r. 

c 

BEST TECHNOLOGY AVAILABLE 

1999 TECHNICAL REPORT 

FOR THE 

PITTSBURG AND CONTRA COSTA POWER PLANTS 

Submitted to: 

SAN FRANCISCO BAY 

REGIONAL WATER QUALITY CONTROL BOARD 

In Compliance With 

Order No. 95-225 

PROVISION D17 NPDES PERMIT NO. CAOOO4880 

and 

CENTRAL VALLEY 

REGIONAL WATER QUALITY CONTROL BOARD 

In Compliance With 

Order No. 95-234 

PROVISION E10 NPDES PERMIT NO. CA0004863 

Submitted by: 

SOUTHER ENERGY CALIFORNIA 

January 31; 2000 

I999 BTA Report 
CONTENTS 

EXECUTIVE SUMMARY 

BEST TECHNOLOGY AVAILABLE TECHNICAL REPORT 

Introduction 

Data Collected on Power Plant Operations 

BTA Monitoring Provision B. 1 - Pittsburg (E3. 1 - Contra Costa) 

BTA Monitoring Provision B. 2 - Pittsburg (B. 2 - Contra Costa) 

BTA Monitoring Provision B. 3 - Pittsburg (B. 3 - Contra Costa) 

BTA Monitoring Provision B. 4 - Pittsburg (E3.4 - Contra Costa) 

BTA Monitoring Provision B. 5. a - Pittsburg (B. 5. a - Contra Costa) 

BTA Monitoring Provision B. 5. b - Pittsburg (B. 5. b - Contra Costa) 

BTA Monitoring Provision B. 5. c - Pittsburg 

Page 

1 

3 

3 

3 

4 

5 

8 

12 

14 

14 

15 

1 1999 BTA Report 
Appendices: 

Appendix A 

Appendix B 

Appendix C 

Appendix D 

Appendix E 

Hourly Gross Megawatts for Contra Costa Units 6 & 7 and Pittsburg Units 

1-7 During the Entrainment Period 

Hourly Gross Megawatts Above Minimum Load for Contra Costa Units 6 

8z 7 and Pittsburg Units 1-6 when Pittsburg Unit 7 was Below Maximum 

Available Capacity During the Entrainment Period 

Exceptions to Hourly Gross Megawatts Above Minimum Load for Contra 

Costa Units 6 & 7 and Pittsburg Units 1-6 when Pittsburg Unit 7 was 

Below Maximum Available Capacity During the Entrainment Period 

Resources Management Program 

Summary of Modifications and Improvements to Intake Systems 

11 1999 BTA Report 
TABLES 

Number Page 

1 Summary of Pittsburg Unit 7 Outages and Curtailments During the 1999 4 

Entrainment Period 

2 Summary of Hours for Contra Costa Units 6 & 7 and Pittsburg Units 1-6 7 

Relative to Pittsburg Unit 7 Operation for the 1999 Entrainment Period 

3 Monthly Capacity Factors and Gross Monthly Generation for the 1999 12 

Entrainment Period 

4 Monthly Cooling Water Flow by Unit Group for Pittsburg and Contra Costa 

Power Plants for the 1999 Entrainment Period 

13 

... 

111 I999 BTA Report 
EXECUTIW SUMMARY 

Southern Energy California, in compliance with provisions of the NPDES permits and BTA 

Monitoring Program requirements for the Pittsburg and Contra Costa power plants, has 

developed this technical report for the 1999 striped bass -- “entrainment period”, which ran from 

May 1 to July 15, inclusive. In accordan>e with permit provisions, the period referred to as the 

eniGnt period is the time from May 1 . . .“or such later date that the Discharger demonstrates 

by a Threshold Monitoring Program or other program approved by Fish and Game that the 

density of striped bass either entrained or located in the river or at the intake structure, 

normalized to 150 mm equivalents, exceeds 0.0005 per cubic meter of cooling water (for 

entrainment sampling) for three consecutive sampling days at either power plant or as defined by 

the agreement with CDFG” and continues until July 15 or until the 38-mm striped bass index is 

predicted to be set, whichever is earlier. Thus the entrainment period does not necessarily 

comprise the entire time from May 1 to the date on which the 38-mm index is set. This year, the 

entrainment period ended on July 15, although the California Department of Fish and Game 

didn’t predict that the 38-mm index would be set until August 6. 

