.0 ft /sec Cooling Lake Operation pgs. 10, 11, 13, 14 & 15-3 Ave. Neosho River 1335 ft /sec 1335 ft /sec WCGS-ER(OLS) flow rate 5.1.2.2 page 5.1-3 Dilution at Le Roy 31.69 31.69 Population at Le Roy -- 624 1980 Census from Coffey County Clerk Telephone Call Record 4/17/81 , Population - 50 mile -- 1980 168,130 WCGS-ER(OLS) 2000 184,470 Table 2.1-4 Circulating water 1204 cfs 1204 cfs WCGS-ER(OLS) discharge flow rate Section 3.3 page 3.3-1 Circulating Water and Service Water Rev. 2 i 6/81
WCGS-ER(OLS) TABLE SA-1 (Sheet 2 of 4) PA RAMETER INDIVIDUAL POPULATION REFERENCE Shore width factor, .3 .3 Reg. Guide 1.109 Cooling Lake p. 15 Table A-2 Shore width factor, Reg. Guide 1.109 Neosho River .2 .2 p. 15 Table A-2 Drinking Water Reg. Guide 1.109 Adult 730 1/yr 370 1/yr pgs. 39 & 40, Teen 510 1/yr 370 1/yr Tables E-4, E-5 Child 510 1/yr 370 1/yr Infant 330 1/yr 370 1/yr Fish Consumption Reg. Guide 1.109 Adult 21 Kg/yr 6.9 Kg/yr Pgs. 39 & 40, Teen 16 Kg/yr 5.2 Kg/yr Tables E-4 & E-5 Child 6.9 Kg/yr 2 2 Kg/yr Infant 0.0 Kg/yr 0.0 Kg/yr Invertebrate Consumption Reg. Guide 1.109 Adult 5 Kg/yr 1.0 Kg/yr Pgs. 39 & 40, Teen 3.8 Kg/yr .75 Kg/yr Tables E-4 & E-5 Child 1.7 Kg/yr .33 Kg/yr Infant 0.0 Kg/yr 0.0 Kg/yr Shoreline Exposure Reg. Guide 1.109 Adult 12 hr/yr 8.3 hr/yr Pgs. 39 & 40, Teen 67 hr/yr 47 hr/yr Tables E-4 & E-5 Child 14 hr/yr 9.5 hr/yr Swimming hrs per person HERMES Pgs. 144 & 145, Adult 7.8 hr/yr 3.42 hr/yr Tables III-31 & 32 Teen 45.0 hr/yr 19.2 hr/yr Child 28.2 hr/yr 12.0 hr/yr 9 9 "9
- ~
g
-(g (w/ )
WCGS-ER(OLS) TABLE 5A-1 (Sheet 3 of 4)
! PARAMETER INDIVIDUAL POPULATION REFERENCE Boating hrs per person HERMES Pgs. 144 & 145',
Adult 52.2 hr/yr 29 hr/yr Tables III-31 & 32 Teen 52.2 hr/yr 29 hr/yr Child 29.0 hr/yr 16.53 hr/yr Hold up time hrs hrs Inherent to program Water 12 24 Kug. Guide 1.109 P. 69 Fish 24 168 Pgs. 12 & 69 Invertebrate 24 168 Pgs. 12 & 69 Shoreline exposure 0 0 P. 69 Swimming 0 0 P. 69 Boating 0 0 P. 69 POPULATION Fraction of Population Inherent to progran: Adult 71% Teen 11% Child 18% Le Roy Population - 1980 50 Mile Population - 1980 Reference calculated Adult 443 Adult 119,372 from Lc Roy - 1980 Teen 69 Teen 18,494 Census from Coffey Child 112 Child 30,263 County Clerk. 50 Mile - Total 624 Total 168,130 WCGS-ER(OLS) Table 2.1-4 Sport Fish Harvest - Hazleton Lake Use Feasibility Study WCGS-ER(OLS) Appendix 2A Page 2A-8 Lake Capability 54,000 fishing trips annually 2 lbs per trip from lake. Page 2A-4 18.4% of Kansas population are fishermen. Sport Fish Harvest Fish Harvest Site Specific 675 Kg/yr 48,990 Kg/yr Sport Invertebrate Harvest Invertebrate Harvest Site Specific 97.9 Kg/yr 26,350 Kg/yr Rev. 2 6/81
WCGS-ER(OLS) TABLE SA-1 (Sheet 4 of 4) POPULATION REFERENCE Le Roy Population - 1980 50 Mile Population - 1980 Shoreline Recreation Shoreline Recreation 7,984 hrs /yr 2,147,000 hrs /yr Site Specific Swimming Swimming 4,184 hrs /yr 1,126,500 hrs /yr Site Specific Boating Boating 16,700 hrs /yr 4,498,000 hrs /yr Site Specific Nearest Downstream Water Intake Location - Le Roy Individual Intake Population Intake Reg. Guide 1.109
.2678 gal / day 167 gal / day Site Specific Annual Liquid Release Source Terms WCGS-ER(OLS)
Table 3.5-2 9 9 "9
WOGS-ER(OIS) '![') As TABLE 5A-2 The following assunptions and paramters were used in GASPAR for estimating doses at the Wolf Creek Generating Station site frm gaseous effluents: PARAMETER VALUE ASSIGNED REFERENCE Distance frm facility to the 1546 miles Map masurement NE corner of the US- (Maine) in miles Fraction of year leafy .75 K-State Extension Service vegetables are grown Fraction of crop from garden Default value .76 Reg. Guide 1.109-7 Fraction of year cows are on .5 K-State Extension Service pasture Fraction of daily intake of Default value 1.00 Reg. Guide 1.109-28 cows derived from pasture while on pasture Fraction of year goats are on .5 K-State Extension Service ONj pasture Fraction of daily intake of Default value 1.00 Reg. Guide 1.109 goat from pasture while on pasture Fraction of year beef cattle .5 K-State Extension Service are on pasture Fraction of daily intake of Default value 1.00 Reg. Guide 1.109 beef cattle derivix! fran pasture while on pasture Absolute humidity over 63.1% Table 2.3-3 growing season WOGS-ER(OLS) Average tenp3rature over 64.4 *F Table 2.3-1 growing season WCGS-ER(OLS) Total anntnl release time 1925 hrs /yr Bechtel letter to of intermittent purge SNUPPS BLSE-6610 q;eration Oct. 31, 1978 Annual gaseous release Table 3.5-3 NCGS-ER(OLS) source terms O (V f Average meteorological relative concentrations Table 5.2-1 EXE-ER(OLS) Dames & Moore X/O m p rt 7699-062-07 (X/Os) Rev. 2 6/81
i WCGS-ER(OLS) TABLE SA-3 40 YR. RECONCENTRATION FACTORS NUCLIDE RECONCENTRATION IN LAKE RECONCENTRATION AT CWD H-3 6.13E+001 6.23E+001 Cr-51 9.35E-001 1.94E+000 Mn-54 9.90E+000 1.09E4001 Fe-55 2.75E+001 2.85E+001 Fe-59 1.51E+000 2.51E+000 Co-58 2.38E+000 3.38E+000 Co-60 4.37E+001 4.47E+001 Br-83 3.37E-003 1.00E+000 Mo-99 1.00E-001 1.10E+000 Tc-99M 8.42E-003 1.01E+000 Te-129M 1.14E+000 2.14E+000 I-131 2.72E-001 1.27E+000 Te-132 1.09E-001 1.11E+000 I-132 3.23E-003 1.00E+000 I-133 2.95E-002 1.03E+000 Cs-134 2.27E+001 2.37E+001 I-135 9.40E-003 1.01E+000 Cs-136 4.37E-001 1.44E+000 Cs-137 7.30E+001 7.40E+001 Zr-95 2.18E+000 3.18E+000 Nb-95 1.18E+000 2.18E+000 Rb-86 6.29E-001 1.63E+000 Ru-103 1.34E+000 2.34E+000 Ru-106 1.20E+001 1.30E+001 Ag-110M 8.31E+000 9.3]E+000 Cc-144 9.30E+000 1.03E+001 Br-84 7.45E-004 1.00E4000 Sr-39 1.75E+000 2.75E+000 Te-127M 3.64E+000 4.64E+000 Te-127 1.32E-002 1.01E+000 Te-129 1.61E-003 1.00E+000 I-130 1.75E-002 1.02E+000 Te-131M 4.22E-002 1.04E+000 Br-85 7.01E-005 1.00E+000 Rb-88 4.18E-004 1.00E+000 Sr-91 1.35E-002 1.01E+000 Y-91M 1.17E-003 1.00E+000 Te-131 5.87E-004 1.00E+000 I-134 1.24E-003 1.00E+000 (1) 40 yrs of reconcentration based on: Yeats Blowdown + Seepage Lake Invel 3 Normal-post drought 31.59 40 cfs 3.5 cfs 4.847E+009 ft 3 Pre-drought 3.58 3.5 cfs 3.5 cfs 4.650E+009 ft 3 Drought 4.83 0 cfs 3.5 cfs 4.451E+009 ft (2) Drought occurs at the end of the 40 yr perial. Rev. 2 6/81
WCGS-ER (OLS ) fN 7.3 0THER' ACCIDENTS
} \s / 7.3.1 EXPLOSIVE AND TOXIC MATERIALS Accidents that do not involve radioactive materials could have consequences that af fect the environment. Such~ accidents include chemical explosions or fires, and leakage or rupture of vessels 'containing oil or toxic materials. The ef fects o f accidents on the normal operation of the plant are discussed in Section 2.2.3 of the Wolf Creek Generating Station Final Safety Analysis Report (WCGS FSAR). The fire protection system is described in Section 9.5.1 of the FSAR.
The principal criterion established for this facility for the storage of toxic or explosive material is that the impact o f accidents involving any significant quantity of materials will be confined within the site boundary. The ef fect of chemical explosions or fires on the environment beyond the site boundary is minimized by the fire protection system and the relative isolation of these potential sources of explosions or fires. If an explosion or fire were to occur, the offsite environmental effect would occur from airborne emissions such as sulfur dioxide carbon monoxide, hydrocarbons, nitrogen oxides, and particulates. At worst, 7- g the effects from this accider.t would be short-term. Two (v; examples of combustible materials are as follows: Heating Fuel Oil - a maximum of 470,000 gallons of No. 2 grade fuel oil is stored at the site approximately 380 feet from the power block. The storage tank is confined by a berm which prevents the release of fuel oil if failure of the tank should occur. The berm has the capacity to hold the entire contents of the tank. Any spillage is handled according to the Spill Prevention Control and Countermeasure Plan and will have no adverse environmental impact. No. 2 grade fuel oil has a relatively low volatility since its vapor pressure is usually less than 0.1 pounds per square inch (psi). At normal storage temperatures explosive mixtures are not i formed; thus an explosion hazard should not exist. No. 2 grade fuel oil will sustain combustion if its ignition temperature is reached by an outside heat source. The airborne combustion products from such an event would be diffused at the site boundaries, thereby reducing concentrations. Hydrogen - a maximum of 120,000 standard cubic feet (scf) of hydrogen is stored on the site. It is stored in modular high pressure (2450 psig) bottles outside and approximately 650 feet from the power block but not near i p)
\d 7.3-1
WCGS-ER(OLS) the site boundaries so that neither the offsite environs nor the power block would be endangered by an explosion involving hydrogen. Any leakage from the hydrogen bottles would be rapidly diluted with atmospheric air thus preventing an explosive mixture from forming in any area other than the immediate area of any postulated leak. Leakage of hydrogen into the atmosphere is not harmful since it merely adds an insignificant quantity to the existing inventory. The hydrogen header serving the power block is provided with a mechanical check valve which would isolate flow in the event of a postulated pipe rupture. The storage of material which could cause offsite toxic concentrations high enough to have adverse environmental consequences are provided with a confinement barrier. The following are examples of such toxic materials: Sulfuric Acid (H,SO 3 ) - A maximum of 61,000 gallons of a 66 6 Baume soluEion of sulfuric acid is stored outdoors at the nite. The sulfuric acid is stored in a lined carbon steel tank located above a pit filled with limestone to confine and neutralize releases to the immediate area. The pit has the capacity to hold the entire contents of the tank. A maximum of 11,000 gallons of a 66 Baume solution of sulfuric acid is also stored indoors at the shop building. The acid is stored in a lined carbon steel tank which is confined by a berm. This berm will preclude the possibility of an uncontrolled release of sulfuric acid. Sodium Hydroxide (NaOH) - A maximum of 16,000 gallons of 50-percent colution of sodium hydroxide is stored in a lined carbon steel tank indoors at the shop building. This tank is confined by the same berm used to confine the sulfuric acid tank. Since the simultaneous rupture of the sodium hydroxide and sulfuric acid tanks is considered highly unlikely, the berm is not designed to hold the entire contents of both tanks. The postulated mode of failure of these tanks is a slow leak condition. A drain is provided within the berm to remove and neutralize any accidentally released material. Each of the tanks can be independently monitored and controlled. Chlorine (C19 Liquid) - Up to 21 1-ton liquid chlorine containers are onsite either installed in the clorination system in the circulating water screen house, or in the chlorine storage facility located approximately 150 feet north of the circulating water screen house. (See Figure 2.1-4) In addition, four 150-pound storage vessels will be stored near the shop building in the chlorine house. Because potentail accidental releases of chlorine from these containers would be considerably less than these Rev. 2 7.3-2 6/81
'WCGS-EC(OLS) s CHAPTER 10.0 /
i ( / STATION DESIGN ALTERNATIVPS During the construction permit review, a variety of station design alternatives were considered in Chapter 10.0 of the Environmental Report Construction Permit Stage (FR(CPS)). The designs selected were approved by the NRC in the course of granting a construction permit. for Wolf Creek Generating Station, Unit ' No. 1 (WCGS) as _ discussed in the following se ct ions'. In some cases no alternatives were presented in the ER(CPS) when there was only one clear design choice. *he implementation of the selected design is discussed in tais' chapter. 10.1 CIRCULATING WATER SYSTEM It was concluded by the Applicants in the ER(CPS) and the NRC staff in the Construction Permit Final Environment Statement (CPPES) that a 5090 acre cooling lake was superior to all alternatives considered for the dissipation of heat from WCGS. The cooling lake is described in Section 3.4. 10.2 INTAKE SYSTEM The preferred design alternative of the intake structure for .s the WCGS circulating water system as proposed by the Appli-
\ cants in the ER(CPS) and approved by the NRC in the CPFFS utilizes a conventional screenhouse with vertical travelling screens.
The design selected for the WCGS makeup water system by the Applicants in the ER(CPS) and approved by the NRC in the CPFES utilizes a similar screenhouse with travelling screens ' located on a deadend channel constructed along the east bank of the Neosho River just downstream of the John Redmond Dan. The plant intake systems are described in Section 3.4. ~ 10.3 DISCHARGE SYSTEM No alternative desig u were proposed by the Applicants in the ER(CPS) for the discharge structures in the circulating water and makeup water systems. The NRC concurred with the use of concrete outfall structures for these systems in the CPFES. The discharge structures are described in Section 3.4. l v ; 10.0-1
WCGS-ER(OLS) 10.4 CHEMICAL WASTE TREATMENT The chemical waste treatment processes to be implemented for WCGS are those proposed by the Applicants in the ER(CPS). The systems which involve chemicals are the circulating water system, steam cycle system and domineralized water system as described in Sections 3.3 and 3.6. 10.5 BIOCIDE TREATMENT The alternative chcson by the Applicants in the ER(CPS) to control biological growth and slime buildup in the cooling water which passes through the main condenser an' auxiliary heat exchanger tubes at WCGS is an intermittent chlorination program utilizing chlorine gas. A description of the chlor-ination program is given in Section 3.6. and ER(CPS) Section 3.6. 10.6 SANITARY WASTE SYSTEM The sanitary waste treatment system implemented for WCGS uses the treatment method proposed by the Applicants in the ER(CPS). The water treatment system is described in Section 3.7. Effluent water quality requirements are imposed on the facility by the State of Kansas under the NPDES permit program. 10.7 LIQUID RADWASTE SYSTEMS As discussed in Section 5.2, the liquid radwaste systems for WCGS described in Section 3.5 conform to the "as low as reasonably achieveable" (ALARA) criteria of 10 CPR 50 Appen-dix I. Consequently, no discussion . of alternative liquid radwaste systems was presented in the ER(CPS) or is war-ranted herein. 10.8 GASEOUS RADWASTE SYSTEMS As discussed in Section 5.2, the gaseous radwaste systems for WCGS described in Section 3.5 conform to the ALARA criteria of 10 CFR 50 Appendix I. Consequently, no dis-cussion of alternative gaseous radwaste systems was pre-sented in the ER(CPS) or is warranted herein. 10.9 TRANSMISSION PACILITIES l The major 345-kV transmission line construction associated with WCGS will be along the preferred routes proposed by the Applicants in the ER(CPS) and concurred with by the NRC in the CPPES with the following exception:
- a. The Wolf Creek-Craig transmission line will be shortened by approximately 14 miles and will terminate at the West Gardner Substation Rev. 2 10.0-2 6/81
=. . - _ . _. -. .- . -- -
WCGS-ER(OLS) , fg becoming the Wolf Creek-West Gardner trans-mission line (see Section 3.9).
- (v)
An additional 69-kV transmission line, not identified in the
. ER(CPS), was constructed by a Kansas Electric Power Coopera-tives member between the WCGS substation and the nearby Phillips Petroleum Company pipeline pumping station at Sharpe, Kansas. Because of the shortness of this line (less than three miles) and there being only one practical route for the line, no alternatives are postulated.
See Section 3.9 for a discussion of the WCGS transmission facilities. 10.10 OTiiER SYSTEMS No other systems have been identified for which potential environmental effects warrant consideration of design alter-natives. O i i i ) I O l Rev. 2 l 10.0-3 6/81 ,
. _ . ~ . , -
WCGS-ER(OLS) s CHAPTER 12.0 ENVIRONMENTAL' APPROVALS AND CONSULTATIONS The design, construction and operation of Wolf' Creek Gener-ating Station, Unit No. 1 (WCGS) is subject to a number of licenses, permits and conditions resulting from the review and approval of numerous local, state and federal agencies. Pursuant to these requirements the Applicants have made contacts with and have secured the appropriate approvals, licenses, permits and certificates from the various govern-mental agencies as described in the Environmental Report-Construction Permit Stage (ER(CPS)) and as updated below: 12.1 STATUS OF ENVIRONMENTAL REGULATORY REQUIREMENTS AND CONSULTATIONS 12.1.1 FEDERAL AGENCIES 12.1.1.1 Nuclear Regulatory Commission The Nuclear Regula tory Commission's Atomic Safety and Li-censing Board conducted public hearings concerning the WCGS 3 construction permit application. The hearings were held on November 12 and 13, 1975, ' at Burlington, Kansas, January
- f 26-28, February 2-6, February 23-26, March 2-5, April 26-30, June 24-25, 1976, March 5 22-23, 1977 at Kansas City, Missouri, and May 4, 1976, at Bethesda, Maryland.
