NC0024406_Renewal Application_19960805

Duke Power Company
Electric System Support
13339 Hagers Ferry Road
Huntetsville, NC28078-7929
DUKE POWER
August 5 1996
Mr. David A. Goodrich
Permits and Engineering Unit
North Carolina Department of Environment,
Health and Natural Resources
P.O. Box 29535
Raleigh, North Carolina 27626-0535
Subject: Duke Power Company - Belews Creek Steam Station
NPDES Permit Renewal, NC#0024406 - Stokes County
File: MS -706.15
Certified Z 403 319 168
Dear 44P.-6earlmh:
The above referenced permit expires January 31, 1997. GS 143-215.1(c) and Part II.B.10 of
the subject permit requires the submittal of an application for renewal at least 180 days prior
to expiration.
Please find enclosed in triplicate, the application for renewal of the subject permit and a check
in the amount of $400.00 to cover the renewal processing fees pursuant to 15A NCAC
2B.0105(b). We request notification that the application is complete.
Please' note. that outfall 002 -and -outfall- 005 in the previous permit have been abandoned- and
that a.._ request - to'- reduce. sampling- frequency _ of selected parameters is - pending. Data
representative of station operation for the period of January through December 1995 is used
throughout the NPDES application' where available. In addition, supplemental information is
enclosed to reflect conditions for the station, selected pages of the Station's NPDES permit
marked up with suggested changes, and a report on physico-chemical and biological studies of
Belews Lake.
Should you have any questions or desire additional information, please contact Ron Lewis
[phone] or me at [phone].
Very Truly Yours,
o . arter
Technical Systems Manager
Electric Systems Support/Environmental Division
xc: David Russell NCDEHNR Regional Office, Winston-Salem
Printed on recycled paper

NPDES
Supplemental Information
for
Belews Creek Steam Station
Permit#0024406

GenerPage 1
al Information
Belews Creek Steam Station (BCSS) is a coal-fired electric generating plant
operated by Duke Power Company. BCSS is located on Belews Lake at NC
County Road 1908 approximately eight miles northeast of Walnut Cove in
Stokes County near Winston-Salem, North Carolina.
BCSS is the largest coal -burning station on the Duke system. The two unit
facility has consistently ranked as one of the most efficient coal plants in the
nation.
BCSS Units 1 and 2 began commercial production in August 1974 and
December 1975, respectively.. When operating at full power, the station sends
more than 2 million kilowatts of electricity over transmission lines to homes,
schools, businesses and industries of the Piedmont Carolinas.
An index to system descriptions and a line drawing showing the water flow
through BCSS follow, indicating sources of intake water, operations contributing
to the effluent, and treatment provided. The average daily flows in parentheses
for outfall 001 and outfall 003 are based on flows reported to NCDEHNR on the
monthly discharge monitoring reports required per the NPDES permit for BCSS
for the period of January through December 1995. Other flows on the line
drawing and in a brief narrative description of sources contributing to each
outfall effluent that follows are an approximation of average daily station
operation by operators.
Su /amental
Information

INDEX OF GENERAL INFORMATION
L Intake Screen Backwash
//. Once Through Non -Contact Cooling Water
A. OUTFALL 001
1. Non -contact Condenser Cooling Water
2. Closed Loop Recirculated Cooling Water System
3. Hydrogen and Oil Cooling Systems
B. Induced Draft Fan Motor Bearing Cooling Water
OUTFALL 003 - Ash Basin Treated Effluent
A. Yard Ho/ding Sump
1. Power House Sump
a. Water Treatment System
b. Condensate Feedwater System Effluent
C. Turbine and Boiler Room Drains
d. Proposed Groundwater Remediation
B. Fly and Bottom Ash Sluicing
C. OUTFALL 006
1. Boiler Cleaning Wastes
D. Coal Yard Sumps
1. Coal Pile Run-off
E. Ash Basin Run -Off
/V. Ash Basin Capacity
V. Sanitary Spray Irrigation System
V/. Storm Water
A. Yard Drainage to Intake Cana/
B. Yard Drainage to Discharge Cana/
VI/. Spill Prevention
A. O// Storage
V///. Hazardous Substances
IX. Belews Lake Balanced and Indigenous Populations
Page 2
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LINE DRAWING OF WATER FLOW THROUGH BELEWS CREEK STEAM STATION
COUNTY: STOKES STATE: NC
[INTAKE AREA OF BELEWS LAKE I
INDUCED DRAFT FAN
COOLING WATER (035 MGD)
t COOLING WATERI LOW & HIGH PRESSURE
MISCELLANEOUS USES:
SYTEM SERVICE WATER SYSTEM
COOLING. WASHDOWN & FIRE
PROTECTION
WA TER TREATMENT SYSTEM
INTAKE
SCREEN
BACKWASH
STATION AIR CONDITIONING ASH HOPPER SEALS &
(11.112 MGD)
COOLING
RCW
COOLER
SYSTEM (15.4
TURBINE AND BOILER ROOM
MGD)
DRAINS POWER HOUSE SUMP
HYDROGEN AND OIL COOLER
SYSTEM (5 SS MCD)
CONDENSER FEEDWATER
SYSTEM
SANITARYSYSTEM
(O.INU MGD)
EVAPORATIVE LOSSES
(11.111 mgd)
'
SPRAY IRRIGATION SYSTEM
................. YARD HOLDING
(3.85 MCD)
HOLDING POND
13 MCD) OUTFALLM.
COAL YARD SUMPS
(0.08 MGD)
I STORMWATER (0.08 MGD) STORMWATER
(11.47 MGD)
OUTFALL 001 BELEWS LAKE
(1124.1 MGD)
NC#0024406 P emit Appl.
