NC0000396_Draft Permit 2004_20040426

Progress Energy
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CERTIFIED MAIL 7003 1680 0002 1069 8311
File:1252013-1 April 26, 2004
Ms. Susan Wilson
North Carolina Division of Water Quality
NPDES Unit
1617 Mail Service Center
Raleigh, NC 27699-1617
Subject: CP&L —Asheville Steam Electric Plant
NPDES Permit No. NC0000396
Draft NPDES Permit comments
Dear Ms. Wilson:
Enclosed are our comments on the subject draft NPDES permit. We appreciate the opportunity
to comment. If you have any questions please contact Louise England at [phone].
Sincerely,
William A. Phipps
Plant Manager—Asheville Plant
Enclosure
Progress Energy Carolinas,Inc.
Asheville Steam Plant
200 CP&L Drive
Arden,NC 28704

Asheville Steam Electric Plant
Draft NPDES Permit Comments
PART I
Section A(1). — Effluent Limitations And Monitoring Requirements
• PE requests clarification that these monitoring requirements continue until the FGD
treatment system is used to treat FGD wastewater. After the wetland treatment system ✓
vegetation is planted, water from Lake Julian will be used to establish the plants and
may, on occasion, be discharged. PE does not feel that this constitutes start-up of the
FGD treatment system.
• Progress Energy Carolinas, Inc. (PE) requests that the requirement to monitor and
report Chlorides for Outfall 001 prior to the startup of the FGD treatment system be
eliminated. The current permit does not contain this requirement and operation of the
plant has not changed to cause this monitoring to be added.
Section A(2). — Effluent Limitations And Monitoring Requirements
• PE requests clarification that these monitoring requirements begin only after the FGD
treatment system is used to treat FGD wastewater. After the wetland treatment system
vegetation is planted, water from Lake Julian will be used to establish the plants and
may, on occasion, be discharged. PE does not feel that this constitutes start-up of the
FGD treatment system.
• Both Chlorides and Total Chlorides are required to be monitored and reported for Outfall
001 after start-up of the FGD treatment system. PE requests that the requirement to
monitor and report Chlorides be removed.
• PE requests that the monitoring frequency of weekly for metals and Total Chlorides be
reduced to monthly. Monthly monitoring should provide the needed data to evaluate the X �O '#'(L 'F
discharge from Outfall 001. In addition, weekly monitoring is costly for the sample y
analyses and burdensome for plant personnel collecting the more frequent samples.
• Because the Total Mercury limit of 0.63 pg/I is new for an existing outfall (Outfall 001),
PE requests that a schedule of compliance of 3 years be allowed. Because there is I �C'R-
limited Total Mercury data available for this outfall, PE would like to collect data for 2 P,.ki �c
years in order to evaluate monthly and seasonal variability and then have one year to s"�
implement corrective actions if needed.
Section A(5). — Effluent Limitations and Monitoring Requirements
• PE requests clarification that these monitoring requirements begin only after the FGD
treatment system is used to treat FGD wastewater. After the wetland treatment system✓
is planted, water from Lake Julian will be used to establish the plants and may, on
occasion, be discharged. PE does not feel that this constitutes start-up of the FGD
treatment system.
• PE requests that the monitoring frequency of weekly for metals and Total Chlorides be
reduced to monthly. Monthly monitoring should provide the needed data to evaluate the/
1

Asheville Steam Electric Plant
Draft NPDES Permit Comments
discharge from Outfall 001. In addition, weekly monitoring is costly for the sample
analyses and burdensome for plant personnel collecting the more frequent samples.
• PE assumes that the sample type for Flow for Outfall 005 is an instantaneous
measurement. If this is a correct assumption, PE requests that the sample type be
revised to Instantaneous.
Section A(6). —Stormwater Limitations and Monitoring Requirements/Analytical Monitoring
• The reference to Part II, Section A(17). as specified in the last sentence of this page
cannot be found. It is believed that this is meant to refer to a definition of representative •
storm event which is not found in this draft permit.
Section A(11).h. —Stormwater Pollution Prevention Plan
• The requirement to perform visual monitoring is found in A(7) not A(4).
Section A(12).c. —Stormwater Minimum Monitoring and Reporting Requirements /
2
• The definition for a representative storm event does not exist in Part Il, Section A—or
anywhere else in the draft permit.
Additional Comments
• PE requests that the following comment be included in the permit: "If the Permittee,
after monitoring for at least six months, determines that effluent limits contained herein
are consistently being met, it may be requested of the Director that the monitoring
requirements be reduced to a lesser frequency."
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Re:Draft permit for NC0000396
Subject: Re: Draft permit for NC0000396
From: [e-mail]
Date: Mon, 05 Apr 2004 11:00:28 -0400
To: [e-mail]
I recommend the draft permit mod contain a re-opener clause that
requires a WQ-based effluent limit be included, if necessary, based on
the results from the monitoring of new metals.
I will fax the concurrence memo indicating my comments.
Karrie-Jo Robinson-Shell, P.E.
----- Forwarded by Karrie-Jo Shell/R4/USEPA/US on 04/05/2004 10:55 AM
Karrie-Jo Shell
To: Susan Wilson <[e-mail]>
03/31/2004 10:43 cc:
AM Subject: Re: Draft permit for NC0000396(Document link:
Karrie-Jo Shell)
OK. I'll get back with you ASAP.
Karrie-Jo Robinson-Shell, P.E.
Susan Wilson
<susan.a.wilson@n To: Karrie-Jo Shell/R4/USEPA/US@EPA
cmail.net> cc:
Subject: Re: Draft permit for NC0000396
03/31/2004 10:14
AM
It's just a modification (the permit expires next year, December 31,
2005).
[e-mail] wrote:
1 of 3 4/5/2004 11:31 AM

Re: Draft permit for NC0000396
Is this action a permit mod or a re-issuance? If it is a
re-issuance, I
believe they are suppose to submit a new permit application.
Karrie-Jo Robinson-Shell, P.E.
Susan Wilson
<susan.a.wilson@n To: Karrie-Jo
Shell/R4/USEPA/US®EPA
cmail.net> cc:
Subject: Re: Draft
permit for NC0000396
03/31/2004 09:55
AM
Karrie-Jo,
As we had discussed previously (and as Mark did with Duke Power),
their
'application' is their request for the modification -just the
letter
and supporting material for the modification. The latest letter
and
supporting material is dated March 8, 2004, then they did a slight
revision and the supporting material explaining that they'll be
using
Lake Julian water for dilution source to wetlands (instead of ash
pond
water) should also be attached. Let me know if Valery didn't copy
those
with the fact sheet and I'll send you a hard copy. Thanks.
Also - I forgot to add a special condition regarding a study they
Will
have to conduct to determine the presence of selenate and selenite
in
the discharge. I already discussed this with Progress. I'll send
you
guys an e-mail with the Special condition, which will be added in
2 of 3 4/5/2004 11:31

Vie:,Draft permit for NC0000396
the
final permit (I just forgot to put it in).
Shell.Karrie-Jo®epamail.epa.gov wrote:
I did not receive the application. Can you send it?
'Thanks,
Karrie-Jo Robinson-Shell, P.E.
3 of 3 4/5/2004 11:31 AM

uek(c NOTICE
STATE OF
NORTHCAROLINA
ENVIRONMENTAL
MANAGEMENT
COMMISSION/
NPOVICE CENTERIT
AFFIDAVIT OF PUBLICA N i 200
1617 MAI L
.SERVI
RALEIGH NC 27699-1617
NOTIFICATION OF
INTENT TO ISSUE A
NPDESWASTEWATER
PERMIT
on the Basis of thorough BUNCOMBE COUNTY
staff review and applica-
tion of NC General Statute SS.
143.21, Public law 92-SM
and orridregulatorns,t�he NORTH CAROLINA
North Carolina Environ-
mental AM1anagerr>e%>3
Commission propanes
issue a National Pollutant limination
Discharge undersigned,
Before the a NotaryPublic of said
System (NPDES) waste
water discharge permit to County and State, duly commissioned, qualified and
the Person(s)listed below
=effective 45 daays from the authorized by law to administer oaths, personally
date of this notice.
Written comments regard- appeared Darryl Rhymes, who, being first duly
Proposed wll I be accepted uPermit sworn, deposes and says: that he is the Legal
days the Pudoft
of thisaftentice. ail"com- Billing Clerk of The Asheville Citizen-Times,
ments received prior to
#0 date are considered in p engaged in publication of a newspaper known as
the final determinations
regarding the proposed
peimB. The Director of The Asheville Citizen-Times, published, issued,
the NC Division of Water
Quality may decide to hold and entered as second class mail in the City of
a public meeting for the
Proposed permit should Asheville, in said County and State; that he is
the Division receive a sig.
ntert resest.t degree of public
iauthorized to make this affidavit and sworn
interest.
copies of the draft permit statement; that the notice or other legal
and other suptiOr}ing in- .
fomxafion on file used to advertisement, a true copy of which is attached
determine conditions pre
asent vailailedupon permit are hereto, was published in The Asheville Citizen-
available upon request
a ucton. Mail Times on the following date: March 25, 2004. And
comments and/or requests
for irNormation to the NC that the said newspaper in which said notice, paper,
Division of Water Qualify
at call Ms. Valero Stephens the above address or
cdocument or legal advertisement were published
at(919)733-MM extengion
520. Please include the were, at the time of each and every publication, a
NPDES permit number
(atfached) in any com- newspaper meeting all of the requirements and
munication interested
persons may also visit the qualifications of Section 1-597 of the General
Division of Water Quality
at Raleigh,
N.Na'27W4-114Street., Statues of North Carolina and was a qualified
Raleigh,NC 276041148 be,
tween the hours of 8:00 am
and 5,01 pmto review in- newspaper within the meaning of Section 1-597 of
formation on file.Permit Number
NPDES
the General Statues of North Carolina.
NC11000361,Unimin Corb&
rationSchoolhouse
Quartz -Plant, Aver.
County has applied for re. Signed this 29th day of Marc 2004
newal of its permit qis
charging to the North Toe
River in the French Broad i
R(ver Basin. Currently
fluoride is wafer quality
(united. This discharge
xray affect future atloca. ( ignature of person I .king affidavit)
Y)ons in this portion of the
receiving stream:
Progress Energy Caroli-
nas, Incorporated, Sworn to and subscribed before me the 29th day of
Asheville Steam Electric March 2004
Plant, 200 CPBL Drive,
Arden, NC 28704, has ap.
Plied for a modification of
its NPDES permit
(NC00i)0396) discharging
treated industrial Waste. ++
water to the French Broad ` + ++ J�YE h tiyG
River in the French Broad �+• A
River Basin.The NPDES .• �P` 1�
Permit is being modified to
Include the discharge of
treated flue gas desulfuri-
zation wastewater. Mer- h(Notarylic)cury Is water quality Jim-iced. This discharge may mission expires the 3rd day of eri* F €
thhisPoct fr`tiionoimeh'riiv'�ba- 2008. ILIC cj•{