On January 19, 1977, the Board issued a Partial Initial Decision in which it made all the findings required by 10 CFR Part 51 with respect to NEPA matters, and determined that there is reasonable assurance that the proposed site is a suitable location for a nuclear power reactor of the size and type proposed. Subsequently on January 24, 1977, the Nuclear Regulatory Commission granted a Limited Work Author-iza tion permitting certain activities at the site which might be characterized as site construction preparatory activities. On April 18, 1977, an amendment was granted to the Limited Work Authorization permitting the initiation of construction of specific structures at the site. On May 17, 1977, the Nuclear Regulatory Commission issued construction permit CPPR-147 authorizing the constructon of
- WCGS.
g V 12.1-1
WCGS-ER(OLS) 12.1.1.2 Environmental Protection Agency The Environmental Protection Agency (EPA) implements provi-sions of the Federal Water Pollution Control Act (FWPCA) as amended that requires the licensing and certification of effluent water discharges from federally licensed indus-trial projects. The EPA has granted the Kansas Department of Ilealth Environment (KDIIE ) authority to certify activities as provided by FWPCA Section 401 and to issue permits through the National Pollution Discharge Elimination System (NPDES) program as provided by Section 402 of the Federal Water Pollution Control Act. Kansas Gas and Electric Company (KG&E) has kept the EPA in-formed of its intentions relating to proposed discharges from WCGS through official meetings, correspondence, and telephone conversations, and has discussed the conditiona and standards relating to the NPDES permit which was subse-quently issued by the KDIIE. 12.1.1.3 U.S. Army Corps of Engineers Section 404 of the Federal Water Pollution Control Act authorizes the Army Corps of Engineers to regulate the discharge of dredge and fill material, including construc-tion materials in the waters of the United States. In accordance with the provisions of thia act the Applicants have secured 404 permits for all applicable structures: Permit for construction of issued May 27, 1976 two highway bridges Permit for construction of 8 ' issued January 29, 1977 raw water pipeline. I Permit for construction of three issued January 29, 1977 rullroad access bridges Permit for construction of issued May 20, 1977 cooling water impoundment. Dam permit for construction issued May 20, 1977 of water intake pumping struc-ture. Several meetings weite held with the U.S. Army Corps of
- Engineers, Tulsa District office relative to the location l and type of structure to be utilized in pumping water from the John Redmond Reservoir to the Wolf Creek cooling lake O
Rev. 2 12.1-2 6/81 l i l l
WCGS-ER(OLS) 240.0 HYDROLOGICAL AND GEOTECHNICAL ENGINEERING BRANCH v Q240.1 ER-OL, p. 3.3-2, Sec. 3.3.6. Please indicate the (ER) makeup water ' rates used in simulating the Wolf (3.3) Creek cooling lake drawdown during the 16-year (1948-1964) design weather period. R240.1 The makeup rate for the 16-year cooling lake anal-ysis was divided into three makeup schedules given as follows: For the predrought, January 1, 194.9 to July 31, 1952, the makeup rate varied from 0 to 120 cfs; during the drought, August 1, 1952 to May 31, 1957, the makeup rate was fixed at a constant 40 cfs; and for the post drought, June 1, 1957 to 7ecember 13, 1964, the makeup rate varied itom 0 to 1.10 cfs. In the predrought and post drought periods where the makeup va ried from 0 to 120 cfs, the T.AKET program calculated the amount of makeup requir:J to maintain a constant cooling lake elevation of 1087 feet MSL. The attached tables list the aver-age monthly makeup flow rates for the 16-year cooling lake analysis for Unit 1 and Units 1 and 2 respectively. 4 1 Rev. 2 l 240-1 6/81
NR(OIE) TABIE 240.1-1 Rmthly Average WGS Cboling Iake Makeup Flow Rate, cfs, Frun 1949 to 1%4 WCS - Urtit 1 Mmth/ Year 1949 1950 1951 1952 1953 1954 1955 1956 1957 1958 1959 1%0 1961 1962 1%3 1964 JAri 0 26.07 24.37 18.14 40.0 40.0 40.0 40.0 40.0 58.64 62.99 50.03 67.50 38.27 61.44 63.24 FIB 0 23.55 9.18 20.94 40.0 40.0 40.0 40.0 40.0 54.27 59.34 44.75 51.99 43.21 59.20 65.46 Muut 0 34.67 20.85 .40 40.0 40.0 40.0 40.0 40.0 5.70 69.26 20.66 37.48 40.50 47.76 73.74 APRIL 0 44.57 9.43 0 40.0 40.0 40.0 40.0 40.0 46.27 67.04 52.52 31.33 78.74 96.34 43.85 MAY 0 16.67 0 35.03 40.0 40.0 40.0 40.0 40.0 53.05 43.40 54.56 0 103.56 89.63 79.21 JUNE: 0 18.04 0 81.65 40.0 40.0 40.0 40.0 0 52.64 87.42 83.83 36.02 25.74 84.55 46.78 JULY 14.07 0 0 63.25 .40.0 40.0 40.0 40.0 57.71 11.28 32.91 79.61 93.95 93.55 108.55 115.02 AUG 62.94 0 0 40.0 40.0 40.0 40.0 40.0 118.33 85.36 96.66 76.76 92.11 108.52 117.54 92.53 SEPT 25.05 0 0 40.0 40.0 40.0 40.0 40.0 79.25 54.% 103.25 135.36 10.72 12.04 102.06 95.69 Ocr 33.94 24.40 0 40.0 40.0 40.0 40.0 40.0 63.34 93.90 12.60 48.60 59.44 75.35 107.42 95.0 Nov 48.76 51.51 0 40.0 40.0 40.0 40.0 40.0 54.28 73.87 78.92 75.36 54.08 64.31 80.44 83.68 DEC 23.56 28.83 .94 40.0 40.0 40.0 40.0 40.0 57.71 59.98 58.39 65.89 5d.43 66.84 72.53 65.04 Rev. 2 6/81 O - - O - -- O _
. _ _ , _ . . __ _. . _ . . _ _ _ _ - , m
-~
] N a) i 6
iCGS-ER(OIS) TABLE 240.1-2 Monthly Average 50GS Cooling take Make@ Plow Rate, cfs, Prom 1949 to 1%4 50 2 - Units 1 & 2 Mtmth/ Year 1949 1950 1951 1952 1953 1954 1955 1956 195'. 1958 1959 1960 1961 1%2 1963 1964 JAN .55 37.58 36.74 29.31 40 40 40 40 40 120 73.68 60.42 78.39 46.46 70.30 7468 FEB 0 34.70 13.42 34.31 40 40 40 40 40 120 70.45 56.65- $3.40 57.92 71.92 78.93 MMoi 0 48.27 39.94 3.45 40 40 40 40 40 120 83.65 31.33 51.64 52.95 62.05 87.15 APRIL 10.82 59.0 24.58 10.62 40 40 40 40 40 120 82.40 69.02 44.16 93.98 112.02 58.21 MY 24.04 31.51 0 68.84 40. 40 40 40 40 120 61.40 71.85 0 115.61 107.94 92.% JttlE 45.68 '39.17 0 100.27 40 40 40 40 120 120 101.67 101.18 74.30 49.97 101.11 68.83 JULY 36.15 4.94 0 84.38 40 40 40 40 120 70.28 56.06 99.02 110.62 111.69 120 120 AUG 82.67 0 0 40 40 40 40 40 120 108.92 ' 116.13 97.21 112.78 ~113.71 120 120 SEPT 42.37 16.87 0 40 40 40 40 40 120 80.37 119.59 119.33 26.27 42.20 120 118.50 OCT 51.07 75.16 0 40 40 40 40 40 120 110.86 29.33 76.68 78.09 94.83 120 111.58 Nov 61.83 64.67 9.72 40 40 40 40 40 120 87.80 91.89 90.19 67.15 76.10 120 98.74 DEC 35.0 39.48 39.18 40 40 40 40 40 120 70.01 70.34 76.93 69.45 79.59 86.29 74.92
- Rev. 2 6/81 l
1
WCGS-ER(OLS) Q240.2 ER-OL, p. 3.4-1, Sec. 3.4.1. For one 1150 MWe (ER) unit operating at a 100-percent average annual (3.4) load factor, will the yrculating water heat re-jection rate be 8.1 9x 10 Btu /hr as stated in Sec. 3.4.1 or 7.87 x 10 Btu /hr as indicated in Sec. 3.4.4? R240.2 The circulating water heat rejection rate for one 1150 MWe unit operating at ig0 percent average annual load factor is 7.87 x 10 Btu /hr. 9 The 8.1 x 10 Btu /hr heat rejection rgte mentioned in Section 3.4.1 should be 8.0 x 10 Btu /hr and represents the heat rejection rate fpr the circu-lating water system plus 0.13 x 10 Btu /hr heat rejection rate for the service water system. Q240.3 ER-OL, p. 3.4-3, Sec. 3.4.3.2. The calculated (ER) velocities of the water approaching and within the (3.4) circulating water intake structure do not seem to be accurate. The staff has presented in the FES-CP, Table 3.1 the various intake velocities for a total flow rate of 1256 cfs. Please prepare the similar table for the modified intake structure and the revised flow rate of 1204 cfs. R240.3 See revised Sect.on 3.4.3.2, page 3.4-3. The water intake velocities listed in Section 3.4.3.2 replace Table 3.1 of the FES-CP. Q240.4 ER-OL, p. 3.4-3, Section 3.4.3.2. Please provide (ER) an engineering drawing showing the width of the (3.4) modified circulating water discharge chute, and also indicate the discharge velocity for a total flow rate of 1204 cfs. R240.4 The width of the modified circulating water dis-charge chute is 75 feet as shown in the plan view of drawing S-500 provided with formal response. The discharge velocities below the circulating water discharge chute for a total flow rate of 1204 cfs are calculated to be 1.15 f t/sec and 1.5 ft/sec for the lake levels of 1087.0 ft (normal operating level) and 1085.0 ft (low water level for 1-unit) respect ively. O Rev. 2 240-2 6/81
KCS-ER(OLS ) Q240.5 ER-OL, p. 3.4-4, Sec. 3.4.4. Please indic3te the g (ER) service water temperature rise . and the combined E N (3.4) circulating and service water temperature rise for the station operating at full load. R240.5 The service water tempe rature rise and the com-bined . circulating and service water temperature rise for one unit operating at 100% load are given as follows: Service water temperature rise = 6.4'F Plant temperature rise (Combination = 29.6*F of circulating and service water) Circulating water temperature rise = 31.5'F
\
e t i I f l Rev. 2 240-3 6/81 1
h WCGS-ER(OLS) Q240.6 ER-OL, p.3.4-4, Sec. 3.4.4. Please provide a copy (ER) of the manual describing the LAKET computer model (3.4) used to calculate the cooling lake temperature distribution. R240.6 The LAKET program is proprietary so that only the LAKET program abstract is attached for your review. The LAKET user's manual is available in Sargent & Lundy offices for NRC's inspection. O 1 O Rev. 2 240-4 6/81
WCGS-ER(OLS) I R240.6 (continued) [U} PROGRAM ABSTRACT TITLE: LAKET - One-Dimensional Lake Thermal Prediction Program PROGRAM NO.: 09.5.072-5.0 AUTHOR: R. J. Slezak PROGRAM SCOPE: LAKET analyzes th transient thermal performance of one-dimensional lakes, rivers, and channels. Varying plant flow rate and rise temperature are treated. Lake TDS and turbine back-pressure may be computed. Runs may switch between open and closed cycle, and between constant level and varying level. INPUT: Lake configuration, meteorological conditions, and plant operational
~N data. , \s_/ OUTPUT: Lake temperatures, elevation, and water balance components. Full statistical monthly, seasonal, yearly, and total d
summaries for all variables. Computer-4 generated plots of all calculated variables versus time are available with the LAKPLOT (09.5.115-1.0) post processor. COMPUTATIONAL APPROACH: A LaGrangian formulation of the mass and energy conservation equations is implemented. Plug flow is assumed through the channel. A 3-hour time step is used for all variables. ESTIMATED RUNNING TIME: One CPU minute per year of simulation. MACHINE: UNIVAC 1106 Core size 7 22k words a Rev. 2 240-5 6/81
WCGS-ER(OLS) 0240.7 Describe the effects of plant consumptive water (ER) use on existing and projected downstream water (2.4) users under low flow conditions up to and includ-
- ing the 2 percent chance drought. The description l
should include current information on water use and current projections of future use. R240.7 A discussion of the effects of plant consumptive water use on downstream water use rs during the period of record drought of 1952-1957 was discuss-ed by the NRC staff in the Supplemental Testimony, dated January 6, 1976, on contention I-1 during the Atomic Safety and Licensing Board hearings. This period-of-record drought is estimated to have a recurrence interval of fif ty years (2% chance drought). The NRC staff in their discussion con-cluded that even if all the water rights, senior to Kansas Water Resources Board's right to John Redmond Reservoir storage, set out in Kansas De-partment of Agriculture list, are included as downstream users, there is sufficient storage availab le in John Redmond D.esetvoir to provide 41 cfs to the WCGS and to satisfy rights of down-stream users through the period-of-record drought. O O Rev. 2 240-6 6/81
WCGS-ER(OLS) 0240.8 Provide a flow-duration curve for the Neosho River l (ER) at Wolf Creek reflecting regulation by the John (2.4) Redmond Rese rvoir. Also provide an estimate of the 7 consecutive day once in 10 year low flow for the river at Wolf Creek under the same conditions. Discuss the effect of plant operation on these parameters. Provide in your discussion your as-sumptions regarding reservoir release rates and plant withdrawals. R240.8 The nearest U.S. Geological Survey gaging station on the Neosho River downstream of John Redmond Reservoir and near the confluence of Neosho River and Wolf Creek is at Burlington, Kansas. This gaging station at Burlington, Kansas, is approxi-mately five miles downstream of John Redmond Pes-ervoir and the confluence of Neosho River and Wolf Creek is approximately 4 miles downstream of this gaging station. The flow-duration information for Neosho River at Burlington, Kansas, for the period October 1964 to September 1979 is presented in Figure 240.8-1. The 7-day 10-year low flow for the same period is 17.3 cf s. During low flows, the flows in Neosho River below
- John Redmond Reservoir would constitute the re- /
i leases from the reservoir for water rights and
/ water quality purposes. Even with plant operation at WCGS, the releases for water rights and water quality will be made from the Reservoir and, hence, the flow-dr'ation for the low-flow range would not be af';c ed at Burlington nor at Wolf Creek.
The Attachment M to the supplemental testimony by NRC staff dated January 6, 1976 on contention I-1 during Atomic Safety Licensing Board hearings (Construction Permit Stage) gives average monthly flows in the Neosho River below John Redmond Res-ervoir with WCGS operation for the period 1951-1959. Attachments A and B to the above testimony tabu-late the water quality and water rights releases below John Redmond Reservoir. The plant makeup water rates (withdrawal from John Redmond Rescr-voir) are discussed in Section 3.3.6 of WCGS, i ER(OLS). See response to Question 240.7 regarding the effects of plant consumptive water use on existing and projected downstream water users under low flow conditions. Rev. 2 240-7 6/81
100p00.0 O 10p00.0 % u
\
'\
\
\
1900.0 \- It\ a h - _ _
\ = t r N <
b E o l00'O
~
( x
\
u 10.0 l 1.0 0.1.2 0.5 1.0 2 5 10 20 30 40 50 60 70 60 90 95 98 99 99.5 99.9 TIME IN PERCENT OF INr.CATED PERIOO 99 8 PERIOD OF RECORD: ,, 6v . 2 6/81 OCT.1964 - SEP.1979 I E ' G MUM UNIT NO. I DMRONMENTAL REPORT CPERATING LICENSE Figure 240.0-1 Plow-Duration Curve - Daily Flow of Neosho River at Burlington
WCGS-ER(OLS) i ' EX 0240.9 Provide the dates of the minimum daily flows shown
, (ER) in Table 2.4.3 of the ER. If these low flows were (2.4 )- - a result of reservoir filling,, provide minimum daily flows (and dates) for the period after the reservoir began normal operation.
R240.9 See reviced Table 2.4-3 for dates of minimum daily flows for the period September 1, 1964 through
. September 30, 1977. Regulated storage of John Redmond Reservoir began on September 1, 1964.
ij i l 1 I i l i 4 i l t I Rev. 2 240-8 6/81 1
. - , - - -m y-.y..-._ m -,,,.m,, - _ _
WCGS-ER(OLS) 0240.10 Provide a description of the analysis used to de-(ER) termine the runoff into Wolf Creek Cooling Lake (2.4) for the cooling lake simulation study. Describe the gaged basins used to extrapolate flows for Wolf Creek including location, size, period of record, whether the streams are effluent or influ-ent, and any adjustments made other than for drain-age area. R240.10 Since Wolf Creek is ungaged, no records of stream flows are available. Streamflow data for Wolf Creek were synthesized from the U.S. Geological Survey records for the following gaging stations: Drainage Area Period of Gaging Station (sq. mi.) Record Used
- 1. Neosto River at Council Grove, Ms. 250 1938-1977
- 2. Neocho River at Anericus, Ks. 622 1963-1977
- 3. Neosho River at Strawn, Ks. 3015 1922-1963
- 4. Neosho River at Burlington, Ms. 3042 1962-1977
- 5. Neosho River at Iola, Ks. 3818 1917-1977
- 6. Virdigris River at Madison, Ks. 181 1955-1976 All the above stations are located adjacent to the Wolf Creek drainage area and the available data is adjusted to correlate with the creek's drain-age area. The average intensity of streamflow at the gaging stations was applied to the drainage area of Wolf Creek to obtain the runof f into Wolf Creek cooling lake. No adjustments are made other than for drainage area.
The Neosho River and Wolf Creek are characterized as effluent streams in ER(OLS) Section 2.4.1.2. l l 9 Rev. 2 240-9 6/81
e WCGS-ER(OLS) r3 0240.11 Justify the conservatism of the estimates of Wolf ( } (ER) Creek Cooling Lake seepage, evaporation, and in-
'w/ (3.3) flow that have been used as input.to the consump-tive water use analysis and cooling lake drawdown studies.
R240.11 Seepage The maximum seepage estimated from the cooling lake and through the cooling lake dam is 0.102 cfs, when the lake level is at the normal operating level of 1087.0 feet MSL. . (See Section 2.4.2.4.2 and Table 2.4-10 of ER(OLS) and Section 2.5.6.6.1 of FSAR.) A seepage of 3.5 cfs at the lake level of 1087.0 feet MSL was used in the cooling lake analysis. The use of the higher _ seepage of 3.5 cfs is conservative because, during drought con-ditions (August 1952 through May 1957), the higher seepage would force the cooling lake to operate at more severe conditions, greater lake drawdown and higher lake temperatures. Evaporation The evaporation predicted by LAKET are based on the most accurate predicted method available from published sources and experimental studies listed below: (~\ ( Patrick Ryan and Donald Harleman, "An Analytical and Experinental Study of Transient Cooling Pond Behav-ior," MIT Report No. 161, 1973. D. K. Brady, W. L. Graves and J. C. Geyer, "Sur-face Heat Exdlange at Power Plant Cooling Lakes", Cooling Water Studies for Edison Electric Institute, Report No. 5, John Hopkins University, November 1969. B. A. Ticheror and A. G. Christianson, " Cooling Pond Temperature vs. Size and Water Loss", presented at ASCE National Water Resources Engineering Meeting, Phoenix, Arizona, January 1971. Inflows The inflows into Wolf Creek cooling lake are esti-mated as described in response to Q240.10 (2.4). The estimated flows are shown in Table 2.4-22 of the FSAR. During the historic drought period of 1952-1957, for a period of six consecutive months (September 1956 to February 1957), the flows are negligibly small. Also for the 7 month period, from August A 1953 to Februa ry 1954, the flow is less than 0.2 ( j)
\,
cfs. Therefore, it can be concluded that the in-flows used in the anlysis are conservative. Rev. 2 240-10 6/81
WCGS-ER(OLS) 0240.12 Provide detailed stratigraphic sections used for (ER) seepage calculations along the seepage secto rs (2.4) shown on Figure 2.4-17. These sections should clearly ider.*.ify the various stratigraphic members, their length, thickness, and elevations; and the location of walls or streams intersecting these membe rs in the vicinity of the plant. Photo copies of sections plotted for Table 2.4-10 calcu-lations are acceptable. R240.12 The detailed stratigraphic sections were trans-mitted with formal response. The same stratigra-phic sections, as well as other supporting tech-nical information, were previously provided as written testimony on Contention I-2 during the earlier environmental hearings (Construction Per-mit Stage). O O Rev. 2 240-11 6/81
! WCGS-ER(OLS)
'/] Q240.13 Calculate the radiological ' consequences of a li-(ER) quid pathway ~ release . from a postulated core melt' (7.1) accident. The analysis should assume, unless otherwise justified, that there has been a pene-tration of the reactor- basemat by the molten core mass, and that a substantial portion-of radioac-tively contaminated sump water was released to the ground. Doses should be compared to those calcu-lated in the Liquid Pathway Generic Study (NUREG-0440, 1978). Provide a summary of your analysis procedures and.the values of parameters used (such as permeabilities, gradients, populations affected, water use). .It is suggested that meetings with the staff of the Hydrologic Engineering Section be arranged so that we may share with you the body of information necessary to perform this analysis.
R240.13 The requested analysis to calculate the radiolog-l ical consequences of a liquid pathway release from a postulated core melt accident will be performed. The analysis will be conducted in accordance with guidance received from the NRC staff. The results of the analysis will be provided to the NRC in the form of a revision to the Environmental Report (OLS) in the near future. O i .i j l O ' O Rev. 2 240-12 6/81
WCGS-ER(OLS) 0240.14 Descriptions of floodplains, as required by Execu- ' (ER) tive Order 11988, Floodplain Management, have not (2.4) been provided. The definition used in the Execu-tive Order is: Floodplain: The lowland and relatively flat areas adjoining inland and coastal waters including floodprone areas of offshore islands, including at a minimum that area subject to a one percent or greater chance of flooding in any given year. a) Provide descriptions of the floodplains ad-joining the Neosho River, Wolf Creek and Wolf Creek Cooling Lake adjacent to the site. On suitabic scale map (s) provide delineations of those areas that will be flooded during the one percent (100 year) and .2 percent (500 year) chance floods both before and after plant construction. b) Provide details of the methods used to deter-mine the floodplains in response to a. above. Include your assumptions of and bases for the pertinent parameters used in the computation of the one percent flood flow and water ele-vation. If studies approved by the Federal Insurance Administration (FIA) are available for the site and adjoining area, the details of the analysis used in the reports need not be supplied. You can instead provide the reports from which you obtained the flood < plain information. c) Identify, locate on a map and describe all structures and topographic alterations in the floodplains. Q240.15 a. Discuss the hydrologic effects of all items (ER) identified in response to question 14c. Dis-(5.7) cuss the alteration in flood flows in Wolf Creek below Wolf Creek Cooling Lake. Deter-mine the offect of the cooling lake on the 50, 10, 1, and .2 percent chance floods (2 year, 10 year, 100 year, and 500 year floods) in Wolf Creek below the cooling lake. Expected reservoir water level and storage and the time of the storm should be taken into account.
- b. Provide details of your analysis used in response to a. above.