SLUICE
ASH BASIN
OUTFAL 003
7.4 MGD)
DAN RIVER

Page 4
L Intake Screen Backwash
(0.02 mgd)
Each unit has four stationary intake screens of the same size (18 ft x 23
ft) and are removed for cleaning. The intake screens are backwashed at a
rate of 500 gpm for approximately five minutes each on as needed basis.
The total volume of water used is 0.02 mgd. This intake screen
backwash is discharged back into the station intake. The debris is
collected within a cleaning basin and consists mainly of twigs, leaves, and
other material indigenous to Belews Lake. The collected debris is removed
and composted.
//. Once Through Non -Contact Cooling Water
A. OUTFALL 001
1. Condenser Cooling Water
(1124.10 mgd)
Raw water from Belews Lake is passed through condensers and
auxiliary equipment on a "once -through" basis to cool equipment
and condense exhaust steam from the turbines. Cooling water
passes through a network of tubes in the condenser and selected
heat exchangers (e.g. turbine lube oil coolers, condensate coolers,
miscellaneous closed system coolers). This raw water in the
condenser tubes absorbs heat from a closed system of highly
purified exhaust steam from the turbines and converts it back to
water. The condensed exhaust steam is returned to the boilers and
recycled in this loop a number of times. The raw cooling water is
returned to the lake. No chemicals are added and only heat
rejected from the condensers and auxiliary equipment is absorbed,
hence the term "once through, non -contact cooling water" is
applied. _
The condensers at BCSS are cleaned mechanically. Normally,
amertap balls are cleaning the tubes on a continuous basis while
the plant is operating. Periodically, metal scrapers, plastic scrapers
or .rubber plugs are forced through the tubes to rid them of scale or
other deposits.
Each of the two units at BCSS have four condenser cooling water
(CCW) pumps. The capacities of these pumps are listed in Table 1.
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Information

Page 5
Normal plant operation of the CCW pumps is based on intake and
discharge temperatures and unit load. The maximum pumping
capacity is 1457.28 mgd and the average CCW flow for 1995 was
1124.10 mgd. To avoid a system trip that would suddenly reduce
the discharge flow 'at outfall 001, each unit is on an independent
system. This practice leads to a higher reliability factor for the
units and protection of aquatic life taking refuge in the . discharge
canal during cold weather.
Con
Table 1
censer Cooling
Water Pump Operating Conditii
Number of
pumps
Total Flow
(gpm)
Intake
Temperature
(°F)
1
184,000
2
333,000
<61
3
444,000
61-69
4
506,000
>69
2. Recirculated Cooling Water (RCW) Coolers
(15.4 mgd)
ms
Depending on the temperature of the raw lake water and the
operation of BCSS, once through non -contact condenser cooling
water is passed_ through the RCW coolers to maintain the closed
loop cooling water within the RCW system at 95°F or below. The
RCW system supplies cooling water to various equipment and is
composed of a storage tank, three 50% capacity RCW pumps, two
100% capacity heat exchangers (RCW coolers), and associated
piping and valves for the two units. Recirculated cooling water is
supplied from the CCW system to the RCW storage tank (capacity
of 19,000 gallons) and makeup water is added, as required per
tank level and temperature controls.
The maximum flow of once through non -contact condenser cooling
water through each of the two RCW coolers is 5360 gpm or 7.72
mgd. Non -contact cooling water discharged from the RCW coolers
combines with the condenser cooling water and is discharged from
outfall 001.
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3. Hydrogen and Oil Coors
(5.58 mgd)
Once through non -contact cooling water is supplied from the Low
Pressure Service Water System that draws water from the CCW
system to hydrogen and oil coolers. The system consists of two
High Pressure Generator Hydrogen Coolers (maximum combined
flow of 3,990 gpm), four Low Pressure Generator Hydrogen
Coolers (maximum combined flow of 3520 gpm), and two Turbine
Lube Oil Coolers (maximum combined flow of 7400 gpm) for each
BCSS unit. A maximum of 43.0 mgd of cooling water can flow
through these coolers when both units of BCSS are operated at full
load. Discharge from these coolers combines with the condenser
cooling water flow and discharged at outfall 001.
B. Induced Draft Fan Motor Bearing Cooling Water
(0.35 mgd)
Once through non -contact cooling water is supplied from the Low and
High Pressure Service Water System to the bearings of the induced draft
(ID) fans to remove excess heat. No chemicals are added to the once
through raw lake water discharged to Belews Lake. The rate of flow
through the control equipment is. 'approximately 0.86 mgd when both
units of BCSS are operated at full load.