Draft Permit review- Progress Energy/Asheville
Subject: Draft Permit review- Progress Energy/Asheville
From: John Giorgino <[e-mail]>
Date: Tue, 30 Mar 2004 09:02:54 -0500
To: Susan A Wilson <[e-mail]>
Ciao Susan, Ho guardato NC0000396. Li facciamo elencare attualmente per un % del lim
@ 1.4% e non 1.5 del
chr come scritto. Capisco the la volontA del lim ha ottenuto a 1.9% dopo to start-up
del sistema di trattamento di FGD. E 1.5% un cambiamento the sarA fatto o un errore?
Riguardi mighori,
John
Hi Susan, I looked at NC0000396. We have them currently listed for a chr lim @ 1.4% and
not 1.5 % as written. I understand that the lim will got to 1.9% after start-up of the FGD
treatment system. Is 1.5% a change that will be made or an error?
Best regards,
John
John Giorgino
Environmental Biologist
North Carolina Division of Water Quality
Aquatic Toxicology Unit
Mailing Address:
1621 MSC
Raleigh, NC 27699-1621
Office: 919 733-2136
Fax: [phone]
Email: [e-mail]
Web Page: http://vrw)Ar.es]D.enr.state.nc.us
CrPtL_
priLAt (7-)
C
kit c04-
I of 1 4/l/2004 9:45 AM

RE.Asheville
Subject: RE: Asheville
From: "England, Louise" <[e-mail]
Date: Wed, 17 Mar 2004 08:09:19 -0500
To: "'Susan Wilson"' <susan.a.wilson®ncmail.neb
1) If we discharged the wetland into the ash pond we would need to use a larger amount of
water for dilution due to the chloride concentration that would build up in the ash pond.
This would mean increased flow into the ash pond which will reduce the retention time in
the pond. We have concerns that we will begin having TSS problems and need to have the
pond dredged out on a more frequent basis. Dr. Rogers also felt that the wetlands
discharge would not receive much treatment as the solids content of the scrubber
wastewater will already be reduced by the clarifier and equalization basin prior to the
wetland.
2) Quite a bit of the piping from the intake structure has already been place in the ground.
Originally we had been told that the piping was not big enough to supply water from Lake
Julian for dilution. That's when the decision was made to use ash pond water for dilution.
We later found out that the piping was large enough to supply dilution water. We also
talked with Dr. Rogers and Entrex who said that because we were going to use ash pond
water the wetland would need to be much larger due to the metals loading from the ash
pond. We felt that we may have problems finding the required area for the wetland on site.
Hopefully this will answer Dave's questions. If not, let me know and I will try to do a better
job. I spoke with Ben White and he agrees that there should be no significant changes.
Thanks for all your work on getting the permit out so quickly.
Louise
-----Original Message-----
From: Susan Wilson [mailto:[e-mail]]
Sent: Tuesday, March 16, 2004 4:20 PM
To: England, Louise
Cc: valery stephens
Subject: Asheville
Louise,
Dave had a couple of questions I don't think I adequately answered for
him. Could you again explain 1) why you guys are not routing the
treated FGD wastewater to the Ash Pond? 2) Why you guys are not using
Ash pond effluent for dilution? Thanks much.
Are you folks comfortable with this going out to notice tomorrow? Do
you expect any more significant changes? I'd rather not make any
significant modifications (like we did today) once this is out to
notice. I should have this finished up this afternoon and likely Valery
will run the notices first thing tomorrow morning. If you'd like to
'stop the presses', I'd suggest you notify her in the morning directly.
(she's at 733-5083, ext. 520 - I'll copy her on this to let her know).
Susan
1 of 1 3/17/2004 9:12 AM

DENR/DWQ
FACT SHEET FOR NPDES PERMIT DEVELOPMENT
NPDES No. NC0000396, Progress Energy Carolinas, Inc. (PEC)
Asheville Steam Electric Plant
Facility Information
Applicant/Facility Name: Progress Energy Carolinas, Inc. / Asheville Steam Electric Plant
Applicant Address: 200 CP&L Drive, Arden, NC 28704
Facility Address: (same)
Permitted Flow 001 - Variable - 3.25 MGD avg.; 002 - Variable
(Outfall 004 is an internal outfall); SW- 1 through 6 (various
stormwater outfalls)
Type of Waste: 100 % Industrial
Facility/Permit Status: Major modification - modification of Outfall 001 to include the
new wastestream
County: Buncombe
Miscellaneous
Receiving Stream: French Broad Regional Office: ARO
River (001)
Stream Classification: C Quad FBNE
303(d) Listed?: No Permit Writer: S. Wilson
Subbasin: 040302 (French Date: March 16, 004
Broad)
Drainage Area (mi2): 655 (French
Broad River
discharge, 001)
Summer 7Q10 (cfs) 304
30Q2 (cfs):
Average Flow (cfs): 1769
IWC ft: Est., 1.9%
(Based on a now
of 3.79 MGD)
Primary SIC Code: 4911
SUMMARY
Progress Energy Carolinas (PEC) - Asheville Steam Electric Plant is a coal fired steam electric
generating plant (2 Units; 2 internal combustion turbines). The site has I ashpond and a 320
acre cooling pond (Lake Julian).
Progress submitted their request for modification of their permit on October 14, 2003 (and
submitted an addendum March 11, 2004; and an additional addendum March 16, 2004). The
company is currently operating under the NPDES permit issued December 17, 2001, which will
expire December 31, 2005.
The modification request is in response to North Carolina's Clean Air Initiative (Clean
Smokestacks Bill), which requires the reduction of SOx and NOx from air emissions. As a result
of this initiative, the company plans to install Flue Gas Desulfurization (FGD), systems at
several plants, beginning with this one. The FGD is essentially a scrubber system to remove
SOx by mixing flue gas with a limestone slurry. Operation is predicted to begin in the fourth
quarter of 2005.
aa- elm," F}N`� sU Emu w FAIL 1 y U/�tT
COIF /� - Pam
W04,9- Gc,,� l FLS B� Q�
PEC Asheville NC0000396
NPDES Renewal
Page 1

The FGD blowdown is predicted to generate a flow of 0.108 MGD, with relatively elevated
concentrations of metals and chloride. Progress Energy plans to treat the FGD blowdown via '
clarification, equalization, and constructed wetlands (this is the same general treatment
scenario that Duke Power will use). Dilution flow (water from Lake Julian) will be added to the
EQ basin to provide dilution for the wetland plants (appx. 0.432 MGD) due to the elevated
chlorides level. The treated FGD blowdown will then be routed to the effluent outfall from the
Ash Pond (Outfall 001) at the secondary settling basin. Please refer to the diagram in the
modification submittal dated March 2004. Predicted concentrations from the Ash Pond (Outfall
00 1) are listed on the attached pages (Tables la& lb).
No other changes in wastewater are anticipated at the plant. The addition of FGD blowdown
will only affect the effluent discharge from the ash pond via Outfall 001. Modification of this
permit is reflected on Part A.(1.). Other Outfalls and parameters will remain the same as the
previous permit issued and approved December 17, 2001.
Stream flows: A query was submitted to USGS regarding updated streamflows to account for
2001 drought conditions. The flows presented in this fact sheet represent those updated
streamflows. [Detailed letter from USGS is contained in this file].
TOXICITY TESTING:
Current Requirement: Chronic P/F at 1.4%, January, April, July, October
Recommended Requirement: Slight modification due to updated stream flows and wasteflows.
Proposed Requirement: Chronic P/F at 1.9%, January, April, July, October.
The facility has had an exemplary toxicity monitoring record for the past 4 years.
COMPLIANCE SUMMARY: BASED ON THE PREVIOUS 2 YEARS
There are no outstanding and/or chronic compliance problems related to the NPDES permit.
There was one NOV in 2003 (one daily maximum chlorine violation for Outfall 002). The facility
has not appeared on the Quarterly NonCompliance Report (QNCR) for major facilities.
INSTREAM MONITORING:
Progress is not required to perform any instream monitoring related to Outfall 001 on the
French Broad River. No additional instream monitoring will be required with this modification.
The French Broad River biological conditions generally range from Good-Fair to Good in this
subbasin, with a Good rating downstream of the discharge near Asheville. The French Broad
River is not listed as impaired on the state's 303(d) list.
PROPOSED CHANGES:
As outlined in the attached spreadsheet, based on estimated values of the blowdown
concentration, estimated effluent concentrations from the wetlands treatment system can be
calculated. The wetlands treatment system is predicted to remove appx. 90% of the mercury
and appx. 85% of the selenium*. Maximum predicted effluent concentrations can be
determined based on a coefficient of variation of 0.6 and multiplier of )13.2 (as outlined in NC's
RPA procedure based on EPA's Technical Support Document). ( r--A )
Based on these values, the Division would promulgate a limit for mercury. Where a water
quality standard or EPA criteria exist, other parameters will be monitored. If no standard or
criteria exist, no monitoring will be required at this time (but will be noted for future reference
should toxicity problems occur).
Due to the potential for fish tissue concentration-fish tissue studies for mercury will be
required annually.
* The Clemson report indicates values higher than this- the estimates were calculated using
the above removal efficiencies (R.E.) and the published R.E., with little to no effect on the
overall results at Outfall 001.
PEC Asheville NC0000396
NPDES Renewal
Page 2

