NC0004774_Waste Water Permit Submittal_20150318

doll) DUKE Marty K Sideds
Senior Vice President
le ENERGY. Environmental,Health and Safety
528 South Church Street
Mal Code:EC3XP
Charlotte,NC 28202
[phone]
March 18,2015
North Carolina Division of Water Resources
1617 Mail Service Center
Raleigh NC 27699-1617
Attn:Jeff Poupart,Water Quality Permitting Section Chief
Subject NPDES Waste Water Permit Submittal
Supplemental information
Dear: Mr. Poupart,
Duke Energy is submitting herewith a revised supplemental narrative, induding dewatering
language and dewatering data, in support of the Buck Station NPDES application package
previously provided in mid-July 2014, mid-October 2014,October 31 2014 and December 18,
2014. Please include this supplemental information in that package for your review.
If you have any questions regarding these materials, please contact Mr. Steve Cahoon at(919)
546-7457,[e-mail].
1 cert,wider penalty of law,that this document and all attachments were prepared under my direction or
supervision in accordance with a system designed to assure that qua! ed personnel properly gather and
evaluate the information submitted. Based on my inquiry of the person or persons who manage the system,or
those persons directly responsible for gathering the information,the information submitted is,to the best of my
knowledge and belief true,accurate,and complete. I am aware that there are significant penalties for
submitting false information,including the possibility of fines and imprisonment for knowing violations.
Sincerely,
i4.4))...A.4.;
arry . Sideris
SVP, Environmental Health and Safety
RECEIVED/DENRIDWR
MAR 1 9 2015
Water Quality
Permitting Section

Attachment
Buck Station
NC0004774
Updated Supplemental Information with
Dewatering Language and Dewatering Data
RECEIVEDIDENRIDWR
MAR . 9 2015
Water Quality
Permitting Section

NPDES Supplemental Information
for
Buck Steam Station
NPDES Permit No. NC0004774
RECEIVEDIDENRIDWR
MAR i 9 2015
March 2015
Water Quality
Permitting Sectior

NPDES Supplemental Information
Buck Steam Station I NPDES Permit No.NC0004774
March 2015
I. General Information
Buck Steam Station (BSS) is a previously active fossil-fueled, electric generating plant located in Rowan
County approximately three miles east of Spencer, North Carolina. The station has six retired coal-fired
generating units that are in the process of being decommissioned. The original two coal-fired units(Units
1 and 2)were put into service in 1926. Units 3 and 4 were retired in mid-2011, and Units 5 and 6 were
retired in April 2013. The station also had three oil-or gas-fired combustion turbine units(Units 7, 8, and
9) that were retired in October 2012 and partially removed in 2014. The former coal-fired and oil-fired
station generation area encompasses approximately 50 acres.
The BSS property encompasses approximately 643 acres that border the southern shore of the Yadkin
River in the upper reaches of High Rock Lake. The station is accessed from Dukeville Road off of Long
Ferry Road. The facility includes a Powerhouse, former coal storage yard located south of the
Powerhouse that encompasses approximately 4 acres, the Units 3 and 4 Switchyard located immediately
east of the Powerhouse that encompasses 1 acre, and the Units 5 and 6 Switchyard located immediately
southwest of the Powerhouse that encompasses 1.3 acres. The coal unloading and handling operation
and empty fuel oil storage tank and associated fuel unloading station has been decommissioned. The
facility currently contains two warehouses, paved parking areas, rail lines, paved roadways, and gravel-
surfaced roadways.
Three active ash settling basins (Cells 1, 2, and 3) are located at BSS (the new primary cell, the old
primary cell, and the secondary cell) generally southeast of the station Powerhouse. These three basins
are interconnected and have a combined total natural drainage area of approximately 372 acres. An
additional approximately 73 acres of stormwater runoff from certain station yard areas is also routed to
the yard sump and subsequently pumped to this ash basin system. Discharge structures conveying
stormwater runoff at BSS include various corrugated metal pipes(CMP)and steel pipes.