OUTFALL 003 - Ash Basin Treated Effluent
(7.40 mgd)
The ash basin accommodates flows from the power house sumps, yard holding
sump, ash sluice lines, the chemical holding pond, the coal yard sumps, and
rainfall run-off from the watershed of the basin. Seepage from the toe -drains at
the base of the ash basin dikes goes to the Dan River. The toe -drains are
needed to allow, as designed, seepage to occur from the earthen dikes. This
ensures the structural integrity of the dikes.
A. Yard Ho/ding Sump
(3.85 mgd)
Waste can accumulate in the yard holding sump from the power house
sumps, the condenser feedwater system, and the coal yard sumps.
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Page 7
During a boiler cleaning, these wastes accumulate in the yard holding
sump and are then pumped to the chemical holding pond.
�. Power House Sumps
(3.85 mgd)
Wastes accumulate in the power house sumps that discharges to
the yard holding sump and includes wastewater from (1) water
treatment equipment, (2) floor wash water, (3) equipment cooling
water and (4) miscellaneous leaks„ These wastes originate from
the following systems:
a. Water Treatment System
(0.09 mgd)
The water treatment system consists of one retention tank,
two pressure filters (diatomaceous earth'), two activated
carbon filters, and one set of make up demineralizers. The
pressure filters each have a capacity of 500 gpm. Filters are
backwashed weekly with approximately 220 lbs of
diatomaceous- earth going to Station sumps that discharge to
the ash basin.
Make up demineralizers are operated in sequence (one cell at
a time). Regeneration of these cells is required
approximately every other day. A regeneration requires 60
gallons of 66°Be sulfuric acid and 300 gallons of 50%
sodium hydroxide. An average dilute waste chemical and
rinse flow of 0.17 mgd is realized (for one hour . per
regeneration). The diluted acid and caustic are discharged to
the yard holding sump and then pumped to the ash- basin.
The useful life of the resin varies and when replacement is
needed the spent resin is sluiced to the ash basin.
b. Condensate Feedwater System
(0.2 mgd)
The condensate feedwater system provides continuous flow-
through boiler feedwater to BCSS supercritical . pressure
boilers. Condensate polishing demineralizers of the
powdered resin type are used to filter the feedwater. The
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Page B
mixed anion -cation powdered resin provides filtering and ion
exchange. Spent resins and associated wastes are pumped
to the ash basin for treatment and disposal,
(1). Evaporative Losses, Soot Blowing
(0.10 mgd)
Exhaust steam from the turbine is used periodically to
blow soot off.the outside of the boiler tubes. Thus,
some of the condensate feedwater is evaporated in
the boiler.
C. Turbine and Boiler Room Drain System
(1.16 mgd)
Turbine and boiler room drains, receive flow from once
through non -contact cooling water of the Station air
conditioning system, the fire protection system, washdown,
and miscellaneous Station uses
1. Station Air Conditioning
(1.30 mgd)
Once through non -contact cooling water is supplied
from the Low Pressure Service Water System to cool
the Station air conditioning equipment. A maximum
combined flow of 3.46 mgd of cooling water can flow
through two chiller units. No chemicals are added to
the once through raw lake water that drains to the
Station sumps where it is pumped to the ash basin.
2. Fire Protection, Washdown, and
Miscellaneous Station uses
(1.07 mgd) _
The fire protection system, washdown, and
miscellaneous Station uses from closed system
drainage, cleaning, and testing can contain:
* Corrosion inhibitors, e.g. Calgon CS and Betz,
Powerline 32011 Biocides, e.g. Calgon H-300 and
H-5102
1 Molybdate based corrosion inhibitors are planned for future use.
2 Approval for Biocides Calgon H-300 and H-510 was given by letter to Ms. Dayna Russell
(DPC) from Mr. Preston Howard (NCDEHNR) dated 8/19/93.
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* Laboratory wastes
* Cleanings' (e.g. small heat exchangers) Dispersant,
e.g. polyacrylamide
* Wetting agent, e.g. sodium lauryl sulfate
* Detergent, e.g. tri -sodium phosphate.
* Leak testing, e.g. disodium fluorescing dye
* Miscellaneous system leakage's (small leaks from
pump packings and seals, valve seals, pipe
connections)
* Moisture separators on air compressor precipitators
* Floor wash water
* Emergency fire fighting water
* Ash sluice system overflow
* Low Volume Wastewater
d. Proposed Groundwater Remediation
(0.03 mgd)
A groundwater remediation is presently underway to recover
free petroleum product that leaked from a underground
storage tank. The water that is recovered is currently taken
off-site. In the future, after approval is granted by
NCDEHNR, it is proposed to use a total fluids recovery
system to recover contaminated groundwater and free
product from the site. Remediation system equipment will
be used to remove the petroleum from the recovered
groundwater, and the reclaimed petroleum would be
transported off-site for treatment while the treated
wastewater would be discharged to the ash basin via the
power house sump. If approved by NCDEHNR a maximum
flow rate of approximately 0.03 MGD will be discharged to
the ash basin from the groundwater remediation system.