` PROPOSED SCHEDULE FOR PERMIT ISSUANCE:
Draft Permit to Public Notice: March 17, 2004 (est.)
Permit Scheduled to Issue: May 10, 2004 (est.)
STATE CONTACT:
If you have any questions on any of the above information or on the attached permit, please
contact Susan Wilson at [phone] ext. 510.
REGIONAL OFFICE COMMENT:
1/7/04-Larry Frost of the Asheville Regional Office had no outstanding comments. The draft
permit will be sent to the region for review.
NAME: DATE:
3�il�oh - e-toPteo hrQ oN �/}ar sjeer, pw-ueT �.Siflwl 4�o/�-4i^�oJ
PEC Asheville NC0000396
NPDES Renewal
Page 3

NOTES FOR APPLICATION OF GUIDELINES:
40 CFR 423 STEAM ELECTRIC POWER GENERATING POINT SOURCE CATEGORY
(STARTING AT 423.12 & 423.13)
The basic permitting for Outfall 001 has not been changed and will not be changed with the addition of
FGD blowdoum.
423.12(b)(1) pH- 6-9 SU
423.12(b)(2) No discharge of PCB compounds
423.12(b)(3) Low volume wastes
Parameter Daily max, Monthly avg.,
/1 /l
TSS 100 30
Oil & grease 20 15
423.12(b)(4) Fly ash and bottom ash
Parameter Daily max, Monthly avg.,
mg/1 mg11
TSS 100 30
Oil & grease 20 15
423.13(e) Chemical metal cleaning wastes (Limits expressed in internal outfall 004)
Parameter Daily max, Monthly avg.,
m /l m /l
Total copper 1 1
Total zinc 1 1
The most stringent concentration-based limits have been used for outfall 001.
PEC Asheville NC0000396
NPDES Renewal
Page 4

Attachment 1 a for Fact Sheet
Progress Energy Carolinas, Inc.(PEC)
Asheville Steam Electric Plant
NC0000396
Mass Input to Predicted Mass Output from Estimated Effluent Estimated Effluent
Parameter Estimated FGD Wetlands lbs/day^ Removal Eff. Wetlands lbs/day^ conc.Mg/I^^ conc.ug/I
Blowdown Conc.' %
Antimony 80.00 - 0.0721 0.0000 0.0721 0.0023 2.28
----
-7-Arsenic 58.00 ------ 0.0522 0.0000 0.0522 _ 0.0017 1.65
Barium(mg/1) 2.19 1.9681 0.0000 i 1.9681 0.0623 62_26
Beryllium 2.00 0.0018 0.0000 0.0018 0.0001 0.06
Boron 283.00 0.2549 0.0000 0.2549 0.0081 8.06
Cadmium 7.00 0.0063 0.0000 - 0.-0063 0.0002 0.20
Chloride m _20000.00 18014.4000 _0.0000_ 1804.400.0_ 569.9208 569920.84 J
.Chromium f 73.00 0.0658 0.0000 0.0658 r 0.0021 2.08
!_Cobalt __ t_ 75.00 0.0676 0.0000 0.0676 0.0021 2.14
CI opper rt 59.00 0.0531 0.0000 0.0531 0.0017 1.68
Fluoride__(m I 12.00 10.8086 0.0000 10.8086 0.3420 341.95
Lead 92.00 0.0829 0.0000 0.0829 0.0026 2.62
Manganese m 11.65 10.4970 0.0000 10.4970 0.3321 332.09
MI_ercury 27.00 0.0243 90.0000 0.0024 0.0001 0.08
Mbdenum 15.00 0.0135 0.0000 0.0135 0.0004 0.43
Nickel 433.00 0.3900 0.0000 0.3900 0.0123 12.34
'Selenium m l 3.65 ! 3.2912 85.0000 0.4937 0.0156 15.62
'Silver 7.00 0.0063 0.0000 0.0063 0.0002 0.20
Sulfate m I 7098.00 6393.3106 0.0000 6393.3106 1 202.2649 202264.91
Thallium 55.00 0.0495 0.0000 0.0495 1 0.0016 1.57
,T --
Vanadium _ _ _ 52.00 0.0468 0.0000 0.0468 0.0015 1.48
Zinc(BIZ _ 3.15 1 2.8364 0.0000 2.8364 0.0897 89.73
*Concentrations are in ug/I unless otherwise noted
"+These values are human health based on fish consumption-Qavg dilution used in lieu of 7010s.
^ Mass input to ashpond-based on FGD est.blowdown of 0.108 MGD and est.concentrations provided by Progress.
=0.08 mg/I*0.108 MGD*8.34
^^The concentration output is based on the flow from the ash pond(3.25 MGD)+(flow from FGD(0.108)+Dilution flow(0.432)).
=mass(lbs/day)/(3.79*8.34)
=conc. Mg/I

Progress Energy Carolinas, Inc. (PEC) Attachment 1 b for Fact Sheet
Asheville Steam Electric Plant
NC0000396
Parameter Estimated FGD (C Waters) Allowable Estimated Effluent Acute Maximum Predicted
Blowdown Conc. ' WQ standard EPA Criteria Allowable u /I conc. u /l^^ Values u /I conc.for RPA# Limit or Monitor?
Antimony 80 640+ 194 m /l 194000 2.28 1 30.09 Monitor
Arsenic 58 50/10 2.63/3.03 m /I 2630 1.65 21.82 Monitor
Barium(m /l) 2.2 m /I 62.26 821.88
Beryllium 2 6.5/0.11117-- 342/35 35 0.06 0.75 Monitor
Boron 283 8.06 106.45
Cadmium 7 2 105 105 0.20 15 2.63 Monitor
Chloride(mg/1) 20000 m /l 230 m /I AL 12100 m /l 12100000 569920.84 7522955.15 Monitor AL
Chromium 73 50 2.63 m /l 2630 2.08 1022 27.46 Monitor
Cobalt 75 2.14 28.21
Copper 59 7 AL 368 368 1.68 22.19 Monitor
Fluoride(mg/1) 12 m /I 1.8 m /I 94.7 m /l 94700 341.95 4513.77 Monitor
Lead 92 25 1.32 m /l 1320 2.62 34.61 Monitor
Manganese(m /I) 11.65 mgA 100+ 30.3 m /I 30300 332.09 4383.63 Monitor
Mercury 27 0.012 0.63 0.63 0.08 1.02 Limit
Molybdenum 15 0.43 5.64
Nickel (mg/I 433.00 88 4.63 m /I 4630 12.34 261 162.87 Monitor
Selenium m n 3.7 m /I 5 263 263 15.62 56 206.17 Monitor**
Silver 7 0.06 AL 3.2 3.2 0.20 1.23 2.63 Monitor AL
Sulfate(mg/1) 7098 m /l 202264.91 2669896.78
Thallium 55 1.26+ 382 382 1.57 20.69 Monitor
Vanadium 52 1.48 19.56
Zinc(mg/1) 3.1 m /I 50 AL 2.63 m /I 2630 89.73 1184.49 Monitor AL
*Concentrations are in ug/l unless otherwise noted
"+These values are human health based on fish consumption-Qavg dilution used in lieu of 7Q1Os.
(Thallium is updated criteria, using NC's FCR factor)
^^The concentration output is based on the flow from the ash pond(3.25 MGD)+(flow from FGD(0.039)+Dilution flow(0.432 MGD))=3.79 MGD.
=mass(lbs/day)/(3.79*8.34)
=conc.Mg/I
# Estimated effluent conc.*13.2
**Although an acute limit for selenium will not be given-Progress will be required to speciate selenium(this will provide info on which is more prevalent in the effluent)
DA=655 mi2
7Q10s=304 cfs
Qavg = 1769 cfs
IWC= 1.9%(based on 7Q10s)
IWC=0.33%(based on Qavg)
IWC's are based on 95th percentile flow values from Outfall 001 for the period 11/00 through 11/03(excluding 9.9 MGD flow).
95th percentile flow from Ash Pond is 3.25 MGD
Limit or monitor determined by one data point(the estimated concentration from the ash pond effluent). As defined in EPA TSD
for one data point, CV= 0.6 and the multiplier is 13.2