The Buck Tie Station is a large 230 kV and 110 kV regional substation facility located within the BSS
property boundaries approximately 1,500 ft south and upgradient of the Powerhouse. This tie station is a
separate facility unassociated with the BSS,and is neither inspected nor maintained by BSS personnel.
The Buck Combustion Turbine Combined Cycle(CTCC)station is a new generating facility located south
of the Buck Tie Station within the BSS property boundaries. The CTCC station came online in late 2011
and is a separate facility from the BSS from a NPDES permitting standpoint. In addition, BSS maintains
an up-to-date Spill Prevention Control and Countermeasure(SPCC) Plan in place in accordance with the
U.S. Environmental Protection Agency(USEPA)Oil Pollution Prevention Regulation 40 CFR Part 112.
II. Outfall 002 -Ash Basin
Coal Station&Simple Cycle Combustion Turbines
Waste streams generated from the BSS Powerhouse and adjoining land(stormwater)are currently routed
to a yard sump located east of the BSS Powerhouse. The yard sump is configured to house four vertical
sump pumps which pump collected wastewater to Cell 2.
The wastewater generated from the BSS Powerhouse includes groundwater seepage through the plant
sub-structure and the turbine building and boiler building sumps, chiller condensate drains, sanitary
waste, and well water softer backwash waste. The BSS Powerhouse wastewater will continue to be
generated until the Powerhouse is fully decommissioned, demolished, and graded for overland
stormwater flow.
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NPDES Supplemental Information
Buck Steam Station I NPDES Permit No.NC0004774
February 2015
BSS Powerhouse Waste Water
The BSS powerhouse sump water originates from both the boiler and turbine rooms and is routed to the
yard sump. Based on review of inflow sources to the BSS sump pumps,existing pump curves, and visual
observations, an intermittent flow of approximately 900 gallons per minute (gpm) with an operational
frequency of 5 minutes four to five times per hour has been determined. This equates to an average
continuous flow of approximately 300 gpm to the yard sump.
Storm Water to Ash Basin
The ash basin at BSS accommodates storm water flows from the yard drainage sump and rainfall runoff
from the basin watershed area. The average rainfall runoff flows are based on 44 inches of rain per year
with 100% runoff from the pond surfaces and 50% runoff from other areas.The average runoff for the ash
basin watershed area is 0.299 million gallons per day(MGD).The coal yard drainage at BSS drains to the
wastewater sump and is then pumped to the ash basin.The coal yard has been modified has an average
runoff of 0.065 MGD based on 44 inches of rain per year with 50% runoff. Averaged over a typical year,
the total storm water runoff that goes to the ash basin is approximately 0.364 MGD.
Sanitary Wastes and Potable Water
BSS uses an on-site well for its sanitary and potable water needs.The well water passes through a water
softening system, a reverse osmosis system and is then chlorinated for disinfection purposes. The water
conditioner is regenerated once every 25,000 gallons for 2 hours. The regeneration demands
approximately 1,600 lbs of water softener salt pellets per month and 1,200 gallons of water per
regeneration. The estimated average flow of domestic waste is 0.002 MGD. Effluent from the well is
discharged to the yard sump and then to the ash basin.
Combined Cycle Plant
Buck Combustion Turbine Combined Cycle Addendum to the Buck NPDES Application
As described in Section I, full commercial operations for the CTCC station came online in late 2011. The
start-up and associated NPDES discharges from the Combined Cycle system testing and commissioning
operations began November of 2011.
Wastewaters at the CTCC consist of surface condenser cooling tower blowdown, reverse osmosis reject
wastes, treated sanitary effluent, oil/water separator treated effluent, and boiler blowdown. These waste
waters are routed to Cell 1 with subsequent gravity flow to Cell 2 and 3. The make-up water treatment
system is comprised of a clarifier, gravity filters,two pass reverse osmosis system(RO), and a mixed bed
ion exchange polisher demineralizer. Make-up water is fed to the boilers to generate steam to turn the
turbines.
Regulatory notifications will be made including the completion of a biocide 101 worksheet to the state for
biocide use 90 days prior to anticipated discharge.
Service Water
influent
Make-up water from the Yadkin River is conveyed through three raw water pumps to a Graver clarifier.