B. Fly and Bottom Ash Sluicing
(2.75 mgd)
Electrostatic precipitators are used to remove fly ash from the stack
gases. The ash is treated in the flue gas ductwork with SO3 conditioning
to improve removal efficiency. Typically, the dry -fly ash captured in
1 To date small closed system cleanings (e.g. heat exchangers) have not used these
chemicals, reserved for future use.
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Page 10
these precipitators is collected in temporary storage silos for subsequent
disposal in a permitted on-site landfill or for recycling in off-site ash
utilization projects. If the system that collects the dry -fly ash is not
operating, then the fly ash can be sluiced to the ash basin. Bottom ash
from the boilers is usually water sluiced to holding cells for recycling
activities per reuse permit#WO0007211. In the case of equipment failure
or immediately following an outage, service water is used to sluice the
ash to the ash basin.
Electrostatic precipitators at BCSS are normally cleaned by mechanically
rapping the wires and the plates inside the precipitator. Before major
precipitator work is performed they are cleaned by a wash down. The
wash water is pumped to the .ash basin from the yard drain sumps.
C. OUTFALL 006
1. Boiler and Filter Cleaning Wastes
(0.003 mgd)
BCSS has two supercritical boilers that are cleaned on an as
needed basis. Tube 'inspections are done during outages to
determine when cleaning is needed. The chemical cleaning wastes
are pumped to the chemical holding pond. After proper treatment,
the pond effluent is discharged into the ash basin at a controlled
rate to provide further treatment. A list of the chemicals and
approximate amounts for one boiler cleaning is as follows:
Boiler Cleaning :Chemicals and Amounts Used Per Unit
Chemical
Amount
Hydroxyacetic acid
22,400 lbs
Formic Acid'
11,200 lbs
Ammonium Hydroxide
(26°Be')
150 gal
Ammonium Bifluoride
2,800 Ibs
Corrossion Inhibitor
(Proprietary)
500 lbs
Hazardous, substance as listed in 40 CFR 302.4
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Page 11
Two auxiliary boilers are cleaned with an alkaline boilout. These
cleanings are not performed routinely and are done on an infrequent
basis. The alkaline cleaning wastes are pumped to the ash basin.
A list of the chemicals and approximate quantities for one auxiliary
boiler alkaline boilout is listed below: .
Alkaline Boilouts (only after major boiler tube work)
The condensate polisher filters` and filtered water system filter are
cleaned with citric acid and sodium hydroxide on an as needed
basis. The -chemical .and, -quantity used per year for this cleaning is
listed below:
Chemical
Amount
pChemical
Soda Ash
300 Ib.
X=100 Detergent
(0.05%)
2 gal
Antifoam Agent
(0.025%)
1.5 gal
The condensate polisher filters` and filtered water system filter are
cleaned with citric acid and sodium hydroxide on an as needed
basis. The -chemical .and, -quantity used per year for this cleaning is
listed below:
Chemical
Amount
Citric acid _
600 lbs
Sodium Hydroxide
15,000 lbs
D. Coal Yard Sumps
(0.45 mgd)
1. Coal Pile Run-off
(0.08 mgd)
The coal yard covers approximately 51 .5 acres. The average
rainfall run-off is 0.08 mgd. This run-off is based on 40 inches of
rain per year with 50% run-off. During winter, freeze conditioning
agents (i.e. diethylene glycol) maybe added to coal by a vendor
prior to shipment or sprayed on the coal pile to prevent freezing.
Based on an application rate of two pints of 50 ppm diethylene
glycol per ton of coal and 10,000 tons of coal per train load, the
addition of freezing agents will not significantly alter the coal pile
run-off wastestream and the discharge of the ash basin at outfall
003.
Hazardous substance as listed in 40 CFR 302.4
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Page 12
Most of the coal yard drains into the ash basin near the point of
ash influent. Floor washwater from equipment in the coal handling
area and the remaining drainage from the coal yard flows to the
coal yard sumps where it is then pumped to the ash basin.
E. Ash Basin Run -Off
(0.47 mgd)
Non -point sources of storm water to the ash basin includes coal pile
runoff. Based on forty inches of rain per year with fifty percent run-off,
and the watershed area of the ash basin, the yearly average rainfall run-
off to the ash basin is 0.47 mgd.
Ash Basin Capacity
Part III Section R of the existing NPDES permit for BCSS requires the permittee
to provide and maintain at all times a minimum free water volume (between the
top of the sediment level and the minimum discharge elevation) equivalent to the
sum of the maximum 24 hour plant discharges plus all direct rainfall and all
runoff flows to the pond resulting from a 10 year, 24 hour rainfall event, when
using a runoff coefficient of 1.0.
