HomeMy WebLinkAboutC-1332 - Study of Master Plan Supply Facilities for Portions of Pressure Zones III, IV, and V - Harbor View HillsMAR 22 )t)h March 22, 1971
TO: CITY COUNCIL
By the CITY COUNCIL
FROM: Public Works DepartmenirITY OF NKwOMRt WCH
SUBJECT: STUDY OF MASTER PLAN WATER SUPPLY FACILITIES FOR PORTIONS OF
PRESSURE ZONES III, IV, AND V.
RECOMMENDATIONS:
1. Receive the report on "Master Plan Water Supply
Facilities for Portions of Pressure Zones III,
IV, and V ".
2. Refer report to the Council Water Committee for
study.
3. Authorize the staff to obtain proposals for design
and preparation of plans and specifications for
construction of the facilities.
DISCUSSION:
On December 21, 1970 the Council authorized execution of an agreement with
Shuirman- Simpson, Civil Engineers, for performing the subject study. Copies of the
resulting report are attached for members of the Council.
In connection with the development of the recently annexed area known as
Upper Harbor View Hills, Sector IV, construction of the facilities studied is needed.
These facilities consist of a major pumping station for Pressure Zones III and IV at
Big Canyon Reservoir, a transmission main in the future easterly extension of San Joaquin
Hills Road, and a Zone IV reservoir to be located northerly of San Joaquin Hills Road
and easterly of future Spy Glass Hill Road. Construction of a pressure regulated inter-
connection between Zones II and III at Big Canyon Reservoir will also be included in
the project.
A meeting of the Council Water Committee has been scheduled for March 29.
Among other items on the agenda, it is anticipated that the committee will consider
recommendations on the financing of the construction of the water supply facilities.
In order to meet current scheduling it is also recommended that proposals
be obtained from consultants for design of the facilities.
It is expected that detailed information and recommendations regarding costs,
financing, and design agreements will be presented for Council consideration at the
meeting of April 12, 1971.
r
in
iirector
I0
MAR 2 z 1971
By the CITY COUNCIL
C)TY s;W NrwpiQ%,v pWQH
CITY OF NEWPORT BEACH
MASTER PLAN
WATER SUPPLY FACILITIES
PORTIONS OF ZONES III, IV '& V
L March, 1971 J
March 15, 1971
CONSULTING CIVIL ENGINEERS
Public Works Department
City of Newport Beach
Newport Beach, California
Attention: Mr. Benjamin B. Nolan
Gentlemen:
In accordance with the Agreement dated December
23, 1970, we have completed the necessary engineering studies
for Master Plan Water Supply Facilities for portions of zones
III, IV, and V, and are submitting herewith our report.
The ultimate estimated cost of the improvements
recommended, including the two pumping stations, reservoir,
transmission mains, and pressure reducing station is $435,200.
The estimated cost of the first phase of the improvements
required to serve Sector IV of Harbor View Hills is $369,800.
The cost estimates include an allowance for a
million gallon prestressed concrete reservoir buried to the
top of the walls, but not covered with earth. Also, land-
scaping of the site has not.been included in the estimates.
If the landscaping installation is to be the responsibility
of the City and the reservoir is to be completely buried,
then the cost estimates will need to be increased.
A substantial amount of time was spent on an
economic comparison of electric motors versus natural gas
engines as prime movers for the two pumping stations. The
annual cost of natural gas engines appears to be slightly
less than for electric motors, but because of greater
reliability and simplified maintenance the electric motors
have been recommended.
We will be available at your convenience to
discuss any aspect of the report. .
Respectfully submitted,
SHUIRMAN- SIMPSON
Don ld C. Simpson
Fritz C. `Sk�leppat
• DCS:c
NEWPORT CENTER BUILDING
369 San Miguel Drive
Newport Beach, California 82660
0141644 -0663
•
1•
s
INDEX
SECTION
PAGE
I.
Purpose of Study ----------------------- -, -
- -- 1
II.
Criteria ------- ------ -=------- ------ -- - - --
-- 3
III.
Board of Fire Underwriter Requirements - - -
- -- 3
IV.
Water Service Zone IV - General ------- - - -
- -- 4
A. Water Requirements ------ ------- --- - - -
--- 5
B. Proposed System------------------- - - -
- -- 6
C. First Phase Development'----------- - - -
- -- 8
D. First Phase Reservoir Capacity ---- - - -
- -- 9
E. Elevation of Reservoir No. 1 ------ - - -
- -- 11
F. Type of Reservoir Construction ---- - - -
- -- 14
V.
Pressure Reducing Station Zone III
to Zone II --------- --------------- ---- - - -
- -- 16.
VI.
Pump Station Zone III ----------------- - - -
- -- 18
A. Operational Criteria -- =- .---------- - - -
- -- 18
B. Electric Motor Alternate ---------- - - -
- -- 19
C. Natural Gas Internal Combustion
Engine Alternate --------------=--- - - -
- -- 20
D. Type of Pump ------- ---------------------
21
VII.
Pump Station Zone IV ------------------ - - --
-- 22
A. Operational Criteria -------------- - - -
- -- 22
B. Electric Motors as Prime Movers.--- - - -
- -- 23
C. Natural Gas Internal Combustion
Engines as Prime Movers ----------- - - -
- -- 23
VIII.
Cost Comparisons of Electric Motors
versus Gas Engines -------------------- - -
- - -- 25
IX.
Cost Estimates ------------------------ - -
- - -- 29
TABLES
Table No. 1 -------------- --------- ---- - -
- - -- 10
Table No. 2 ----- ---------------------- - -
-- -- 12
Table No. 3 ------- -------------------- --
- - -- 12 .