Carolina Power & Light Company
Asheville Steam Electric Plant
National Pollutant Discharge Elimination System Permit Number NC0000396
Attachment 3
Form 2C- Item 11-B Flow, Sources of Pollution, and Treatment Technologies
The Asheville Steam Electric Plant is located in Arden, North Carolina south of Asheville, North
Carolina. The Asheville Steam Electric Plant is a coal-fired, steam cycle electric generating
plant with two generating units. Two Internal Combustion (IC) Turbines are also located on the
plant site. The plant has a 320-acre cooling lake (Lake Julian) on the east side of the French
Broad River in Buncombe County, North Carolina.
Chemical constituents contained in the discharges from this plant will, in part be representative
of the naturally occurring chemical quality of the intake water and will also have chemical
constituents of such quality and quantity associated with similar discharges for fossil generating
facilities of this size, type and in this geographical location. Either all or part of the elements
listed on the Periodic Table, either singularly or in any combination, may from time to time be
contained in the discharge.
Outfall 001 - Discharge from Ash Pond to French Broad River
The Plant's ash pond, which is located east of the French Broad River and south of the plant,
discharges into the French Broad River. The ash pond receives ash sluice water, low volume
wastes, coal pile runoff, air preheater cleaning water, fire protection system drainage, chemical
metal cleaning wastes (potentially), storm water and other waters from the Combustion Turbine
Facility constructed on the Plant's site. The proposed wheel wash and weigh stations will also
discharge to the Ash Pond. The Pond provides treatment by sedimentation and neutralization
to the above-referenced individual waste streams. Water leaves the ash pond via a standpipe
with skimmer and flows by pipe and lined ditch to a secondary basin, where it is discharged by
overflow to a ditch that coveys it to the French Broad River. Detailed descriptions of the
individual waste streams are below.
Ash Sluice Water
Fly ash and bottom ash from both units are hydraulically conveyed by an ash sluice pipeline to
the ash pond. An Amine Enhanced Fuel Lean Gas Reburn (AEFLGR) process will be installed
on Unit 1 in the spring of 2000. This process utilizes urea to reduce NOx emissions and will be
1

Carolina Power & Light Company
Asheville Steam Electric Plant
National Pollutant Discharge Elimination System Permit Number NC0000396
used in high ozone months (approximately May through September). A byproduct of this
process is ammonia which will be carried to the ash pond via ash sluice water.
Coal Pile Runoff
Storm water runoff from the coal pile is collected in drainage ditches that surround the coal pile.
The drainage ditches are routed to the ash pond for treatment. During maintenance activities,
sludges removed from catch basins, sumps, etc. may be transported to the old and/or the new
ash pond for disposal.
Storm Water
Storm water runoff from the plant area, parking lots, combustion turbine area, oil storage and
handling facility and the plant's 115 KV substation is routed to the ash pond for treatment.
During maintenance activities, sludges removed from catch basins, sumps, etc. may be
transported to the old and/or the new ash pond for disposal.
Low Volume Wastes
Boiler water make up is withdrawn from Lake Julian and purified utilizing vendor supplied
equipment. A second option is to perform these activities using plant equipment to filter, soften,
and evaporate make up water with the filter backwash, softener regeneration, and softener
rinses discharged to the ash pond. The water softeners are regenerated using salt. Boiler
water is treated with ammonia, hydrazine, and sodium hydroxide. Boiler and evaporator
blowdown and drainage is sent to the ash pond and may contain small quantities of the
chemicals. Some molybdate waste from the closed cooling water system is created through
valve leakage and maintenance activities and is discharged to the ash pond. A furnace ash
hopper seal is maintained by using plant service water. A standard operation water level is
maintained in a seal trough for the ash hopper seal. Overflow from this trough is discharged to
the ash pond. A sodium hydroxide solution is fed into this flow stream as necessary for ash
pond pH adjustment. Coal dust suppression is achieved by spraying a proprietary chemical on
coal at different stages of coal use. Small amounts of excess dust suppression chemical have
the potential to be discharged to the ash pond via plant drains or coal pile runoff. Small
amounts of urea waste from bulk urea unloading operations are discharged to the ash pond.
All plant area floor drains are routed to the ash pond and include equipment drainage and wash
down along with rainfall runoff. During maintenance activities, sludges removed from catch
basins, sumps, etc. may be transported to the old and/or the new ash pond for disposal.
2

Carolina Power & Light Company
Asheville Steam Electric Plant
National Pollutant Discharge Elimination System Permit Number NC0000396
In many cases, added chemicals are consumed or chemically altered during the plant
processes. Only trace amounts might be recoverable in water entering the ash pond.
Detectable levels of these chemicals would not be expected to occur in ash pond discharges.
Flue Gas Desulfurization Blowdown (Low Volume Waste)
The Flue Gas Desulfurization (FGD) system directs flue gas into an absorber where a limestone
(calcium carbonate) slurry is sprayed. Sulfur dioxide in the flue gas reacts with the limestone to
produce calcium sulfate (gypsum). This system reclaims any unreacted limestone slurry to be
reused in the absorber. A small blowdown stream is used to maintain the chloride
concentration in the reaction tank. The blowdown stream is passed through a clarifier to
remove solids and the chloride concentration in the waste stream is diluted using water from
Lake Julian. A constructed wetland is used to remove metals, mercury and selenium
specifically, and the treated wastewater is discharged into the secondary settling pond.
Air Preheater Cleaning (Low Volume Waste)
After the Amine Enhanced Fuel Lean Gas Reburn (AEFLGR) system is operational, the air
preheater will be water washed on a more frequent basis. It is expected to require cleaning
once per year or more frequently as needed. The wastewater from this activity will be
discharged to the ash pond.
Chemical Metal Cleaning Wastes
The boilers are chemically cleaned every five-to-eight years using a weak citric acid solution.
This cleaning solution and its rinses are stored on site for disposal by evaporation in an
operating unit's furnace. Typical cleanings would result in a waste of approximately 80,000
gallons. Should evaporation not be used, the waste can be routed to a treatment basin for
neutralization and precipitation prior to being conveyed to the old ash pond with permission of
the DWQ, to the newer ash pond, or other means of disposal. Cleaning of other heat
exchanger surfaces may produce 5,000-10,000 gallons every three-to-five years.
Other Wastes
Operation of the combustion turbine (CT) generation facility may produce turbine blade wash
water, inlet filter cooling water, various condensate waters, and water from equipment and tank
drains. These wastewaters will be collected in the storm water collection system of the CT site
3

Carolina Power & Light Company '
Asheville Steam Electric Plant
National Pollutant Discharge Elimination System Permit Number NC0000396
and routed to the ash pond. During maintenance activities, sludges removed from catch
basins, sumps, etc. may be transported to the old and/or the new ash pond for disposal.
- Plant Potable and Sanitary System -
The supply of water for plant potable and sanitary use is obtained from the Asheville/Buncombe
Water Authority system and waste from this system is discharged to the Metropolitan Sewage
District System.
- 230 KV Substation Storm Water-
Storm water runoff from the substation located adjacent to the plant is conveyed to the old ash
pond.
Outfall 002 - Discharge to Lake Julian
Once-Through Cooling Water
This flow provides condenser cooling water for the generating units 1 and 2. Maximum
condenser flows for units 1 and 2 are 124 MGD and 162 MGD, respectively.
Once-through cooling water is used to supply non-contact cooling water for the component
closed cooling water system. The component closed cooling water system flows combine with
unit 1 and 2 condenser flows prior to discharge to Lake Julian. Maximum component closed
cooling water system flows for unit 1 and 2 are 9.1 MGD and 10.2 MGD, respectively.
Discharge flow to Lake Julian is calculated at the intake to unitsl and 2 condensers and to the
circulating water to the heat exchanger. The discharge of water from the heat exchangers is
routed to an ash sump. The majority of this water is further routed to the discharge of units 1
and 2 condensers. Less than one per cent of the flow to the ash sump is used to supply ash
sluice water, preheater cleaning water, and fire protection water.
Control of biological fouling on heat-exchanger surfaces is accomplished by addition of sodium
hypochlorite as required, which is usually less that 2 hours per day per unit, with a net total
residual chlorine of less than 0.2 ppm discharged during that period. Cooling is accomplished
by evaporation from the surface of Lake Julian and mixing and convection with lake waters.
Make up for Lake Julian is from the French Broad River, natural runoff and creek flows. Water
is pumped from the French Broad River during dry periods to supplement the flow. Although
4

• Carolina Power & Light Company
Asheville Steam Electric Plant
National Pollutant Discharge Elimination System Permit Number NC0000396
discharge from Lake Julian to the river is extremely rare, any occurrence would be during
periods of heavy rainfall.
5