A summary of the significant findings and conclusions related to the provisions of the BTA 

Monitoring Program is presented below: 

a Reductions in cooling water system operations and striped bass losses were achieved at 

the two power plants as a result of measures implemented during the 1999 striped bass 

entrainment period. The entrainment period extended from May 1 through July 15,1999. 

The entrainment period was terminated July 15, as described in the “Agreement Between 

The Pacific Gas and Electric Company and the California Department of Fish and Game 

for the Monitoring and Mitigation of Striped Bass in the Sacramento-San Joaquin 

Estuary”. This agreement was reassigned upon sale of the Pittsburg and Contra Costa 

power plants to Southern Energy California. CDFG predicted that the 38-mm striped 

bass index would be set on August 6, 

a Measures implemented during the 1999 entrainment period at the Contra Costa and 

Pittsburg power plants to reduce striped bass losses included: operation of the variable 

speed circulating water pump controls; removal of circulating water pumps from service 

as soon as practicable to reduce cooling water volumes on units which were not in 

operation; preferential operation of Pittsburg Unit 7; dispatch of committed units to 

minimize the frequency of discharge temperatures exceeding 86“ F; and reduced unit 

loading as part of the Resources Management Program. 

a As provided for in the PG&E/reassigned Southern Energy California and CDFG Striped ~ 

$2, ) 

c, 

@ <*- 

F. f 

Bass Agreement (1995), the 1986 striped bass distribution, the current year operations, 

and the average __,^l__.&-,.*-.--“-*%- of 1976 1978, .-.--n.C*m*r.+., and .IC- 1979 nw-yy-a opera$@ alive 

yb,y,p’f, reduction of 89.0 percent in striped bass losses fro 

--“--.*-.,,.- 

.pl ,p ”) - \,p .c..i” t:x, 

t. 

i 

1 1999 BTA Report 
0 Preferential operation of Pittsburg Unit 7 in accordance with the Resources Management 

Program was achieved during the 1999 entrainment period. Pittsburg Unit 7 was 

available 1,824 hours (100 percent) during the 1999 entrainment period. For 97.9 percent 

of the time that either (1) Pittsburg Unit 7 was operating at maximum available capacity, 

or (2) when Pittsburg Unit 7 was operating at less than maximum available capacity (per 

the RMP), Contra Costa Units 1-7 and Pittsburg Units 1-6 were operating at or below 

minimum capacity. 

0 Pittsburg Units 1-6 and Contra Costa Units 4-7 are equipped with temperature-modified, 

variable speed circulating water pump controls. The variable speed pump controls 

contributed to a reduction in cooling water volumes. 

2 I999 BTA Report 
I t 

BEST TECHNOLOGY AVAILABLE 

TECHNICAL REPORT 

Introduction 

Southern Energy California (SECAL) has prepared this technical report to comply with provisions of 

the NPDES permits and BTA (best technology available) Monitoring Program requirements for the 

Pittsburg and Contra Costa power plants. In 1993, Delta smelt was listed as a threatened species 

under both the federal and state Endangered Species Acts. As provided for in the 1995 Striped Bass 

Agreement between PG&E (reassigned to SECAL upon sale of Pittsburg and Contra Costa power 

plants in April, 1999) and CDFG, striped bass monitoring was not conducted in 1999 because of the 

possibility of collecting a Delta smelt. SECAL and the CDFG agreed to use striped bass entrainment 

data from 1986, a year which closely approximated 1999 bay outflow conditions, and actual 1999 

power plant cooling water systems data to estimate losses for 1999. Since no threshold monitoring 

was done, the striped bass entrainment period ran from May 1 through July 15, and terminated on 

July 15, as stipulated in the CDFG striped bass agreement. CDFG predicted that the 38-mm index 

would be set on August 6,1999. 

This report presents a restatement of each provision from Section B of the BTA Monitoring and 

Reporting Program requirements for both NPDES permits, followed by a discussion of compliance 

with that provision. For purposes of this compliance report, the monitoring requirements will be 

listed as they appear in the Monitoring and Reporting Program for the Pittsburg Power Plant with the 

corresponding requirement, if any, for the Contra Costa Power Plant in parentheses. 