Table No. 4 ------------------------- -- - -
- - -- 22
APPENDIX
PAGE
Operating Cost for Electric Motors Zone III and IV - - -- 31
Operating Cost for Natural Gas Engines Zone III and IV- 34
Pump Station Zone III, Electric Motors - Cost Estimate- 36
Pump Station Zone IV, Electric Motors - Cost Estimate -- 38
Pump Station Zone III, Natural Gas Engines -
Cost Estimate ----------------------------------- - - - - -- 39
Zone IV Natural Gas Engines - Cost Estimate ----- - - - - -- 42
"Phase I" Construction Estimate ----------------- - - - - -- 42
Sitework Pump Station Zone III and IV ----------- - - - - -- 45
Pressure Reducing Station Zone III to Zone II -
Cost Estimate ----------------------------------- - - - - -- 46
Reservoirs - Cost Estimate ---------------------- - - - - -- 47
Transmission Mains - Cost Estimate -------------- - - - - -- . 48
•
POWER SCHEDULES
Southern
California.Edison
Company
- Schedule
No.
PA -1
Southern
California
Edison Company
- Schedule
No.
PA -2
Southern
California
Gas Company - - --
Schedule
No.
G -46
Southern
California
Gas Company - - --
Schedule
No.
G -51
PLATES
Plate 1 - Water Service Zones III and IV
Plate 2 - Reservoir No. 1
Plate 3 - Pump Station - Zone III & IV - Electric Motors
Plate 4 - Pump Station - Zone III & IV - Natural Gas Engines
Plate 5 - Water Transmission Mains
•
I. PURPOSE OF STUDY
40 The purpose of this study was to investigate, analyze,
and submit preliminary alternative layouts and cost estimates
for Master Plan Water Supply Facilities for portions of Zones
III, IV, and V to be constructed by the City and a pressure
reducing station that would permit water to be supplied from
Zone III to Zone II.
The following specific items were included in this
study:
1. Review the existing schematic designs for the Zone
III and the Zone IV pumping stations to be located
adjacent to Big Canyon Reservoir.
2. Investigate alternative designs for the two stations,
• using Big Canyon Reservoir as a suction for the Zone
III station, and the Zone III pumping station and /or
existing 24 -inch Zone III line as suction for the
Zone IV pumping station.
3. Recommend the capacities and the number of pumps for
each pumping station that would allow for stage
construction to meet the required demand as the
area to be served increases.
4. Prepare a preliminary layout for a pressure
regulated interconnection between Pressure Zones
III and II at Big Canyon Reservoir.
5. Prepare preliminary cost estimates for the pressure
regulated interconnection and the Zone III and Zone
. IV pumping stations.
- 1 -
0
6. Prepare an economic analysis of electrical motors
versus natural gas engines for the pumping station
PUMPS
7. Determine the capacity and investigate alternative
designs for.the Zone IV reservoir.
8. Prepare cost estimates and preliminary layouts
for the 16 -inch transmission main and the Zone IV
reservoir required to serve Sector IV of Harbor
View Hills.
9. Prepare alternative preliminary layouts showing
the relationships of the pumping stations,
pressure regulator, transmission main, and
reservoir which will permit a specific alternative
to be chosen.
- 2 -
I2. CRITERIA
• In general the 1965 report of James M. Montgomery,
Consulting Engineers, entitled "Study of Water Pressure
Zone III ", has been used in this study to determine water
requirements and boundaries of the various service zones.
In the Montgomery report a water duty of 2.5 acre -feet/
acre /year was recommended for use in determining the water
requirements for single - family residential developments.
It was further recommended in the Montgomery report
that the maximum day demand for design purposes be equal to
1.8 times the average day, and that the peak hour demand be
equal to 3.6 times the average day.
The Montgomery report recommended that Service Zone
contours.
III. BOARD OF FIRE UNDERWRITER REQUIREMENTS
Fire flow and storage requirements were discussed
with the engineers of the Pacific Fire Rating Bureau, and the
grading schedule used by the Bureau in rating a city's fire
protection system was reviewed. It was concluded that the
reliability of the water system is rated by the Bureau on the
• -. 3
III be
defined by
170 -foot
and
355 -foot contours and that
Service
Zone IV be
bounded
by
the 355 -foot and 540 -foot
contours.
III. BOARD OF FIRE UNDERWRITER REQUIREMENTS
Fire flow and storage requirements were discussed
with the engineers of the Pacific Fire Rating Bureau, and the
grading schedule used by the Bureau in rating a city's fire
protection system was reviewed. It was concluded that the
reliability of the water system is rated by the Bureau on the
• -. 3
system's ability to provide maximum day demand plus the
• required fire flow under the following conditions:
1. Any portion of the pipe network out of
service for 5 days.
2. The largest pump out of service for 5
days.
3. Power to drive pumps out for 2 days.
In areas which are primarily residential in character
the duration of the required fire flow may be reduced by 50
percent when applying the above criteria. In a pump -tank
system, as is planned for Water Service Zone IV and the other
higher zones, the pumps, pipe networks, and reservoirs are
the individual elements making up the total integrated system.
From the Underwriter's point of view, they are concerned with
• the reliability of the total integrated system rather than any
of the separate elements. Therefore in designing a pump -tank
system the individual elements should be designed to develop
the most economical system that will provide the required
reliability.
IV. WATER SERVICE ZONE IV - GENERAL
In the 1965 Montgomery report, Water Service Zone IV was
shown as an area comprising 750 acres of land in the coastal
area of the Irvine Ranch, bounded on the west by new MacArthur
Boulevard and on the east by the drainage divide easterly of
Crystal Cove. In that report it was assumed that the ultimate
easterly boundary of the City would be this same drainage divide.