Free water volume of ash basin at BCSS:
Estimate of runoff from 10yr/24 hr storm:
Natural drainage area of ash basin 655.0 acres
Yard Sumps 87.6 acres
Precipitation from 10yr/24 hr storm 5.1 inches
Total stormwater runoff to ash basin 315.6 Ac -ft
Estimate max. 24.hr dry weather waste stream discharging to ash basin:
From weekly station records, maximum recorded ash basin discharge on
8/15/86 with no mention of rainfall = 17.9 MGD
For conservatism, increase maximum discharge recorded at station by
10%: 0 7,900,000 gal x 1.1)/325,872 gal/Ac-ft = 60.4 Ac -ft
Free Water Volume = 315.6 + 60.4 = 376.0 Ac -ft
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Estimat
Page 13
Estimated quantity of solids (ash) to be discharged to ash basin from time
of most recent physical survey 0 1/3/93) to expiration of permit
6/30/2000 using 1/31/97 PROMOD coal consumption forecast:
Free Water Volume = 376.0 Ac -ft
Estimated Solids to Ash Basin = 312.2 Ac -ft
Required Volume = 688.3 Ac -ft.
From a 11/3/93 physical survey, estimate of total ash basin water volume
= 3.403 Ac -ft (pond elev. 790 msll
Conclusion: The ash basin at BCSS has sufficient capacity for the term of the
new permit, since the estimate of the total ash basin water
volume (3,403 ac -ft) is over four times the required volume
(688.3 ac -ft) for the term of the new permit..
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Estimated
Estimated
Estimated
Ash
Bottom Ash
Estimated
Time Period
Ash
Landfilled or
Discharged
Bottom Ash
Production
Recycled
to Ash Basin
Discharged to
0 000's tons)
0 000's tons)
0 000's tons)
Ash Basin
(Ac -ft)
Nov thru De
83.7
78.3
5.4
4.5
1993
1994
495.1
459.5
35.6
29.7
1995
426.8
397.9
28.9
24.2
Jan thru Jun
211.9
192.2
19.7
16.4
1996
Jul thru Dec
274.6
259.4
15.2
12.7
1996
1997
553.7
507.8
45.9
38.3
1998
506.1
465.4
40.7
34.0
1999
527.8
484.7
43.1
-35.9
2000
548.3
503.0
45.3
37.8
2001
558.8
512.3
46.5
38.8
2002
570.6
522.8
47.8
39.9
Total
4757.4
4383.3
374.1
312.2
Free Water Volume = 376.0 Ac -ft
Estimated Solids to Ash Basin = 312.2 Ac -ft
Required Volume = 688.3 Ac -ft.
From a 11/3/93 physical survey, estimate of total ash basin water volume
= 3.403 Ac -ft (pond elev. 790 msll
Conclusion: The ash basin at BCSS has sufficient capacity for the term of the
new permit, since the estimate of the total ash basin water
volume (3,403 ac -ft) is over four times the required volume
(688.3 ac -ft) for the term of the new permit..
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Page 14
V. Sanitary Spray Irrigation System
Sanitary waste is pumped to a spray irrigation system per permit #WO0005873.
The sanitary waste from the plant receives primary treatment in a 600,000
gallon capacity aerated lagoon. Drawoffs from the lagoon discharge to a
concrete chlorine contact chamber. To polish the effluent, the spray irrigation
system routes a circuit of water treated with chlorine over approximately seven
acres of land divided into .four vegetated plots, each with an area of 270 square
feet. The yearly loading per plot averaged approximately 6.1 inches per acre in
1995.
Vl. Storm Water
Non -point sources of storm water to the yard drainage system is based on forty
inches of rain per year with fifty percent run-off, and the yard watershed area,
the yearly average rainfall run-off to.Belews Lake is 0.08 mgd.
A. Yard Drainage to Intake Canal
(0.03 mgd)
B. Yard Drainage to Discharge Canal
(0.05 mgd)
Vll. Spill Prevention
A. Oil Storage
BCSS has one large above ground oil storage tank (260,000 gals). This
tank is surrounded by a dirt dike designed to contain the entire contents
of the tank in the event of an accidental rupture. All oil storage facilities
are covered under the BCSS Spill Prevention Control and Countermeasure
Plan.
VIII. Hazardous Substances
The following is a list of the hazardous substances located on site that are listed
in 40 CFR 302.4.1 These substances are identified in order to qualify for spill
1 See description of boiler and filter cleaning processes (pages 10 and 11)
for hazardous substances that may be on site when these system need to be
cleaned.
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Page 15
reporting exemptions as outlined in 40 CFR 117.12. These substances are
anticipated to be discharged to the ash basin on a continuous or intermittent
basis within the scope of relevant station operation. Values represent maximum
quantities usually on-site at any given time and do not necessarily reflect
quantities discharged. Various amounts of these substances may go to the ash
basin for treatment due to use in site laboratories, small leaks, spills, or drainage
from closed loop systems. Treatment of these substances and their by-products
is achieved by physical, chemical, and biological activity in the ash basin.
Chronic toxicity monitoring of the ash basin effluent (outfall 003) is required per
the BCSS permit.