Data Collected on Power Plant Operations 

The following operations data were collected at both the Pittsburg and Contra Costa power plants in 

accordance with Section A of the BTA Monitoring and Reporting Program: 

Hourly records compiled on the operation of each circulating water pump at both plants from 

May 1 to July 15, 1999. Records for the constant speed circulating water pumps at Contra 

Costa Units 1-3 and Pittsburg Unit 7 show whether each pump was in or out of service. 

Records for variable speed circulating water pumps at Pittsburg Units 1-6 and Contra Costa 

Units 4-7 show the percent of flow for each pump. 

Hourly discharge temperatures compiled from Foxboro temperature recorders located in the 

discharge conduits at Pittsburg Units 1-4, 5 and 6, and the Contra Costa Units 1-5, 6 and 7 for 

the period from May 1 to July 15,1999. 

Hourly records of gross electrical generation for Contra Costa Units 6 & 7 and Pittsburg Units 

1-7 during the 1999 entrainment period. 

3 I999 BTA Report 
BTA Monitoring Provision B. 1. - Pittsburg (Provision B. 1. - Contra Costa) 

A tabulation of outages and curtailments for Pittsburg Unit 7 by occurrence with a brief 

description of the cause of each occurrence during the previous entrainment period. 

Discussion 

Table 1 presents information on the curtailments and outages during the 1999 entrainment 

period. Unit 7 did not have any forced.or scheduled outages. Two curtailments affected the 

unit’s generating capacity during the 1999 entrainment period. Unit 7 remained available for 

service during these forced curtailments. 

Table 1 

Summary of Pittsburg Unit 7 Outages and Curtailments 

During the 1999 Entrainment Period 

Total Curtailment (Mwe) Outage (Mwe) 

Start Date / Time End Date / Time Hours Reason Forced Scheduled Forced Scheduled 

05-24-99 / 1430 05-24-99 / 1805 4 Feedwater heater high level trip 62 

06-26-99 / lo00 06-29-99 / 2210 82 Feedwater heater head leak 12 

* 

* Note: the hours reported are for the entrainment period only. 

4 I999 BTA Report 
BTA Monitoring Provision B. 2. - Pittsburg (Provision B. 2. - Contra Costa) 

A comparison of hourly electrical generation by unit at Contra Costa Units 1-7 and Pittsburg 

Units 1-6 with the generation at Pittsburg Unit 7 (expressed as a percentage of available 

capacity) during the previous entrainment period as it pertains to compliance with provisions of 

the Resources Management Program. 

Discussion 

Hourly gross megawatts for Contra Costa Units 6 & 7 (Units 1-5 were not operated in 1999, and 

consequently, are not reported here) and Pittsburg Units 1-7 for each day of the entrainment 

period (May 1 through July 15) are provided in Appendix A. Also included in this appendix is 

the hourly generation at Pittsburg Unit 7 expressed as a percentage of available capacity. 

Pittsburg Unit 7 available capacity reflects the maximum generation possible from the unit each 

hour. The available capacity varies in response to changing operating conditions as reported in 

the unit-specific curtailments and outages (shown in Table 1) for Unit 7. 

Appendix B provides the hourly gross megawatts above minimum load for Contra Costa Units 6 

& 7 and Pittsburg Units 1-6 when Pittsburg Unit 7 was operating at less than 100 percent of its 

available load during the entrainment period. To arrive at the values in Appendix B, the 

minimum load established for each unit was subtracted from the hourly generation values 

reported for each unit in Appendix A. Minimum load is set each year by the Operations 

Department of the power plants and is based on the current operating condition of the units. In 

1999, the minimum load was 35 megawatts for Pittsburg Power Plant Units 1-4 and 50 

megawatts for Pittsburg Power Plant Units 5 & 6 and Contra Costa Power Plant Units 6 & 7. 

Unless a unit was operating above minimum load when Pittsburg Unit 7 was not operating at full 

available capacity, generation at the units is reported as a zero in Appendix B. Appendix B thus 

serves to highlight all instances when one or more of the units at the two plants was operating 

above minimum load at the same time that Pittsburg Unit 7 was not operating at full available 

capacity. 