• Progress Energy Carolinas, Inc.
Asheville Steam Electric Plant
National Pollutant Discharge Elimination System Permit Number NC0000396
Attachment 2
Form 2C - Item II-A Flow, Sources of Pollution, and Treatment Technologies
Stream Name Average Flow Comments
A Ash Pond Discharge 3.10 MGD Outfall 001
B Intake to Once-through Cooling&Circulating 250.1 MGD
Water to Heat Exchangers
C Plant Potable and Sanitary Uses 0.002 MGD To POTW
D Makeup to Lake from River 7500 gpm Maximum Flow
E Low Volume Wastes
• Ash Hopper Seals 0.05 MGD
• Sandbed Filter Backwash 2600 Gal/event Rare Usage
• Water Softener Regeneration and Washing 3100 Gal/event Rare Usage
• Boiler Blowdown 0.006 MGD Startup-Estimated
F Circulating Water from Heat Exchangers 19.3 MGD Estimated
G Ash Sluice Water 2.0 MGD Estimated
H Dam Seepage 0.09 MGD Calculated
I City Water Supply to Boiler Makeup 0 MGD Rare Usage
J Coal Pile Runoff 0.01 MGD Based on Average Annual
Rainfall of 47"and 50%Runoff
K Storm Water 0.052 MGD Estimated
L Chemical Metal Cleaning Wastes 0-90,000 Gallons Normal Practice is Evaporation
(0 gallons anticipated)
M Water From Combustion Turbine Facility 0-0.02 MGD Intermittent
Operation
N From Lake to Intake 250.15 MGD Estimated
O Intake to Service Water 0.05 MGD Estimated
O Fire Protection Water 0.010 MGD Estimated
R Air Preheater Cleaning 10,000 gallons/event Estimated
S Discharge to Lake Julian 248.4 MGD Outfall 002-Estimated
T Emergency Fire Protection Water 0 Used for fire fighting
U Diesel Fire Pump to Lake Julian 0.128 MG/week Estimate-pump testing
V Flue Gas Desulfurization Blowdown 0.108 MGD Estimated
X Intake to FGD system 0.864 MGD Estimated
Y Chloride Dilution Water 0.432 MGD Estimated
z Constructed Wetland Discharge 0.54 MGD Estimated
2

French Broad Make-Up
River Water Intake Stormwater Old Ash Pond
X Flue Gas V Equalization
D Settling
Zone
Desulfurization Clarifier Basin
ne Y
Units 1 &2 S Lake Julian
Condensers Outfall 002
B
Lake N Intake F
Structure Circulating Water Ash Sum
Julian to Heat Exchanger p
U Diesel T
Fire Fire Preheater Ash Evaporation
Pum Protection Cleaning Sluice in Boilers
System Water Water L
Service Water Q R Chemical Metal
Vendor supplied Cleaning Waste
water treatment G Constructed
Wetland
Combustion M
Turbine Site Z
New
Low Volume E Ash Pond Secondary French Broad
Waste Sources Settling River
Basin A Outfall 001
. to Water J H
K
Dam Seepage
Coal Pile
Potable and Public Runoff Attachment 2-form 2C-Item IIA Flows,Sources of
Public C
Pollution,and Trument Technolooies
Water Sanitary Sewage
Supply System System Progress Energy Carolinas,Inc.
Asheville Steam Electric Plant
Buncombe County Page 1 of 2

CP&L-A Progress Energ Flow Instantan
NC0000396
50050-Flow.i
95th Percentile 95th Percentile
Month Day Year UoM Value Modifie calcs. calcS.
11 1 2000 mgd .04 9.9 4.01
11 9 2000 m9d 2.78 4.01 3.75
11 16 2000 mgd 2.11 3.75 3.75
11 20. 2000 mgd 2.33 3.75 3.5
11 23 2000 mgd HOLD 3.5 3.5
11 30 2000 mgd 1.91 3.5 3.5
12 6 2000 mgd 2.33 3.5 3.5
12 13 2000 mgd 2.11 3.5 3.5
12 21 2000 mgd 2.33 3.5 3.25
12 25 2000 mgd HOLD 3.25 3.25
12 26 2000 mgd HOLD 3.25 3.01
12 27 2000 mgd 2.11 3.01 3.01
1 1 2001 mgd HOLD 3.01 3.01
1 4 2001 mgd 2.11 3.01 3.01
1 10 2001 mgd 1.15 3.01 3.01
1 15 2001 mgd 1.33 3.01 2.78
1 23 2001 m9d 2.11 2.78 2.78
1 25 2001 mgd 2.11 2.78 2.78
2 1 2001 mgd 1.15 2.78 2.78
2 6 2001 mgd 2.11 2.78 2.78
2 15 2001 mgd 1.51 2.78 2.78
2 19 2001 mgd 2.33 2.78 2.55
2 27 2001 mgd 1.91 2.55 2.55
3 8 2001 mgd 1.7 2.55 2.55
3 12 2001 mgd 1.51 2.55 2.55
3 21 2001 mgd 4.01 2.55 2.55
3 27 2001 mgd 2.55 2.55 2.55
4 3 2001 mgd 2.33 2.55 2.55
4 11 2001 mgd .82 2.55 2.33
4 19 2001 mgd 1.7 2.33 2.33
4 25 2001 mgd .29 2.33 2.33
5 1 2001 mgd 1.51 2.33 2.33
5 B 2001 mgd 1.91 2.33 2.33
5 15 2001 m9d 1.7 2.33 2.33
5 22 2001 mgd 2.33 2.33 2.33
5 28 2001 mgd HOLD 2.33 2.33
5 29 2001 m9d 1.91 2.33 2.33
6 7 2001 mgd 3.5 2.33 2.33
6 12 2001 m9d 1.51 2.33 2.33
6 18 2001 mgd 9.9 2.33 2.33
6 25 2001 mgd 2.11 2.33 2.33
7 5 2001 mgd 1.7 2.33 2.33
7 10 2001 m9d .67 2.33 2.33
7 16 2001 mgd 2.55 2.33 2.33
7 23 2001 mgd 1.7 2.33 2.33
7 30 2001 mgd 2.55 2.33 2.11
8 9 2001 mgd 1.33 2.11 2.11

CP&L-A Progress Energ Flow Instantan
NC0000396
50050-Flow,I
95th Percentile 95th Percentile
Month Day Year UOM Value ModiBe calcs. CBIOS.
8 14 2001 mgd 3.5 2.11 2.11
8 21 2001 mgd .67 2.11 2.11
8 28 2001 mgd 2.11 2.11 2.11
9 3 2001 nqd HOLD 2.11 2.11
9 5 2001 mgd 1.51 2.11 2.11
9 11 2001 mgd 2.55 2.11 2.11
9 18 2001 mgd 1.7 2.11 2.11
9 25 2001 mgd 3.5 2.11 2.11
10 2 2001 mgd 1.51 2.11 2.11
10 9 2001 mgd 1.33 2.11 2.11
10 18 2001 mgd 2.55 2.11 2.11
10 23 2001 mgd 1.51 2.11 2.11
10 30 2001 mgd 1.33 2.11 2.11
11 6 2001 mgd .98 2.11 2.11
11 13 2001 mgd 2.11 2.11 2.11
11 19 2001 mgd 2.78 2.11 2.11
11 26 2001 mgd 1.7 2.11 2.11
12 6 2001 mgd 2.11 2.11 2.11
12 11 2001 mgd 3.01 2.11 1.91
12 19 2001 mgd 3.25 1.91 1.91
12 26 2001 mgd 2.33 1.91 1.91
1 1 2002 mgd HOLID 1.91 1.91
1 2 2002 mgd .1 1.91 1.91
1 7 2002 mgd 3.01 1.91 1.91
1 14 2002 mgd 1.91 1.91 1.91
1 23 2002 mgd 1.51 1.91 1.91
1 29 2002 mgd 1.15 1.91 1.91
2 4 2002 mgd 2.33 1.91 1.91
2 14 2002 mgd 3.5 1.91 1.91
2 20 2002 mgd 1.33 1.91 1.91
2 26 2002 mgd 3.01 1.91 1.91
3 6 2002 mgd 1.7 1.91 1.91
3 12 2002 mgd 3.5 1.91 1.91
3 20 2002 mgd 3.25 1.91 1.91
3 27 2002 mgd 2.78 1.91 1.91
4 4 2002 ngd 1.7 1.91 1.91
4 9 2002 mgd 3.01 1.91 1.91
4 17 2002 mgd 3.01 1.91 1.91
4 22 2002 mgd 1.51 1.91 1.91
4 29 2002 mgd 1.7 1.91 1.7
5 7 2002 mgd 1.33 1.7 1.7
5 14 2002 mgd 1.91 1.7 1.7
5 22 2002 mgd 2.78 1.7 1.7
5 27 2002 npd HOLID 1.7 1.7
5 28 2002 mgd 2.78 1.7 1.7
6 5 2002 mgd 3.75 1.7 1.7
6 11 2002 mgd 1.51 1.7 1.7
li
2