Hazardous Substances at Belews r.rPPir Ctnam ct!m+;--
SUBSTANCE
QUANTITY
SOURCE/LOCATION
USE
Acetic acid
2 Ib
Lab/Warehouse
Water Analysis
Acetone
1 Ib
Lab
Water Analysis
Ammonia
5 Ib
Lab
pH control
Ammonium hydroxide
20001b
Powerhouse
pH control
Ammonium Molybdate
4 Ib
Lab
Water Analysis
Borates
1 Ib
Warehouse
Sanitary Cleaner
Butyl Carbitol
2401b
Crusher House
Dust Suppressant
Calcium hypochlorite
701b
Warehouse
Water
Analysis/Cleaner
Chlorodifluoroethane
15 Ib
Warehouse
Dust Suppressant
Chloroform
1 Ib
Lab
(to be deleted)
Cupric chloride
1 lb
Lab
Water Analysis
Cupric nitrate
1 Ib
Lab
Water Analysis
Cupric sulfate
6 Ib
Lab
Water Analysis
Dodecanoic acid
7.5 Ib
Warehouse
Cleaner
EDTA
5 lb
Warehouse
Cleaner
Ethanol
571b
Lab/Warehouse
- Water
Analysis/Cleaner
Ethylene glycol
3301b
Warehouse
Equipment cooling
Formaldehyde (34%)
1 gal
Lab/Warehouse
(to be deleted)
Hydrazine (54.5%)
220 gal
Powerhouse/Warehouse
Oxygen
Scavenger
Hydrazine sulfate
1 Ib
Lab
Water Analysis
Hydrochloric acid
12 gal
Lab/Warehouse
Water Analysis
Hydroflouric acid
1 Ib
Lab
Water Analysis
Hydrogen sulfide
13 Ib
Bulk Sulfur Tank
Condition Fly Ash
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DM"I r -
Nitric acid
1 Ib
Lab/Warehouse
Sample
Preservation
Oxalic acid
8 Ib
Lab
Water Analysis
Phosphoric acid
3 Ib
Lab/Warehouse
Water
Analysis/Cleaner
Potassium hydroxide
3 Ib
Lab
Water Analysis
Potassium permanganate
1 Ib
Powerhouse/Lab
Air/Water
Analysis
Silicic acid
25 Ib
Warehouse
Cleaner
Sodium bisulfite
0.5 Ib
Lab
Water Analysis
Sodium hydroxide (50%)
5000 gal
Powerhouse
Demineralizer
Sodium nitrite
1440 Ib
Powerhouse
Corrosion Inhibitor
Sodium nitrite
12 Ib
Crusher House
Dust Suppressant
Sodium sulfite
20 lb
Lab
Water Analysis
Sodium Tetraborate
Pentahydrate
400 Ib
Powerhouse
Corrosion Inhibitor
Styrene divinylbenzene
5200 Ib
Powerhouse
Water Treatment
Sulfuric acid
4000 Ib
Powerhouse
Demineralizer
Sulfuric acid
3 Ib
Lab
Water Analysis
IX. Belews Lake Balanced and Indigenous Populations
The attached report entitled, "Assessment of Balanced Indigenous Populations in
Belews Lake Near Belews Creek Steam Station", indicates balanced and
indigenous populations are recovering. Recovery of populations in Belews Lake
is associated with a decrease of selenium bioaccumulation in populations of
Belews Lake, following installation of a system to collect and landfill dry -fly ash
in 1984 and reroute of the ash basin discharge from Belews Lake to the Dan
River in 1985.. The fish eating advisory on Belews Lake was recently -revised
by the North Carolina Department of Environment, Health and Natural Resources
from all fish species to only three species (common carp, crappie, and redear
sunfish). Duke Power continues to maintain an environmental monitoring
program on Belews Lake and the Dan River to assess populations. Annual
summary reports of environmental monitoring of the Dan River per Part III.S of
the present NPDES permit indicates that reroute of the ash basin discharge from
Belews Lake to the Dan River has had no adverse impact on the balanced and
indigenous populations in the Dan River.
Supplemental
Information

Page 17
Duke Power Company's operating experience during the past five years under
the thermal limitations imposed in NPDES Permit No. NC#0024406
substantiates for Belews Creek Steam Station that the "thermal component of
the discharge assures the protection and propagation of shellfish, fish and
wildlife in and on the receiving body of water."
Per Part III.Q of the present permit, Duke Power requests that the thermal
monitoring and reporting requirements for lake samples be reduced to monitoring
only at the present site downstream of the Dam.
Supp/emental
Information

160.00
150.00
140.00
130.00
120.00
110.00
100.00
3 90.00
L
Z
80.00
L
1
n 70.00
tlJm
60.00
50.00
40.00
30.00
20.00
10.00
,9 1 8,
I I w
1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994
YEAR

BELEWS AND DAN RIVER STEAM STATION NPDES'PERMIT MONITORING PROGRAM
LOCATION PARAMETER BELEWS CREEK SS DAN RIVER SS
Condensor Cooling
Water Discharge Flow
Temperature
Ash Basin Discharge
Flow
Oil & Grease
pH
TSS
Total Copper
Total Iron
Total Arsenic
Total Nitrogen
Total Phosphorus
Sulfates
Sulfide
Barium
Fluoride
Acute Toxicity
Chronic Toxicity
Pollutant Analysis
OUTFALL 001
daily
daily (April -October)
weekly (November -March)
at uplake and at dam
OUTFALL 003
weekly
twice/month
twice/month
twice/month
monthly
monthly
monthly
monthly
monthly
monthly
monthly
qarterly (Feb, May, Aug, Nov)
annually
OUTFALL 001
daily
daily at discharge &
downstream at HWY 700
bridge crossing
OUTFALL 002
weekly
twice/month
twice/month
twice/month
twice/month
twice/month
quarterly at, above, &
below outfall 002
quarterly
quarterly
quarterly
quarterly
quarterly (Mar, Jun, Sep,
Dec)
annually