Constraints imposed by rapid changes in system demand or the necessity to maintain system 

reliability precluded the preferential operation of Pittsburg Unit 7 on some occasions. The 

margins of Appendix B have been numbered to indicate those instances when Pittsburg Unit 7 

was operating at less than maximum available capacity when other unites) were operating above 

minimum load. These margin numbers correspond to the event numbers listed in Appendix C 

which summarize the date, time, and affected units for each instance of non-preferential 

operation. Appendix C also provides a description of the situation or problem that caused the 

occurrence. Instances when Unit 7 was not operating at full available capacity when another unit 

was operating at less than 10 MW above minimum load are not discussed. 

Evaluating compliance with provisions of the Resources Management Program (W) requires 

consideration of both the preferential operation of Pittsburg Unit 7 during the entrainment period 

and operational constraints related to meeting electrical system demand and maintaining system 

reliability. Preferential operation of Pittsburg Unit 7 can involve a change from the standard unit 

5 1999 BTA Report 
dispatch schedule of the Independent System Operator or SECK to maximize power production 

from Pittsburg Unit 7 before increasing power production above minimum load at any other unit 

at the Pittsburg and Contra Costa power plants as required under Section D.14 and E.7 of each 

power plants "DES Permits, respectively (See Appendix D for a complete listing of all 

provisions of the RMP). This preferential operation scheme is to be in effect throughout the 

striped bass entrainment period. 

Appendix B represents the tabulation of 14,592 hourly observations during the entrainment 

period (Pittsburg Units 1-6 and Contra Costa Units 6 & 7 = 8 units x 1,824 total hourly 

observations during the entrainment period = 14,592). During the striped bass entrainment 

period, Pittsburg Unit 7 was available 100 percent of the time. Table 2 provides a summary of 

the information presented in Appendix C relative to Pittsburg Unit 7 operation during the 

entrainment period. For 97.9 percent of the time that either (1) Pittsburg Unit 7 was operating at 

maximum available capacity, or (2) when Pittsburg Unit 7 was operating at less than maximum 

available capacity (per the RMP), Contra Costa Units 1-7 and Pittsburg Units 1-6 were operating 

at or below minimum capacity. 

Table 2 demonstrates adherence to preferential operation of Pittsburg Unit 7 during the 1999 

entrainment period. 

6 1999 BTA Report 
Table 2 

Summary of Hours for Contra Costa Units 6 &7 and Pittsburg Units 1-6 

Relative to Pittsburg Unit 7 Operation for the 1999 Entrainment Period 

Number of Percentage 

(Hours) Total 

Observations of 

PPPU7 at less than Maximum Available 

PPPU7 Operating 

a.4 

Under RMP Provision 1,480 10.1 

PPPU7 at Maximum Available 

0 Mwe above Minimum 

Load for CCPPU6 & 7 

Subtotal 

and PPPU1-6 

Mwe above Minimum 

Load for CCPPU6 & 7 

and PPPU1-6 

1-9 

10-25 

26-50 

51-75 

76-100 

101- 150 

151-200 

20 1-250 

>250 

12,816 

14,296 

147 

11 

20 

12 

5 

28 

10 

11 

52 

87.8 

97.9 

1 .o 

0.1 

0.1 

0.1 

4.1 

0.1 

0.1 

0.1 

0.4 

Subtotal 296 2.1 

Total 14,592 100.0 

Note: Generation is reported as a zero when a unit is operating at, or below, minimum load as 

well as when Pittsburg Unit 7 is operating at full available capacity. 

7 1999 BTA Report 
BTA Monitoring Provision B. 3. - Pittsburg (Provision B. 3. - Contra Costa) 

A summary of information used to determine the start and end date of the entrainment period. 

Discussion 

The 1999 entrainment period ran from May 1 to July 15, inclusive. The NPDES permits state 

that “the entrainment period shall commence either May 1 or such later date that the Discharger 

demonstrates by a Threshold Monitoring Program or other program approved by Fish and Game 

that the density of striped bass either entrained or located in the river or at the intake structure, 

normalized to 150 mm equivalents, exceeds 0.0005 per cubic meter of cooling water (for 

entrainment sampling) for three consecutive sampling days at either power plant, or as defined by 

the agreement with the CDFG.” Threshold monitoring was not conducted; therefore, the 

entrainment period began May 1. 