The pH is adjusted with caustic, and coagulant(ferric sulfate), polymer, and sodium hypochlorite are also
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NPDES Supplemental Information
Buck Steam Station I NPDES Permit No.NC0004774
February 2015
added. Sludge is removed via sludge pumps and sent through a thickener where more polymer is added.
Ultimately, the sludge is sent to a plate and frame filter press for dewatering and then to a permitted
landfill for disposal.
Water from the clarifier is further treated by the gravity filters and sodium hypochlorite is added for
biological control. The filtered water is stored in the Fire Water/Service Water Tank. This filtered water
feeds the plant fire main and supplies the service water pumps.
Boiler Make-Up Water/Condensate
Boiler make-up water is fed from the Fire/Service Water Tank(300,000 gallon tank)and sent through the
Reverse Osmosis(RO) system to the mixed bed demineralizer cells. An anti-scalant is added to the RO
inlet to reduce scale formation. Sodium hydroxide is added for pH control to convert carbon (CO2)
bicarbonate. Sodium bisulfite is also injected to reduce any residual chlorine at the RO inlet to chloride
ion.
The auxiliary boiler feed water is treated with ammonia and an oxygen scavenger.
Citric acid and sodium hypochlorite is used in the Ultra Filtration (UF) system during chemical backwash
cycles. Citric acid is used in the RO system to remove scale and mineral deposits during cleaning cycles.
Boiler water/condensate is further treated at the Heat Recovery Steam Generator (HRSG) with the
addition of phosphates to protect from corrosion and ammonia for pH control.
Condenser Cooling Water
Condenser Cooling Water(CCW)is supplied through filtered water sent to the 10-cell cooling tower. This
water is recirculated and cycled with approximately 5% make up added hourly to account for blowdown
and evaporation loss. CCW water is treated with a dispersant corrosion inhibitor, sodium hypochlorite and
a non oxidizing biocide.
Cooling tower blowdown is treated with sodium bisulfite for residual chlorine reduction to chloride ion prior
to the water being sent to the waste water sump. Effluent from the wastewater sump is piped to the
primary ash basin.
The CCW pumps circulate 94,000 gpm. There are 2 CCW pumps installed on this system. The cooling
tower blowdown rate averages 816 gpm.
The maximum capacity of the cooling tower is approximately 197,500 ft3 or 1,477,620 gallons. At the
normal water level,the capacity is 151,600 ft3 or 1,133,870 gallons.
Chiller Cooling Towers
The four inlet air chillers have cooling water that is treated with a dispersant corrosion inhibitor, sodium
hypochlorite and a non oxidizing biocide. Blowdown water is sent to the two chiller sumps. Ultimately, the
chiller tower blowdown water is pumped to the cooling tower basin.
HRSG and Auxiliary Boiler Blowdown
All blowdown from the HRSG drains, auxiliary boiler, demineralizer water treatment, and the boiler
blowdown tank are routed to the boiler blowdown sump.This sump discharges to the cooling tower basin.
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February 2015
Closed Loop Cooling System
The closed loop cooling system blowdown from the heat exchangers is also routed to the cooling tower
basin.
Sanitary Waste System
Sanitary waste is routed through the lift station and pumped to a package plant. This unit includes a
chlorination chamber (sodium hypochlorite tablets). Effluent is ultimately pumped to the waste water
sump.
Plant Drainage System
All yard and floor drains from the generation equipment areas and auxiliary systems are routed to a
common drain system and through an Oil Water Separator (OWS). The OWS discharges to the
wastewater collection sump.
Drains from the water treatment building area, fire protection system, sanitary waste system, condenser
circulating system, and cooling tower blowdown are routed to a wastewater collection sump. This effluent
is pumped to the primary ash basin.
Containments for all transformers, the ammonia tank, and unloading area are routed to the storm drain
system. Drains from the cooling tower chemical feed sumps and unloading areas are also routed to the
plant drain system.