For the purposes of this Study it has been assumed that
•
- 4 -
this is still the most probable easterly limit of the service
• boundary, but at the same time it is recognized that a system
should be designed,which would be flexible enough to, accommodate
either an increase or a decrease in the ultimate service area.
The general extent of the proposed service area is.shown
on Plate I. The area outlined is approximately 850 acres. As
can be seen, this service zone is a narrow strip of land lying
between the 355 -foot and the 540 -foot contours. A large part
of this zone represents a transition in topography between the
Coastal Shelf and the ridges of the San Joaquin Hills.. The
general steepness of the slopes would seem to suggest that the
overall densities of land use might.be somewhat less than in
either Zone III below or Zone V above.
Although planned land uses in part of the service zone
• are currently being studied by The Irvine Company, it appears
that the Montgomery report assumption that the primary land
use will be single - family detached dwellings is still valid.
Therefore, in estimating water requirements it has been
assumed that the ultimate land use for the service zone will be
single - family detached dwellings.
A. WATER REQUIREMENTS
Based on a predominantly single - family residential
development, an ultimate area of 850 acres and a water duty of
2.5 acre - feet /acre /year, the water requirements for the service
zone are estimated as follows:
• - 5
•
\J
L
Annual demand
2120 Acre -Feet
Average
day ---------
- - - - -- 1330
gpm
Maximum
day ---------
- - - - -- 2400
gpm
Peak hour -- - - - - --
4800 gpm
Although the Board of Fire Underwriters recommends a
minimum fire flow of 750 - 1000 gpm for a four -hour duration
for residential -type developments, it is recommended for
planning purposes that a fire flow of 1500 gpm and a duration
of six hours be used. This would provide some flexibility in
the event.uses requiring larger fire flows, such as schools,
apartment complexes, or neighborhood shopping centers, are
constructed.
$, PROPOSED SYSTEM.
In the Montgomery report, the ultimate Zone IV system
consisted of a pumping station located at Big Canyon Reservoir
and a ground level reservoir on Pelican Hill connected by a
16-inch pipe line. It was recommended that the pumping station
be sized to pump an average maximum day requirement of approxi-
mately 2100 gpm. The reservoir was to be 3.0 million gallons
which would provide one maximum day's water requirement.
In the Montgomery report, the area of the zone was shown.
as 750 acres;however the area of the zone outlined on Plate I
is approximately 850 acres. This is the reason maximum day
demand is shown as.2400 gpm in the paragraph above.
In determining the pumping and storage requirements it
is recommended that the reliability requirements of the
^ 6 -
•
Underwriters be applied insofar as is practical and economically
feasible. If the pipe line is broken just beyond the pumping
station, then the total 5 -day maximum demand plus fire flow
would have to be obtained from storage. This would require a
reservoir or.reservoirs with a capacity of 17.7 million gallons.
Of this total only 0.24 million gallons would be the fire flow
requirement. The same storage quantity would be required if
there was a total pumping station failure. It does not appear
to be economically feasible to provide this quantity of storage.
A more balanced system could be obtained by reducing the size of
the reservoir and increasing the reliability of the pumping
station through the.use of standby pumps and secondary sources
of power. Due to the configuration of the zone, the reliability
•
of the pipe line network could be increased only by the
construction of a parallel main or by the development of a
secondary.source of supply. A .parallel main in itself would not
necessarily provide increased reliability in all cases. A
wash -out of a road or an earthquake fault might damage both
lines simultaneously because of their proximity. A secondary
source of supply would provide much greater reliability. In the
'Montgomery report it was recommended that all of the water
service zones above Zone IV obtain their primary source of supply
from a pumping station to be located at San Joaquin Reservoir.
If and when this pumping station, together with reservoirs in the
higher zones, are constructed a secondary source of supply would
then be available to Zone IV.
- 7 -
In the City of Los Angeles, the Department of Water and
• Power operates numerous pump -tank systems throughout the Santa
Monica Mountains. The Department's standard criteria for the
design of these systems is that 300,000 gallons of storage be
provided for every cubic foot per second of maximum day demand.
The pumping stations are sized to deliver an average of one
maximum.day demand with the largest pumping unit out of service.
In general, the pumps are powered by electric motors. A standby
gas engine driven pump, sized to deliver the fire flow requirement
or a minimum of 1500 gpm, is also installed at each station. The
Los Angeles City storage criteria, if applied to Zone IV, would
require a reservoir capacity of 1.6 million gallons. In general,
the City of Los Angeles attempts to provide at least two reservoirs
• to serve each zone with each reservoir having a minimum capacity
of 1 million gallons.
Based on all the factors discussed above and an ultimate
Zone IV development of 850 acres, it is recommended that one
maximum day's storage or-3.5 million gallons be provided with
a_ minimum of two reservoirs. The pumping station for this same
service area should be designed to pump an average maximum day's
demand or 2400 gpm.
C. FIRST PHASE DEVELOPMENT
The first phase development that will be served by the
Zone.IV pumping station and reservoir is Sector IV of Upper
Harbor View Hills. This development will have approximately
130 acres in Service Zone V, and 160 acres in Service Zone IV.
8
This initial development is shown on Plate I. The initial
• 290 acres-in Zones IV and V will have a maximum day demand of
approximately 800 gpm. The reservoir capacity to provide one
maximum day's storage would be 1.15 million gallons.
It is not feasible to construct the initial reservoir at
the Pelican Hill location as shown in the Master Plan. Since
The Irvine Company has not completed precise planning for
development in the Pelican Hill area, it would probably be
impossible to construct a reservoir that could be. integrated
into a future development. In addition, the pipeline from the
pumping station at Big Canyon Reservoir to Pelican Hill would
need to traverse undeveloped land, and it is likely that future
development would necessitate an expensive relocation.