Under the NPDES permits, the entrainment period can end when “the density of striped bass 

normalized to 150 mm is less than 0.0005 per cubic meter of cooling water (for entrainment 

sampling) in any three consecutive monitoring samples at both Pittsburg and Contra Costa Power 

Plants, or the day when the striped bass 38 mm index is set, as predicted by CDFG whichever is 

earlier” or as described in the “Agreement Between The Pacific Gas and Electric Company and 

the California Department of Fish and Game for the Monitoring and Mitigation of Striped Bass 

in the Sacramento-San Joaquin Estuary”. This agreement was reassigned upon sale of the 

Pittsburg and Contra Costa power plants to SECAL. The 1999 entrainment period ended as 

stipulated in the agreement on July 15. CDFG predicted that the striped bass population would 

reach 38-mm as of August 6, 1999 (See letter to Southern Energy Delta from Perry Herrgesell 

(CDFG) dated September 21, 1999). 

8 1999 BTA Report 
YL 

d 

blank page left for CDFG letter 

9 1999 BTA Report 
blank page left for CDFG letter 

10 1999 BTA Report 
blank page left for CDFG letter 

11 1999 BTA Report 
BTA Monitoring Provision B. 4. - Pittsburg (Provision B. 4. - Contra Costa) 

A summary of monthly capacity factors and generation by unit for the Pittsburg and Contra 

Costa power plants and monthly cooling water flow by unit group as in A.2 for the preceding 

entrainment period. 

Discussion 

The 1999 entrainment period ran from May 1 through July 15, 1999. Monthly generation, 

capacity factors, and cooling water volumes are therefore reported for the months of May, June, 

and July 1-15. 

The monthly capacity factors (percent) and generation by unit for Contra Costa and Pittsburg 

power plants during May, June, and July 1-15, 1999 are presented in Table 3. 

A capacity factor is determined by dividing the actual gross unit generation by the maximum 

potential generation during the period of interest. The capacity factor gives an indication of the 

amount of generation a unit is producing versus the maximum generation a unit can produce. 

Power 

Plant 

Contra Costa 

Unit 1 

Unit 2 

Unit 3 

Unit 4 

Unit 5 

Unit 6 

Unit 7 

Pittsburg 

Unit 1 

Unit 2 

Unit 3 

Unit 4 

Unit 5 

Unit 6 

Unit 7 

Table 3 

Monthly Capacity Factors and Gross Monthly Generation 

for the 1999 Entrainment Period 

CaDacity Factors’ 

Gross Monthly 

Generation (MWH) 2 

May June Julf May June July’ 

0 0 0 

0 0 0 

0 0 0 

0 0 0 

0 0 0 

6.0 2.1 21.4 

5.8 10.0 27.4 

0 0 0 

0 0 0 

0 0 0 

0 0 0 

0 0 0 

15,480 6,670 26,530 

14,780 24,830 34,000 

0.0 4.7 15.6 0 5,800 9,540 

0.0 1.8 15.5 0 2,250 9,510 

0.0 1.7 10.5 0 2,140 6,410 

1 .o 1.9 11.9 1,310 2,340 7,270 

0.0 9.1 22.6 0 21,540 26,790 

11.1 6.1 15.8 27,200 14,540 18,790 

28.7 32.8 47.5 158,100 175,000 126,500 

These numbers represent the gross capacity factors for the unit’s generators. 

These numbers represent the MWHs generated by both the main and the house-unit generators. ’ July 1-15, only. 

12 1999 BTA Report 
The monthly cooling water flow (m3 x 10') by unit group for Contra Costa and Pittsburg power 

plants during May, June, and July 1-15, 1999 is presented in Table 4. These data are presented 

by unit group because each group shares the same water intake structure. 

* In millions 

Table 4 

Monthly Cooling Water Flow* by Unit Group for Pittsburg 

and Contra Costa Power Plants for the 1999 Entrainment Period 

Power Plant May June July ( 1 - 15) 

Pittsburg 

Units 1-4, & 7 3.90 10.12 17.60 

Units 5 & 6 9.54 15.60 14.32 

Contra Costa 

Units 1-5 0.00 0.00 0.00 

Units 6 & 7 8.70 10.20 13.83 

of cubic meters. 