CP3L-A Progress Energ Flow Instantan
NC0000396
50050-Flow,i
95th Percentile 95th Percentile
Month Day Year UOM Value Modifie talcs. calcs.
6 18 2002 mgd 1.15 1.7 1.7
6 20 2002 mgd 1.15 1.7 1.7
6 25 2002 mgd 1.15 1.7 1.7
7 2 2002 mgd .98 1.7 1.7
7 9 2002 mgd 1.33 1.7 1.7
7 16 2002 mgd 2.33 1.7 1.7
7 23 2002 mgd 2.11 1.7 1.7
7 29 2002 mgd 1.7 1.7 1.7
8 7 2002 mgd 3.75 1.7 1.7
8 14 2002 mgd 2.78 1.7 1.7
8 21 2002 mgd 2.33 1.7 1.7
8 26 2002 mgd 1.51 1.7 1.7
9 3 2002 mgd .82 1.7 1.7
9 10 2002 mgd .82 1.7 1.7
9 18 2002 mgd .29 1.7 1.51
9 24 2002 mgd 1.91 1.51 1.51
10 2 2002 nw 1.15 1.51 1.51
10 9 2002 nw 1.33 1.51 1.51
10 15 2002 mgd 2.33 1.51 1.51
10 22 2002 mgd 1.15 1.51 1.51
10 29 2002 mgd 1.33 1.51 1.51
11 7 2002 mgd 1.15 1.51 1.51
11 13 2002 mgd 2.11 1.51 1.51
11 18 2002 mgd 2.33 1.51 1.51
11 25 2002 mgd 1.7 1.51 1.51
12 3 2002 mgd 1.7 1.51 1.51
12 9 2002 mgd 1.91 1.51 1.51
12 18 2002 mgd 1.91 1.51 1.51
12 23 2002 nw 1.33 1.51 1.51
1 1 2003 mgd HOLD 1.51 1.51
1 2 2003 mgd 1.15 1.51 1.51
1 7 2003 mod 2.11 1.51 1.51
1 15 2003 nw 1.7 1.51 1.51
1 23 2003 mgd 2.33 1.51 1.51
1 28 2003 rngd 1.91 1.51 1.33
2 5 2003 mgd 1.51 1.33 1.33
2 11 2003 mgd 1.91 1.33 1.33
2 20 2003 mgd 1.7 1.33 1.33
2 24 2003 mgd 2.11 1.33 1.33
3 4 2003 mgd 2.11 1.33 1.33
3 11 2003 mgd 1.51 1.33 1.33
3 19 2003 mgd 1.7 1.33 1.33
3 25 2003 mgd 1.7 1.33 1.33
4 2 2003 mgd 1.91 1.33 1.33
4 8 2003 mgd 1.51 1.33 1.33
4 14 2003 mgd 1.15 1.33 1.15
4 22 2003 mgd 1.51 1.15 1.15
3

r
CP&L-A Progress Energ Flow Instantan
NC0000396
50050-Flow.i
95th Percentile 95th Percentile
Months Day Year UOM Value Modifie calcs. calcs.
4 29 2003 mgd 1.51 1.15 1.15
5 5 2003 mgd 2.33 1.15 1.15
5 12 2003 mgd .82 1.15 1.15
5 20 2003 mgd 1.91 1.15 1.15
5 26 2003 mgd HOLD 1.15 1.15
5 28 2003 mgd 1.51 1.15 1.15
6 2 2003 mgd 1.33 1.15 1.15
6 10 2003 mgd 1.91 1.15 1.15
6 17 2003 mgd 2.33 1.15 1.15
6 24 2003 mgd 1.7 1.15 .98
7 3 2003 mgd 2.55 .98 .98
7 4 2003 mgd HOLD .98 .82
7 8 2003 mgd 2.55 .82 .82
7 15 2003 mgd 1.7 .82 .82
7 22 2003 mgd 1.7 .82 .82
7 29 2003 mgd 1.7 .82 .67
8 6 2003 mgd 2.11 .67 .67
8 12 2003 mgd 2.33 .67 .29
8 19 2003 mgd 2.33 .29 29
8 26 2003 mgd 1.91 29 .1
9 3 2003 mgd 1.91 .1 .04
9 10 2003 mgd 1.51 .04
9 17 2003 mgd 1.51
9 24 2003 mgd 2.11 3.475 3.25 =95th percentile value
9 30 2003 mgd 1.51 =95th percentile value (without 9.9 MGD value)
10 7 2003 mgd 1.91
10 16 2003 mgd 2.11
10 21 2003 mgd 1.91
10 26 2003 mgd 2.11
11 4 2003 mgd 1.7
11 11 2003 mgd 1.91
11 17 2003 mgd 1.91
11 24 2003 mgd 1.91
4

CP&L-A Propos Ener9 Flow Instantan
NC0000396
60060-Flow,i
95th Percentile
Month Day Year UoM Value MWIfle calcs.
11 1 2000 m9d .04 9.9
11 9 2000 m9d 2.78 4.01
11 16 2000 m9d 2.11 3.75
11 20 2000 m9d 2.33 3.75
11 23 2000 m9d HOLD 3.5
11 30 2000 m9d 1.91 3.5
12 6 2000 m9d 2.33 3.5
12 13 2000 mod 2.11 3.5
12 21 2000 mpd 2.33 3.5
12 25 2000 mpd HOLID 3.26
12 26 2000 m9d HOWD 3.25
12 27 2000 m9d 2.11 3.01
1 1 2001 m9d HOLD 3.01
1 4 2001 mod 2.11 3.01
1 10 2001 m9d 1.15 3.01
1 16 2001 mod 1.33 3.01
1 23 2001 mod 2.11 2.78
1 25 2001 mod 2.11 2.78
2 1 2001 mod 1.15 2.78
2 6 2001 m9d 2.11 2.78
2 15 2001 mpd 1.51 2.76
2 19 2001 m9d 2.33 2.78
2 27 2001 m9d 1.91 2.55
3 8 2001 m9d 1.7 2.56
3 12 2001 m9d 1.51 2.56
3 21 2001 mod 4.01 2.56
3 27 2001 mod 2.55 2.55
4 3 2001 npd 2.33 2.55
4 11 2001 mpd .82 2.55
4 19 2001 m9d 1.7 2.33
4 25 2001 m9d .29 2.33
S 1 2001 mod 1.61 2.93
6 8 2001 mpd 1.91 2.33
6 15 2001 nqd 1.7 2.33
5 22 2001 mgd 2.33 2.33
5 28 2001 nqd HOLD 2.33
5 29 2001 mpd 1.91 2.33
6 7 2001 mpd 3.5 2.33
6 12 2001 m9d 1.51 2.33
6 18 2001 mpd 9.9 2.33
6 25 2001 ngd 2.11 2.33
7 5 2001 mod 1.7 2.33
7 10 2001 m9d .67 2.33
7 16 2001 m9d 2.66 2.33
7 23 2001 mod 1.7 2.33
7 30 2001 m9d 2.55 2.33
8 9 2001 mpd 1.33 2.11
1

' 1
cP&L-A Progress Energ Flow Inslantan
N00000396
50050-Flow,I
95th Percentile
Month Day Year UoM Value Modflie caics.
8 14 2001 mod 3.5 2.11
8 21 2001 mgd .67 2.11
8 28 2001 mod 2.11 2.11
9 3 2001 mod HOLID 2.11
9 5 2001 nod 1.51 2.11
9 11 2001 m9d 2.55 2.11
9 18 2001 mod 1.7 2.11
9 25 2001 mod 3.5 2.11
10 2 2001 mgd 1.51 2.11
10 9 2001 mgd 1.33 2.11
10 16 2001 mgd 2.55 2.11
10 23 2001 nod 1.51 2.11
10 30 2001 mgd 1.33 2.11
11 6 2001 mgd .98 2.11
11 13 2001 mgd 2.11 2.11
11 19 2001 mod 2.78 2.11
11 26 2001 mgd 1.7 2.11
12 6 2001 mod 2.11 2.11
12 11 2001 mod 3.01. 2.11
12 19 2001 m9d 3.25 1.91
12 26 2001 mod 2.33 1.91
1 1 2002 mod HOUD 1.91
1 2 '2002 mod .1 1.91
1 7 2002 mod 3.01 1.91
1 14 2002 mod 1.91 -1.91
1 23 2002 mgd 1.51 1.91
1 29 2002 mgd 1.15 1.91
2 4 2002 m9d 2.33 1.91
2 14 2002 m9d 3.5 1.91
2 20 2002 mgd 1.33 1.91
2 26 2002 rrod 3.01 1.91
3 6 2002 mgd 1.7 1.91
3 12 2002 nod 3.5 1.91
3 20 2002 nod 3.25 1.91
3 27 2002 nod 2.78 1.91
4 4 2002 mgd 1.7 1.91
4 9 2002 mgd 3.01 1.91
4 17 2002 mgd 3.01 1.91
4 22 2002 mod 1.51 1.91
4 29 2002 mgd 1.7 1.91
5 7 2002 mod 1.33 1.7
5 14 2002 mod 1.91 1.7
5 22 2002 n* 2.78 1.7
5 27 2002 mod HOOD 1.7
5 28 2002 mod 2.78 1.7
6 5 2002 mgd 3.75 1.7
6 11 2002 mgd 1.51 1.7
2

CiP&L-A Progress Energ Flow Instantan
NCO000396
50050-Flow,i
95th Percentile
Month Day Year UoM Value ModMe calls.
6 18 2002 mgd 1.15 1.7
6 20 2002 mgd 1.15 1.7
6 25 2002 mgd 1.15 1.7
7 2 2002 mod .98 1.7
7 9 2002 m9d 1.33 1.7
7 16 2002 mgd 2.33 1.7
7 23 2002 mgd 2.11 1.7
7 29 2002 mgd 1.7 1.7
8 7 2002 m9d 3.75 1.7
8 14 2002 mgd 2.78 1.7
8 21 2002 ngd 2.33 1.7
8 26 2002 rrgd 1.51 1.7
9 3 2002 mgd .82 1.7
9 10 2002 mpd .82 1.7
9 18 2002 mgd .29 1.7
9 24 2002 mgd 1.91 1.51
10 2 2002 nW 1.15 1.51
10 9 2002 m9d 1.33 1.51
10 15 2002 mgd 2.33 1.51
10 22 2002 m9d 1.15 1.51
10 29 2002 m9d 1.33 1.51
11 7 2002 m9d 1.15 1.51
11 13 2002 m9d 2.11 1.51
11 18 2002 m9d 2.33 1.51
11 25 2002 m9d 1.7 1.51
12 3 2002 mgd 1.7 1.51
12 9 2002 mod 1.91 1.51
12 18 2002 mgd 1.91 1.51
12 23 2002 mgd 1.33 1.51
1 1 2003 mgd HOLD 1.51
1 2 2003 mod 1.15 1.51
1 7 2003 mod 2.11 1.51
1 15 2003 mgd 1.7 1.51
1 23 2003 mod 2.33 1.51
1 28 2003 mod 1.91 1.51
2 5 2003 mgd 1.51 1.33
2 11 2003 mgd 1.91 1.33
2 20 2003 mgd 1.7 1.33
2 24 2003 mod 2.11 1.33
3 4 2003 mgd 2.11 1.33
3 11 2003 mgd 1.51 1.33
3 19 2003 mgd 1.7 1.33
3 25 2003 mod 1.7 1.33
4 2 2003 mgd 1.91 1.33
4 8 2003 mgd 1.51 1.33
4 14 2003 m9d 1.15 1.33
4 22 2003 mgd 1.51 1.15
3