• Due to the proximity of the proposed reservoir site in
Sectoriv to the pumping station, it .would be difficult to .
construct a reservoir with capacity to serve the entire Zone
as envisioned in.the Master Plan. Such a reservoir at this
site would need to be constructed at.an excessively high
elevation.in order to. provide reasonable operating pressures
at the extreme easterly end of the Zone. A reservoir
constructed at such an elevation would require the pumping
station to operate against an excessively high head. In
addition, a single reservoir would not provide operating
flexibility to temporarily take the reservoir out of service.
D. FIRST PHASE RESERVOIR CAPACITY
In order to determine the capacity of Reservoir No. 1
• - 9 .-
1
•
(Upper Harbor View Hills) a Hardy -Cross network analysis was
made of the ultimate system to serve the Zone.. It was assumed
for the purposes of analysis that Reservoir No. 2 would be
constructed eventually in the vicinity of Pelican Hill.
TABLE N0. 1
Pump Reservoir Reservoir
DEMAND Station No. 1 No. 2
flow(gpm) flow(gpm) flow(gpm)
Max Day + 1500 gpm Fire Flow 2400 225 in 1725 out
Peak Hour
Max Day, Reservoirs only
2400
420
out
1980
out
0
860
out
1540
out
Filling of Reservoirs,
0 Demand 2400 1170 in 1230 in
Table No. 1 shows the inflows and outflows from the two
reservoirs under varying demand conditions that were obtained
from the network analysis. As can be seen, the outflows from
Reservoir No. 2 are greater than from No. 1 under ail operating
conditions. The ratio of the outflows is approximately 1:4
under peak hour conditions and 1:2 for a maximum day without
the pumping station operating. Based on this analysis it
appears that the capacities of the two tanks probably should
be in the ratio of approximately 1:3. It is therefore
recommended that Reservoir No. 1 have a capacity of 1.0 million
gallons. If. the ultimate service zone remains as shown in the
Montgomery report, then Reservoir No. 2 should have a capacity
i
10 -
E
•
•
of approximately 2.5 million gallons. The 1.0 million gallons
in Reservoir No. 1 will provide approximately one maximum day's
storage for the first phase of development. If the service
zone continues to expand easterly, available storage would be
reduced below one maximum day until such time as the second
reservoir.is constructed. If, because of rapid expansion of
the zone, the available storage were reduced below a
desirable minimum the total water supply for the zone could be
increased on an interim basis until the second reservoir were
available by adding additional pumping capacity.
E. ELEVATION OF RESERVOIR NO. 1
The problem of selecting an elevation for Reservoir No. 1
is complicated due to the
ultimate service . area and
location of Reservoir No.
elevations that should be
analysis was made for two
varying operating conditi�
uncertainty of the size of the
not knowing for certain the future
2. In order to obtain the range of
considered, a Hardy -Cross network
different systems with a number of
ins..
The first system to be analyzed provided for an ultimate
service area as shown in the Montgomery report, and consisted
of a pumping station at Big Canyon Reservoir with a capacity
to supply average maximum day requirements, and two
reservoirs located in Upper Harbor View Hills and on Pelican
Hill, Table No. 2 shows the reservoir elevations that would
be required to provide the indicated pressures in the upper-
most portions of the zone in the vicinity of Reef Hill.
- 11 -
• Pump . Reservoir Reef Hill
DEMAND Station Water Surface Elev. 540.
psi Elev. I psi
Max Day, Reservoirs only 160 641
40
Max Day + Fire Flow
1500 gpm
2400 gpm from Pump 181 668 20
Max Day + Fire Flow .
1500 gpm
without pumps 172 671 20
Peak Hour 173 652 40
Filling of Reservoirs,
no demand 171 641 44'
. The second system analyzed was for a service zone extending
easterly to.the vicinity of Pelican Hill with a pumping station
at Big Canyon Reservoir, and a single reservoir.located in Upper
•
Harbor View Hills. The required reservoir water service elevations
to obtain the indicated pressures are shown.in Table No. 3
TABLE NO. 3
P.S. Press. Reservoir Pelican Hill
DEMAND and Water Surface Elev. 540
Output Elev. & Outflow psi
Max Day, + Fire Flow
1500 gpm 150 psi 621' 20 psi
1600 gpm 1600 gpm
Peak.Hour 164 psi 655' 40 psi
1600 gpm 1800 gpm
- 12 -
The operating pressure for maximum day or peak hour
• conditions should be a minimum of 40 psi in the uppermost
portion of the zone. Likewise for maximum day plus fireflow,
conditions the minimum pressure anywhere in the zone should be
20 psi. This could be achieved by setting the water surface
elevation of Reservoir No. 1 at approximately 671 feet. As
can be seen from Plate No. 2, for a reservoir with a height of
25 feet, the top of the pad for a covered reservoir would need
to be approximately 689 feet.
On the other hand, if.the water surface of Reservoir No. 1
is set at.a somewhat lower elevation, the minimum operating
pressures in the easterly extremities of the ultimate service
zone could be increased to the recommended minimums by installing
an in -line booster pump or, if and when the secondary source of.
• supply is provided from San Joaquin Reservoir, the pressure could
be boosted by obtaining some water from the higher service zone.
In addition, Reservoir No. 2 could be. located near the easterly
extremity of the zone, thus improving pressure conditions.
Rather than require the pumping station at Big.Canyon
Reservoir to continuously operate against a higher head, it is
recommended that the water surface elevation of Reservoir No. 1
be set at an elevation of 640 feet and that, if and when needed,
the pressures in the extremity of the zone be increased by one
of the three suggested... alternative methods.