13 1999 BTA Report 
BTA Monitoring Provision B. 5. a. - Pittsburg (Provision B. 5. a. - Contra Costa) 

Compliance with Resource Management Program 

Discussion 

Evaluating compliance with provisions of the RMP requires consideration of both the 

preferential operation of Pittsburg Unit 7 during the entrainment period and operational 

constraints related to meeting electrical system demand and maintaining system reliability. 

Preferential operation of Pittsburg Unit 7 can involve a change from the standard unit dispatch 

schedule of the Independent System Operator or SECAL to maximize power production from 

Pittsburg Unit 7 before increasing power production above minimum load at any other unit at the 

Pittsburg and Contra Costa power plants except as stipulated under Section D. 14 and E.7 of each 

power plants NPDES Permits, respectively (See Appendix D for a complete listing of all 

provisions related to the RMP). Preferential operation of Pittsburg Unit 7 is required throughout 

the striped bass entrainment period. In 1999, the entrainment period ran from May 1 through 

July 15. 

During the striped bass entrainment period, Pittsburg Unit 7 was available 100 percent of the 

time (1,824 out of a possible 1,824 hours). Table 2 demonstrates adherence to either preferential 

operation of Pittsburg Unit 7 when it was available for service or to the provisions of the RMP 

during the 1999 striped bass entrainment period. For 97.9 percent of the time either (1) Pittsburg 

Unit 7 was operating at maximum available capacity, or (2) when Pittsburg Unit 7 was operating 

at less than maximum available capacity (per Provisions D. 14 and E.7 of the RMP), Contra Costa 

Units 1-7 and Pittsburg Units 1-6 were operating at or below minimum capacity. 

BTA Monitoring Provision B. 5. b. - Pittsburg Provision B. 5. b. - Contra Costa) 

Status of intake improvements and modification, if any. 

Discussion 

No improvements or modifications to the intake systems were made in the previous 12-month 

period (since the last BTA report was submitted, January 31,1999). 

A summary of previous intake improvements and modifications, including installation of 

temperature modulated variable speed pumps at Pittsburg Units 1-4 and Contra Costa Units 4-5 

and a circulating water crossover system on Contra Costa Units 1-3 (1987 and 1988) are listed in 

Appendix E. 

14 1999 BTA Report 
BTA Monitoring B. 5. c.- Pittsburg 

A summary of intake screen operation (rotation frequency) at Contra Costa and Pittsburg Power 

Plants, and fish pump operation at the Contra Costa Units 1-5 intake during the previous 

calendar year. 

Discussion 

Debris retained, along with fish and invertebrates, by the cooling water intake screens at the 

Pittsburg and Contra Costa power plants is removed during screen rotation and washing. This is 

to maintain intake water velocities as close as practicable to design levels as specified in 

provisions of the NPDES permits. Screen rotation and washing are initiated either manually, by 

a timer, or when the hydraulic differential across the screen exceeds a predetermined maximum. 

Intake screens are normally operated on a timer set for two wash cycles per 8-hour shift at the 

Pittsburg Power Plant and three wash cycles per 8-hour shift at the Contra Costa Power Plant, 

with each wash cycle 15 minutes in duration. All intake screens in operation at both power 

plants were rotated and cleaned using dual high-pressure spray washes at a frequency of not less 

than once every four hours with the exception of those intake screens removed from service by 

mechanical failure, periodic maintenance inspections, or overhaul. 

Because Contra Costa Units 1-5 were not in service during the entrainment period, the fish 

pumps were not operated in 1999. 