CP&L-A Progress Energ Flow Instantan
NC0000396
50050-Flow.i
95th Percentile
Month Day Year UoM Value ModMe calcs.
4 29 2003 mgd 1.51 1.15
5 5 2003 mgd 2.33 1.15
5 12 2003 mgd .82 1.15
5 20 2003 mgd 1.91 1.15
5 26 2003 mgd HOLID 1.15
5 28 2003 mgd 1.51 1.15
6 2 2003 mgd 1.33 1.15
6 10 2003 mgd 1.91 1.15
6 17 2003 mgd 2.33 1.15
6 24 2003 mgd 1.7 1.15
7 3 2003 m9d 2.55 .98
7 4 2003 mgd HOLID .98
7 8 2003 mgd 2.55 .82
7 15 2003 mgd 1.7 .82
.ta
7 22 2003 mgd 1.7 .82
7 29 2003 mgd 1.7 .82
8 6 2003 m9d 2.11 .67
8 12 2003 mgd 2.33 .67
8 19 2003 mgd 2.33 29
8 26 2003 m9d 1.91 .29
9 3 2003 m9d 1.91 .1
9 10 2003 mgd 1.51 .04
9 17 2003 mgd 1.51
9 24 2003 mgd 2.11 3.475 =95th percentile'
9 30 2003 mgd 1.51
10 7 2003 mgd 1.91
10 16 2003 mgd 2.11
10 21 2003 mgd 1.91
10 28 2003 m9d 2.11
11 4 2003 mgd 1.7
11 11 2003 mgd 1.91
11 17 2003 m9d 1.91
11 24 2003 mgd 1.91
4

f
• Or aiq IM4!>
Z�sf p F�O'n►�
CP&L-A Progress Ener9 Flow Instantan
NC0000396
50050-Flow,i
Month Day Year UoM Value ModHie N*Jf vi A4jj
11 1 2000 mgd .04-
11 9 2000 mgd 2.79-
11
.78-11 16 2000 mgd 2.11 1.03
11 20 2000 mgd 2.33
11 23 2000 mgd HOLD
11 30 2000 mgd 1.91
12 6 2000 mgd 2.33 c TM
12 13 2000 mgd 2.11 aS
12 21 2000 mgd 2.33 (I LE
12 25 2000 mgd HOLID
12 26 2000 mgd HOLD
12 27 2000 mgd 2.11
1 1 2001 npd HOLD
1 4 2001 mgd 2.11-
1 10 2001 m9d 1.15
1 15 2001 mgd 1.33
1 23 2001 mgd 2.11
1 25 2001 mgd 2.11
2 1 2001 mgd 1.15
2 6 2001 mgd 2.11
2 15 2001 mgd 1.51
2 19 2001 mgd 2.33
2 27 2001 mgd 1.91
3 8 2001 mgd 1.7
3 12 2001 mgd 1.51
3 21 2001 mgd 4.01
3 27 2001 mgd 2.55
4 3 2001 mgd 2.33
4 11 2001 m9d .82
4 19 2001 mgd 1.7 -f
4 25 2001 mgd 29
5 1 2001 mgd 1.51
5 6 2001 m9d 1.91
5 15 2001 mgd 1.7
5 22 2001 mgd 2.33
5 26 2001 mgd HOLD
5 29 2001 mgd 1.91
8 7 2001 mgd 3.5
6 12 2001 mgd 1.51
6 18 2001 mgd 9.9
6 25 2001 mgd 2.11
7 5 2001 mgd 1.7
7 10 2001 mgd .67
7 16 2001 m9d 2.55
7 23 2001 mgd 1.7
7 30 2001 mgd 2.55
8 9 2001 m9d 1.33

CPBL-A Progress Energ Flow Instantan
NC0000396
50050-Flow,I
Month Day Year LION Value ModHle
8 14 2001 mgd 3.5
8 21 2001 mgd .67 f
8 28 2001 mgd 2.11
9 3 2001 mgd HOLD
9 5 2001 mgd 1.51
9 11 2001 mgd 2.55 2
9 18 2001 mgd 1.7
9 25 2001 m9d 3.5
10 2 2001 mgd 1.51
10 9 2001 mgd 1.33
10 16 2001 mgd 2.55 •r
10 23 2001 mgd 1.51
10 30 2001 mgd s_
11 6 2001 mgd .98
11 13 2001 m9d 2.11 _ I
11 19 2001 mad 2.78
11 26 2001 mgd 1.7
12 6 2001 mgd 2.11
12 11 2001 m9d 3.01 _ q •C
12 19 2001 mgd 3.25 L
12 26 2001 mgd 2.33
1 1 2002 mgd HOLD
1 2 2002 mgd .1
1 7 2002 mgd 3.01
1 14 2002 rrgd 1.91
1 23 2002 mgd 1.51
1 29 2002 mgd 1.15
2 4 2002 mgd 2.33
2 14 2002 mgd 3.5
2 20 2002 mgd 1.33 (�
2 28 2002 mgd 3.01
3 6 2002 m9d 1.7
3 12 2002 rngd 3.5 = 2 8
3 20 2002 mgd 3.25
3 27 2002 mgd 2.78
4 4 2002 mgd 1.7
4 9 2002 mgd 3.01 - 2,1
n
4 17 2002 mgd 3.01 (�
4 22 2002 mgd 1.51
4 29 2002 mgd 1.7
5 7 2002 mgd 1.33
5 14 2002 m9d 1.91 2.2
5 22 2002 mgd 2.78
5 27 2002 m9d HOLD
5 28 2002 m9d 2.78
6 5 2002 m9d 3.75
6 11 2002 mgd 1.51
2

CP3L-A Progress Energ Flow Instantan
NC0000396
50050-Flow,i
Month Day Year UoM Value Modifie
6 16 2002 mgd 1.15
6 20 2002 mgd 1.15 I •?�
6 25 2002 mgd 1.15
7 2 2002 mgd .98
7 9 2002 mgd 1.33
7 16 2002 mgd 2.33 z b
7 23 2002 mgd 2.11
7 29 2002 mgd 1.7^
8 7 2002 mgd 3.75
8 14 2002 mgd 2.78
8 21 2002 mgd 2.33
8 26 2002 mgd 1.51
9 3 2002 mgd .82
9 10 2002 mgd .82
9 16 2002 mgd .29 V 6
9 24 2002 mgd 191
10 2 2002 mgd 1.15
10 9 2002 mgd 1.33 t�
10 15 2002 mgd 2.33
10 22 2002 mgd 1.15
10 29 2002 mgd 1.33
11 7 2002 mgd 1.15
11 13 2002 mgd 2.1.1 I /�
11 18 2002 mgd 2.33 v
11 25 2002 mgd 1.
12 3 2002 mgd 1.7
12 9 2002 mgd 1.91
12 18 2002 mgd 1.91
12 23 2002 mgd 1.33
1 1 2003 mgd HOLID
1 2 2003 mgd 1.15
1 7 2003 mgd 2.11
1 15 2003 mgd 1.7
1 23 2003 mgd 2.33
1 28 2003 mgd 1.91
2 5 2003 mgd 1.51
2 11 2003 mgd 1.91 Z (�
2 20 2003 mgd 1.7
2 24 2003 mgd 2.11
3 4 2003 mgd 2.11
3 11 2003 mgd 1.51 l
3 19 2003 mgd 1.7
3 25 2003 mgd 1.7
4 2 2003 mgd 1.91
4 8 2003 mgd 1.51
4 14 2003 mgd 1.15
4 22 2003 mgd 1.51
3

fti
CPBL-A Progress Energ Flow Instantan
NG0000396
500.50-Flow,i
Month Day Year UoM Value ModiNe 1
4 29 2003 mgd 1.51
5 5 2003 mgd 2.33
5 12 2003 mgd .82
5 20 2003 mgd 1.91
5 26 2003 mgd HOLID
5 28 2003 mgd 1.51
6 2 2003 mgd 1.33
6 10 2003 mgd 1.91
B 17 2003 mgd 2.33
6 24 2003 mgd 1.7
7 3 2003 mgd 2.55
7 4 2003 mgd HOLD
7 8 2003 mgd 2.55 Z 0
7 15 2003 mgd 1.7
7 22 2003 rngd 1.7
7 29 2003 mgd 1.7
8 6 2003 mgd 2.11
8 12 2003 mgd 2.33 2, k-7
8 19 2003 mgd 2.33
8 26 2003 mod 1.91
9 3 2003 mgd 1.91
9 10 2003 mgd 1.51
9 17 2003 m9d 1.51 - I• I
9 24 2003 mod 2.11
9 30 2003 mod 1.51
10 7 2003 mgd 1.91
10 16 2003 mod 2.11 = Z
10 21 2003 mod 1.91
10 28 2003 mgd 2.11
11 4 2003 mod 1.7
11 11 2003 mod 1.91 .
11 17 2003 m9d 1.91
11 24 2003 mgd 1.91
4