It is further recommended that Reservoir No. 1 have an
overall height of approximately 25 feet and an internal .
• - 13 -
diameter of approximately 85 feet. This configuration in the
• tank would require the bottom of the tank to be set at
elevation 630 as shown on Plate No. 2. The upper ten feet of
the tank should be used for operational storage, and the lower
ten feet of the tank reserved for fire storage. If the
operational storage is located above elevation 640 then a
minimum pressure of 40 psi would be available on a maximum day
in all portions of the zone without the pumping station oper-
ating. The lower ten feet of the tank would provide 0.5
million gallons storage. Approximately 0.54 million gallons
is. required for a fire flow of 1,500 gpm for a six -hour duration.
F. TYPE OF RESERVOIR CONSTRUCTION.
The reservoir should be either a steel tank with exterior
and interior protective coatings or a prestressed reinforced
• concrete tank without exterior or interior protection. The cost
of burying a steel tank beyond one -third of its depth increases
sharply, whereas the cost of the pre- stressed concrete tank
is essentially the same whether totally exposed or buried to
the top of the tank. The cost of a"million gallon reservoir,
using a steel tank buried not more than one -third its height,
without site preparation, backfill, and inlet and outlet
structures, is approximately $80,000. The cost of the same
size reservoir using a pre- stressed concrete tank, either
totally exposed or backfilleo to the top of the tank, exclusive
of site preparation, backfill, and inlet and outlet structures
is $107,000 based on an E.N.R. index of 1400. If it is desired
• - 14 -
to bury the pre- stressed concrete tank and landscape the top,
then three feet of fill would be required. The loading from
the three feet of backfill would increase the cost of the
tank $2.60 per square foot, or for a tank of 85 ft. diameter
the additional cost would be approximately $14,700.
If the reservoir is located within the Upper Harbor View
Hills development, immediately adjacent to single - family homes,
it is recommended that the tank be backfilled to the top of
the wall except for a wall portion that might be exposed in
a cut or fill slope. The additional $14,700 expenditure to
completely cover the tank must be weighed against the aesthetic
value of not having the top surface exposed, and /or the value
of the additional useful space. If the developer provides a
• site with a pad elevation the same as the bottom of the tank
and stockpiles the necessary backfill material, it is estimated
that the cost of backfilling the tank will add approximately
$18,000. In addition to improving the appearance, the tank
manufacturers indicate that complete backfilling substantially
increases the life of a concrete tank because temperature
differentials between the interior and exterior surfaces of the
wall are reduced, thus minimizing cracking and spalling.
40 - 15 -
• V. PRESSURE REDUCING STATION ZONE III TO ZONE II
The estimated ultimate average day water require-
ment for Zone III will be 3,760 gpm, according to the 1965
report of James M. Montgomery. To determine the maximum.
flow which the station will have to handle, the following
assumptions were made:
1 Station will supply water to Zone II
on an emergency basis only and, therefore,
..may be designed for intermittent flow.
2. During operation of the station, the
demand in Zone III will not exceed 3,760
..gpm (ultimate average day).
3.. The pressure in the proposed.24" pipe
which will feed the station, shall not
be less than + 40 psi.
4. The existing 16" pipe at the Irvine
Industrial Complex will be extended to
• connect to C.M. 11.
Based on the above assumptions, the maximum
allowable flow from Zone III to Zone II through the station
is 14,000 gpm. Any greater flow would lower the pressure
in portions of Zone III below 40 psi, and would also result
in excessive velocities in the 24" line.
A typical layout for the station is shown on
Plate 3 and 4. The 12" Clayton Valve #92 shown has a minimum
flow rate of 80 gpm and a maximum intermittent rate of
7,.000 gpm. In parallel, the two valves will provide a
maximum capacity of 14,000 gpm. The demand in Zone II
will always be greater than the minimum flow rate of the
valves.
• - 16 -
To insure the assumed operating conditions are
• not exceeded, the valves should include both pressure-
reducing and pressure- sustaining capabilities. The Clayton
#92 valve shown will serve such a dual function by maintain-
ing a pressure of approximately 10 psi in Zone II, which .
corresponds to a reservoir elevation of 302 feet, and
maintaining a minimum pressure of 40 psi upstream in the
24" Zone III line.
•
VI. ZONE III PUMPING STATION
• A. OPERATIONAL CRITERIA .
Based on the James A. Montgomery.report, the
ultimate peak hour demand for Zone III will be 13,540 gpm,
and the maximum day plus fire flow will be 11,700 gpm. In
addition, the water requirements for Zone IV will have to
be supplied from Zone III facilities. The demand for Zone
IV will be supplied by the Zone IV pumping station which
will be designed to meet the maximum daily requirements.
The ultimate capacity of this pumping station will be 2,400
gpm as previously indicated in Section IV of this report.
The total requirement, therefore, to meet a peak hour demand
in Zone III and a maximum day demand in Zone IV is 16.,000
•
gpm.
The primary function of the Zone III pumping station
is.to provide a back -up source of supply for Zone III and for
Zone IV, which is normally supplied from San Joaquin reservoir.
The most vulnerable link in the primary source -of supply is
the 43" MWD cross feeder. In the event of a failure of this
line, the proposed Zone III pumping station should be able to
meet the entire demand of 16,000 gpm. If the station is
designed for a capacity of 5,000 gpm as previously contemplated,
then only average day demands could be satisfied, in our
opinion, the pumping station should be designed to provide
maximum day .demands plus fire flows or peak hour demand,
whichever is greater, since this is the criteria that will
• � - 18 -
be used by the Board of Fire Underwriters in evaluating the
•
reliability of the system. Zone III contains the major
portion of Newport Center which, in future evaluations by
the Underwriters, will be considered the "high value area"
and the entire rating of the City could be seriously
affected if this portion of the system did not meet the
reliability requirements. However, since the Zone III
pumping station is an alternate source of supply it is not
necessary that standby pumps be provided.