15 1999 BTA Report 
BEST TECHNOLOGY AVAILABLE 

1999 TECHNICAL REPORT 

FOR THE 

PITTSBURG AND CONTRA COSTA POWER PLANTS 

APPENDICES 

Submitted to: 

SAN FRANCISCO BAY 

REGIONAL WATER QUALITY CONTROL BOARD 

In Compliance With 

Order No. 95-225 

PROVISION D17 NPDES PERMIT NO. CA0004880 

and 

CENTRAL VALLEY 

REGIONAL WATER QUALITY CONTROL BOARD 

In Compliance With 

ORDER NO. 95-234 

PROVISION E10 NPDES PERMIT NO. CA0004863 

Submitted by: 

SOUTHERN ENERGY CALIFORNIA 

January 31,2000 

1999 BTA Report 
TABLE OF CONTENTS 

Appendix A Hourly Gross Megawatts for Contra Costa Units 6 & 7 and Pittsburg Units 1-7 

During the Entrainment Period 

Appendix B Hourly Gross Megawatts Above Minimum Load for Contra Costa Units 6 & 7 and 

Pittsburg Units 1-6 when Pittsburg Unit 7 was Below Maximum Available 

Capacity During the Entrainment Period 

Appendix C Exceptions to Hourly Gross Megawatts Above Minimum Load for Contra Costa 

Units 6 & 7 and Pittsburg Units 1-6 when Pittsburg Unit 7 was Below Maximum 

Available Capacity During the Entrainment Period 

Appendix D Resources Management Program 

Appendix E Summary of Modifications and Improvements to Intake Systems 

1999 BTA Report 
Appendix A 

Hourly Gross Megawatts for Contra Costa Units 6 & 7 and Pittsburg Units 1-7 During the 

Entrainment Period 

1999 BTA Report 
Appendix B 

Hourly Gross Megawatts Above Minimum Load for Contra Costa Units 6 & 7 and 

Pittsburg Units 1-6 when Pittsburg Unit 7 was Below Maximum Available Capacity 

During the Entrainment Period 

I999 BTA Repori 
Appendix C 

Exceptions to Hourly Gross Megawatts Above Minimum Load for Contra Costa Units 6 & 

7 and Pittsburg Units 1-6 when Pittsburg Unit 7 was Below Maximum Available 

Capacity During the Entrainment Period 

1999 BTA Report 
Exceptions to Hourly Gross Megawatts Above Minimum Load for Contra Costa Units 

6 & 7 and Pittsburg Units 1-6 when Pittsburg Unit 7 was below Maximum Available 

Capacity During the Entrainment Period: 1999 

Event Affected Plant & Unit 

Number me Contracosta Pittsburg Time 

1 05/06/99 6 6 0500-0600 

6 0500 

2 05/19/99 7 0900 

3 05/20/99 7 0900 

4 05/24/99 7 0900 

5 05/25/99 7 0400-0500 

6 05/27/99 6 2200 

7 05/28/99 7 2000 

8 06/09/99 5 1700-2200 

9 06/22/99 5,6 1900 

10 06/28/99 67 1,5,6 1900 

11 06/29/99 6 5 2200 

12 06/30/99 6,7 1,3,4,5,6 1500 

13 06/30/99 67 1,3,4,5,6 1700-1800 

14 06/30/99 67 5,6 2200 

15 07/08/99 5 2300 

16 07/19/99 67 1500 

17 07/11/99 5 2200 

18 07/12/99 677 1,2,4,5,6 1400-1900 

19 07/13/99 67 0900 

20 07/14/99 67 5,6 0800 

21 07/14/99 67 5,6 1100 

23 07/14/99 67 5,6 1900 

24 07/15/99 67 5,6 0900 

25 07/15/99 67 1400 

22 07/14/99 67 5,6 1300-1600 

26 07/15/99 697 16 1900 

27 07/15/99 67 2000-2200 

28 07/15/99 7 2300 

Comments 

PPPU7 coming on line after fuel 

economy 

PPPU7 raising load simultaneously 

See event #2 

See event #2 

CCPPU7 ordered to low-range AGC 

PPPU6 ordered to low-range AGC 

CCPPU7 valve testing 

PPPU5 vibration testing after overhaul 

See event #2 

PPPU7 thought to be at full available 

Lowering load simultaneously 

See event #15 

See event #15 

See event #16 

See event #16 

See event #15 

PPPU5 ordered to high-range AGC 

See event #15 

See event #2 

See event #2 

See event #15 

See event #15 

See event #15 

See event #2 

Load change on PPPU7 ordered by 

SCEM 

See event #16 

CCPPU6,7 ordered to full available by 

SCEM 

CCPPU7 lowering load 

c- 1 1999 BTA Report 
Appendix D 

Resources Management Program 

1999 BTA Report 
Provisions Related to BTA* 

14. (7. - Contra Costa) 

if 

During the entrainment period, the discharger shall implement the following 

Resources Management Program, which is designed to minimize adverse 

environmental impacts: 

a. The Discharger shall maximize the commitment of, dispatching of, and 

power production from Pittsburg Unit 7, as required to meet system 

demand, in place of and before the dispatching and power production 

above minimum load at any other unit at Pittsburg or Contra Costa Power 

Plants, except under the following conditions: 