ASH BASIN t•
418 1�vslu� �`a
a
418.5 �
___18..0 .
• "" : ,'' ` ,�
x Q�422.0`t 417.2
•` `" r 'r
BELEW
CREEK '
4kX410 TION 418.1,.• . -
vZ
' -=410 0-.
z
`��- � '••'1 .` � 417.1
419.0-
•• *419 -4�_
419.. 2 , "
419.5
US. HWY 158
•405.0.
Figure 1 The Belews Lake study area near Belews Creek Steam Station.
RIVE17
I LLWAY
•414.0
423.3
KILOMETERS I 2 3 q
MILES 0 '
2 3
As/�C Y�c� (�0S/
rrCvz�q
--- --- - - � S a Y�f�cQ X10 ✓vv��
oyau �)

BELEWS LAKE DUKE POWER COMPANY ENVIRONMENTAL MONITORING LOCATIONS
LOCATIONS WATER CHEMISTRY MACROINVERTE- FISH
(See attached table) & BRATES &
SEDIMENTS (As & Se) PLANKTON
UPLAKE
• 405.0 Water in W & Su
Sediment in Sp
• 405.1
TRANSITION
e 419.1
• 419.2 Water in W & Su
• 419.3 Water in W & Su
Sediment in Sp
• 419.4
MAIN -LAKE
• 410.0 Water in W & Su
• 410.2
• 416.0 Water in W & Su
• 418.0 Water in W & Su
• 418.1
BIP in Su BIP in Su
NAA in Sp&F NAA in Sp&F
NAA in Sp & F
NAA in Sp&F
NAA in Sp&F
NAA in Sp&F
NAA in Sp & F
BIP in Su BIP in Su
NAA in Sp&F
NAA in Sp&F
BIP in Su BIP in Su
NAA in Sp&F
• 418.3
Water in W & Su
• 417.1
Sediment in Sp
• 417.2
Sediment in Sp
• 422.0
Sediment in Sp
• 423.3
Sediment in Sp
BIP=Balanced and Indigenous Population Monitoring
NAA=Neutron Activation Analyses
Q=Quarterly (Jan/Feb, Apr/May, Jul/Aug, Oct/Nov), Sp=Spring (Apr/May), Su=Summer (Jul/Aug), F=Fall (Oct/Nov),
W=Winter (Jan/Feb)

Belem Lake Recovery Monitoring for 1995
Parameters:
Locations
405.0
410.0
416.0
418.0
S/T
Depth
5 m
25 m
35m
20m
Copper
Lab Codes
S/T
S/P10
S/T
SOO
Water Chemistry Analyses
S/P10
Lend
HGA Pb S/P10 S/P10 S/P10 SOO
In-situ:
SOO
Manganese
ICP 24 S/P10 S/P10 S/P10 SOO
S/P
S/P10
Temperature
Hydrolab
S/P
S/P
S/P
S/P
Dissolved Oxygen '
Hydrolab
S/P
S/P
S/P
S/P
PH
Hydrolab
S/P
S/P
S/P
S/P
Conductivity
Hydrolab
S/P
S/P
S/P
S/P
Secchi Depth
P -Profile (0.3,1.2,...