O Rev. 2 240-13 6/81
WCGS-ER(OLS) R240.14/240.15 These two Questions (240.14 and 240.15) are inter-related. Therefore, a common response is provided. A description of the Neosho River basin and Wolf Creek watershed is given in Section 2.4.1.2 of the ER(OLS) and Section 2.4.1.2 of the FSAR for the Wolf Creek Generating Station (WCGS). The flood prone area, the area flooded due to a 100-year flood, in the vicinity of the site prior to the construction of the WCGS and its facilities is shown in Figure 240.14/240.15-1. The flood prone area is taken from Flood llaza rd Bounda ry Maps for Cof fey County, developed by the Federal Insurance Administration, U.S. Department of Ilousing and Urban Development, dated August 1977. Maps showing the area flooded by a 500-year flood are not developed by the FIA and, hence, are not available. However, a S tanda rd Project Flood (SPF) was developed for the Wolf Creek cooling lake and is presented below. The facilities for WCGS, which may potentially alter the flood plains of the streams in the site
, area are the cooling lake dam, the makeup water e
' screenhouse on the Neosho River below John Radmond j dam, the circulating water screenhouse and dis-charge structure, the makeup discharge structure and the offsite roads and ra ilroad track. All these facilities are identified in Figure 240.14/ 240.15-2. The circulating water screenhouse, dis-charge structure and the makeup discharge struc-ture are built along the shoreline of the cooling lake and will have negligible of fect on the Wolf Creek flood plain. A description of other facil-ities and their potential effects on the flood plains of the streams is given below. Floods in Cooling Lake A cooling lake was developed for WCGS by con-structing a dam across Wolf Creek. The 100-year flood level in the cooling lake is estimated to be 1089.8 MSL. The flood prone areas above the dam due to a 100-year flood before and after the con-struction of the dam are shown in Figure 240.14/ 240.15-2. The boundaries of the property owned by the applicant are also shown in Figure 240.14/ 240.15-2. The area covered by the 100-year flood in the cooling lake is well within the prope rty boundaries (Figure ^40.14/240.15-2). Beyond the [' ' prope rty bounda ry in the upper reaches of Wolf
! Creek, the 100-year flood in the cooling lake does Rev. 2 240-14 6/81
WCGS-ER(OLS) R240.14/R240.15 (continued) not affeet the flood prone area which existed prior to construction of the main dam. The 500-year flood was not generated for the Wolf Creek cooling lake. Ilowever, a standard project flood (SPF) was developed for WCGS and is dis-cussed in Section 2.4 of the WCGS FSAR addendum. The cooling lake level during a SPF is estimated to be at an elevation of 1091.7 feet MSL and the area potentially flooded due to SPF would be with-in the property boundaries. The complete description of the development of flood hydrographs (100-year flood, and SPF) with and without the cooling lake is given in Section 2.4 of the FSAR addendum. These flood hydrographs are presented in Figures 2.4-17 and 2.4-19 of the FSAR addendum. Floods in Wolf Creek Below Cooling Lake Dam The peak flood flows in Wolf Creek below the cooling lake will be conside rably smaller, com-pared to the peak flood flows prior to the con-struction of the cooling lake due to the storage capacity of the cooling lake available above the lake normal operating level of 1087.0 feet MSL. The peak flood flows in Wolf Creek below the cool-ing lake for 2-year, 10-year, 100-year and stand-ard project floods were obtained by routing the respective flood hydrographs through the cooling lake and over the service and auxiliary spillways. The description of the spillways and the flood routing proceduro are described in detail in Section 2.4 of the FSAR addendum. The starting elevation in the cooling lake was assumed to be at the service spillway crest level of 1088.0 feet MSL though a part of the flood could be absorbed by the storage capacity available between the nor-mal operating level of 1087.0 feet MSL and spill-way crest level. Table 240.14/240.15-1 presents the peak flood flows in Wolf Creek downstream of the cooling lake dam together with peak flows during preconstruction condition without the cool-ing lake. The table clearly shows that the po6t-construction peak flood flows are much lower than the corresponding preconstruction flood peaks. Ilence, the flooding of the areas below Wolf Creek dam due to Wolf Creek flood flows is much reduced after the construction of the cooling lake. Rev. 2 240-15 6/81
WCGS-ER(OLS) h [~N R240.14/240.15 (continued) L Makeup Screenhouse The makeup screenhouse was built downstream of the stilling basin for John Redmond dam spillway, and on the east bank of the discharge channel. Fig-ures 3.4-4, 3.4-5, and 3.4-6 ER(OLS) show the gen-e ral arrangement and location of the makeup screenhouse. The screenhouse is built on the east bank of the discharge channel and as can be seen from Figure 240.14/240.15-2, its encroachment into the 100-year flood zone is very little. IIe nce , the additional flooding in the Neosho River below the John Redmond dam, due to the makeup screen-house, is negligible. Offsite Roads and Railroad Track The offsite roads and railroad track are shown in Figure 240.14/240.15-2. The offsite railroad track crosses Long Creek, Scott Creek, Crooked Creek and Taucket Creek. Suitable bridge and cul-vert openings are provided wherever the roads and track cross the creeks. l l i Rev. 2 240-16 6/81 ; 1
WCGS-ER(OLS) TALLE 240.14/240.15-1 < , PEAK FLOOD FLOWS IN WOLF CREEK (Below Cooling Lake Dam) Recurrence Peak Flow Peak Flow Maximum Cooling Interval (Natural (With cooling Lake Water
-No. (Yea rs) Condition) lake) Level cfs cfs (feet MSL) 1 2 3,725 290 1088.78 2 10 5,941 497 1069.31 3 100 8,363 928 1089.80 4 SPF 20,000 4,188 1091.70 0
O l l Rev. 2 6/81
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, .g And After Construction Of
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WCGS-ER(OLS) y e'5 290.0 ENVIRONMENTAL ENGINEERING BRANCH
\ ~ (V Q290.1 Describe any changes in the routing of the trans-(ER) mission line corridors since the ER-OL (Sec. 3.9).
(3.9) What is the current. state of completion (ER-OL Sec. 3.9)? R290.1 Wolf Creek-Rose Hill Transmission line (345-kV) -- No changes to route, to be completed in 1983. Wolf Creek'-Craig Transmission line (345 kV) -- The
. Wolf Creek-Craig line has been changed and will terminate at a new substation --
West Gardner. The La Cygne-Craig transmission line will be inter-cepted and brought through the West Gardner sub-station where a ring bus arrangement will be used to connect these lines to the Wolf Creek 345.kV line. The West Gardner Substation will have three e' 345 kV lines (Wolf Creek-West Gardner, West Gardner-Craig, and West Gardner-La Cygne). Term-inating the 345 kV Wolf Creek line at West Gardner will result in saving approximately 14 miles of. 345 kV line. The transmission line corridor from-Wolf Creek to West Gardner has not changed. Wolf Creek-West Gardner is to be completed in 1983.
/ Wolf . Creek-Benton transmission zline -
no change. (/ Completed in 1976. Wolf Creek-La Cygne transmission line - no change. Completed in 1976. Wolf Creek tap of Athens-Burlington transmission line no change. Completed in 1975. Wolf Creek to Coffey County REC transmission line - no change. Completed. Q290.2 Give details on the present status of the railroad (ER) spur routing and have there been any changes since (3.9) the FES-CP Sec. 3.9? R290.2 l
- a. Railroad Spur Route: The route of the completed railroad spur is shown on drawing S-300 (copy provided with formal response).
- b. Changes since FES-CP Section 3.9: The right-of-way ~for the offsite railroad spur varies from a
) width of 60 feet to 180 feet. ,
a I Rev. 2 ( 290-1 6/81 u l
. . ._ . . - - \
I WCGS-ER(OLS) 0290.3 Ilas the water pipeline been completed and have (ER) there been any changes in the proposed route (FES-(3.9) CP Sec. 3.9)? R290.3
- a. The construction of the makeup water pipeline is complete.
- b. The route of the existing pipeline varies from the proposed route shown in FES-CP Section 3.9 at the makeup water screen house (Corps of Engineers property) and at the makeup water discharge struc-ture (KG&E property). The existing route of the pipeline is shown on drawings S-1, M-84, M-85, M-86 and M-87 (copies provided with formal response).
Q290.4 What are the current plans for recreational and (ER) agricultural land use on site when WCGS becomes (3.9) operational? R290.4 No changes will result in recreational land use when WCGS becomes operational because there are no plans to open the lake for public recreational use as described in Section 2.8. Land owned by the Applicants is presently being utilized for agricultural purposes. It is the Applicants' policy to lease such lands when such leasing is consistent with prior commitments and does not interfe re with the future operation of WCGS. No change from this policy is anticipated when WCGS goes into ope ra tion . Section 2.8 also describes this land use policy for land adjacent to the cooling lake and inside the WCGS site boundary. O Rev. 2 290-2 6/81
WCGS-ER(OLS)
.. /'N 0290.5 What mitigative measures will be taken by the ! ) (ER) > applicant (or other agencies) for the protection V of bald and golden eagles that may be attracted to the cooling lake? This is in regards to both pro-tection from plant operation and structures and from recreational use rs of the cooling lake.
R290.5 Because the construction of the WCGS cooling lake will - create habitat f avorable 'for wintering Bald Eagles, mitigative measures have been taken for the protection of 'these endangered raptors. The Golden Eagle, since it occurs only rarely in this part of the state (Schwilling, Pers. Comm) would be of lesser concern. Management considerations and their corresponding mitigative measures for- Bald Eagles include:
- 1. Potential Hazards A. Human disturbance -
The WCGS ' cooling lake is closed to the public and-there-fore human disturbance of Bald Eagles roosting' or feeding _ on the cooling lake will be minimized. [) B. Shooting - Shooting is the most preva-( ) lent single cause of death among Bald Eagles (Coon et al. 1970). Restriction of public access will minimize the inci-dence of _ eagle shootings on the WCGS cooling lake. C. Electrocution - Electrocutions occur when an opgle, or other bird, with a wide wing span makes simultaneous con-tact with any two phase conductors or with a phase conductor and a ground wire. Powerlines with electrical ratings over 69 kv do not present a hazard because of wide line spacing. On powerlines with ratings of 69 kv or less, crossarm type distribution poles are the most likely to be involved with electrocutions (Ansell et al. 1980). The distribution poles used on the 69 kv line near the WCGS cooling lake are not the crossarm type.
- 2. Food Supply Wintering Bald Eagles feed primarily on crip-
)v ) pled or healthy wate rfowl and winter-killed Rev. 2 290-3 6/81
WCGS-ER(OLS) R290.5 (continued) or live fish. They also feed on other water-birds, upland game and small mammals. All of these food sources are available on or near the WCGS cooling lake.
- 3. Vegetative Habitats - Wintering Bald Eagles usually perch in large trees that are adja-cent to foraging areas and provide protection from the wind (Griffin et al. 1980, Steenhoff et al. 1980). Modifications of the initial cooling lake basin clearing plan were made to increase the amount of standing timber left in the upper portions of the lake. Such areas will probably be utilized as perch sites. In addition, small stands of trees left at various locations around the lake will also provide excellent perch sites. It is also quite likely that Baf fle Dikes A and B will be utilized for perching and foraging.
This variety of potential perch sites should reduce usage of power poles for perching.
- 4. Avifauna Surveys - Surveys of the WCGS cool-ing lake have been initiated by the Applicant to determine the amount of Bald Eagle usage and identify any developing problems. Sur-veys are conducted on a semi-monthly basis during the months of January-April and Sep tembe r-Decembe r. Three ground surveys (each at a different time of day) are con-ducted during each half-month period. Aerial surveys of both the WCGS cooling lake and John Redmond Reservoir will be conducted on a monthly basis beginning in September, 1981.
REFERENCES Ansell, A. R., and W. E. Smith, 1980, Raptor Pro-tection Activities of the Idaho Power Company in Workshop on Raptors and Energy Develop-ments, R. H. Howard and J. F. Gore, ed. p. 56-70. Coon, N. C., L. N. Locke, E. Cromartie and W. L. Reichel, 1970, Causes of Bald Eagle Mortality, J. Wildl. Dis. 6(1):70-76. O Rev. 2 290-4 6/81
WCGS-ER(OLS) l 1 I .- R290.5 (continued) . Griffin, C. R., T. S. Baskett.and T. S. Sparrowe, 1980, Bald Eagles and the Management Program at Swan Lake ~ National Wildlife Refuge. in Trans. 45th North Am. Wild, and Nat. Re - p sources Conf. - i Schwilling, M., Non-game, Threatened and Endanger-ed Project Leader, Kansas Fish and' Game, 1981, Personal Communication. Steenhoff, K., S. S. Berlinger and L. H. Fredrick-
- son, . 1980, Habitat Use by - Wintering Bald Eagles in South - Dakota, J. Wildl. Manage.
44(4):798-805, i. j-4 4 4 i. I, i I i h l l
- Rev. 2
[ -290-5 6/81
l WCGS-ER(OLS) J Q290.6 Was the crawfish frog observed in the area to be (ER) inundated by the cooling lake mudflat area? If so, are there other preferred habitat areas within the area that currently maintain a localized popula-tion of this species? R290.6 Records exist which document the occurrence of the northern crayfish frog (Rana areolata) for twelve eastern Kansas counties, including Coffey County. Although there was a single cbserva tion of this species in 1976 on the mudflats of John Redmond Reservoir, there have been no observations made of the crayf;3h frog on the WCGS site. While the lack of observations for this species on site does not entirely rule out the possibility of their occurrence, it does indicate that no large colon-ies, similar to those referenced by Collins (1974), exist on site. REFERENCE Collins, J. T., 1974, Amphibians and Reptiles in Kansas, Univ. of Kans. Museum of Natl. liis t. , Publ. Ed. Se r. No. 1, 283 p. Q290.7 Ilas the baseline terrestrial ecology been done for (ER) the proposed ROWS? Please provide the data. R290.7 No biseline terrestrial ecology data has been col-lected fo r the transmission line right-of-ways. During the ER(CPS) no commitments were made by the Applicant and no recommendations were made by the Commission in the WCGS Final Environmental State-ment to pe rfo rm such monitoring. Consequently, there are no plans to perform ROW monitoring. O Rev. 2 290-6 6/81
WCGS-ER(OLS)' !. A 0290.8 Have there been any changes in the site boundaries? l ( ) (ER) Where are they? QJ . l R290.8 The site boundary was changed in a few minor ways between that described in the Environmental Report Construction Permit Stage (ER[ CPS]) Tnd the Environmental Report-Operating License Stage (ER[OLS)). Figure 2.1-8 of the ER(CPS) and 2.1-6 of the ER(OLS) should be compared to show the changes'. The changes. resulted in less property being purchased for WCGS proper. The nominal acreage within the site boundary in the ER(CPS) was 10,500 acres and the actual amount purchased was 9,818 acres. The specific changes are:
- Sections 13 and 24, T21S-R15E -- Boundary moved cast to section line;
- Section 30, T21S-R16E -- Boundary moved north to half-section line (See revised ER(OLS) Figure 2.1-6);
Section 17, T21S-R16E -- Boundary excludes NW 40 acres (See revised ER(OLS) Figure 2.1-6); Section 9, T21S-R16E -- Boundary moved west to f section line; and b - Section 36, T20S-R15E -- Boundary moved west to follow lake contour. 4 Q290.9 How many hectares on site are grazed prairie and (ER) how many are old farmland? R290.9 In answering this question, grazed prairie was understood to be grasslands in which the sod has never been tilled, and old farmland was interpret-ed asreturned been land that' to was once cultivated and has since grass. There are an estimated 626 hectares of grazed prairie and 72 hectares of old fa rmland that are above elevation 1087 and l within the site boundary. Information concerning ' demography of land below elevation 1087 is given in Section 4.1.1 of the ER (CPS). Ni Rev. 2 , 290-7 6/81
,, - , --- - --,.;- - - - - , - - ,-- -.-na , -. w-,,-,.g
WCGS-E R ( OLS ) 0290.10 Provide a Table similar to Table 3.9-1 indicating (ER) the percentage of prime and unique farmlands onsite. (2.1.3) R290.10 TABLE 290.10-1 PRIFE NO UNIQUE FARMLMIDS ON WCG SITE Prine Unique Total Percent Farmland Farmland Acres Prime & Unique Onsite 7,756 acres 0 acres 9,818 79% The total acreage is based on field inspection sheets and is an estimate. Exact acreage of prime fa rmland can be supplied upon issuance of the US Soil Conservation Service Master Soil Map of Coffey County. O 1 O Rev. 2 290-8 6/81
WCGS-ER(OLS): v g i Q290.11.- Provide an update ' of the listing of Rare and En- ~ (ER), dangered Species. [ -(2.2.1) , R290.11: JOne species, the Bald Eagle, named'on the official
~ list _' of t.hreatened and . endangered species for the-United States (U.S. Dept. Lof Interior,~1979) and
' classified as 'e'ndangered - by the state.of Kansas, was observed on and : near _ the WCGS site. No other.
, ' species:'on. the federal . list : has been observed during monitoring activities._
- One . species listed on the state of Kansas endan-gered species list,- the Neosho madtom (Noturus
, placidus)',L has been collected during monitoring activities at WCGS. It-has been collected consis-tently: at two Neosho River ' locations since 1978. Two bird, ona fish, and one amphibian syecies classified as . threatened by tne state of Kansas have - been ~ collected or observed near WCGS. The prairie falcon was observed in 1979. and again in 1981 as-a winter resident. The least tern was F observed at John Redmond Reservoir (JRR) in 1977.
- The blue sucker has consistently been collected at
!- several Neosho River locations since 1978. This species has been collected at JRR (Location 1)
- most frequently. The. northern crayfish frog has been observed only once on the JRR mudflats in 1976, t
The bobcat, a species previously listed as endan-j gered (federally), has been observed by tracks
- in 'the north floodplain area in 1977 during moni-toring and in 1980 as an incidental siting by site
- j. personnel. <
The following list includes those species classi- { fled as endangered or threatened by the state of Kansas.
- ENDANGERED WILDLIFE IN KANSAS i
l 1. Black-footed Ferret Mustela nigripes
- 2. Gray' Bat Myotis grisescens
- 3. i'eregrine Falcon Falco peregrinus
- 4. Whooping Crane Grus americana L 5. Eskimo Curlew Numenius borealis
- 6. Bald Eagle
- Haliaeetus leucocephalus
- 7. Neosho Madtom
- Noturus placidus
- 8. Pallid Sturgeon Scaphirhynchus albus j
- 9. Sicklefin Chub Hybopsis meeki
- 10. Central Newt Notophtalmus viridescens louisianensis Rev. 2
- 290-9 6/81 i
L _,_ _ _ . - _ . _ _ - . _ _ _ . . - _ . _ . _ . _ - _ - - - -
HCGS-ER(OLS) R290.11 (continued) j
- 11. Grotto Salamander Typhlotriton spelaeus '
- 12. Gray-bellied Salamander Eurycea multiplicatd~
griscogaster
- 13. Cave Salamander Eurycea lucifuga
- 14. Small Amphibious Snail Pomatiopsis lapidaria
- 15. Warty-backed Mussel Quadrula nodulata
- 16. Heel-splitter Mussel Anodonta suborbiculata THREATENED WILDLIFC IN KANSAS
- 1. Prairie Falcon
- Falco mexicanus
- 2. Least Tern
- Sterna albifrons
- 3. Blue Sucker
- Cycleptus elongatus
- 4. Arkansas Darter Estheostoma cragini
- 5. Topeka Shiner Notropis topeka
- 6. Alligator Snapping Macroclemys temmincki Turtle
- 7. Northern Crawfish Frog
- Fana areolata circulosa
- 8. Riffle Beetle Optioservus phaeus
- Found on or near WCGS site O
i l i O Rev. 2 290-10 6/81 l
WCGS-ER(OLS) f]
!, f 0290.12 (ER) ovide a discussion on the potential short-term
.id long-term effects of. electric fields on humans V (5.5) and describe - the grouading procedures to be util-ized to prevent primary and secondary shocks.
R290.12 Electric utilities commonly employ various ground-ing practices and techniques as simple and highly ef fective methods for keeping induced voltages and currents from having harmful effects. All trans-mission lines associated with Wolf Creek are 345 kV or less. Transmission at these voltages is called EHV (extra high voltage) transmission. When electric utilities began building UHV (ultra high voltage) transmission lines (greater than 500 kV) in the 1960's the potential for increased effect on humans was recognized and studied. One study condwted by American Electric Power during 1962-1992 with the assistance of the John Hopkins medical group studied electrostatic field effects on the human body (Scherer, et al. un-dated). One of the objectives of the study was to determine if the electric field could cause either short or long-term effects on human health. Medical examination was made on 11 linemen who performed live line maintenance at 345 kV using V' both barehand and hot-stick methods. The medical study consisted of opthamological, otolarynogo-logical, urological, and neuro-psychiatt _al as well as physical and laboratory examinations. The nine year continuous study revealed no effects in their health resulting from exposure to high volt-age lines. No evidence of any malignancy, or changes in physical, mental, or emotional states were found. Numerous other studies have also been completed or are ongoing. EPRI collected and reviewed this information and published two reports summarizing 4
' the biological effects of high-voltage electric fields (EPRI RP381, 1975; EPRI EA-1123, 1979).
The 1975 report concluded and the 1979 report con-
+
firms the conclusion that it is highly improbable that electric fields from transmission lines have - i any signi ficant biological effects on healthy in-dividuals who encounter such fields in a normal way under normal conditions. However, the reports alao relate that there may be subtle and as yet un-d 0.ected effects of such electric fields. Further studies to determine if other effects exist are presently being conducted. Rev. 2 290-11 6/81
WCGS-ER(OI9) R290.12 (continued) Years of operating experience have indicated that with proper grounding ElIV and UIIV transmission lines pose no hazard to the health and well being of humans. Grounding techniques employed by KG&E and KCPL include for 345 kV lines:
- 1. Static wir s overhead of the lines;
. Ground wires on wooden structures;
- 3. Ground rods on wooden or steel struc-tures, if required, to limit ground resistance to 10 ohms or less;
- 4. Fences grounded at 1/4 mile intervals that run parallel to the line or within 200 feet of the center line;
- 5. Fences that cross the line grounded 50 feet on each side of the center line for KG&E and 80 feet for NCPL; and
- 6. Minimum ground clearance of 30 feet in open country and higher elsewhere.