De-Watering
At the present time, Duke Energy is expecting to discharge the wastewater generated from the
dewatering and removal of ash from the site through the current Outfall 002. To facilitate the excavation
and transfer of ash from Cells 2 and 3 to Cell 1 prior to being capped in place (based upon the current
closure strategy dependent upon groundwater modeling results), dewatering of the ash basins will be
required. It is anticipated that as dewatering proceeds, some additional treatment may be needed to
meet the current and anticipated NPDES permit discharge limits in place at Outfall 002 downstream from
the ash basin. The following definitions may be useful when considering these activities:
• Ash basin free water.Water in an ash basin located above the settled layer of ash.Ash basin free
water has undergone treatment in the ash basin, has the same general characteristics as water
discharged when the facility was active sluicing ash to the ash basin, is largely devoid of Total
Suspended Solids and meets all applicable NPDES permit limits.
• Ash basin interstitial water. Water in an ash basin that is located within the pore space of
accumulated wastewater sludge or slurry. Ash basin interstitial water must be removed by some
means such as trenching, well points, etc. and would likely require additional treatment before
being released to the environment.
The process we envision for dewatering the ash basins to enable excavation and ash removal is as
follows:
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NPDES Supplemental Information
Buck Steam Station I NPDES Permit No.NC0004774
February 2015
• Free water removal will occur simultaneously from Cells 1, 2 and 3. Initial drawdown of Cell 1 will
be accomplished by removal of upper layer stop logs at the discharge tower to Cell 2, and
likewise Cell 2 to Cell 3. Interstitial water removal will be accomplished through rim ditching,
trenching, and pumping. Treatment of dewatering wastewater may be completed via chemical
and/or physical processes prior to discharge via Outfall 002. This treatment system may require
the addition of a coagulant and/or flocculent to enhance solids removal. Compliance monitoring
required by the NPDES Permit will be performed as specified in the NPDES permit.
The following table presents a summary of the BUCK CTCC chemical and tank information.
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NPDES Supplemental Information
Buck Steam Station I NPDES Permit No.NC0004774
February 2015
BUCK CTCC Chemical and Tank Information
Condensate/Feed Water/Boiler Feed Rate
HRSG11 Phosphate 300 gal tank 0-250 gpd
HRSG12 Phosphate 300 gal tank 0-250 gpd
/Aqueous Ammonia 300 gal tote 0-25 gpd
Auxiliary Boiler
Aqueous Ammonia 300 gal tote 0-0.5 gpd
Oxygen Scavenger 300 gal tote 0-0.5 gpd
Cooling Tower
Dispersant/Corrosion
Inhibitor 2,000 gal tank 0-50 gpd
Sodium Hypochlorite 6,000 gal tank 0-500 gpd
Non-Oxidizing Biocide 300 gal tote 0-500 gpd
Sodium Bisulfite 300 gal tote 0-3 gpd
Cooling Tower Chiller A/B
Dispersant/Corrosion
Inhibitor 2,000 gal tank 0-5 gpd Chemical feed tank is shared with Cooling Tower
Sodium Hypochlorite 6,000 gal tank 0-20 gpd Chemical feed tank is shared with Cooling Tower
Non-Oxidizing Biocide 300 gal tote 0-50 gpd Chemical feed tote is shared with Cooling Tower
Corrosion Inhibitor 300 gal tote 0-1 gpd
Closed Cooling
Biocide Pot feeder in loop-manual dosage-monthly
Glycol Pot feeder in loop-manual dosage-monthly
Filtered Water System
Sodium Hypochlorite 6,000 gal tank 0-576 gpd
Clarifier Polymer 300 gal tote 0-24 gpd
Thickener Polymer 300 gal tote 0-108 gpd
Coagulant 5,000 gal tank 0-576 gpd
Caustic 3,000
UF/RO/Demin
Citric Acid 300 gal tote 0-48 gpd
Sodium Hypochlorite 300 gal tote 0-48 gpd
Antiscalant 300 gal tote 0-16 gpd
Caustic 300 gal tote 0-16 gpd
Sodium Bisulfite 300 gal tote 0-16 gpd Chemical feed tote is shared with Cooling Tower
SCR
Aqueous Ammonia 20,000 gal tank
Sanitary Wastewater Package Plant
Sodium Hypochlorite Tablets Refill as needed
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NPDES Supplemental Information
Buck Steam Station I NPDES Permit No.NC0004774
February 2015
III. Outfall 002A—Yard Sump Overflow
An overflow pipe that directs flow from the sump to the Yadkin River was included in the construction of
the yard sump. Should the pumps in the yard sump lose power, experience a mechanical failure, or
become inundated during a large storm event, the sump would overflow through a pipe into the Yadkin
River.Overflow from this sump is a rare occurrence.