To insure flexibility and to provide for changes
in future water demands or other criteria it is recommended
that the full 36-inch header from the Big Canyon Reservoir
control station be extended in the first phase, and that
outlets be provided to accommodate a minimum of four pumps.
•
The highest service elevation in Zone III is approximately
355 feet. The pumping station should be designed to provide
a minimum pressure of 40 psi at this location (455 feet H.G.)
Since the water surface elevation of Big Canyon Reservoir
fluctuates between 300 feet and 270 feet, the maximum total
dynamic pumping head for the pumping station will be 185 feet.
B. ELECTRIC MOTOR ALTERNATE
Plate 3 shows a preliminary layout of the Zone III
pumping station using electric motors to drive the pumps.
Pumps No. 1 and No. 2 each would have a capacity of 2,700 gpm
and be driven by 150 HP motors. Since Zone III is a closed
system, it is recommended that pump No. 1 be equipped with a
•
variable speed drive in order to accommodate the varying
- 19 -
No. 4 would each have a capacity of 5,500 gpm and be driven
by .350 HP constant -speed electric motors.
It is recommended that the first phase of construc-
tion include the installation of pumps No. 1 and No. 2,
which would provide a capacity -of 5,400 gpm. This would
enable the pumping station to deliver the 5,000 gpm fire
flow of Zone III.
C. NATURAL GAS INTERNAL COMBUSTION ENGINE ALTERNATE
A preliminary layout of the Zone III pumping
station using natural gas engines to drive the pumps is,.
shown on Plate 4. In this gas engine alternate it is
recommended that the total demand of 16,000 gpm be delivered
• with three units. Each of the units would be driven by a
300 HP natural gas engine. It is possible to use three
pumps in.this alternate, rather than the four recommended
for the electric motor alternate, due to the variable speed
operation possibilities with the natural gas engines. This
capability will allow even the large 5,400 gpm pump to be
reduced in speed to meet low water demands of the system.
The operation of the three pumps would be governed by a
pressure- sensing control, and each engine would have an
individual control panel to permit automatic operation of
tie unit.
The first phase of construction would include only
- 20
water demands
without
excessive line surges and
pressure
.
fluctuations.
In this
particular layout, pumps
No. 3 and
No. 4 would each have a capacity of 5,500 gpm and be driven
by .350 HP constant -speed electric motors.
It is recommended that the first phase of construc-
tion include the installation of pumps No. 1 and No. 2,
which would provide a capacity -of 5,400 gpm. This would
enable the pumping station to deliver the 5,000 gpm fire
flow of Zone III.
C. NATURAL GAS INTERNAL COMBUSTION ENGINE ALTERNATE
A preliminary layout of the Zone III pumping
station using natural gas engines to drive the pumps is,.
shown on Plate 4. In this gas engine alternate it is
recommended that the total demand of 16,000 gpm be delivered
• with three units. Each of the units would be driven by a
300 HP natural gas engine. It is possible to use three
pumps in.this alternate, rather than the four recommended
for the electric motor alternate, due to the variable speed
operation possibilities with the natural gas engines. This
capability will allow even the large 5,400 gpm pump to be
reduced in speed to meet low water demands of the system.
The operation of the three pumps would be governed by a
pressure- sensing control, and each engine would have an
individual control panel to permit automatic operation of
tie unit.
The first phase of construction would include only
- 20
the installation of pump No. 1 providing a capacity of 5,400
• gpm, which as in the electric motor alternate would meet the
5,000 gpm fire flow requirement.
D. TYPE OF PUMP..
Both Plate 3 and Plate 4 contemplate the use of
turbine -type pumps rather than centrifugal -type pumps. The
initial cost of centrifugal pumps is substantially less than
turbines but, because of the relationship of the ground
elevation at the pumping station site to the water surface
elevation in Big Canyon Reservoir, it will be possible to
maintain a positive suction on the pumps over a wider range
of fluctuation of the reservoir water surface using turbine-
type pumps.
I
- 21 -
VII. PUMP STATION ZONE IV
A. OPERATIONAL CRITERIA
The water requirements of Zone IV:were previously
established in Section IV of this report as 800 gpm initially,
I
d
and 2,400 gpm ultimately. The suction line for Zone IV would
have a varying hydraulic gradient due to the operation of San .
Joaquin Reservoir. The normal water level is at elevation
460 feet. Every two years.the reservoir is lowered to 400
feet for inspection and cleaning of the sides. It takes about
two months to lower the water to this.elevation. The operation
conditions for the Zone IV pump station are shown in Table 4.
TABLE NO. 4
PUMP STA. ZONE IV
Water Elev. ----------- -----------------
San Joaquin.Demand in Demand in Positive Required Total
Reservoir Zone III, Zone IV, Suction Discharge Dynamic
•
(Level) GPM GPM Mead Head Head
Norma Max Day Max Day =
465' 6,770 2,400 160' 400' 240'
Normal Night Night-
465' 0 filling 185' 402" 217'
Res.