These features limit the potential shock hazard to secondary or imperceptible shocks well below the painful shock or let-go shock threshold. REFERENCES EPRI RP 381, 1975, Biological Effects of Ifigh-Voltage Electric Fields. EPRI EA-1123, 1979, Biological Effects of fligh Voltage Electric Fields: An Update. l Scherer, Jr., II . N., and B. J. Ware, Undated, Environmental Ef fects of liigh Voltage Trans-mission, American Electric Power Service Corporation. O Rev. 2 2 '> 0-J 2 6/81
WCGS-ER(OLS)
,m - Q290.13 Provide a discussion of the potential problems of
[ ') U'R) seasonal waterfowl impacting the proposed trans-
\ j (5.5) mission lines bordering the Wolf Creek Cooling !
Lake. R290.13 There is no doubt that birds collide with trans-mission lines and that populations utilizing Wolf Creek Cooling Lake (WCCL) will be susceptible to such collisions. However, the potential for such collisions can be greatly reduced through a wide varie ty of mitigative measures (Thompson, 1978). Preventive measures taken by the Applicant to reduce the potential for transmission line colli-sione include siting of lines, tower design and prevention of fright / flight collision pctential.
- 1. Initial siting of lines Only a small percentage of the existing 345 and 69 kV transmission lines pass ove r WCCL.
In the areas where crossings occur standing timber should help to reduce the potential hazard. Standing timber will reduce the clearance between lines and the land config-uration, thereby channeling the birds over the lines. In some cases, existing lines A) (V paralleled each other thereby clustering the corridors to reduce collision potential. Two additional 345 kV lines are to be con-structed to transmit power from WCGS. Both enter the area from the east, with one tra-veling to the West Gardner substation in a NNE direction and the other going down the east side of WCCL then west to the Rose Hill substation. The Wolf Creek-Rose Hill line is positioned close to the existing 69 kV line. Paralleling these lines should reduce colli-sion potential.
- 2. Tower Design By reducing the number of horizontal planes formed by powerlines, the collisions involv-ing flocks flying through the lines will be reduced. The existing 345 kV lines at WCGS l
have both two plane and three plane sections. The new 345 lines will have two horizontal planes. 1 o Rev. 2 290-13 6/81
\
WCGS-ER(OLS) i R290.13 (continued)
- 3. Prevention of Fright / Flight Reactions The WCGS cooling lake is closed to public access. By restricting human disturbance and hunting, mortality due to birds are startled or distracted collisions when will be minimized.
- 4. Surveys Surveys of the WCGS cooling lake have been initiated by the Applicant in order to deter-mine the amount of waterfowl usage and iden-tify any developing trends. Surveys are conducted on a semi-monthly basis during the months of January-April and September-December. Three ground surveys (each at a different time of day) are conducted during each half-month pe riod . Aerial su rveys of both the WCGS cooling lake and John Redmond Reservoir will be conducted on a monthly basis beginning in September, 1981.
O O Rev. 2 290-14 6/81 l
WCGS-ER(OLS) f
,o 291.0 ENVIRONMENTAL ENGINEERING BRANCH I [ ,QJ O291.1 Provide the following information on the lime (ER) sludge pond:
- a. Location on the station site, including the distance from the pond wall to the cooling lake;
- b. Major diversions;
- c. Materials of construction;
- d. Need for and frequency of clearout and ulti-mate disposal of wastcs removed;
- e. Estimated seepage rate from the pond into the groundwater;
- f. Estimated composition and flow rate of efflu-ent from the ' pond into the cooling lake.
R291.1
- a. The lime sludge pond is located north of the switch yard and west of the meteorological tower x' (see Figure ~ 2.4-14 ) . With the cooling lake at normal operating pool level (elevation 1987.0 ft),
the distance from the base of the lime sludge pond to the cooling lake will be approximately 50 feet.
- b. The lime sludge pond has two diversions, a sluice structure and an emergency spillway. The spill height for the sluice structure is at elevation 2003'5" and for the emergency spillway at 2004'.
- c. The lime sludge pond is unlined and has been con-structed by excavating the existing grade of the pond area to a maximum height for the bottom of 1997.5' elevation. The excavated soil (inorganic cohesive soil) was used to build the dikes around the pond. The dike slopes are 3:1, vertical to horizontal. Dike slopes are cove red with either four inches of seeded topsoil or twelve inches of ;
filter type II covered by twelve inches of riprap l class facing. I
- d. The lime sludge pond is sized to contain all the influent from the lime softener blowdown, carbon and sand filter backwash, and regenerative waste O for 2 units in operation and 40 years of plant life. The resulting lime sludge pond size is 180 Rev. 2 291-1 6/81 l l
,- -~ - - - - - - . . - , . . , - . - . -_, , , , _ - - - , , - - -
WCGS-ER(OLS) R291.1 (continued) i 1 acre-ft with an average depth of 7.8 ft and cor- j responding surface area of 1 million square feet.
- e. The seepage rate from the lime sludge pond is ex-pected to be less than 10 gpm assuming upper bound permeability values for underlying soil and rock formations and will probably be less than 1 gpm.
The runoff into the lime sludge pond will be neg-ligibly small due to dikes on three sides and a intercepting drainage ditch on the fourth ride,
- f. At the end of 40 yea rs of plant operation, the sludge accumulated in the lime sludge pond for 2 units ir. operation is estimated to be 19 acro-ft and approximately 1 ft deep (for the influent val-ues listed in Figure 3.3-1 of the ER(OLS); values are doubled for 2 units in operation). The re-mainder of the lime sludge pond (161 acre-ft and 6.8 ft depth) at the end of 40 years will still have sufficient capacity to accommodate the worst rainfall. The 100 year-24 hour rainfall in the vicinity of the Wolf Creek Station is only 8 r inches (U.S. Commerce Weather Bureau, Technical Paper No. 40). Also, the lime sludge pond volume will have sufficient capacity to accommodate the worst recorded wet years (from the Chanute, Kansas weather data used in the LAKET analysis) from 1949 to 1951 (typically, on an annual average basis, the precipitation rate in the Wolf Creek Station area is lower than the natural evaporation rate).
These three consecutive wet years would increase the sludge pond water level by only 2.5 ft, leaving 4.3 ft margin in the lime sludge pond (the 1 ft sludge accumulation included). The spillway in the lime sludge pond was origin-ally designed for use during heavy rainfalls. How-ever, with reduced demineralized makeup water design demand and thus, the corresponding reduc-tion in pretreatment and demineralizer wastes (reduced lime sof teners blowdown, carbon and sand filter backwash, and regenerative waste), the spillway is no longer required even during the heaviest of rainfalls as discussed previously. O l Rev. 2 291-2 6/81
WCGS-ER(OLS) A Q291.2 Please provide more details on the calculations ( t (ER) of the blowdown discharge limits calculated in k )- (3.6) Section 3.6.2.2 of the OLER. In particular:
- a. Provide a complete- -description of the model used to calculate the allowable blowdown limits;
- b. Indicate the values used for the diffusion parameters and flow velocities in these cal-cula tions . Describe the model assumptions made in these calculations;
- c. The data given in the OLER _ imply t_ hat the
! concentrations of the TDS, SO} and C1 in the blowdown are the same as in tMe cooling lake. However, such factors as incomplete diffusion or mixing of solutes or concentration strati-fication in the cooling lake might make the blowdown solute concentration different from that of the lake as a whole. Indicate wheth-er such factors have been considered and, if so, what analysis has been made;
- d. Provide the. bases of gr the so_urce(s) for the criteria for TDS, S0 and C1 cited for the
,O > 1 Neosho River.
R291.2 a., b. The following is a brief description of the anal-ysis and results for the dispersion of blowdown discharge from Wolf Creek Lake in the Neosho River. The TDS concentration distribution in the Neosho River is analyzed with a steady state dispersion model assuming the effluent discharge as a point continuous source on one of the banks of the river. The dispersion in the vertical and trantverse di-rections of the river is conside red . The longi-tudinal dispersion is neglected as it will be lower in comparison with the convection due to the ambient velocity of the river. The velocity in the river cross-section is assumed constant and an equivalent rectangular cross-section of the river is assumed for computation. The following equation is used to find the concen-tration under steady state conditions: CQ
~
2( As C = 4, g g x- exp yz -h[2 + Equation 1 Rev. 2 291-3 6/81
WCGS-ER(OLS) R291.2 (continued) in which: C = Concentration at any point in the river Cg = Effluent concentration Qg = Rate of flow of offluent U = Average velocity of flow in the cross-section D y,D = Dispersion coefficients in the y and z z directions X = Longitudinal distance Y = Lateral distance Z = Vertical distance As the model is for unbounded channel, the effect of boundaries of the channel are taken care of by using method of images. The dispersion coefficients were calculated from the following empirical equations developed for natural streams (Ref. 1). log = -3.547 + 1.378 log Equation 2 log = -8.1 + 1.558 log Equation 3 in which: B = Top width of flow in river j II = Ilydraulic depth of flow l 9 = Kinematic viscosity of water l Different combinations of Neosho River discharge, l blowdown discharge and initial effluent TDS con-l centration are used in the computations. Figure 291.2-1 is a summary of the results. The maximum flow area in the cross-section along the Icngth of the river which is having a concentration 2 500 mg/l (includes 400 mg/l Neosho River ambient TDS concentration) is computed and plotted against the blowdown discharge with C as a variable. From these curves the blowdown 81scharges and C g values Rev. 2 291-4 6/81
[ WCGS-ER(OLS) [j / R291.2 (continued) N' corresponding to 'the maximum flow area equal to 25 percent of the . total flow cross-section are picked and plotted on Figure 291.2-1 with the Neosho River discharge as a variable. The 25 per-cent flow area is designated as a mixing zone according to Kansas Water Quality Criteria f for interstate and intrastate waters of Kansas. The following is used as input for the dispersion calculations:
- 1. An average section of the two surveyed cross-sections, one at the confluence with Wolf Creek and the other 600 feet downstream, is assumed downstream of the confluence of Wolf Creek with Neosho River. The rectangularized
-cross section adopted for computation has a width of 92 feet and depth of 9.0 feet for a discharge of 1335 cfs.
- 2. The average velocity through the river for a discharge of 1335 cfs is computed as 1.6 ft/
sec. The bottom slope of the river is obtained from the USGS (Burlington and Le Roy
) Quadrangle Sheets, 7.5 minute se ries) topo-V graphic maps. A Manning's 'n' of 0.05 is-assumed in the velocity computations.
- 3. The concentrations are computed at intervals of distances both laterally and ve rtically.
- 4. The point of injection for this computation is assumed to be at 5 feet from the bottom.
- 5. The values of dispersion coefficients used for a river discharge of 1335 cfs are cal-culated from equations (2) and (3) and they are:
D = 0.101 f+2/sec I 2 0 = 0.00031 ft /sec 7
- c. The cooling lake water quality calculations were based on complete mixing in the cooling lake.
This issue of using complete mixing in the cooling lake water quality calculations has been discussed previously during the Atomic Safety and Licensing Board hearings (Construction Permit Stage). In this testimony, the NRC staff agreed that the use of complete mixing in the water quality calcula-tions was valid. Rev. 2 291-5 6/81
WCGS-ER(OLS) f R291.2 (continued)
- d. The Kansas Water Quality Criteria for interstate and intrastate waters of Kansas, approved by Envi-ronmental Protection Agency August,,1978, is used to establish criteria for TDS, SO and C1 (see i 4
ER(OLS) Section 3.6.2.2). l l REFERENCE
- 1. Bansel, M. K., " Dispersion in Natural Streams,"
Journal of the Ilydraulics Division, ASCE, Vol. 97, No. Hyll, Proc. Paper 8540, November 1971, pp. 1867-1886. O O Rev. 2 291-6 6/81
WCGS-ER(OLS)
' (p)
Q291.3 . Outline the derivat. ton of the concentrations given (ER) in Tabic 3.6-1. Are the values for the cooling y/ (2.4) lake averages over the whole lake - are they steady state ' values? Discuss why the normal val-ucs for the Redmond Reservoir are so much higher than those riven in Tabic 2.4-11. R291.3 Table 3.6-1 lists the chemical constituents of the water in the John Redmond Reservoir and the Wolf Creek cooling lake (for one and two' units in oper-ation) covering a period of 1949 through 1964 which includes a 2 percent chance drought. Since the regulated storage of the John Redmond Reser-voir did not begin until September 1, 1964, the John.Redmond Reservoir water quality data in Table 3.6-1 were developed on the basis of published + Neosho River water quality data (obtained from
" Water Resources Data for Kansas," U.S. Geological Survey and Kansas State Board of Health, Division of Sanitation). With these Neosho River data as input,- the LAKET program was used to predict the total dissolved solids (TDS) levels in the John 4
Redmond Reservoir. The predicted TDS levels in the reservoir provided data for the calculation of the cycles of concentration (the cycles of concentration is defined as the ratio of the con-(])
/ centration of TDS in the circulating water to that in the makeup water and represents the ef fect of evaporation on the concentration of dissolved minerals). The concentrations of the other con- ,- stituents in the water, listed in Table 3.6-1, were then determined by simply increasing these constituents concentrations for the Neosho River by the cycles of concentration, i.e., cycles of concentration times the concentration of the constituents.
The cooling lake water quality data listed in Tabic 3.6-1 were developed in a similar fashion. The John Redmond Reservoir water quality data were used as input into LAKET to predict the TDS IcVels in the cooling lake. The cycles of concentration were then determined which was used to cycle up the other water quality constituents. However, the cooling lake data includes sulfuric acid addi-tion (for scale control in the condenser). This means that, with the added acid, the TDS and sul-fate levels are increased by more than the cycles of concentration value, while the alkalinity is reduced due to a lower pH. The effects of acid addition are described in ER(OLS) Section 3.6.2. The Wolf Creek cooling lake water quality data V tabulated in Tabic 3.6-1 were predicted by the I Rev. 2 291-7 6/81
N M T O S I E T S A N T E C S IL G G 1 N N I I T - d w t g Y TIM A 2 l o M T RO E P . B 0 0 I LA AA ENO N 1 9 d 5 L
/
Oft GE ET I T R 2 t e
> 3 T GNOP e i H RM I
o EC K U ER r u i m o T 1 E g 5 A 8 E L L
< W / R A i T F S 6 C N D F E T I
2 L N O O ov W R Ge W R D o S 4 -
'4 0
4) 9, e S F g:' N (C w l o 0F 5 g N W N
\ q. D O
N W T h 4 M
\ \ 0I 4
; 2 i
o t _ o. 0 0 0 o o o 0 0 8 0 4 o o t 2 ( I t o G m(gv 1 52 ll{lll
- . . .. _ _.- . . _ - . . . - - . - . . ~ . . . - . .-. ._
WCGS-ER(OLS) R291.3 (continued)
}'
LAKET ' progtam based on the conservation of total dissolved solids and water .as a function of time. For a given time interval, the' cooling lake water quality is assumed constant over the entire lake
- (i.e., complete mixing).
The John Redmond Reservoir water quality data given in Tabic 3.6-1 are different than those
- given in Tabic 2.4-11 because the water quality data in Table 3.6-1 are based on a longer time
- intertal' (the TDS data are for a period of 1949 to l 1964) th.nn just the three years tabulated in '
. Table 2,4-11.- This difference in data base results in higher water quality data values for. the John Redmond' Reservoir and represents - the ! record period of water quality data. For the , cooling lake design, a record period of water quality data is essential and the use of these
- higher values are conservative.
l i l 4 ? \1 i ! a i t f 5 Rev. 2 291-8 6/81 [ t
+m -a -- e,-- P-
WCGS-ER(OLS) l Q291.4 Indicate whether essential service water is with-(ER) drawn continuously or only during an accident or shutdown? R291.4 Essential service water (ESW) is not withdrawn continuously or used during shutdown. ESW is used during accident conditions and for testing. Q291.5 Provide estimates of the maximum total residual (ER) chlorine concentration (including that combined as chloramines and chloroorganics) to be expected at the circulating water discharge outlet to the cooling lake. R291.5 Chlorination of the condenser cooling water is designed for three 30-minute applications per day. The chlorine dosage will be varied to maintain a free residual chlorine between 0.1 and 0.5 mg/l at the condenser outlet during each chlorination period. The total chlorine residual (including chlorine combined as chloramines and chloro-organics) will depend on the chlorine demand of water.- However, during Atomic Safety Licensing Board hearings (Construction Permit Stage) in 1976, it was reported that the total chlorline residual would range between 0.68 mg/l and 1.08 mg/l et the circulating water discharge outlet to the cooling lake. O Rev. 2 291-9 6/81
WCGS-ER(OLS) qO -Q291.6 Where is the service water discharged? Is sulfur-ic acid added to the service water? If so, how (\ (ER) much is added?
- R2 91. 6 The service water is discharged into the circulat-ing water (CW) system downstream of the condensors prior to CW system leaving the power block. Sul-furic acid is not added to the service water system. <
The principle expected corrosion products from
, water passage through the .irculating and service water systems will be from..the piping and heat exchange rs . . The concentrations of these corrosion products will be low, on the order of ppb or less.
The potential chemical species are summarized below: Carbon Steel - Fe 23, 0 Fe34 0 , Fe(OH)3' F 2 03.31120 90-10 Cupronickel - Cu2 0, Cu0, Nicu0 2' Ni 34 0 Stainless Steel - Fe 0 , Fe U 23 3 4' Fe(OH)3' Fe 02 3 3H2, e 0 , Cr Fe0 4, 24 2 NiCr 24, 0 Ni 0 , Cr 0 34 34 The concentration of the species will depend upon the ratios of metals present in the system, temp-crature and chemical composition of the water. The underground service water piping will have cathodic protection which will reduce corrosion in this pipe. Rev. 2 291-10 6/81
WCGS-ER(OLS) f Q291.7 According to the OLER, Ammonia, Hydrazine, Potas-(ER) sium Chromate, and Turco Decon 4521 and 4520 are used in the power block system. Provide estimates of the usage of these chemicals. Also discuss the ultimate fate of these chemicals. Identify the pathways to the environment from the plant and indicate the amount and concentrations of these chemicals in the pathways. R291.7 Ammonia Expected blowdown from normal operations should not exceed .25 ppm Nil FSAR Table 10.3-4). The blowdown from Hot Skan(See dby is less than 10 ppm. All other conditions should have Nii 3 n entration of less-than-or-equal-to .5 ppm. Hydrazine FSAR Table 10.3-4 shows hydrazine concentration as 75-100 ppm during cold hydro and cold wet lay-up. Otherwise the hydrazine content should not exceed the 0, by 5 ppb. The maximum 0 3 concentra-tion in blowdown and feedwater is lets than 100 ppm. The path / to the environment for NH, and hydra-zine would be from condenser tube ledkage to the circulating water. Potassium Chromate Potassium Dichromate is used in the component cooling water system. Pathways to the environment would be from heat exchanger leakage to the ser-vice water system. Normal operational levels of K 2 Cr0 4 in the CCW are . 175-225 ppm (Cr03). Initial system conditioning will require 1000 ppm (Cr04) for the first week after filling the system The initial filling residue and any subsequent system drain down would be collected, tested and disposed of in an approved manner, e.g. wastes treated to bring the chromium concentrations to less than 5 ppm, or the waste would be removed to a disposal facility. Turco Decon 4521 and 4502 (not 4520) Turco Decon is used to decontaminate parts / equipment and its usage is dependent on the work being done. When used, Turco Decon 4521 is mixed with water, 8 oz to the gallon; and 2 lbs of Turco Decon 4502 is mixed with a gallon of water. Turco Decon is disposed as drummed solid waste via the chemical waste tank. Rev. 2 291-11 6/81
WCGS-ER(OLS) b Q291.8 Indicate the coracontration and types of chemicals
\ (ER) discharged in the rad-waste system ef fluent into the cooling lake.
R291.8 The reactor coolant system is the normal source of chemicals which may be discharged, after treatment by the liquid radwaste processing system, via the radwaste effluent to the lake. Maximum releases are provided in Table 291.8-1. Each concentration is based on an average expected flow rate of 1,394 gals / day. t 4 i i 4 i i I i l Rev. 2 291-12 6/81
4 WCGS-ER(OLS) f iABLE 291.8-1 TYPE AND CONCENTRATION OF CilEMICALS IN RADWASTE EFFLUENT TO COOLING WATER LAKE ITEM OUTPUT CONCENTRATION Boric Acid 4 opm Chlorides 0.15 ppm Fluorides 0.15 ppm Suspended Solids 1.0 ppm pli Control Agent (Li 011) 2.2 ppm (as Li) Silica 0.2 ppm Aluminum 0.05 ppm Calcium 0.05 ppm Mag'icaium 0.05 ppm O i Rev. 2 l 6/81 l
WCGS-ER(OLS) k Q291.9 According to the OLER Section 3.6.3.2 cach domin-
/^^I (ER) eralizer train will be regenerated once every 26 (d (3.6) days, and only one will be used at any given time with the other train kept as a spare. Explain why the relevant entries of Table 3.6-2 are calculated for twice the above regeneration rate.
R291.9 Soo revised Section 3.6.3.2. Each domineralizer train will be regenerated once overy 13 days. Q291.10 According to Table 3 of the OLER about two (ER) mole equivalents of II 6-2 are used in regeneration of (3.6) the domineralizers for each mole equivalent of 011. As a result, during each regeneration, one-half the acid is discharged unused into the alkaline lime sludge pond. Please verify or correct the above entries in the Table.