1) Whenever Pittsburg Unit 7 is committed, Pittsburg Unit 5 or 6 may 

operate at minimum load for the purpose of providing steam necessary 

to start or restart Pittsburg Unit 7. 

2) The Discharger may remove Pittsburg Unit 7 from service for 

emergency or unscheduled maintenance, for personnel or equipment 

safety, or for the reliability of the system. 

3) The Discharger may have Pittsburg Unit 7 at less than full available 

load when other committed units are dispatched above minimum load 

necessary to meet system stability, equipment or personnel safety, and 

to respond to system transient conditions. 

4) When generation from Pittsburg Unit 7 is not needed, the Discharger 

may have one unit in operation at Pittsburg and/or Contra Costa, 

without dispatching Pittsburg Unit 7, if necessary to maintain system 

reliability according to prudent utility operating practice, including 

equipment and personnel safety, or to provide steam supply. 

5) The Discharger may operate units without restraint at either power 

plant if the Discharge demonstrates with the threshold monitoring 

program that the densities of striped bass do not exceed the threshold 

at that power plant. 

b. The Discharger shall minimize the commitment and dispatch of all units at 

Contra Costa Power Plant to minimize cooling water flows unless 

commitment and dispatching of these units is necessary to meet system 

demand, to meet power pool commitments, and/or to maintain system 

* From section D. and E. Provisions of the NPDES permits for the Pittsburg and Contra 

Costa power plants, respectively. 

D- 1 1999 BTA Report 
J 

reliability according to prudent utility operating practice, including 

equipment and personnel safety. 

c. All committed units at Pittsburg and Contra Costa power plants must be 

dispatched to the level at which the unit discharge temperatures equal 

86 OF before the discharge temperature for any similar unit is allowed to 

exceed 86 OF unless the unit is located at a plant which has fish densities 

below the threshold level as demonstrated by the threshold monitoring 

program. 

d. The Discharger shall schedule Pittsburg Unit 7 overhauls so that work 

shall not occur between 1 May and 30 July each year. 

e. The Discharger shall minimize circulation water flows under all 

conditions, 

temperatures 

shall use 

except during clorination, while maintaining discharge 

pursuant to Provision 14. c (7. c - Contra Costa). The Discharger 

the variable speed pumps whenever the units operate at reduced loads in 

accordance with design parameters. Reduced load is defined as less than 

95% of maximum load for the existing variable speed pumps. The 

Discharger shall shut off circulation water for uncommitted units as soon 

possible, except as required according to prudent operating practices to 

ensure personnel and equipment safety. 

as 

f. The Discharger shall recirculate house unit cooling water to suction when 

the house units at Contra Costa are in service without the main units. 

D-2 1999 BTA Report 
Appendix E 

Summary of Modifications and Improvements to Intake Systems 

1999 BTA Report 
Summary of Modifications and Improvements to Intake Systems 

Year Modification andor Improvement 

1999 None 

1998 None 

1997 None 

1996 None. 

1995 None. 

1994 Fiberglass baskets installed on Contra Costa intake screen number 8 (12/94) and 9 

(3/94). 

1993 Fiberglass baskets installed on Contra Costa intake screen number 6 (6/93) and 7 

(3/93). 

1992 None. 

1991 Fiberglass baskets installed on Contra Costa intake screen number 10 (1 1/91). 

1990 None. 

1989 None. 

1988 Temperature modulated variable speed pumps installed on Pittsburg Units 1-4 and 

Contra Costa Units 4 & 5. 

1987 Water crossover system installed on Contra Costa Units 1-3. 

E- 1 1999 BTA Report