Low Max Day Max Day
400' 6,770 2,400 95' 400' 305'
'
The operating range of the pumps will be between 217' and 305'
total dynamic head, depending on the demand in Zone III and the
elevation of the San Joaquin Reservoir. The average operating
head of. the pumps will be between 217' and 2401. The pumps
i
world be'designed for a. capacity of 800 gpm at 305' TDH and a
speed of 1,800 rpm, At the lower head of 217',_capacity will
increase to 1,000 .,gpm: At the anticipated normal operating
•
i
- 22 -
I
d
•
•
head of 2401, it is recommended that the capacity of the pumps
will be about 900 gpm.. First phase construction should include
two 800 gpm pumps. This will provide sufficient capacity for
the initial development.
B. ELECTRIC MOTORS AS PRIME MOVERS
A constant speed electric motor of 75 HP driving a
vertical turbine pump will satisfy the criteria for the Zone
IV pump station. The electric motors will not be overloaded
at the lower head operation due to the flat horsepower curve
of the turbined.
C. NATURAL GAS INTERNAL COMBUSTION ENGINES AS PRIME
MOVERS
Natural gas engines are presently used by many
water companies for booster or deep -well pumping. The most
significant advantage of using a natural gas engine is favor-
able fuel economy. Also, its flexibility in speed and horse-
power makes it easily adaptable to changing pumping require-
ments. With a regular maintenance program, many years of
service can be expected. Several oil companies use natural
gas engines in outdoor installations, but to increase the
reliability of the engines, they should have at least a metal
weather enclosure or roof. Heavy rain may short circuit the
ignition system. Most water companies and /or municipalities
have their natural gas engines inside an inexpensive
corrugated metal or concrete -block building.
A different selection of pumps is possible with
gas engines. Besides the turbine recommended for the
- 23 -
electric motor operation, a centrifugal pump could meet
• the hydraulic requirements for the station. The horsepower
requirements will increase to 100 HP at the lower dynamic
head condition. The cost of the centrifugal pump is
approximately two - thirds the cost of a vertical turbine
pump, but the efficiency of the centrifugal pumps is
approximately 708 compared to 808 of the turbines. In a
continuous pumping operation, the higher efficiency of the
turbine will result in better fuel economy so turbines are
proposed.for the pump station in Zone IV.
- 24 -
0
0
0
VIII. COST COMPARISON OF ELECTRIC MOTORS VS. GAS ENGINES
A study was made to determine whether electric motors
or gas engines should be used as prime movers for the Zone
III and IV pumping stations.
In order to compute the annual energy cost, the
following ultimate operating conditions were assumed:
Zone III Station - Standby only. Operate 5 days a year.
Zone IV Station - 2 pumps continuous operation.
1 pump intermittent, 6.hr /day.
The annual energy charges based on the above
assumptions are as follows:
Annual Energy Charge
Electric Motors, PA -1 rate --- - - - - -$ 26,131
Electric Motors, PA -2 rate --7 ----- 18,931
Gas Engines G -51 interruptible - - -- 81155
Gas Engines G -46 firm ------- - - - - -- 8,318
The estimated costs of the pumping stations used in
the economic analysis were as follows:.
Electric Motors
Zone III -------------------- - - - - -- $130,474
Zone IV --------------------- - - - - -- 52,185
Site Work ------------------- - - - - -- 3,800
Total Cost $186,459
Gas Engines - Interruptible Supply
Zone III -------------------- - - - - -- $176,688
Zone IV --------------------- - - - - -- 78,631
LPG System ------------=----- - - - - -- 12,300
,. , ..
Site Work "`�----- 's�:�- +�-- ---- - - - --- 3,800
Total Cost $271,419
- 25
0
Gas Engines - Firm Supply
•
Zone III $176,688
i
i
Zone IV 78,631
Site Work 3,800
Total Cost $259,119
Based on the above energy and capital costs, a
i
station life of 20 years and an interest rate of 7 %, the total
I
annual cost of the combined Zone III and Zone IV pumping
i
station is-estimated as follows:
i
Gas Engines Gas Engines.
Electric Motors _Interruptible Firm
Capital Recovery Cost $17,600 $25,619 $24,458
i
I'
Energy Cost 18,931 8,155 8,318
is
f
Maintenance Cost 600 3,400 3,400
•
Total Annual Cost $37,131 $37,174 $36,176
It appears from the above that the most economical
solution would be the use of gas engines as prime movers
with a firm gas supply. However, the relatively.small difference
of approximately $1,000 between the use of the gas engines
j
and electric motors must be weighed against several other
intangibles which have not been included in the above costs.
The electric motors are certainly more reliable and their
�.
operation simpler than gas engines. The maintenance cost of
electric motors is relatively small and any error we have made
in estimating.the mainteriance.cobts will not have a substantial
I
I
effect on the total annual cost. In the gas engines the
i
annual maintenance cost is a substantial item and is more
.
difficult to estimate. The cost information that we used,for
it
the maintenance of gas engines was obtained from the Gas
-. 26 -
�;
Company and the engine manufacturers and may or may not
• be indicative of the actual costs to be encountered. For
instance, most of the gas engine installations that we
observed were in some type of an enclosed building. In the
cost estimate we prepared, metal engine enclosures were
provided, but the engines will not be in an enclosed structure
The salt air exposure at Big Canyon without the engines in
a building could result in higher than average maintenance
costs.
Gas engines, however, do have the distinct advant-
age over the constant speed electric motors in that the
speed can be varied to meet varying demand conditions. This
feature would be more advantageous on the Zone III pumping
station, which is a closed system. In order to accommodate
the fluctuating demand a variable speed drive has been
included on one unit of the Zone III pumping station for
the electric motor alternate. This results in an added
cost of $4,000. If natural gas engines with the on -site
LPG system were used, the overall reliability in the event
of an earthquake would probably be greater than for either
electric motors or natural gas engines without the LPG system.