~
I R291.10 See Tablc 3.6-2 corrections to sodium hydroxide entries. This table provides the quantity of chemicals going into the primary and mixed bed demineralizers, but the effluent from the domin-cyalizers, may contain different proportions of s II and Oli . 0291.11 Provido details on the derivation of the numbers (ER) given in Tabic 3.6-6 of the OLER. (3.6) R291.11 . Table 3.6-6 of the OLS-ER lists the impurities removed by one domineralizer train in the treat-ment of 216,000 gallons of makeup condensate. Based on the specified influent water quality and the design of fluent water quality, the domineral-iter manufacturer's guaranteed this removal of impurities. 10 Rev. 2 291-13 6/81
WCGS-ER(OLS) 0291.12 Describe the program for monitoring TDS, So", and (ER) C1 concentrations in the Neosho River or in the blowdown to ensure that discharge criteria are met. H291.12 Blowdown discharges from Wolf Creek Cooling Lake (WCCL) will comply with Kansas water quality cri-teria. The monitoring program which will document compliance with the criteria will be delineated by the requirements of the operating NPDES permit issued by the State of ransas. At this time the NPDES permit has not been modified to cover WCCL discharges, See the response to Question 291.15 for additional discussion concerning the Wolf Creek NPDES permit. 0291.13 Indicate whether discharged fluids, including oil (ER) spills in the transformer vault discharged through the oily waste separator system. If not, describe the discharge system where the effluents go and the amount of oily discharge to be expected. De-scribe the oily waste separator system and the fate of the separated oil and aqueous wastes af ter 1 caving the system. R291.13 Any potentially oily waste, including oil spi:Is in the transformer vaults, can be dircated to the oily waste separator where oils and liquids are separated by their density differences. Should an oil spill be well contained, the oil could instead be cleaned up and drummed for reclaiming. Table 3.6-7 gives a summary of oily waste dis-cha rge rates. Separated oil is reclaimed from the sepa rator and aqueous wastes are routed to the cooling lake. A drawing showing the site drainage plan and routing of piping to the oil separator was in-cluded with formal response. O Rev. 2 291-14 6/81
WCGS-ER(OLS) D 0291.14 Verify or correct the following changes in the . ( (ER) OLER supplied during the sito visit. Annual use (3.4) of NaOCL for potable water disinfection 315 lbs/yr instead of 1315 lbs/yr (Tabic 3.6-2). Limo soft-ener blowdown contains ferric hydroxide instead of forrents hydroxide (page 3.6-5). R291.14 Annual use of Na0C1 for potable water disinfection
, should be -315 lbs/yr instead of 1,315 lbs/yr.
1 The lime sof tner blowdown contains forric hydrox- , ido instead of ferrous hydroxide. i 1 4 i l-i h I i i j I I I i i 1 1 I i . I
?
Rev. 2 . 291-15 6/81 i
- i
l WCGS-ER(OLS) 0291.15 Please supply a list, and copies if available, of (ER) all permits needed to discharge effluents during station operation. The OL-ER, Section 12, states that the discharge permit No. 1-NE07-R002 will be modified as WCGS becomes operational. Describe the expected modifications. If availabic give pollutant limits for the modifications. Identify and describe effluent discharges into the cooling lake or the lime sludge pond that will not be covered by a permit. R291.15 A copy of the present NPDES pe rmit (No. I-NE07-P001) issued by the Kansas Department of Health and Environment (KDHE) is attached. This pe rmit controls effluents at three onsite locations: 001 Domestic warte treatment plant discharge 002 Stormwater runoff from the construction site 003 Concrete batch plant holding pond discharge S ince closure of the Wolf Creek Cooling Lake (WCCL) dam in November 1980, all plant effluents are being contained in the WCCL impoundment of water and there have been no discharges from Wo1f Creek. Consequently, monitoring of the NPDES pa rame te rs is presently not required. The re-sponse to Question 291.17 discusses the range of time intervals which are projected to be required to fil1 the WCCL. Prior to discharging from the lake the present NPDSS permit will be modified to reflect the dis-charge point being the WCCL outlet. DiscusElons with KDilE personnel indicate that pollutant limits required in the present pe rmit would be typical of those required to be in compliance with Kansas Water Quality Criteria if the operating NPDES per-mit were issued today. All ef fluent discharges from Wolf Creek are either into the cooling lake or the lime sludge pond. (See Question 291.I concerning discharges from the lime sludge pond.) All drainage in the vicinity of the plant is into the cooling lake so monitor-ing at the outlet of the cooling lake means that all effluent discharges will be cove red by a pe rm '. t . l O Rev. 2 ' 291-16 6/81
.- . . . - . . . -.m.- -
m .. - -- - . . _
^
W Sittl<r <>f Kesus<rs . . . nn e..un. co...no,
\
r' '" ' . D j' I-i, , 10Ril81311'liTil'(16 lll R8 l,'il'!! 8110 lIW Joseph E Haskin5. SfCitfJfr Fortes Tw*f , forchJ Mawas 66ti20 "" '/ 913 662 9360 ? is March 21,1980 o i j Kansas NorthGas & Electric Co. - Wolf Creek Station 4 0<tG7 WQ-201 Market Q P.O.' Isox 208 /,7W @.94c.C s wichita, Kansas 67201 fRt ', !. Cg8 ll Re: Kansas Water Pollution Control 5y, .[y.vy <. c$ ff, ! e b' T 9 ,p i Permit No.1-NE07-P001 f,9 /ggs# -
- Gentlemen
1-This is to inform you that you have fulfilled all filing requirements for a i s the National: Pollutant Discharge 1:limination to forward your new permit. We are pleased System (NP j as needed original permitfor for monitoring your files. and reporting purposes, you need to retain t We suggest you carefully read the terms and conditions of your permit and 4 that you understand that these terms and conditions are enforceable under : both State and l'cderal law. i { j; We look forward to working with you in the achievement and maintenanc of hi0h quality water .for the State of Kansas, f 4 Sincerely yours, t \ f! jlc fdd., p 16h=~ ('^!
, ?
Gerald Stoltenberg, P.E. '# Director - ! Division of Environment GS:am1Q1 < Enclosure cc: Southeast District e f I
Kansas Permit Number: 1-N!;07-PD01 l federal Pcimit Number: KS-0079057 K ANSAS WATI:lt Pol.l.UTION CONTROL. PF.llMIT AND At)TilOltl%ATION TO 1)lSCIIAltGl: IINDl;lt Till; NATIONAL. POI.LUTANT DISCilAl(Gl: 1:LIMINATION SYSTl;M Pursuant to the provisions of Kansas Statutes Annotated 65-16<l and GS-165, the federal Water Pollution Control Act as amended, (33 U.S.C.1251 et seq: the "Act"). Owner: The Kansas Gas and I:lectric Company Owner's Address: 201 North Market, P.O. Box 208 Wichita, Kansas G7201 facility Name: Wolf Creek Station facility 1.ocation: llurlington, Kansas 66839 Coffey County iterciving Stream & liasin: Neosho River via Wolf Creek Impoundrient Neosho ltiver Basin is authorized to discharge from the waste treatment facility described herein, in accordance herein. with effluent limitations and monitoring req iirements as set forth O This permit shall hecome effective tiarch 21, 1980
, will supersede all previous permits and/or agreements iii~cfEcDetween tIiH5nsas Department of Ilealth and I:nvironment and the permittee, and will expire April 30, 1983 .
FACILITY Dl:SCRIPTION: Discharge consists of package plant effluent from domestic wastes, stormwater runoff from the water plant f rom site, andhatch a concrete overflow piant.from sediment control holding ponds treating process N g\
\
\ hA ne
' eckelhrphiCiiis55~ Department of lle51tli~aiidTnvironment S
X) ate _Aarck i LG6 O
g Page 2 9 Kansas Permit No.1-N!:07-P0( A. I'.lTI.UI'.NT 1.lMITATIONS f)ND MON _l'lyRING f(LWilliMI; HTS
'I he pernuttee is authorized to discharge from outf all(s) with serial number (s) as speci-lied in the applic.ilion f or this permit. The effluent limitations shall become effective on the dates specified herein. Such discharges shall be controlled, lim, led, and moni-tored by the per mittee as spet:ilied. The initial icporting lieriod shall begin in April 1980 and end in June 1980 .
1:ach consecutive three month per-i0:1 ther ealler shall constitute a reporting period. There shall be no discharge of float-ing solids or visible loam in other than trace amounts. l.:ITI.U,Ei3 i' I IMI"'ATIONS MONITORING REQUIREMENTS I inal I. imitations tipon Effective Date issuance dutlall~Ninnber antf ~ ~ ~ ~ ~ Measuremen t Sample 1:ffluent i arameter (s) l'requency_ Type, 001 - 1)omestic Waste Treatment Plant into Wolf Creek I' low - MCD (llase i low = 0.03 MCD) ---- Weekly Hiochemical Oxygen I)emand (5-1)ay) Weekly grab Daily Aver age-my/l(Ibs/ day) 30( 7.5) Daily Maximum-mg/l(lhs/ day) <l5(11.3) 1 Total Suspended Solids Daily Aver age-mg/l Weekly grab 1)aily Maximum-mq/l 30( 7.5)
%(l1.3)
I'ree Available (:blorine Weekly Daily Maximum-mg/l grab 1.0 pil - Standard linib. G.0-9.0 Weekly grab 002 - Ston.nwater r_unoff,f rom construction _ site, During the period beginning on the eflective date and lastir.g through the date of expir-ation the primittee is authorized to discharge trum outfall(s) serial number (s) 002 Such discharges shall be limited and monitored by the permittee as specified below: Monitoring of the elltuent will not he required unless there is a significant change in the quality or quantity of the subject discharge. The Water Quality Criteria for inler-state and intrastate Waters of Kansas as f ormulated by the Kansas Department of Ilealth and l'.nvironment , Regulation 28-16-28, will be applicable. 1. The pit shall not be less than 6.0 standard units nor greater than 9.0 standard umis.
- 2. The discharge shall be essentially f ree of visible oil or grease and in no circum-3.
stances iesult in deler ioralion of the receiving water 5; quality.
^ Contr ol of excessive suspended solids shall be undertaken as necessary to prevent receiving water delciioration.
U
l' age 3 gi Kansas Permit No. I-NE07-P00
- 4. There shall be no sludge banks or deposition of solids downstream from the outfall.
0
- 5. There shall be no discharge of floating solids or visible foam in other than trace amounts.
Any violation of the above referenced Water Quality Criteria shall be reported immediately to the Kansas 1)cpartment of llcalth and Environment, llureau of Water- pollution Control, in Topeka, Kansas. 003 - IHscharge_lantfrom concrete batch p sediment control holdingyond receiving process water from the Total Suspended Solids Monthly grab Daily Maximum-mg/l 50 pil-Standard tJnits 6.0-9.0 Monthly grab it . STANDAlti) CONDITIONS in athlition to the specified conditions stated herein, the permittee shall comply with the attached Part i Standard Conditiens dated May 1,1979. C. SCllEDtH.C Ol' COMPI.l ANCI'. None D, suppl.EMl:NTAl. CONI)lTIONS
- 1. This per mit shall he modified, or alternatively, revoked and reissued, to com-ply with any applicable effluent standard or limitation issue <l or approved under Sections 301 (b)(2), (C), anti (D), 304 (b)(2), and 307 (a)(2) of the Clean Water Act, if the effluent standard or limitation so issued or approved:
- a. Contains different conditions or is otherwise more stringent than any elfluent limitation in the permit, or
- b. Controls any pollutant not limited in the permit.
The permit as modified or reissued under this paragraph shall also contain any other requirements of the Act then applicable. O
fflective Mas- 1 L ') ? 0
'J/.. WARD CONUlll0Ti l'O R E ANSA $ W 4TLR tVLLUTION CW. TROL 4WD NATIDNAL p0LLUTANT DistilARGE ILlHINAfloh SYSTEM PE9 HITS PART I CLNLR AL CONUl fl0NS 1, pepresentative Samplent A.
Samples anJ measurements taken as required herein shall be representative ot' the nature ana volume of the sonatored discharga. All samples shall be taken at the locations designate 1 in this permat, and unless specified, at the outfall(s) before the effluent joins or is Jiluted by Jnv other toly of water or substance. B.
$tonitoring results shJil be recorded and reported on forms ac:cptable to the Dis ts aan anJ post-mantel 's later than the 28th JJy of the month fo!!owing the ccepleted reporting pernoJ. Signed copies of these, and all other reports requarcJ herein, shall be subestted to:
Fansas Depsttment of Health $ Environment Division of Environment wates pollution Control Section Topeka. Kansas 66o20 1913) 8t2 9160
- 2. Schedule of Compliance: No later than il calendar Jays following each Jate sJentified ir the "5EEil3l gress or,ean o f C5mpilinie", the permittee shall submit to the above aJJtess, either 1 report of pro-the CJse of speCillc actions being required by adenttitcJ dstes, a written notLCe of
~
compitance ur noncompliance. in the IJtter Case, the notice shall incluJe the cause of non:ompliance, any remedial actions taken, and the probability of meeting the next schedule requirements. or, if there are no more schedule requirements, when such noncompliance will be corrected.
- 3. Definitions A.
The "Jaily average" Jischarge means either the total discharge by wesght during a calenJar month JtvtJe1 by the number of Jays in the month that the facility was operating, or the average cancen-tration for the month. The daily average discharge shall be determane1 by the vnna t ion ot all metsured JJaly discharges by weight disaded Iy the number of day 5 during the calenJar month when the measurenents were maje, or by the summatton of all concentrstaans determineJ Juring the B. c ilend ar menth J ty tJed by the number of samples collected and analy:cJ. T he a !I "J hJur a ilperind. y ma i smum" Jischarge means the total discharge by weight or aserage concentration during C.
/ 1he " monthly aserage", other than for fccal coliform bJcterta, ts the arithmette mean ot the ~~- selues nor sieluent samples collected in a perioJ of 30 consecutive Jays. The monthly sverige tar tecal cultforn bacteria is the geometric mean of the value of the effluent sanples collected in a period of 10 tonsecutive days.
D. The "=eektv aversge", other than for fecal colitarm batteria, is the arithmetae mean of the values inr effluent sa*pnes collectcJ nn a period of seven consecut tie Jays. The weekly aserage for fesal coliform bacteria is the geometric mean of the values for efttuent samples co!!e:ted in a pe riod of seven consecutive d ays. E. The " grab saiple" is an individual sample collected in less than 15 minutes, f. A " composite simple" is a combination of inJividual samples in which the vol ume a t each inds-vtJual the flaw sample rate overLs proportional to the discharge flow, o r the sample f requency is proportioncJ to the sample pertoJ. G, 11 The "Ast" means the Lican Water Act, Public law 95*217. 1.
"DLvision" means Divtsiun of Environment, Kansas Department of Ilealth and Environnent.
" Department" means the kansas Department of Health and Fneironment.
- 4. fest priceJures*
All analyses requtred by this permit shall conform to the requa tements of Scriton Illih) oI~the~Act, Jnd shall be conducted in a laboratory certitied by the Department. For each eessurement or simpic the permittee shall record the esact place, date, .inJ ttme of sa,pling; the Jate et the analsse.; t he an alyt ic al techenques or methods used; and, the results. li the permittee mont-tars iny pollutint at the location (si JesignateJ herein more frequent!y than reqetrcJ by this permit, using requarcJ approved in L.B. proseJures, the results shall be included in the Discharge ?lanitoring Report form sbove. Such increased frequency shall also be inJicateJ.
- 5. ResorJs ketention- All recorJs anJ information resulting from the monitoring activtraes requirej hy IIsi W Uit' IE luting all records of analyses anj calibration and anantenance of ?nstru,entatt u and
~
trsnritags trum continuous langer al requested monitoring by t he Uit t sion. instrumentation, shall be rctainel for J mininum at 1 years, or 6. i?h a n ge in Discharge: All lascharges tuthort:ej herein shJ t t be consistent with the terms and con-dit'ioni~3f~t Ki s Ecimit . The Jascharge of any rollutant not authort:eJ by this per9st or of any pollutant IJentified in this permnt more frequently than or at a level in etcess ct that authort:cJ shall constitute a violation of the perant. tny ticality espansions, production or tio= increases, or pr? cess msJtfscattons whnh =til result in new, Jillerent, or increascJ Jistharges of pollutants . hall he reported to the Disaston at least one hundreJ eighty (1801 Jays beture such c hange s. 7, 9antemplian(v Natifications: io7epF.IiVWr liIIDis teum If. orfor ant reason, the perenttee Jees nor eneply with or =ttl be unable i
',~ weekly sverage effluent Itmitation specificJ in this permit, the j
l f permittee shall gravtJe the Depirrment with the t allowing informatann in writing ditnin 3 Jaya of bec aming aware of such canJ a t ion- ) l
\
1 1
a r. . a r t son' oMCls is h st ac_ _ - -ana s tuu .i ,n. 2mp i a ou e n.4 R. t he p;r iaJ Je con 6 o:pl a inc e. , encluting cra't .lates a:J t ace s ar . af rut sorresttJ. the antact- , patoJ ttc1 the nicenzpliansd is CapcGled tis sunt inue, anJ steps being taken to r:Juee. stacanato
.ind prsvent vreur tsn< e of th ? rnicc; ply ing J a scha rgo.
the aaove anfoamJeson shall he providcJ with the nuoma t t al of the regula r Ot scharge 'lonitortng Repor t form for violations Jf monthly average of Jaily Jverage effluent limitattons. 4. I winittes ggvration: The permittee sh. ell at all times maintain en goo 1 woiking or.ler anJ efficient InJ'ei rec t i s c17 5FFia t e all t re e teen t. 6alleetion, and control systems or (seiletles used to achieve (omplaense wsth the terms anJ conJitions of this permit. Maintenince of treatment tactLsteem whtth tesults en 'est Jatton nf effluent quality shall b. scheJule.1 and sh all be e arrieJ coat in a manner approveJ in advance by theJuring non critical water quality periods Division. the petaattee shall take all necessary steps to minimate any JJrerse imp.it t to waters of the State resulting tron noncompliange witti any cifluent limatJttons specifted in this permit, including such accelersted or aJJitional monttoring as necessary to determine the nature and impact of the noncomplying Jischarge.
- 9. B vpj s sjn p Any divarsion from or hyp.ess of facilities necessary to maintaan comolaance with that per-mit is prohibited, encept where necessary to prevent loss of human 16se or severe propertv Jamage; or there escesssie storm JrainJge or runoff would Jamage any f acalat tes necessas y to c annl y wi th this per-mit.
The permittee shall ~immediatelv notify the Division by telephone of each 5tpass and shall conttre the t elephone hue been 12 ken not to iprevent fica t sun UitliTINter espla ining wha t caused the spill on bypass and what actiens recurrence.
- 10. RemarcJ Substances: SoltJs, sludges, filter hachwash, or -ther pollutants removeJ in the course of treatment or control of wastewaters shall be Jisposed of in a manner acceptable to the Otv t sion.
- 11. Pawer railures: The permittee shall prov6Je an alternate pvwer source suf ficient to operata anJ waste-water suntrol~ facilities or halt or otherwise control production anJ all discharges upon the loss of the primary source of power to the wastewater control tacilities.
12. At3h t of fntry? The permittee shall allow authorited representatives of the Division or the [nviron-EinIII~Irot es tion Agency upon the presen ta t ion o f credentia l s, to en te r upon the pern a t t ee 's premises where an et tluent source is located or in which any records are required to be kept by this petett, and at reasonible 4tmes to have access tu and copy Jny records requireJ to be krot br this permit, to in-soect any monitoring equtpment or monito ing method required in this permit; anJ to sample any discharge from the f acility an1 any waste or mat rials generated or stored on the premise?. II. fransfer of OwnershiJ: The permittee s3all notify the succeeding omner, controlling person, or operator oIlhe esistence of this permit by certified let ter, a copy of which shall be forwarded to the Davision. 14 A v .a i l a b i l i t y_n t Re torts: Licept for Jata Jetermined to be confidential undet restton 108 of the Act, all repor t s pr epar eT an accordance =st h the terms of this permit shall be available for publac inspec-tien at the otfices of the Department. fifluent Jats shall not be consider-J conitJential. Enowing;r making ins f a l se s t a t e'aer.t on any such report nay result in the imposition of crtminal penalties as provided for in Section 309 of the Act and K.S.A. 65 170c.