f
RE:-FGD concentrations
Subject: RE: FGD concentrations
From: "England, Louise" <louise.england®pgnmail.conv
Date: Mon, 15 Mar 2004 09:30:49 -0500
To: "'Susan Wilson"' <[e-mail]
The previous concentrations were based on coals that consisted of 0.09%chloride. We
then found from the fuels group that we could possibly use coals up to 0.25% chloride.
The concentrations and flow were changed based on this 0.25% chloride coal. Let me know
if you have any more questions.
Thanks,
Louise England
-----Original Message-----
From: Susan Wilson [mailto:[e-mail]]
Sent: Thursday, March 11, 2004 5:33 PM
To: England, Louise
Subject: FGD concentrations
Louise,
Why are the FGD concentrations different than the previous submittal?
Did you guys just get better estimates? Thanks.
1 of 1 3/15/2004 9:54 AM

r
Re French Broad Flows
Subject: Re: French Broad Flows
From: "John C Weaver" <jcweaver®usgs.gov>
Date: Fri, 27 Feb 2004 15:58:39 -0500
To: Susan Wilson <[e-mail]>
Susan,
For what it's worth, I thought I would let you know that I received the
hard copy of your request this afternoon. I'm not sure whether to laugh or
bemoan something that took over four weeks to work its way from your desk
to mine. Nevertheless, let me know if you did not receive the advance fax
copy of our response earlier this week.
Also, looking at your map shows that the site you identified is somewhat a
little different from the location where I provided the estimates. The
location that I used is downstream at the Long Shoals bridge (NC 280).
Your site was shown to be upstream of the reservoir off of Long Shoals Road
(NC 280). The difference in drainage areas at the two locations is about 5
sgmi. However, given that we're dealing with drainage areas between 655
and 660 sqmi, any adjustment to account for your specific location would
not cause the values to be that much different.
Just thought I would point this out to you...
Thanks.
Curtis Weaver
Susan Wilson
<susan.a.wilson@n To: John C Weaver <jcweaver®11sgs.9ov>
cmail.net> cc:
Subject: Re: French Broad Flows
01/30/2004 10:23
AM
You should get the hard copy soon, put it in the mail Wednesday. Thanks
Curtis.
1 of 3 3/l/2004 7:43 AM

Re: French Broad Flows
John C Weaver wrote:
Susan,
Just a note to let you know that I received your request. We ask for
about
a month to respond to a formal request. I will attempt to have a response
completed by mid- to latter part of February.
Thanks.
JCWeaver
Susan Wilson
<susan.a.wflson@n To: "John C Weaver"
<[e-mail]>
cmafl.net> cc:
Subject: French Broad
Flows
01/28/2004 12:29
PM
Curtis -
I'd like to formally request stream flows (Drainage Area, 7q 1 Os, 7q 1 Ow,
and Qavg) for the French Broad River where Hwy. 146 crosses the French
Broad near Skyland (Buncombe Co.). I'll send you a hard copy in the
mail, but if you could go ahead and proceed that would be great.
Give me a ring if you have questions. 733-5083, ext. 510. Thanks much.
Susan
2 of 3 3/l/2004 7:4;

r _
NT OF
_ United States Department of the Interior
H O
7 �
U.S. GEOLOGICAL SURVEY
M4RCH 3 3916 Sunset Ridge Road
Raleigh,North Carolina 27607
February 23, 2004
Ms. Susan A. Wilson, Environmental Engineer F E B 2 5 2004
N.C. Division of Water Quality, NPDES Unit
1617 Mail Service Center
Raleigh, North Carolina 27699-1617
Dear Ms. Wilson:
In response to your request for low-flow data, the U.S. Geological Survey (USGS) does not
have site-specific, low-flow discharge data for French Broad River at NC 280 near Skyland,
NC (station id 03447840, drainage area 660 mi2). The low-flow characteristics that are pro-
vided on the attached sheet have been computed by correlating the runoff characteristics of a
nearby continuous-record gaging station upstream of the request site. Please note that the flow
estimates do not specifically account for the presence of any diversions or regulation, present
or future, which may occur upstream of the request site. Because a similar request for the
1Q10 low-flow discharge was received about the same time from Progress Energy, this low-
flow statistic is included on the attached sheet.
Low-flow characteristics were analyzed using streamflow records from a continuous-record
gaging station on the French Broad River near Fletcher, operated since July 2001 and located
upstream at Secondary Road 1419 (station id 03447840, drainage area 640 mi2). Because of
the short period of record at the Fletcher gage, low-flow analyses at this gage were completed
by correlation analyses using two other gaging stations having long periods of record (station
id's 03443000 and 03451500). Then, using the difference in drainage areas between the
request site and the Fletcher gage, low-flow characteristics at the request location were deter-
mined using the low-flow yields (expressed as flow per square mile drainage area) at the
Fletcher gage. The estimated 7Q10 discharge is 306 ft3/s and is lower than the estimate pro-
vided to you in an e-mail dated January 14, 2004.
Analyses of low-flow characteristics at all three gaging stations indicates a decreasing trend
in low-flow yields between the gages at Blantyre and Asheville. Between these two locations,
the river is affected by some diversions occurring in tributaries along with regulation by small
upstream reservoirs and a power plant located about 8 miles upstream of Blantyre. The anal-
yses indicate that most of the decrease in low-flow yields occurs between the Blantyre and
Fletcher gages.
The table shown on the accompanying page summarizes the low-flow characteristics at the
gaging stations used in the analyses. As previously discussed in January, the French Broad
River downstream from Blantyre is affected by some regulation and diversions. The low-flow
discharge values are based on streamflow records available through September 2003, and the
associated low-flow yields for each value is listed to provide insight in the changing low-flow
yields between the gages.
[phone] • FAX[phone]

t
Ms. Susan A. Wilson Page 2
February 10, 2004
Low-flow characteristics
(tc3/s)
E Sal
'c Station name w E C o a
= m
00 G 0 c ti
V)
M Q
03443000 French Broad River at Blantyre 296 3.3 197 375 252 316
(Secondary Road 1503,Henderson County) (0.666) (1.267) (0.851) (1.068)
03447687 French Broad River near Fletcher 640 2.7 297 613 397 515
(Secondary Road 1419,Buncombe County) (0.463) (0.957) (0.620) (0.804)
03441500 French Broad River at Asheville 945 2.2 425 833 563 720
(Secondary Road 1348,Buncombe County) (0.450) (0.882) (0.596) (0.762)
These data are preliminary and subject to revision pending approval for publication by the
Director of the U.S. Geological Survey, and are made available through our cooperative pro-
gram of water-resources investigations with the North Carolina Department of Environment
and Natural Resources.
If you have any questions regarding this information, please contact us at [phone]. gyp- 3�3
Sincerely,
/iy6dur
rtseaver
logist
Enclosure

1 �
SUMMARY OF LOW-FLOW ESTIMATES IN RESPONSE TO REQUEST
REQUEST NO: 91623 SITE NO: 01 DATE: 02/10/2004
SOURCE: DENR(DW-01—ACTION: New
STATION NUMBER: 03447840 STATION TYPE: Ungaged(20)
STATION NAME: French Broad River at NC 280 near Skyland.NC
LOCATION: At NC 280(Long Shoals bridge).and 2 miles west of Skyland
LATITUDE: 35°28'53" LONGITUDE: 82'33'28"
QUANDRANGLE NAME AND NUMBER: Skyland [F-8-NE1
COUNTY CODE: Henderson [0891 STATE CODE: NC [371 DISTRICT CODE:_NC
3[ 71
HYDROLOGIC UNIT CODE: 06010105 ENR BASIN CODE: 04-03-02
DRAINAGE AREA: 660 mit
Flow statistics as follows:
AVERAGE FLOW: Estimated using 2.70 ft3/s/mi2 1,780 ft3/s see note A
ANNUAL 7Q10 MINIMUM FLOW: 0.4634 ft3/S/mi2 306 ft3/s see note A
ANNUAL 30Q2 MINIMUM FLOW: 0.9570 ft3/s/mi2 631 ft3/s see note AI
WINTER 7Q10 MINIMUM FLOW: 0.6198 ft3/s/mi2 409 ft3/s see note LA—]
]
ANNUAL 7Q2 MINIMUM FLOW: 0.8041 ft3/s/mi2 531 ft3/s see note U
OTHER FLOW (specify): _1 1100 0.4258 ft3/s/mi2 282 ft3/s see note A
NOTES:
[A]Estimate is based on records collected at or near the request site.
[B]Estimate is based entirely on runoff characteristics observed at nearby streams.
[C]Estimate based on procedures given in USGS Water Supply Paper 2403"Low-flow Characteristics
of Streams in North Carolina"(Giese and Mason, 1993).
[D]Estimate based on procedures given in USGS Water Supply Paper 2403 and in conjunction with
streamllow records collected at or near the request site.
[E]See remarks.
These data are considered provisional and subject to revision pending approval by the Director,USGS.
REMARKS:
•Low-flow estimates based on low-flow characteristics upstream gaging station 03447687 (French Broad
River near Fletcher)during July 2001 through September 2003. 1 Q 10 flow requested by Progress Energy.
•Requested by Ms. Susan Wilson,N.C.Division of Water Quality//Ms. Louise England, Progress Energy
ENTERED BY. JCW FEE CHARGED: $ 150