S
S
S
S
Nutrients:
- Cores will be collected as followed: 405.0: 5 reps ® 3-5 m,
B - Bottom
- 419.3: 5 reps @ 2-3 m,14-17 m; 417.1: 5 reps ® 2-3m; 417.2:5 reps ® 5-7 m;
Ammonia
AA Nut
S/P10
S/P10
S/P10
S/P10
Nitrate+Nitrite
AA Nut
S/P10
S/P10
S/P10
S/P10
Total KjeldaW blitroge
AA TKN
S/P10
S/P10
_
Orthophosphate
AA Nut •
S/P10
S/P10
S/P10
SOO
Total Phosphorus
DG P,AA
S/P10
S/PIO
S/P10
S/P10
Major Cations:
Calcium
ICP_24
S/P10
S/P10
S/P10
S/P10
magnesium
ICP 24
S/PIO
S/P10
S/P10
SOO
Sodium
ICP_24
S/P10
S/P10
S/P10
S/P10
Potassium
ICP 24
S/P10
S/P10
S/P10
S/PIO
Major Anions:
Chloride
AA Nut
S/P10
S/P10
S/P10
SOO
Silica
AA Nut
S/P10
S/P10
S/P10
S/P10
Sulfate
UV_SO4
S/P10
S/P10
S/Pl0
S/P10
Alkalinity
F Alkf
S/P10
S/P10
S/P10
S/P10
Additional:
Turbidity
F_Tutb
S/P10
S/P10
S/P10
S/PIO
Total Susp Solids
S_TSSE
S/P10
S/P10
S/P10
S/P10
Total Organic Carbon
S TOC
S/P10
S/P10
BOD5
S BODL
S/P10
S/P10
Elemental Analyses:
418.3 419.2 419.3 417.1 417.2 422.0 423.3
0.3 m 8 to 17m 2-3 m 5-7 m 25-30 m 17 m
S/T S/P S/P
S/P
S/P S/P
S/T
S/P S/P
SIT
S/P S/P
S/T
S
S/T
S/P10
S/T
SOO
Copper
SOO
S/T
S/P10
S/T
SOO
S/T S/P10
S/P S/P10
S/T S/PIO
S/T S/P10
S/P
S/P10
S/P
S/P10
S/P
S/P10
S/T
S/Pl0
S/P S/P10
S/T S/P10
Aluminum
ICP_24 S/P10 S/P10 SOO SOO
S/T
S/P10
Arsenic
HGA As S/P10 S/P10 S/P10 S/P10
S/T S/P10
SOO
Cadmium
HGA Fd S/P10 S/P10 S/P10 SOO
S/T
SOO
Copper
HGA_Cu' S/P10 S/P10 S/P10 S/P10
S/P
S/P10
Iron
ICP_24 S/P10 S/P10 SOO SOO
S/P
S/P10
Lend
HGA Pb S/P10 S/P10 S/P10 SOO
S/T
SOO
Manganese
ICP 24 S/P10 S/P10 S/P10 SOO
S/P
S/P10
Selenium
HGA So S/P10 SOO SOO SOO
S/T S/P10
SOO
Zinc
ICP_24 SOO SOO SOO S/PlO
S/P
S/PIO
Sediment Chemistry Analyses
Sediment Cores Sampl S_SEDF AB/5
A/B/5 AB/5 AB/5 A/B/5 A113/5
Codes:
AB/C - Frequency of samphng/Depth Interni& Number of Replicates
S - Semiannually (Feb-Mar,Aug-Sep) '
T - Surface (0.3 m)
A - Annually (hby)
P -Profile (0.3,1.2,...
to bottom)
• - Cores will be analyzed for As, Cd. Cu; Se, and Zn by NAA
P10 - Profile (0.3,10, 20, bottom)
- Cores will be collected as followed: 405.0: 5 reps ® 3-5 m,
B - Bottom
- 419.3: 5 reps @ 2-3 m,14-17 m; 417.1: 5 reps ® 2-3m; 417.2:5 reps ® 5-7 m;
- 422.0: 5 reps (d 25-30 m; 423.3: 5 reps ® 2-3 m, 5-7 m, 14-16 m
.

f�
728.07050=732.0--
N DRSS .
vA —NC 770
/ T
I NC
I I
^• \i -T I
Eden o
NC 700
I.
I NC 135 Ash Basin
� Madison
%^" r 733.0 g
' A.
A :
. _ d
Dan River NC 07 NC 14
US 311
730.0
c fish
Ash Basin
'L Belews }
BCSS
Lake
I .
US 220
Figure 2. The Dan River study area near Dan River Steam Station.
o sjti d1xh� rC�,e►' GSI ��Sr�
i�1aS� Was

DAN RIVER ENVIRONMENTAL MONITORING LOCATIONS
LOCATIONS WATER CHEMISTRY MACROINVERTE- FISH
(Temp, DO, pH, Cond, BRATES
705.0 at HWY 700
downstream of DRSS
710.0 atHWY311
upstream of BCSS
720.0 at Madison
downstream of BCSS
728.0 above Smith R.
upstream of DRSS
730.0 below Smith R
upstream of DRSS
731.0 intake DRSS
733.0 discharge DRSS
Alk, TSS, Sulfate, Ca,
As, Cd, Cu, Se,& Zn) &
SEDIMENTS (NAA for
As & Se)
Water - Q
Sediments - Sp
Water - Q
Sediments - Sp
Water - Q
Sediments - Sp
Water - Q
Sediments - Sp
732.0 at NC/VA border Water - Q
downstream of DRSS Sediments - Sp
& Propose replacing
with Location 05.0
BIP in Su
NAA for As, Cu, Se,
&Zn in Su
NAA for As, Cu, Se,
& Zn in Su
BIP in Su
BIP in Su
BIP in Su
BIP in W and Su
NAA Se & Zn in Su
BIP in Su
NAA Se & Zn in Su
BIP in Su
NAA Se & Zn in Su
BIP in W and Su
BIP in W and Su
BIP in W and Su
moved to Location 705 moved to Location 705
BIP=Balanced and Indigenous Population Monitoring
BCSS=Belews Creek Steam Station, DRSS=Dan River Steam Station
NAA Neutron Activation Analyses
Q=Quarterly (Jan/Feb, Apr/May, Jul/Aug, Oct/Nov), Sp=Spring (Apr/May), Su=Summer (Jul/Aug), F=Fall (Oct/Nov),
W=Winter (Jan/Feb)