- 15. Fermit *1#tification:
After nitice and opportunity for a hearing, this permat may be modified, suspel or reinfel in =TJle or in part during its terms for cause including, but nnt limiteJ to, vtolataons o an< tesns ur orJations of this permit; obtatning this peimat by mtsrepresentation or fatture to ds6-close fully all relesamt Inets; or, a change in any condition that reqatres cather a temporary or permanent rcJuetion or elimination of the authorized discharge. 16. T. s u Pntlutants: Notwithstanding Parngraph 15 above, if a tonic effluent staadarj or prohibition [iiclEJini~env schedule of compliance specified in such et fluent standard or prohibition) as est ablished unJer sectton 301(a) of the Act int a tonic pollutant which is present in the Jascharge anJ such stan<larl permit or prohibitton is more stringent than any limitation for such pollutant in t'ias pert t, this shall be rettseJ or modified in accordance with the taste effluent standard or prohibiston the peroittee so notafled. and 17. Civtl an1 Cisminal ltahtittv: Encept as authortsej by statute and paragraph 9 "8> passing", nothing in lEIT per*It~ilGli be construed to relieve the peretttee f rom civ al or c r te anal penalties f or noncom-pLlance. 13. Oil anl syjirdous Substance Lisbiltty: Nathing in this permit shall be ennstrued to prectuJe the in s t a t u t i o n7i~'iri^yTgWa c t io n o r re!! eve the permittee tron any responsibilities, laabtlities, or pentitles et seq. to which the I.ermittee is or may be subject to unJer Settinn ill of the Act, or K.S.A. 65-164 the muntenp.il permittee shall promptly notify the Divtston by telephone upcn dascovertng crude oil or other petroleum derivative in its se=ct system of wastewater treatment facilities. 19. InJu
- t r i al it.er s: the municipal permit tee sh all regulre any injustrial user of the treatment works to siipi Sectionv Ci 309t R~TETt of thet Act.
on s 107 s, 304 of the Act, and any industenal user of storm sewers to comply with
- 20. j_
Le gerty d i3h ts. the issuance of this perms Joes nnt convey any property rights in either real or personal property, or snv esclusive prtvaleges. nor Joos it authori:* iny iniury ta private property or laws invorinsisson of persnnal r ghts, nor any infrangement of or violat tan of f ederal, state or local regulatinns. II. Operstne Certificitton. v I II56~EI an opetator certiftel The peranttee sh411 assure that his westewater fatalities are under the super-by the Department. If the permittee does not have a certs(scJ oper3 tor, or lu .e sb.at4s.A.R. requarrJ sertified operstor, he shall take the approprist e steps to obtain a cert sf ac3 operator as 24 16 19 11. nI'the"Ipfl l's$ pert < dafton Asghts?ofThe .inyprovisions of this permit tre seserable, an.1 a f any pro.tston of this permit. provi s ton nf thi s pa#mit t) any ci ;umstance is hell inv41tJ. the sppla. 6ittnn atiected at therchv. soc h provinton to other ctrcumstances, and the rem.tnJer of this permit, shall not be
- 11. Removal from .ervice:
the permtttee shall inture the Davtstan at leasr 3 months before a pumping it.ition at eptableos other to thewiite t r e of Daitsian a tJe(ammissioning
.s e n t fiealttv tsthat to he willre*eved tres service. 2n3 shall make arrange +cnts health, anJ grounJ and surface wsters. prowtJe adequate protectaan for the publac I
1
4 WCGS-ER(OLS) l 0291.16 Indicate the present status of Wolf Crock Cooling
,[Q ')
(ER) Lake (WCCL) with respect to completion of the Dam and filling. R291.16 The Wolf Creek Cooling Lake (WCCL) construction was.-completed in late 1980. Filling began on November 13, 1980, and has continued intermittent-i ly 'until the present time. As of 5/28/81, WCCL level is 1060.55 and per Figure 2.4-20 (Cooling Lake Area - Capacity Curves) of the PSAR, the lake is at 23 percent of its normal capacity and 41 percent. of its low level operating opacity. 0291.17 Indicate the present pr adiction for completion of (ER) filling of Wolf Crock Caoling Lake (WCCL). R291.17 The prediction for the filling of WCCL during the worst case drought at a 41 cfs fill rate is 23 months- to the minimum operating level and 41 months to the normal operatine Icycl. Ilowever , the prediction for an average y ar at 120 cfs is 5 months to minimum operating Icrol and 14 months to the normal operating 1 cycl. ,f% U 0291.18 Please provide the results of aquatic biological (ER) surveys conducted to date relativo to aquatic organisms in WCCL. R291.18 Scheduled aquatic monitoring on WCCL has been accomplished in February and April of 1981. Ilow-cvor data analyses has not been completed by con-i sultants. Data will be submitted to KU&E in May of 1982 and will be ava ilabic fo r review by the NRC at WCGS. {
~
I-Rev. 2 l 291-17 6/81
WCGS-ER(OLS) 0291.19 Provide details of the monitoring program on WCCL (ER) during filling and as planned af ter station oper-ation begins. This should include information on icthyoplankton and young-of-the-year fishes, espe-cially in the area of cooling water intake. R291.19 The Applicants have initiated the lake filling phnse environmental monitoring program on Wolf Creek Cooling Lake (WCCL). Cooling lake monitor-ing includes limnological and fis' y studies de-signed to investigate the cooling .c as it fills. Lake monitoring will ::haracte rizu the chemistry and biology of the cooling lake while providing information on the success of the fish stocking program. The sampling schedule for this phase of monitoring is outlined in Tables 291.19-2 and 291.19-3. Details of the lake filling phase are outlined as follows: WATER QUALITY Surface waters will be collected six times por year in the cooling lake at Locations 2 and 6 (Figure 6.1-1). Duplicate water samples will be collected from a depth of one meter using non-metallic water camplers with the exception of bac-teriological and oil and grease sampics which will be collected at the surface of the water. Water quality parameters are presented in Tabic 291.19-1. Preservation and analytical methods for water quality appear in ER(OLS) Table 6.1-5. PilYTOPLANKTON Water samples fo r phytoplankton analysis will be collected six times per year at Locations 2 and 6 (Figure 6.1-1; Table 291.19-2). Tge samples will be stored in bottles containing m preservative. The inverted microscope method will be used to determine phytoplankton species composition and abundance. Oil immersion will be utilized for identification and enumeration using the following reporting units: Algal Form Reporting Unit units /ml) Diatoms Each frustule Unicel lu la r Each cell Colonial 4 cells (colonial blue-greens like Microcystis are reported in 50 cell units) Filamentous 100 m lengths Rev. 2 291-18 6/81
WCGS-ER(OLS) f R291.19 (continued) Biovolume determinations will be made using the geometrical configuration that best suits the species and will be expressed as microliters per liter ( 1/1). Appropriate taxonomic keys will be used as identification aids. Carbon fixation rates and chlorophyll a concentrations will be determined and used as indices of phytoplankton primary productivity. ZOOPLANKTON Duplicate zooplankton samples will be collected s ix times per year at Locations 2 and 6 in the cooling lake (Figure 6.1-1; Table 291.19-2). The zooplankton community will be sampled with a conical plankton nct. At each location, two bottom to surface hauls will be collected, com-bined, and preserved. Samples will be examined qualitatively to generate a checklist of zooplank-ton occurring in the cooling lake. Replicates will be collected at each location to determine mean zooplankton standing crop (mg/1). PERIPIIYTON
~ Periphyton collections in WCCL will not be initi-ated until the cooling lake reaches operating pool s '~
' Icvel (1087 MSL) or one year prior to station operation. Sample analysis, upon initiation of collections, will be similar to analytical methods utilized on Neosho River samples.
MACROINVEPTEBRATES Duplicate bottom samples will be collected six tirnos per year from Locations 2 and 6 in the cool-ing lake (Figure 6.1-1; Tabic 291..'9-2). Samples will be collected using a Ponar grab quantitative collecting device. All quantitative samples will be sieved and the organisms that are retained will be fixed and stained. All organisms will be identified to spe-cies, if possible, or to the lowest positive taxo-nomic level. Identifications will be made using appropriate taxonomic keys. All benthic data will be reported as the numbeg of organisms per square meter of substrate (no./m ). PISil The fishery study will provido data useful to KG&E's management effort. The fish study has been 7" designed to evaluate KG&E's stocking program by f targeting stocked species of fish. The year and
' _ - sampling ef fort utilized in the cooling lake l
Rev. 2 291-19 6/81
WCGS-ER(OLS) H291.19 (continued) follows recommendations made in The Kansas Fish and Game Commission manual of survey techniques for reservoir management. The sampling schedule for fishe ry studies during lake-fill appears in Tabic 291.19-3. Specifications for gear to be utilized is shown in Tabic 291.19-4. Catch data will be expressed in units of ef fort. Additional parameters measured in the cooling lake will include conductivity, secchi disk readings, and temperature profiles. Physical data (depth, secchi disk and tempe ra tu re ) will be recorded at the beginning and end of each not set. Sampic locations will be established and identified with land marks to ensure consistency over time. A semi-balloon trawl will be used to sample young-of-year (YOY) fish during summer and fall months (Tabic 291.19-3). No la rval fish sampling is scheduled for WCCL during the lake filling phase. The planned ope rational monitoring program will be designed to assess the effects of station dis-charges on the environment. The operational stud-los will be continuations of the pre-operational lake filling phase studies with modifications based on study findings, lake use, and other fac-tors. Changes to sampling frequency and addition-al studies as described in Section 6.2.1 of the ER(OLS) will be implemented. The proposed schedule for operation monitoring is shown in Tabic 291.19-5. La rva l fish sampling will be included in the operational phase monitor-ing of WCCL. Larval fish will be collected on a twice a month basis from April through July at Location 8. YOY and adult fish sampling will fol-low the methodology used in the last year of lake filling phase monitoring. O Rev. 2 291-20 6/81
WCGS-ER(OLS) h x ( , TABLE 291.19-1
' WATER QUALITY PARAMETERS MEASURED IN SURFACE WATER SAMPLES General Water Quality Parameters Indicators of Industrial and Municipal Contamination Alkalinity, total Calcium Bacteria, fecal coliform Chloride Bacteria, fecal streptococci Color, true Biochemical oxygen demand (5-day)
Conductance, specific Chemical oxygen demand Iron, soluble Hexane soluble materials Iron,. total Organic carbon, total-Magnesium Magnanese, total Trace MetiQs Oxygen, dissolved Oxygen, saturation Copper, total pH Lead, tota) Potassium Mercury, total Residuc, filtrable (total Selenium, total dissolved solids) Zinc, total' Residue, nonfiltrabic (total suspended solids) Sodium Sulfate Temperature
- Turbidity Aquatic Nutrients Ammonia Nitrate Nitrito Organic nitrogen, total Orthophosphate, soluble Phosphorus, total Silica, soluble I
Rev. 2 6/81 4 l
1 l WCGS-ER(OLS) f TABLE 291.19-2 SAMPLING SCilEDULE FOR TIIE AQUATIC PORTION OF THE 1981 LAKE FILLING PHASE OF THE CONSTRUCTION MONITORING PROGRAM FOR WOLF CREEK GENERATING STATION DISCIPLINE Feb Apr Jun A3 Oct Dec Water Quality " Cooling Lake X X X X X X Aquatic Ecology Cooling Lake Phytoplankton X X X X X X Zooplankton X X X X X X Macroinvertebrates Benthos X X X X X X
= Cooling Lake Locations 2 and 6 O
O Rev. 2 6/81
4
~
! hTGS-ER(OLS) TABLE 291.19-3 FISH SAMPLING SCHEDULE FOR THE LAKE FILLING PHASE ENVIRONMENTAL MONITORING _ PROGRAM _ AT THE WOLF CREEK GENERATING STATION, 1981 i Month Jan Feb Mar Apr g Jun Jul A_ugu Sy Oct Nov Dec
- Cooling Lake l Electrofishing" X X X X X X X X X X X X-Trap netting X X
.-Gill netting X ,
- +
I Seining X X X X X X 1 ,
- Trawling X X X X X i
^
Winter sampling will depend on ice conditions. i b
- Trap netting will be in March or April depending on water temperature.
1
-l Rev. 2 6/81 i
WCGS-ER(OLS) l TABLE 291.19-4 j
SUMMARY
OF GEAR TO BE UTILIZED FOR FISli SURVEYS IN TIIE COOLING LAKE FOR WOLF CREEK GENERATING STATION a GEAR TYPE pESCRIPTION UNIT OF EFFORT D.C. olectrofishing Boat mounted boom Approximately 30 shocker min per location Trap net Largo frame 4 not nights fyke nets Gill not Uniform mesh flag 4 not nights nets 100 ft x 8 ft with monofilament panels of 1, 1.5, 2.5, or 4 in. bar mesh Scino 50 ft x 6 ft bag 2 - 90' arc drags seine per location Trawl Semiballoon otter trawl
" From A Manual of Survey Techniques for Roscrvoir Management, Kansas Fish and Game Commission.
l Rev. 2 l 6/81
N - 1 i f i j htGS-ER(OLS) .,
- TABLE 291.19-5 I i l SAMPLING SCHEDULE IN THE COOLING' LAKE DURING THE l OPERATIONAL MONITORING PROGRAM i i
Month Location , Sample Type Feb Apr May Jun Jul Aug Oct Dec 2 6 8' 9 l a ! Water Chemistry X X X .X X X X X X X X' X } Phytoplankton X X X X. X X X X X X j Zooplankton X X X X X X X X X X Macroinvertebrates X X X X X X X X X X Larval Fish b X X X X X e X X X X ! Adult Fish X X X X X X a Water chemistry samples will be collected monthly for the first year of operation. b Twice monthly April - July. Winter sampling will depend on ice conditions. I Rev. 2 6/81
---. ,.-.7,..,..,-.,3 .,% , -.,-,,y._ c_.- .. --we-,_,r--- , , - . - - - - - , . - . . , - - - - . - - - - - _ _ _ - - -
WCGS-ER(OLS) { 0291.20 Provide better schematics showing the siting and (ER) configuration of the make-up water intake, the (3.4) cooling water intake and the essential service water intake. The ER-OL provides figures showing locations, but details of configurations and adja-cent shoreline are needed, [ER-OL p. 3.4-2,
- p. 3.4-3].
R291.20
- a. Makeup Water Screen House (MU Intake)
- 1. Siting of the MUSH is shown on S-1 and S-128.
- 2. Configuration is shown on A-100 and A-101.
- 3. Adjacent shoreline is shown on S-125, S-126 and S-127,
- b. Circulating Water Screen House (Cooling Water Intake)
- 1. Siting is shown on S-1 and S-11.
- 2. Configuration is shown on A-115, A-116, A-117, S-490, S-491, S-492, S-493 and S-494.
- 3. Adjacunt shoreline is shown on S-62, S-183, S-185 and S-188.
- c. Essential Service Water Pumphouse (ESW Intake)
- 1. Siting is shown on S-1 and S-11,
- 2. Configuration is shown on A-K901, A-K902 and C-KC305.
- 3. Adjacent shoreline is shown on S-80 and S-184.
Referenced drawings were provided with formal response. Rev. 2 291-21 6/81
WCGS-ER(OLS) f 7 's Q291.21 Clarify the following: The statement "The Wolf (k/ ) (ER) Crock Generating Station cooling system is design-(3.4) ed to support two 1150-Mwo pressurized water re-actors . operating at 100 percent average annual lo'ad factor" (n. 3.4-1) is contradictory to the following statement, " Analyses indicate that the cooling -lake will supply adequate water for the operation of one unit operating at 100 percent average annual load factor and two units operating at 88.5 percent average annual load f&ctor" (p. 3.4-2). R291.21 The statement on page 3.4-1 has boca changed to read: "The Wolf Creek Generating Station, Unit No. 1 (WCGS) cooling system is designed to support two 1150-MWe pressurized water reactors (PWR) operating at a 100 porcent average annual load factor for normal co.. 'itions. " The analyses referred to on page 3.3-2 (not 3.4-2) indicated that during the onco-in-50-year drought, that the cooling lake water level was lower and could support two 1150 MWo PWRs operating at an , 88.5 percent average annual load factor. O I ) V Rev. 2 291-22 6/81
,._,m, . _ , e . . - . , _ _ _ , . _ . _ , , . , , - . , _ .- _m , . _ _ , ,
WCGS-ER(OLS) { 0291.22 Discuss the aquatic biotic monitoring program for (ER) area of makeup water intake in the Neosho River. InJicate the parameters to be monitored, the fro-quency and timing of sampling, the date(s) of pro-gram initiation, its duration and the location of the sampling stations. R291.22 The aquatic monitoring program for the area of the Neosho River near the makeup water intake began in 1973. The results from that monitoring phase un-til the present can be found in the consultant's annual reports and in the ER(CPS), Sections 6.1.1.3.2 and 6.1.1.3.1.1, plus ER(OLS), Sections 2.2.2 and 2.4.3.1.1.1. In 1981, the monitoring in this area will include the following parameters: water quality, phyto-plankton, zooplankton, macroinvertebrates and fish. The schedule of sampling is enclosed and begins on January 1, 1981. The location of the sampling is the Neosho River directly below the stilling basin at John Redmond Reservoir. All fish impingement work is performed at the makeup water screen house (MUSH) which is located on the cast side of the Neosho River about 150 yards below the John Redmond Reservoir dam. The impingement study is pe rfo rmed exclusively by KG&E and was committed to by the utility in the PCS, Section 6.1.3.2. Sample dates within the months are randomly selected. Collection work is performed twice por month from August to March and twice per week from April to July. This impinge-ment monitoring is a one year program which was started in Novembe r, 1980. SCIIwUIE OF SAMPLI?G NEAR MKEUP h3r TER IllPAKE Discipline Jan Feb thr A g ((ay Jun Jul M Sg Oct Nov Dec Water Omlity X X X X Phytoplankton X X X X Zoq)larhn X X X X Macroinw rt(brate X X X X Fish Electroshock X X X X X X X X X X X X reinity X X X X X X X Larval Fish * * *
- Inpiryyment * * * * * * * * * * * *
* - twice tronthly
* - twim wekly X - once nonthly Rev. 2 291-23 6/81
WCGS-ER(OLS) l ! 0291.23 Outline the aquatic biotic monitoring program for the site . arca during station operation (sco rc- j (ER) i quests by staff in FES-CP. Sections 6.1.3.2.
' p. 6-3, 6.2.3.2. p. 6-7).. }
l'l R291.23 The planned ~ operational monitoring . program for the i sito area will include activitics on Wolf Crcok response ^ Cooling Lake (WCCL) .as described in i 291.19 and the Neosho River. Biological sampling i 4 on the Neosho River during the operational moni-l toring program will be essentially the same as established in the last year of the Lake Filling Phase (Tables 291.23-1 and 291.23-2). 4 : t i 1 i i i l 4 4 i-i 1-l i ! [ .O Rev. 2 291-24 6/81
WCGS-ER(OLS) , l TABLE 291.23-1 PROPOSED SAMPLING SCIIEDULE FOR Tile AQUATIC BIOLOGICAL PORTION OF Ti!E OPERATIONAL MONITORING PROGRAM FOR WOLF CREEK GENERATING STATION Discittlino Apr Jun Ay Oct pec Aquatic Ecoloy Neonho River Phytoplankton X X X X Periphyton" X X X X Zooplankton X X X X Macroinvetebrates Denthos X X X X Qualitative X X X X Drift X X X X "Neosho River Locations 4 and 10
'Noonho River Location 1 O
Rev. 2 6/81
~_ . _ . . . . ____ __
b WCGS-ER(OLS) N
- TABLE 291.23-2 1
PROPOSED FISII' SAMPLING SCHEDULE FOR THE ! LAKE FILLING PHASE ENVIRONMENTAL MONITORING PROGRAM i
'AT THE WOLF CREEK GENERATING STATION, 1981 !
['r Feb g My Jun Jul u A_ug Oct Dec l ' I Neosho River I
; Electrofishing" X X X X X X X X
! b Scining X X X X X X X ! e ' Larval fish X X X X i u l t a ' , Monthly at Location 1; Locations 4 and 10 i April, June, l October and December, i
- - b Locations 4, 10 and 11 in April, June, October and December; r Location 1 during all indicated months. !
U Day-night sampling twice monthly at Location 1. I i t i l f I j j i , t i : . l i l j- , i i a ! ! Rev. 2 l i 6/81 - l t- _ i
WCGs-En(ots) 0291.24 Describe any stocking of fish in WCCL that has al-(ER) ready taken place, including date introduced, species and number introduced. Also provide a de-scription of future plans for stocking fish in the WCCL. H291.24 stocking activities on WCCL, both past and future, are desi'jned to establish a desirable fishery in the lake. A fishery dominated by predator species will reduce negative impacts on plant operations due to impingement of forage and roughfish species. Stocking activities will additionally maintain options concerning future use of the lake. The WCCL stocki.ng program was initiated in 1978 and continued in 1979 with the renovation of so-1ected ponds in the lake area followed by restock-ing with forage and gamefish. In 1980 that por-tion of Wolf Crock owned by KG&E and all ponds on KG&E prnperty not previously renovated were treated to remove roughfish. Major stockings of forage and game species have followed renovation during prelimina ry filling of the cooling lake in 1980 and into 1981. All stocking activities to date are outlined in Tabic 291.24-1. Table 291.24-2 outlines scheduled stocking of fish into the WCCL for 1981 and proposed stocking for 9, the next seve ral years. The numbe r and species outlined in Table 291.24-2 after 1981 are based on a typically developinc fishery. Iloweve r , long-term stocking plans will be modified based on the success of va rious species and may result in increased or decreased rates for a given species. O Rev. 2 291-25 6/81
I WCGS-ER(OLS) i h
'O t \
I TABLE 291'.24-1 w/ STOCKING RECORD OF WOLF -CREEK COOLING LAKE
~
SPECIES DATE(S) NUMBER LOCATION Flathead Minnow 8/78 56,000- Subimp. Largenouth Bass 8/78 3,500 Subimp. Flathead Minnow .9/79 75,000 Subimp. 11/79 52,000 Subimp.
-Bluegill 9/79 5,000 Subimp.
Smallmouth Bass 11/79 40 Subimp. Largemouth Bass 9/79 2,400- Subimp. Flathead Minnow 5/80 90,000 UHS 6/80 65,000 UHS 8/80 270,000 Subimp. 9/80 57,500 Subimp. Bluegill 5/80 130 Subimp. 6/80 3,150 UHS 8/80 16,000 Subimp. 9/80 12,700 Subimp. Red-car Sunfish 8/80 2,000 Subimp. 10/80 1,000 Subimp. f'"x Black Crappic Smallmouth Bass 8/80 500 Subimp. (w/ ) Largemouth Bass 6/80 6,000 UHS 10/80 1,000 Subimp. Striped Bass 6/80 1,200 UHS Walleye 6/80 7,000 UHS 7/80 5,000 UHS Blue Catfish 10/80 35,000 WCCL
- Channel Catfish 5/80 100 Subimp.