IV. Outfall 004- Intake Screen Backwash
This outfall provides make-up water to the CTCC and used to provide water to the BSS, which is no
longer in service. Intake screens are backwashed at a rate of 255,000 gallons per day (gpd) with
untreated river water.The solid material washed from the screens is collected by a trough and returned to
the lake below a retaining wall downstream from the plant intake. The debris collected on the screens
consists mainly of twigs, leaves, and other materials indigenous to the river and is therefore returned to
the river without any adverse environmental impact.
V. Table 2c-3 Hazardous and Toxic Substances
At BSS,the potential for a toxic and/or hazardous substances being discharge is very low. In reference to
Item V-D of Form 2-C, the substances identified under Table 2c-3 that may be in the ash basin discharge
are as follows:
• Asbestos:Asbestos is present in parts of the station's insulation. The potential exists for asbestos
to be released during an asbestos removal and handling operation and through degradation of
insulation. The amount of asbestos in the ash basin is expected to be at extremely low
concentrations.
• Cyclohexanone: Cyclohexanone is contained in thinners and solvents. The amount of
cyclohexanone on-site in 2014 was less than 15 pounds. Therefore, any cyclohexanone in the
ash basin would be at very low concentrations.
• Xylene:Xylene is primarily at CTCC in gasoline and diesel fuel. Secondary containment systems
are in place in order to prevent xylene from reaching the ash basin. If any xylene did reach the
ash basin, it would be at very low concentrations.
• Others: During the course of the year, products such as commercial cleaners and laboratory
reagents may be purchased which contain very low levels of a substance found in Table 2c-3.
Thus,any discharge of these products to the ash basin would be at very low concentrations.
VI. 40 CFR 117 and CERCLA Hazardous Substances
The Hazardous Substance Table below identifies hazardous substances located on-site that may be
released to the ash basin during a spill in quantities equal to or greater than the reportable quantity(RQ)
levels as referenced in 40 CFR 117, 302 and 355.This list is being provided in order to qualify for the spill
reportability exemption under 40 CFR 117 and the Comprehensive, Environmental, Response,
Compensation and Liability Act.
Hazardous Substance Table
Substance Quantity(lbs.t Source
Sodium Hypochlorite 499,300 Sodium Hypo Tank(Cooling Tower)
Sodium Hypochlorite 499,300 Sodium Hyp Tank(Clarifier)
Ferric Sulfate 499,200 Ferric Sulfate Tank(Clarifier)
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NPDES Supplemental Information
Buck Steam Station I NPDES Permit No.NC0004774
February 2015
Dispersant/Corrosion 21,600 Dispersant/Corrosion Tank(Cooling Inhibitor'Tower)
Caustic 280,800 Caustic Storage Tank(Clarifier)
Ammonium Hydroxide 1,148,000 Ammonium Hydroxide Tank
Note:
1The dispersant/corrosion inhibitor is stored in a 2,000-gallon tank and includes 9.3% Phosphoric Acid, 18%Tagged
High Stress Polymer,and 9%Phoshinosuccinic Oligomer.
VII. Ash Basin Capacity
Wet Weather Detention Volume is the sum of the runoff accumulated in the ash basin that results from a
10-year, 24-hour storm (assuming 100% runoff) plus the maximum 24-hour dry weather waste stream
which discharges to the Ash Basin(refer to NPDES Permit NC0004774).