6/80 3,100 UHS
! 8/80 25,000 Subimp.
10/80 25,000 WCCL Striped X White Bass 5/81 50,000 WCCL Hybrid Subimp = Subimpoundment of WCCL UllS = Ultimate Heat Sink Basin WCCL = Wolf Creek Cooling Lake 4 u 4 Rev. 2 6/81
WCGS-U R (O LS ) TABLE 291.24-2 PLAtifiED STOCKING PROGRAM FOR WOLF CREEK COOLING LAKE SPECIE:S 1981 1982 1983 1984 Illack Crappic 25,000 Smallmouth Bass 50,000 50,000 25,000 Spotted Ilass 25,000 25,000 25,000 Largemouth Bass 100,000 50,000 Striped Bass 50,000 50,000 Striped X White Bass 50,000 50,000 50,000 liybrid Walleye 120,000 120,000 120,000 50,000 illue Catfish 50,000 50,000 50,000 50,000 Channel Catfish 50,000 50,000 50,000
- Actual Number Dependent on Supply
** Stocked 5/81 l
Rev. 2 6/81
. WCGS-ER(OLS) n .Q291.25 Provide the details and. discuss the impacts.of re -
c( ) turn . of material collected from the plant _. intake L/ screens to ' the Neosho River.
.R291.25 -The plant' intake ? screens are located on.the Wolf-Creek Cooling' Lake (WCCL). Any. material impinged on those screens would be either_ removed from the collection' pit- and disposed of onsite or returned to WCCL. 'There is no possibility. of mate rial L impinged on the screens being returned to the Neosho River. which is approximately five. miles-
-away.
lioweve r, the makeup water screen house .(MUSil) in-take will impinge- material which could ~ be returned to the Neosho River . This material is washed off
.the vertical travelling screens' (VTS) into a col-Icction-' pit which drains into the makeup channel.
During low flow, the channel dead ends but still remains contiguous with the reservoir stilling basin. The channel becomes a flow-through system whencycr John Redmond Reservoir releases large amounts of water. Some fish fall back into the channel from the pit. However, because the makeup channel dead ends during the winter months, the fish will either be (A.
^
- recycled on the VTS or caten by the large groups of gulls which visit the area. Decay is slow be-cause of the cold temperatures, thus allowing the gulls ampic time to clean up the dead fish in a couple of days. The slow decay rate of the fish would also minimize any limnological effects which might occur due to the dead fish.
During the winter months, the la rge number of im-pinged fish are pumped from the collection pit into a dumpster and then disposed of onsite. From April to November, the impingement is less than one percent of the number of fish impinged during the winter. These fish will be allowed to drain back into the channel via the collection pit unless a significant number is present. Whereby, the fish will be collected in a 4 foot deep buc-ket not and disposed of in an onsite landfill according to state and local regulations. A sig- , nificant number of fish is that which impedes the i flow of water through the VTS to such a degree as to endanger the operation of the pumps. The ef fect of these fish being returned to the i Neosho River would be minimal. The numbe rs in- [ volved a re small, usually less than 100 per 24-lI\ hour period. Ifigh Bon concentrations would be Rev. 2 291-26 6/81 L
WCGS-CR(OLS) R 2 'J 1. 2 5 (continued) spotty and would probably be the highest near the outfall of the collection pit drain pipe. In other areas of the channel, the BOD levels should be comparabic to the Neosho River DOD levels be-cause the pumps would be continually drawing
" fresh" water into the channel. When the channel and the Neosho Rive r merge during high flow, the effects of the returned material would be even less because the la rge r volume of water would dilute any effects.from so few dead fish.
In conclusion, there will be no material returned to the Neosho River f rom the plant intake screens. Material from the MUSII screens could be returned to the Neosho River but the effects should be minimal. O l O Rev. 2 291-27 6/81
~
WCGS-ER(OLS)
?S 310.0 LSITING ANALYSIS BRANCH
)
8J 0310.1 Are there any substantial changes in ~the station
.(ER) oxternal appearance or layout which have been made subsequent to the description in the OL-ER? If so, please describe.
R310.1 The following buildings /structt:res have been added to the immediate _ power block area (See revised Figure 2.1-4):
- 1. An Auxiliary Warehouse . located. jout east of the Shop Building;
- 2. -Technica1 Support Center -located between the Administration Building and Shop Building;
- 3. Security Building located south of the Admin-istration Building;
- 4. Security Diesel Generator located immediately north of the northwest corner of the Security Building; and
- 5. A cove red walkway connecting the Turbine
' Building, Administration Building, Technical j Support Center, Shop Building, and Security-Building.
1 These a re low visibility structures and do not change the skyline appreciably. The Emergency Operations Facility (EOF) - Simula-tor Complex has been located on the site but 2.8 miles northwest of the power block area (see re-vised Figure 2.1-6). 0310.2 Are there any new roads or rail lines or reloca-(ER) tions of roads or rail lines near the plant which have been proposed subsequent to the description in the OL-ER? If so, please describe. R310.2 There are no new roads or rail lines and no relo-cations of existing roads or rail lines since the
- description in the ER(OLS).
\/ )
Rev. 2 310-1 6/81
WCGS-f!R ( OLS ) Q310.3 Section 2.1.3.3.4 of the OL-ER states: " Currently, (ER) there are no plans for public use of the cooling (2.1.3) lake or lands within the site bounda ry adjacent to the cooling lake not needed during operation of the station and related facilities." It also states that the visito rs center location has not been selected. llave the plans for public use of the cooling lake and adjacent lands been revised? If so, plesse describe. Also, has the visitors center site been selected? If so, please give its description and location. R310.3 Section 2.8 of the ER(OLS) addresses public use of the cooling lake and adjacent lands. As stated therein, there are no plans for public use of the cooling lake. Lands adjacent to the cooling lake and ins ide the WCGS site bounda ry wi11 he used to the extent practical as it was prior to its pur-chaso for the WCGS site. The Visito rs Center is located about 2.8 miles northwest of the plant at the Emergency Operations Facility (EOF) complex (See Figure 2.1-6). The center occupies 760 square feet of display space in the EOF / Simulator / Visitors Center building. O Rev. 2 l 310-2 6/81
A WCGS-ER(OLS). v
. ,m
( j' 0310.4 - Section 2.1.3.2.11- mentions "an increase - in' the i (ER) . . number of large rural homesites on nearby agricul-
' j '
4 (2.1.3) tural land." i.c., within five miles of the site. Uccause of this increase, have the 1980 census results differed significantly from the 1980 pop-ulation forecasts in Table . 2.1-2, ER-OL?- If so, plea.o s revise the population deta for the . five mile area around the site. RJ10.4 Since census results are not generated based on distances from Wolf Crock, the applicants con-
-ducted a house survey in 1980 to determine the population distribution -around the The actual -1980 . population within 5 miles site.
of. Wolf
; Creek was - 3,412 versus . 3,64 0 projected in Table
- 2.1-2. The sectors whose populations dif fered the most from that projected were those which contain Burlington and New Strawn. This -is primarily attributable to increased' numbe rs of- temporary construction' personnel settling in these commun-itics. Once Wolf Creek construction is complete the operations staff will only number 10 percent 1
of the peak construction staff. Tabic ~ 2.1-2 i has been updated to reflect the 1980 population info rmation. (Q
%/
1 0310.5 Provido an estimate of the average annual number (ER) of worke rs required for the operation of Wolf Creek Unit No. 1. State whether the workers are employces or contractors. Also provide an esti-
. mate of the average annual operating workers' pay-roll for the unit.
i R310.5 It is estimated that 284 persons including secur-
; ity personnel will be required for the permanent
' operating staf f .of WCGS. All are expected to be KG&E employees. (This does not include additional
; or contract employment ducing refueling. )
The annual payroll for the first full year of operations is estimated to ;c $5.5 million. J
- v Rev. 2 310-3 6/81 1.
WCGS-f:R (OLS ) 0310.6 Local purchases of goods and services for a nuc-(ER) lear power plant ope ra tion may f requently have a significant impact on the local economy. (For these purposes local may be defined as either the host county or the host county and one or mo re contiguous counties.) Please provide info rma tion on local purchases of goods and services expected to be made by the plant during a typical year of operation. To the extent possible, identify specific types of dollar amo' int s of these purchases. If it appears that there will be no significant local purchases, ex-plain why. R310.6 Once WCGS is in operation local purchases of goods and se rvices will no longer be at the level of those purchases during the construction period. Many of the supply and maintenance items and the specialized se rvices req uired for operations and maintenance are not available in the local area or are not price competitive. Most purchas2s will be made in Wichita and Kansas City. Local purchases of goods such as small tools and office supplies are unlikely to exceed $25,000 per year. O O Rev. 2 310-4 6/81 l
WCGS-ER(OLS)
- / 7 'Q310.7 Construct a table containing dollar estimates of -
i, } (ER) taxes attributable ' to Wolf Creek No. 1,'for each
^~d of' . the fits t five ful1 years of operation. Pro-vide the dollar estimates by type of tax, and by taxing jurisdiction. What percent of the juris-dictions' - total tax revenues are represented by
'the taxes attributable to the Wolf Creek No. 1
! Plant?
R310.7 The most significant impact of taxes' attributable to WCGS will be on local jurisdictions within Coffey County. .- A s shown in Table 310.7-1, WCGS
-will be paying taxes to 20 individual county'jur-isdictions in amounts ranging in 1985 from $11 to
$6,499,187 and contributing up to 99 percent of s.
the revenues received by va rious - jurisdictions. In addition, WCGS will be paying about $600,000 per' year to the State of Kansas for its education and institutions building' fund, based on property owned in Coffey County. 4 Taxes will also be paid to other nearby counties
. through which transmission lines will pass. Esti-
- mated amounts for these taxes'are shown on Table
; 310.7-2, together with estimated income and fran-chise. taxes for 1987.
( i k '1 Rev. 2 310-5 6/81
Wt%S-im i of.Si IAKI 310.7-1 bCIE CREDC GNEPATDC STATICN AD VAl.4RD? ".AX ESTImTIS CFITY CD3':Y TAXI % JURISDICI!ZS 1985 - 1989 1987 1988 1989 1985 1986 4 cf EAL 4 cf MAI., 4 M IGim 4 of ICTE 4 cf TU!AL M TAX RE".VES nG S TAX RE'.T M S bCCS TAX RntcS TAXDG ERISDICTICE E "'AX REtVA.ES M TAX. Fr.T RS_ 606,155 3.57 $ -612,200 3.55 $ 618,411 3.53 593,C89 3.61 5 600,166 3.59 5 State cf Karsas S 6,642,726 88.82 6,709,070 88.34 6,776,197 87.86 6,499,187 89.61 6,576,910 89.30 Coffey Cour:ty
'Ib.Tships 241 41.62 243 41.33 246 41.21 236 41.99 238 41.75 1,414 97.32 Avo.1 1,373 98.99 1,386 98.44 1,400 97.83 Ha. p&n 1,356 99.27 500 41.08 500 40.45 500 42.37 500 41.74 Pottm atomie 500 43.03 48.54 201 48.32 204 48.43 48.87 197 48.76 199 Star 1 94 f.',nifia! Sdiool Districts 33,379 5.36 33,730 5.34 34,081 5.30 32,778 5.43 33,079 5.39 5,214,721 93.89 No. 243 5,071,103 95.44 5,121,778 94.92 5,173,035 94.40 No. 244 5,011,288 95.78 '3 3,6M 5.22 34,013 5.20 5.22 32,987 5.28 33,332 5.25
!b. 245 32,139 Ceretary Districts 129 48.50 130 48.15 131 47.64 126 48.84 127 48.47 604 45.69 Altaront 586 46.40 592 46.18 598 45.93 Bowan-Adgate 579 46.58 282 52.71 284 52.30 276 53.18 279 52.94 Pleasant Hill 272 53.23 3,074 97.84 3,104 97.27 3,014 98.95 3,045 98.42 Str2.ngtown 2,980 99.33 35 11.36 35 11.22 10.88 34 11.41 34 11.22 Wharton 32 Watersheds 11 .03 11 .03 11 .03 11 .04 11 .04 No. 24 4.19 688 4.17 694 4.14 635 4.03 675 4.21 6 81 No. 48 63 .10 64 .10 65 .10 62 .10 63 .10 4,104 No. 90 44.77 4,053 44.36 4,078 43.95 43.56 3,983 4 4.97 4,027 No. 93 Fire Districts 594 4.92 600 4.89 606 4.87 5 81 4.96 588 4.95 1,304 11.20 No. 5 1,304 11.73 1,304 11.55 1,304 11.38 No. 40 1,304 11.92 Southeast Kansas Regioral 202,119 53.69 204,135 53.40 206,171 53.11 197,668 54.16 200,042 53.97 L2brary S12,652,600 S12,779,100 $12,906,900
$12,379,000 $12,527,300 Tota.
Pev. 2 6/81
# 9 e
~. . . . . .
\ ,
4 1 4 1 CGS-ER(OIS )
-l TABLE 310.7-2 ! ESTIETED AD VALOREM TAXES 1985 .1989 i (S000)
Coffey Anderson Butler Franklin Greenwood Johnson Lyon Miarn Tbtal
. Year County Ccunty County County County County County County All Counties i
I 1985 12,379 34 66 116 77 17 5 48 12,743 118 17 12- 49 12,909 i 1986 12,527 34 70 81
]
1987 12,653 35 71 119 82 17 , 12 50 13,038 1988 12,779 35 72 120 83 18 13 50 13,169 f' , 1989 12,907 35 72 121 .84 18 13 50 13,300~ O mER ESTIMATED TAXES 1987
.(S000) i Federal Incoce $92,945 I
! Kansas, Inome & Franchise 32,600 1 I Missouri, Income & Gross Receipts 10,021 i i
)
l Rev. 2 4 6/81 F _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . - _ _ _ + . . - - -. - ,- _ _ . _ _ _ _ . _ _ _ . _ _ _
WCGS-!:R ( O LS ) 0310.8 Please provide the distances of the proposed trans-(ER) mission cor r ido rs from the following properties listed in t.he National Register of Ilistoric Places: Samuel J. Tipton flouse liarris Vicinity Anderson County Columbia 13 ridge Peoria Franklin County I. O. Pickering Ilouse Olathe Johnson County Please give the same in fo rma tion for any other archeological and historical sites or properties listed or eligible for listing located within 2 km of the corridors. R310.8 The distances of the proposed Wolf Creek-Craig transmission cor rido rs from the following proper-ties are: Samuel J. Tipton flouse, 9.8 km; Colum-bia 13 r id ge , 2.1 km; and I. O. Pickering House, 16.9 km. The Wolf Creek-Craig transmission line has been shortened (approximately 14 miles) and is now the Wolf Creek-West Cardner transmission line terminating at the West Gardner Substation (See response to NRC question 290.1). The National Register of Historic Places for Kansas dated February, 1981, obtained from the Kansas State Ilistorical Socie ty in Topeka, was examined to determine if any other archaeological and historical sites or properties were located within 2 km of the transmission corridors. None were found within 2 km of the corridors. The nearest site (greater than 4.3 km) was the C. N. James Cabin, 305 S. State Street, Augusta in 13utle r County. O Rev. 2 310-6 6/81
WCGS-ER(OLS) A l Y 311.0 SITING ANALYSIS BRANCH
\ }
0311.1 As published in the Federal Register (Vol. 45, No. 116, June 13, 1980, Pages 40101-40104) the Nuclear Regulatory _ Commission (NRC) has revised its policy
-regarding accident conside rations in National Environmental Policy Act (NEPA) reviews. Informa-tion regarding the site as well as events arising from causes external to the plant which are con-side red possible contributors to the risk asso-ciated with the plant are to be discussed. Refer- i ences to safety evaluations is acceptable provided the- Environmental Report contains a complete ~over-view with references to specific sections of the PSAR. Accordingly, please provide' an analysis of all of fsite activities and an assessment of poten-tial hazards including: (1) transportation, (2) mining and mineral exploration andfar cpera-tions, (3) industrial activities, and (4) military activity.
R311.1 The requested analysis is presently provided in WCGS FSAR Addendum Section 2.2. See revised Sec-tion 2.1.1.2.
'0i 1 \/ 0311.2 Section 2.1.2.3, Page 2.1-9, discusses peak month-(ER) ly transient population at John Redmond Reservoir.
(2.1.2.3) Please provide an estimate of peak daily usage as well. R311.2 The Corps of Engineers has recreational use sta-tistics which indicate that during an average summer month daily use of the recreational area averages 1,400 persons. Peak usage of the John
- Redmond Reservoir occurred on July 5, 1979 when 10,820 persons entered the recreational area.
i I o
)
v' Rev. 2 311-1 6/81 l
WCGS-ER(OLS) 0311.3 Section 2.1.3.2.9, Page 2.1-18, and Figure 2.1-23 (ER) identifies several abandoned and one operating (2.1.1.2) q ua rry within 5 miles. It is difficult to read Figure 2.1-23. Please clea rly identify the loca-tion of these qua rries. Please identify the maxi-mum quantity and type of any explosives stored at the q ua r ries . Please identify the frequency, qua ntity and transportaton route for each explo-sive type delivered to each quarry. H311.3 Active and abandoned quarries within 5 miles of the plant site, are identified in new Figure 2.1-23a. Abandoned quarries do not have explo-sives utored at the qua rry. The only operating quarty is located 3 miles south-southeast of the plant, site (See Figure 2.1-23a). The maximum qua ntity of explosives stored at this quarry is approximtely 15 tons of ammonium nitrate-fuel ail mixture. Irregular shipments of up to 15 tons of this exp loa ive are delivered to the quarry via US75 and FAS10 (Figure 2.1-7). US75 is utilized to del ive r exp los ive s to other quarries located beyond five miles from WCGS. The maximum load the s hippe r 's trucks can ca rry is 20 tons of explo-sives. Usually less than a maximum load is loaded on a truck fo r delivery with the explosives con-sisting of 75 percent ammonium nitrate-fuel oil mixture and 25 percent class A explosives. O Rev. 2 311-2 6/81
WCGS-ER(OLS) (y 0311.4 Figures 2.1-3, 5, 6 and 7, etc., show an abandoned
.(,v) (ER)
(2.1) A.T. &.S.F. ra ilroad line passing through the. Wolf. Creek Site. FSAR question 310.01' requested an ex-planation of the status of this line and discus-sion of any casements which may exist relative to this ra 11 road line. For completeness, please in- ^ cludo your response to PSAR question 310.01 in the ER. R311.4 The info rma tion requested by FSAR question 310.01 was already contained in the FSAR Addendum Section 2.2.1.4 as follows: The Santa Fe Railroad and right-of-way located 0.3 mile west of the plant site is abandoned. By Interstate Commerce Commission Order in Finance Docket No. 26591, dated February 4, 1972, caption-ed Atchinson, Topeka and Santa Fe Railroad Company Abandonment, B . fl . Junction and Gridley, Franklin and Coffey Counties, it was ordered that the branch line of the railroad extending between milepost 0.0 at B . !! . Junction, Kansas, and mile-post 52 plus 1,518 feet at Gridley, Kansas, be abandened. With this abandonment, title of the right-of-way property _ reverted to the fee simple title owners. v This information is included in Section 2.1.1.2. Rev. 2 311-3 6/81
WCGS-ER(OLS) . 320.0' ' UTILITY FINANCE BRANCH -i
.('~]
/
%d 0320.1- Please provide further information on KEPCo,'in-(ER) cluding present ' status of purchase of 17% of WCGS (1.1) 'and of applications _ for membe rship in SPP and a MOKAN, and the ' latest ' annual report. Please pro-
-vide information available for KEPCo which corre-sponds to that giver for KG&E and KCPL in Tables 4-6, 16-18, 25-34 of the section 1.1.
R320.1 The purchase of a 17 percent interest of WCGS by KEPCo has been approved by the Kansas Corporation Commission, and the Kansas State Legislature has passed an authorization measure. -This measure was signed by the Governor on April 17, 1981. KEPCo will apply = for membe rship in SPP and MOKAN as soon as the purchase is completed. This is ex-pected by Octobe r, ~1981. It is not possible to provide more detailed infor-mation on KEPCo than is provided in the text and tables of the ER(OLS) revised. As shown in Table 1.1-3, KEPCo's orly owned capacity will be the 195.5 MW of WCGS in 1984'and two low-head hydro [q projects with 29.35 MW in 1986.