I. Estimate Runoff to the Ash Basin from a 10-year,24-hour storm:
1. Natural Drainage Area of Ash Basin
New Primary Cell(Cell 1) 173.0
Old Primary Cell(Cell 2) 152.0
Secondary Cell(Cell 3) 47.0
Station Yard Drainage Area Pumped to Ash Basin= 27.0
Total= 399.0
2. Precipitation from 10-yr 24-hr storm = 5.1
3. Total Stormwater Runoff to Ash Basin= 169.58
(Assuming 100% runoff)
II. Estimated Maximum 24-hr Dry Weather Waste Stream Discharging to Ash Basin:
1. Maximum recorded Ash Basin Discharge= 6,000,000
2. Increase maximum daily discharge by 10%for
conservatism and convert units to acre-feet= 2.0.25
III. Wet Weather Detention Volume:
Sum of Parts I.and II. = 189.83
IV. Estimated Quantity of Solids(Ash)to be discharged to Ash Basin through December 31,2016:
Actual or
Estimated Estimated Estimated
Coal Ash Ash
Consumption Production Production
Time Period (1000's tons) %Ash (1000's tons) (Ac-ft)*
(Sept-Dec)
2005 6,010 15.60% 40.6 33.89
2006 17,485 14.80% 112 93.50
2007 18,930 13.20% 105.6 88.15
2008 14,470 12.80% 77.9 65.03
2009 3,880 13.00% 27.3 22.79
2010 7,039.0 12.50% 36.70 30.64
2011 4,006.0 9.60% 15.30 12.77
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NPDES Supplemental Information
Buck Steam Station I NPDES Permit No.NC0004774
February 2015
2012 1,000.0 9.60% 3.80 3.17
2013 1,086.0 9.60% 4.20 3.51
2014 1,925.0 9.60% 7.40 6.18
2015 0.0 0.00% 0.00 0.00
2016 0.0 0.00% 0.00 0.00
Total 8,017.00 30.70 359.63
*Calculation assumes an in-place ash density of 55 lbs per cubic foot.
V. Estimated Total Storage Volume Required through 2016:
Wet Weather Detention Volume= 189.8 Acre-feet
Estimated Solids to Ash Basin Sept.2005-Dec.2016= 359.6 Acre-feet
Total= 549.5 Acre-feet
VI. Results:
Additional Primary Cell 207.4 Acre-feet
2009 Ash Basin Cleanout 80.6 Acre-feet
Old Primary Cell 170.5 Acre-feet
Secondary Cell 121.1 Acre-feet
Total 579.6 Acre-feet
Note:Available Storage based on basin survey dated 8/25/2005
Required Storage Volume Through 12/31/2016: 549.5 Acre-feet
Based on these calculations,there is sufficient capacity in the ash basin to provide the
retention volume specified in the permit through the year 2016.
VIII. Buck Steam Station Balanced Indigenous Population
The BSS operating experience, under the thermal limitations imposed in NPDES Permit No. NC0004774
and field data collected (see attached report), substantiates the discharge from BSS is such that the
protection and propagation of a balanced indigenous aquatic community in the Yadkin River is assured.
Accordingly, Duke Energy Carolinas, LLC requests a continuation of the thermal variance for Outfall 001,
as allowed under NC Administrative Code 15A NCAC 02B .0208(b)and also section 316(a)of the Clean
Water Act.
Duke Energy Carolinas, LLC also requests that the restriction under A (1) for Outfall 001, which limits
stream flow usage, be eliminated. The thermal restrictions are sufficient to protect the aquatic community
as indicated by the attached 2011 BIP report.
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Buck Plant Ash Basin Water Characterization Water Samples Collected January 9, 2015
Sample Description
20-S
Parameter Units Free AB 1 Free AB 2 Free AB 3 Free AB 3 E-20-D E-20-D E- E-20-S E-20-S E-2-D
Surf Surf Surf 4 ft, E-20-D (10u filter) (20u filter) E-20-S (0.45u (10u filter) (20u filter) (0.45u
filter) filter)
Oil and Grease mg/L <5 <5 <5 N/A N/A N/A N/A N/A N/A N/A N/A N/A
Not+NO3 mg/I 6.9 1.3 0.021 0.029 0.022 0.069 0.04 <0.01 0.068 0.071 0.179 0.056
Total Kjeldahl Nitrogen mg/I 2.3 1.3 1.1 1.1 0.47 0.36 0.33 1.3 0.77 <0.15 0.4 0.32
Bromide mg/I <0.5 <0.5 <0.5 <0.5 <0.5 <0.5 <0.5 <0.5 <0.5 <0.5 <0.5 <0.5
Chloride mg/I 75.15 63.3 57.39 57.97 75.8 75.11 74.97 79.02 78.15 78.05 77.23 76.02
Fluoride mg/I <0.5 <0.5 <0.5 <0.5 0.5815 0.569 0.5765 _ 0.668 0.6635 0.6565 0.6575 0.566
Sulfate pg/I 174 130.5 128.8 129.2 187.5 186 186.1 180.4 178.1 177.8 176.9 187.7
Aluminum(Al) mg/I 2.56 0.483 0.108 0.126 21.3 0.23 1.51 32.8 0.031 0.22 1.67 0.083
Barium(Ba) mg/I 0.144 0.073 0.085 0.089 0.643 0.174 0.203 0.974 0.17 0.175 0.204 0.171
Boron(B) mg/I 0.29 0.284 0.287 0.296 0.817 0.786 0.806 0.837 0.783 0.789 0.805 0.787
Calcium(Ca) mg/I 46.4 32.8 29.3 30.5 58.5 54.6 55.6 57.5 50.8 51 52 54.9
Iron(Fe) mg/1 8.53 1.1 0.271 0.293 17.7 0.146 1.17 19.6 <0.01 0.093 0.767 <0.01
Magnesium(Mg) mg/I 17.4 11.1 9.48 9.92 13 11.1 11.3 15.4 12.7 12.7 13 11.1
Manganese(Mn) mg/I 0.142 0.272 0.068 0.07 0.315 0.082 0.094 0.412 0.162 0.164 0.172 0.08
Phosphorus(P) mg/I 2.44 0.72 0.286 0.292 1.09 0.389 0.427 2.7 0.476 0.483 0.531 0.384
Zinc(Zn) mg/I 0.041 0.013 <0.005 <0.005 0.055 <0.005 0.007 0.07 <0.005 <0.005 <0.005 <0.005
Antimony(Sb) PO 6.83 3.36 3.49 3.26 3.62 2 2.09 7.99 8.01 7.84 8.04 1.98
Arsenic(As) Ug/I 5.11 17.3 18.3 17.6 425 316 323 902 347 348 355 306
Cadmium(Cd) PO <1 <1 <1 <1 <1 <1 <1 <1 <1 <1 <1 <1
Chromium(Cr) PO 2.59 <1 <1 <1 13.1 <1 1.07 27.8 <1 <1 1.25 <1
Copper(Cu) PO 12.7 4.1 3.15 3.03 62.1 2.52 6.05 105 1 1.27 5.49 1.63
Lead(Pb) PO 3.21 <1 <1 <1 21.4 <1 1.87 48.3 <1 <1 2.86 <1
Molybdenum(Mo) pg/I 4.88 7.72 23.5 23 136 120 118 154 154 152 153 117
Nickel(NI) pgll 5.91 3.87 5.25 4.86 23.7 3.81 5.07 53.3 5.53 6.11 8.36 3.63
Selenium(Se) pg/I <1 <1 1.3 1.23 <1 <1 <1 14.4 <1 <1 <1 <1
Thallium(TI) pg/I <0.2 <0.2 <0.2 <0.2 1.18 0.295 0.566 1.08 0.231 0.213 0.272 0.295
Vanadium(V) mg/I 22.1 13.1 15.5 15.5 112 22 27.2 288 111 111 116 20.5
Mercury(CVAFS) mg/I 6.96 2.3 0.793 0.731 6.7 0.835 1.11 2.92 <0.500 <0.500 1.44 <0.500
TDS mg/I 620 450 400 400 540 530 530 540 520 530 530 530
TSS mg/I 12 22 8 9 620 <5 40 3700 <5 <5 39 <5