' G'}. Consolidated data' a re not available on system fuel costs, peak hour c onditions, interchanges, etc.,
nor are comparisons maintained on syste.r. forecasts and . actual peaks and ' energy for the 27 member cooperatives. 40320.2 In section 1.3.1 of the ER-OL, reserve margin de-(ER) ficiencies due to delay of WCGS operation are (1.3) stated which for Sunflower Electric exceed expect-ed sales to Sunflower by KEPCo. Please given de-tails of KEPCo/ Sunflower generation and purchases to support the margins stated. R320.2 Section 1.3-1 of the ER(OLS) has been revised. The earlier statements are not applicable. i l J 1 Rev. 2 320-1 6/81
WCGS-ER(OLS) 0320.3 On p. 1.1-27 of the ER-OL in tige description of (ER) the KCPL econometric model C, R and DW are not (l.1) defined. Please do so. R320.3 Definitions of terms not identified are as follows: C = Constant R = Coef ficient of determination II =R adjusted DW = Durbin ' Watson coef ficient There appear to be typographical slips in the 0320.4 (ER) tables for Section 1.1 of the OL-ER.in For exam-the third (1.1) plc, in Table 1.1-12 all entries column (GWil increase) from 1980 on are inconsist-ent with columns 2 and 4. Please provide any cor-rected tables for Section 1.1. Table 1.1-12 has been corrected and revised. h11 H320.4 tables in Section 1.1 of the ER(OLS) have been up-dated with the exception of Table 1.1-7a. umbe rs for any O Q320.5 Please provide current revised (ER) entries in Tables B.2-1 and 2 which have been sig-(1.3) nificantly affected by changes in interest and escalation rates s ince completion of the ER-OL. Please provide any corresponding revisions of the text tables on p. 1.3-3. R320.5 Tables 8.2-1 and 8.2-2 have been revised, as have the text tables on pages 1.3-3 and 1.3-4. O Rev. 2 320-2 6/81
WCGS-ER(OLS)
-m .
/ Y ..Q320.6 P lease provide the most -recent forecast (if.any)
\ '
,/ '(ER) updated by the current actual numbers of the elec-tricity demand and the capacity for the applicants and the powerpools, t
R320.6 The most recent. forecasts of energy and demand, together with 1980 actual experience are given .for . KG&E and KCPL in Tables 1.1-12 and 1.1-13. KEPCo actual experience through 1979 and forecasts are-provided in Table 1.1-14._ Capacity data for the Applicants are presented in Tables - 1,1-1, 1.1-2, 1.1-3, 1.1-4a and 1.1-Sa. SPP _ and MOKAN energy, peak load and capacity data are presented in Tables 1.1-8, 1.1-9, 1.1-10 and 1.1-11. Q320.7 Please . provide, the estimate or evaluation of a (ER) reduction in - the demand for electricity (use and capacity) as a result of various load management programs by the Applicant. R320.7 The forecasts for energy and peah load in Tables 1.1-12, 1.1-13 and 1.1-14 take .nto account the effects of load management programs and reduced rates of growth in demand related to population, economic anu social f acto rs . It has not yet been ( j possible to isolate the individual factors that v contribute to'a reduction in a growth rate.
-Q320.8 Please provide the change (if any) in the reserve (ER) requirements of the applicant and the powerpool.
R320.8 There have been no changes to date in the reserve requirements for the Applicants' and the power pools.
,O,
%.)
Rev. 2 320-3 6/81
WCGS-ER(OLS) 0320.9 Please provide the fuel mix you would use in pro-(ER) viding the replacement energy in case WCGS does not come on line. Also, provide the cost of pro-ducing electricity (mills /kwh) by each fuel type. R320.9 The fuel mixes to be used in providing replacement energy in the event of a delay for WCGS are given in Table 1.1-30 and shown below: FUEL MIX WITl!OUT WCGS - IN PERCENT 1 Year Delay 2 Year Delay 3 Year Delay KG&E Coal 61 .7 57.4 60.4 Oil 0.3 5.4 4.9 Gas 38.0 37.2 34.7 KCPL Coal 97.3 97.0 93.2 Oil 2.6 2.9 6.8 Gas 0.1 0.1 0.1 Estimated fuel costs for replacement energy are: FUEL COSTS IN MILLS PER KWH 1 Year Delay 2 year Delay 3 Year Delay KG&E KCPL KG&E KCPL KG&E KCPL Coal 18.8 19.6 20.5 21.9 22.4 24.7, Oil 61.1 191.6 71.0 207.6 76.7 199.6 Gas 37.7 55.4 45.3 70.2 51.4 91.5 Oil costs went down for third year of delay for KCPL because the oil units will change from low-load spinning reserve units to operation as base load units. The oil units operate at a more efficient heat rate when fully loaded. These fuel costs may be compared with the follow-ing estimated nuclear fuel costs in mills per Kwh: MII LS PER KWil AT CAPACITY FACTORS OF: _. 6 0 .50 .75 .65 1984 8.9 9.1 1987 8.1 8.3 Rev. 2 320-4 6/81
WCGS-ER(OLS) h
. ,q Q320.10: Please provide th'e capacity _ charge, and the price
.of electricity paid to the powerpool to satisfy
( V) (ER)_ the future demand increase in case WCGS does not come on line. Please provide the portion of total incremental . demand satisfied by in-house genera-tion and the purchase from powerpool. R320.10 It is assumed that this question refers to charges that are based on pool obligations . Therefore, the capacity deficiencies used are those' shown in Tables 1.1-1 and 1.1-2 which contain data reported to the MOKAN pool. If WCGS were delayed, KG&E and KCPL . would have to make capacity purchases from outside their systems to cover projected deficien-cies In capacity responsibility. These capacity deficiencies are based on each utility's expected
" capacity responsibility" which includes its sys-tem demand plus firm purchases and sales, etc.
On this basis the projected capacity deficiencies will be as follows, in the event of a delay: Capacity Deficiencies in MW Delay in Years KG&E KCPL O One 37 178 k Two 97 285 x KCPL's deficiencies are based on 20 percent re-serve margin while KG&E's are 15 percent. . KG&E estimates the capacity charge would be
$156.30/KW per year through 1984, calculated as follows:
Capacity charge = $610 per KW x fixed charged rate of approximately .23 = $140.30 plus fixed operations and maintenance (O&M) costs-of $16/KW per year = $156.30 Through 1985 the capacity charge would be
$140.30 plus fixed O&M costs of $17.60/KW per year = $157.90 KCPL estimates that the capacity charge in the time frame 1985-1987 would range between $125 and
$l.50/KW per year.
If the capacity charges estimated by KG&E are ap-plied to the capacity deficiencies above, the fol-lowing total capacity charges are obtained. Rev. 2 320-5 6/81 ! l
WCCS-ER(OLS) R320.10 (continued) Capacity Charges Delay in Years KG&E KCPL One $ 5,783,100 S27,821,400 Two $15,316,300 $45,001,500 In addition to the capacity charges there would be energy costs. In the event of a delay for WCGS, KG&E would use all available coal capacity but then purchase as much outside coal capacity as possible before burning more expensive oil or gas in KG&E plants. It is assumed that the full capa-city deficiency would be purchased about 60 per-cent of the time. On this basis the costs would be as follows: For a one year delay: 37,000 x 8760 x .60 x 1.470 per KWii = $2,858,738 For a two year delay: 97,000 x 8760 x .60 x 1.62C per KWii = $8,259,278 If for the purpose of illustration KCPL's energy costs are computed on the same basis, they would be for one year: 178,000 x 8760 x .60 x 1.47C/KWll = $13,752,850 For two years: 265,000 x 8760 x .60 x 1. 62 C/KWII = $24,266,952 The total capacity charges and energy costs would then be: Total Cost in Thousands Delay Cost Elenent KG&E KCPL One year Capacity charge $ 5,783 $27,821 Energy cmt 2,859 13,753 Total S 8,642 $ 41,574 Two Years Capacity charge $15,316 $45,002 Energy cost 8,259 24,267 Total 23,575 69,269 l Two Years Total Cumulative $32,217 $110,843 l Costs Any delay of WCGS would cause KG&E to burn large quantities of gas and oil. Rev. 2 320-6 6/81
WCGS-ER(OLS)
- o. i
'R320.10 (continued) \s) It is assumed that " total incremental demand" re-fe rs to the increase in ' capacity responsibility without WCGS for the years 1984 over 1983 and 1985 over 1984. The table which follows gives the pro-jected KG&E system capacity responsibility both.
with and without WCGS. Projected RG&E System Capacity Responsibility 1983-1985 KG&E Total System KG&E Capacity a System Capacity Respnsibility Capacity Balance With WoGS 1983 2050 2111 +61 1984 2091 2549 +458 1985 2151 2549 +398 Without NCGS 1983 2050 b 2111 +61 1984 b 2111 -37
.1985 2148 2208 6 'O I 2111 -97 3
"D Includes KG&E system demand plus firm transactions.
[3 The 57 MW increase in capacity responsibility in 1984 and 1985 without WCGS is due to KG&E's power (v' ) supply obligations to REC's which are different with and without WCGS. If the " total incremental demand" is defined as the increase in capacity responsibility without WCGS for the years 1984 over 1983 and 1985 over 1984, then the following situation would exist: In 1984 without WCGS, there would be a 98 MW in-creeae in demand, 37 MW of which would have to be purchased outside KG&E. The remaining 61 MW would be satisfied by existing generation. In 1985 there would be an additional 60 MW increase in de-mand, all of which would have to be purchased out-side KG&E. On a cumulative two year basis the increase would amount to 158 MW of which 97 MW would have to be purchased outside KG&E. KCPL will have to make up any deficits through purchases outside the utility (based on a 20% reserve). I m Rev. 2 320-7 6/81 l
WCGS-ER(OLS) 0320.11 What fixed charge rate has been us<d to calculate (ER) the capital cost portion of the total cost of gen-erating electricity by nuclear fuel? Please refer to Table B.2-2. Why is fixed charge into year 1986 higher than the year 1983 (269.10 vs. 217.58 million dollars)? What inflation rates have been used to arrive at 1986 numbers in this table and other places? R320.11 Fixed cha rge rates used to calculate the capital cost portion of the cost of generating electricity by nuclear fuel are as follows: 1984 (Applied for 9 months) 1987 KG&E 23.0% 24.0% KCPL 27.23 21.63 KEPCo 13.82 12.71 The dif ferences in the calculated amounts shown in Table 8.2-2 are due to the facts that the fixed charge is applied for 9 months in 1984 and that taxes and costs of money are different for the individual owners year by year. Inflation rates vary by year but in general are those estimated by Data Resources, Inc. For 1980 and future years they are as follows: INFLATION RATES BY YEARS 1980 1981 1982 1983 1984 1985 1986 Materials 9.5 9.9 10.0 9.0 8.6 9.8 9.6 Labor 10.0 10.9 10.6 10.5 10.5 11.4 10.4 The composite escalation rate over the life of the project is estimated to be 8.3 percent. I O Rev. 2 320-8 6/81
- r. !
WCGS-ER(OLS)- j i l h 0320.12 Please refer to pages 1.1-4 3 and 1.3-3. Please J -(ER) provide the basis for-calculating the fuci savings K_/ (1.1) or consumptions (in terms of quantity and dollar both) resulting from bringing or not bringing WCGS on line. .The unit of coal _ consumption on this table appea rs to be % correct. The response to Question 3 may be extended to answer Question 6. R320.12 Both KG&E and KCPL use computer runs to estimate future system consumption of fuels and to optimize station .use so as to achieve lowest total cost. Unit fuel costs projected to exist in future years are applied to the quantities obtained to deter-mine the costs for additional fossil fuels. In comparing costs with and without WCGS, a credit is taken for nuclear fuel not burned in the without WCGS case. The results of these computations are given on page 1.3-3 and shown below: ADDITIONAL FUEL CDfUUMPTION AND CDSTS WITHOUT NJGS AND WI'IU INDICATED DELAYS Unit- 1985 1986 1987 Fuel Measure One Two Cumulative Three Cumulative Year Year Year Delay Delay Delay
/
\
OE Coal (000) Tors - - - - - Oil (000) Bbis 236 697 933 683 1,616 Gas IfCF 31,639 29,352 61,171 29,929 91,100 Net Additional Fuel Cost (000) $89,156 S137,590 $226,646 $167,034 $393,780 KCPL Coal (000) Tons 800 954 1,754 1,057 2,811 Oil (000) Bbls 129 206 335 693 1,028 Gas MfCF 50 15 65 0 65
- Net Mditional 1h1 Cost (000) $21,270 $32,994 $54,264 $82,211 $136,475
'IUTAL Coal (000) 'Ibru 800 954 1,754 1,057 2,811 l
Oil (000) Bbla 365 903 1,268 1,376 2,644 Gas f9CF 31,689 29,367 61,236 29,929 91,165 , Net Mditional Fuel Cost (000) S110,426 $170,584 $280,910 $249,245 $530,255 O V Rev. 2 320-9 6/81
WCGS-ER(OLS) f l l Q320.13 Please provide new estimates, if any, of decom-(ER) missioning and dismantling costs. R320.13 No new estimates have been made of decommissioning and dismantling costs. I O I l l O Rev. 2 320-10 6/81
WCGS-ER(OLS) 450.0 ACCIDENT EVALUATION BRANCH 0450,1 Will applicant initiate pre-operational fog moni-(ER) toring program to provide baseline data? If so, provide details of the ple If not, explai.n why such a study will not be undertaken. R450.1 A pre-operational fog monitoring program is being planned. The purpose of the study is to document the frequency of occurrence of natural fog (as opposed to fogs induced by the operation of the cooling lake) along Highway 75 which is located from 0.5 miles to 2.0 miles west of the cooling lake. Tab le 2.3-29 of the WCGS FSAR Addendum Revision 1 2/81 shows that the predominant frequency of light wind (less than 3 meters per second) is from the sectors scutheast through south. This corre-s[>onds with the Dames & Moore Program FOGALL enal-yses which shows the maximum increase in ling lake induced fogging frequency alont Highway 75 to occur approximately 3 miles south through 2 miles north ot New Strawn, Kansas. ,~ While the details of the fog raonitoring program are not completely defined at this time, it is anticipated that a transmissometer and continuous analog recorder will be installed along Highway 75 at a point within 2 to 3 miles of New Strawn, Kansas. The instrument will continuously monitor visibility at an elevation of 1.5 to 2 meters above ground level. Maximum visibility resolution will be at least 100 meters. The fog monitoring program will be initiated in An 1981 and will continue through plant startup. annual analysis will be pe rf o rmed to categorize fogging occurrences by visibility classes and to correlate fog occurrences with the meteorological data acquired at the WCGS meteorological tower. A detailed description of the specific fog moni-toring program will be provided in forthcoming revisions to the WCGS ER(OLS) and FSAR Addendum. I
< ~
4 Rev. 2 450-1 6/81
WCGS-ER(OLS) f l l 0450.2 Please provide a transportation map detailing any (ER) controlled roads, uncontrolled roads, and rail-roads within two miles of the cooling lake. In addition, if available, provide data on the extent of traffic density on the controlled and uncon-trolled roads. R450.2 See Figure 450.2-1. Cof fey County has not developed traffic flow data for the roads near the cooling lake. The follow-ing data are annual ave rage daily traffic esti-mates (AADT) made by the Kansas flighway Commission for flighway 75 north of Burlington between the city limit and New Strawn. Year AADT 1972 3000 1976 2880 1978 3800 1980 4685 Traf fic counts were made by KG&E in 1979 to deter-mine the impact of construction related traffic on local highways. These counts would not be relevant to the operational period for WCGS. It is estimated that during operations the average daily traffic on the controlled access road to the plant will be between 350 and 400 vehicles. O Rev. 2 450-2 6/81
m._ . , . _ . .- _ . _ . _ . - _ _ . . __ _ . . _ TABLE 450.2 - 1 i L-_ _ 'xs _, p) Evacuation Routes Listing' (Sheet 1 of 2) Road Identification Subzone itouto Identification oer Figure 450.2-1 Cdnter (a) FAS 1935 cast (1) to Anderson County
. (0-2 mLle) (b) FAS 153 cast (2) to FAS-149 north (4) i to Kansas 31 north (5) to Osage County-
- A1 U.S. 75~ north (3) to Osage County 81 FAS 153' east (2) to FAS 149 north-(4) to Kansas 31 north (5) to Osage County C1 (a) FAS 149 north-(4) to Kansas 31 north (5) to Osage County ,
(b) FAS 10 east (6) to Anderson County 1 D1- _( a) J.S. 75 south (7) to Woodson County (b) FAS 10 west (8) to Lyon County (c) FAS 1472 (10) east to Anderson County '
- . El (a) U.S. 75 north (3) to Osage County j (b) U.S. 75 south (7) to Woodson County l i, A2 (a) U.S. 75 north (3) to Osage County l
(b) Kansas 31 north (5) to Osage County
- B2 FAS 1134 west (9) to FAS 149 north (4) to Kansas 31 north (5) to Osage County
, C2 (a) FAS 1935 (1) to Anderson County (b) FAS 10 cast (6) to Ande rson County j C3 (a) FAS 10 cast (6) to Anderson County (b) FA9 1472 (10) to FAS L135 north (11) to FAS 10 cast (6) to Anderson County (c) FAS 1135 south (11) to Kansas 57 cast (12) to Anderson County (a) Kansas 57 cast (12) to Ande rson County
- C4
- (b) FAS 1135 south (11) to Kansas 57 east (12) j to Anderson County D2 U.S. 75 south (7) to Woodson County D3 (a) . PAS 10 west (8) to Lyon County (b) U.S. 75 south (7) to Woodson County
~~s E2 FAS 10 west (8) to Lyon County Rev. 2 6/81
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1 TAPT.E 4 50. 2-1 (Sheet 2 of 2) Subzcne Ito u t e Identification por Figure 450.2-1 O I E3 (a) PAS 793 north (13) to old U.S. 50 west (15) to Lyon County (b) U.S. 75 north (3) to Osage County E4 (a) U.S. 75 north (3) to Osage County (b) PAS 793 north (13) to old U.S. 50 west (15) to Lyon County K1 Kansas 57 east (12) to Anderson County K2 Kansas 57 cast (12) to Anderson County K3 Kansas 57 west (14! to Greenwood County K4 Kansas 57 west (14) to Greenwood County K5 PAS 10 went (8) to Lyon County K6 FAS 152 north (16) to old U.S. 50 west (15) to Lyon County K7 (a) U.S. 75 north (5) t.c Osage County (b) Old U.S. 50 west (ii) to Lyon County K8 Kansas 31 north (5) to Osage County Note: tJumbe rs in parentheses indicate road segment n umbe rs as idt ntif ied in Figure 450.2-1. Rev. 2 6/81 l l
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WOLF CREEK GENERATING STATION 1 UNIT NO. l l ENVIRONMENTAL REPORT OPERATING LK:ENSC S7 AGE l Figure 450.2 - 1 l l Transportation Map (Showing Evacuation Routes) Rev. .. 2 6/81 -
WCGS-ER(OLS) h 0450.3 Please provide a copy of the latest version of the (ER) FOGALL Model User's Guide. R450.3 One complete copy of the FOGALL certification / use rs manual wc2 provided with formal response. This manual contains proprietary program code listings which are not to become public record. This information was provided only to assist the NRC in its evaluation of WCGS-ER(OLS) and WCGS FSAR Addendum. 0450.4 Please provide documentation of the procedura used (ER) to validate the FOGALL Model. R450.4 Tl procedure used to validate the FOGALL model is de- -ibed in the ca rt ification/use rs manual pro-videu in response to Question 450.3. The verification of FOGALL was performed by exc-cuting two test cases and manually calculating the expected results. One test case utilized source water tempe ratu re constant with time and area. The second case varied the source water tempera-ture over the source area cach hour. In addition, hand calculations were performed to ve ri fy that the results of each cubroutine conformed with the respective applied theoretical model or mathmeti-cal equation. The model design is based upon accepted principles of atmospheric physics; computed values were hand verified; and the test cases were designed to detect fog, no fog, ice, and no ice conditions at defined receptors. The validation procedure, therefore, provides a high degree of confidence that the FOGALL results are representative of actual conditions. O Rev. 2 ' 450-3 6/81 l
WCGS-ER(OLS)- , f
/T 473.0 RADIOLOGICAL ASSESSMENT BRANCH
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'NJ' 0470.1 Confirm that the land use ir Table 2.1-18 has not (ER) changed since 1978.
4 (2.1.3.2.4) R470.1 See new Tabic 2.1-18a which provides updated near-est receptor inforn.ation determined in 1980. Dose calculations presented in Sectico 5.2 are based upon the 1980 receptor information. Q470.2 Provide information concerning the location of the (ER) visitors center and an estimate of the number of (2.1.3.3.4* visitors anticipated annually. R470.2 The Visitor's Center is located in the EOF complex about 2.8 miles northwest of the power block (See Figure 2.1-6). The number of visitors anticipated annually at the visitor's Center is 5,000 - 7,000 based on projections of visits to the Wolf Creek < construction site. '. *O What is the fraction of daily intake of cows de- - 0470.3 (ER) rived from pasture during the grazing season? (2.1.-15) R470.3 Essentially 100 percent of the daily intake of cattle is derived from pasture during the grazing season. As the pasture becomes depleted late in
- each annual grazing season, farmer-stockmen may provide supplemental feed to their pastured live-stock.
Q470.4 Provide information concerning the population ! (ER) served by the City of LeRoy's Municipal Water (2.1.3.4.1) System. R470.4 The population of LeRoy determined during the 1980 census is 624 pe rsons . m I Rev. 2 470-1 6/81 1 - --
WCGS-E R (OLS ) f 0470.5 Provide a copy of the informa tion referenced in (ER) Section 5.2 that was to have been updated in mid-(5.2) 1980. R470.5 See revised Section 5.2 and Appendix 5A. 0470.6 Appe.idix 5A of the ER states that a summa ry of (ER) dose models and a list of assumptions used for (Appendix Wolf Creek were presented in Append'x 5.2A of the 5A) ER-Construction Permit Stage, however in reviewing this information, the addition of the computer code FOOD in the ER-OL became apparent. Therefore, please provide an updated summa ry of the dose models and assumptione used. R470.6 Appendix SA has been revised. Computer Code FOOD and other dose models have been replaced with more current computer codes (GASPAR, LADTAP II) and information in Appendix 5A is for these current codes. O O Rev. 2 j 470-2 6/81
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