This does not seem particularly important for the Zone III
pumping station because the station is functioning only
as a standby. The Zone IV pumping station, however, will
be a primary source of supply. The above cost estimates for
the electric motor alternate for this station were based
- 27-
of the pumping station could be increased substantially if
the electric motor alternate is selected, and if a 1,500
gpm capacity pump driven by a gas engine equipped with an
LPG system is substituted for the fourth 800 gpm electric-
driven pump. The fourth unit would function as a standby
for the three electric- driven pumps and in the event of an
electric power outage, would be capable of delivering a
full fire flow.
Based on the foregoing economic analysis and the
other factors which have been discussed, it is recommended
that both the Zone III and Zone IV pumping stations be
equipped with electric motor prime movers, and that prior to
• the installation of the fourth pumping unit for the Zone IV
pumping station, consideration be given to installing a
1,500 gpm gas engine- driven pump in lieu of the electric
motor - driven unit.
• - 28 -
on four
electric motor - driven pumps
all
of equal size,
•
with one
functioning as a stand -by
unit.
The reliability
of the pumping station could be increased substantially if
the electric motor alternate is selected, and if a 1,500
gpm capacity pump driven by a gas engine equipped with an
LPG system is substituted for the fourth 800 gpm electric-
driven pump. The fourth unit would function as a standby
for the three electric- driven pumps and in the event of an
electric power outage, would be capable of delivering a
full fire flow.
Based on the foregoing economic analysis and the
other factors which have been discussed, it is recommended
that both the Zone III and Zone IV pumping stations be
equipped with electric motor prime movers, and that prior to
• the installation of the fourth pumping unit for the Zone IV
pumping station, consideration be given to installing a
1,500 gpm gas engine- driven pump in lieu of the electric
motor - driven unit.
• - 28 -
0
•
IX. COST ESTIMATES
Detailed cost estimates which were prepared for the
various segments of the master plan facilities are included
in the Appendix of this report. The following is a summary
of these estimates, including an allowance of 258 for
engineering and contingencies:
Ultimate Pumping Station Capacities:
Zone III Pumping Station, electric
motors -------------------------- - - - - -- $130,500
Zone IV Pumping Station, electric
* motors ------- ---- -------- ---- --- - - - - -- 62,200
1.0 MG Prestressed Concrete Reservoir - 162,000
Pressure Reducing Station ------- - - - - -- 10,000
16" Transmission Main ----------- - - - - -- 56,400
24" Transmission Main ----------- - - - - -- 14,100
Total Estimated Cost $435,200
* (Includes allowance of $10,000 for 1,500 gpm
.gas engine- driven pump in lieu of 800 gpm
electric motor - driven pump.)
Phase I Pumping Station Capacities:
Zone III Pumping Station, electric
motors ---- ---- ---- -- ------ --- --- --- --- $ 87,000
Zone IV Pumping Station, electric
motors ---- ----- --------- --------- - - - --- 40,300
1.0 MG Prestressed Concrete Reservoir - 1621000
Pressure Reducing Station ------- - - - - -- 10,000
16" Transmission Main -- _ -- - - - -^ 56,400
24" Transmission Main -- ------- -- - -- --- 14,100
Total Estimated Cost $3690800
0. - 29 -
The foregoing estimates provide for a reservoir
• backfilled to the top of walls, but not covered with earth.
If it is desired to increase the capacity of the reservoir
to 1.5 MG, then the estimated costs should be increased by
$22,000.
•
e
• OPERATING COST FOR ELECTRIC MOTORS ZONE III AND IV
A. Annual Power Cost
Operating conditions:
Zone III, standby only, operating 5 days a year 1,000 HP.
Zone IV, 2 pumps continuous operation, 1 pump
intermittent, 6 Hr /Day.
Yearly KW Hours consumedi:
Zone III
r1L
1,000 HP x .745 KW /HP x 5 DAYS /YR x 24 HRS /DAY - 89,500 KWHR /YR
Zone IV
150 HP x .745 KW /HP x 365 /DAYS /YR x 24 HRS /DAY = 978,930 KWHR /YR
75 HP x .745 KW /HP x 365 DAYS /YR x 6 HRS /DAY = 122,366 KWHR /YR
Zone III and IV Total
1,190,796 KWHR /YR
Cost per Schedule No. PA -1
Annual Service Charge: 1,225 HP x $6.75/HP $ 8,269/YR
KWHR /HP 4 1,190,796/1225
KWHR /HP = 972
Energy Charge = 1,190,796 KWHR x $0.015 /KWHR $17,862/YR
Annual Total $26,131
Cost per Schedule No. PA -2
Estimated Demand:
1 month, 1225 HP x 0.745 KW /HP = 910 KW
11 month, 225 HP x 0.745 KW /HP = 168 KW
Demand Charge:
For 11 month, demand = 168 KW. Charges are
• based on at least 508 of the highest demand established in the
31
1 • preceding 11 months, which is 50% of 910 KW = 455 KW
11 x ($75 + (455 - 75) x $0.90) _ $4,587
r
1 x ($75 + (910 - 75) x $0.90) _ $ 827 '
i
i
Total $5,414 /YEAR
Energy Consumption:
1st Month
Zone 111 1,000 HP x 0.7.45 KW /HP x 5 DA /MO x 24 HR /DA= 89,500 KWHR /MO
Zone IV 150 HP x 0.745 KW /HP x30 DA /MO x 24 HR /DA= 80,640 KWHR /MO
75 HP x 0.745 KW /HP x30 DA /MO.x 6 HR /DA= 10,080 KWHR /MO
Total 180,220 KWHR /MO
Next 11 Months
150 HP x 0._745 KW /HP x30 DA /MO x 24 HR /DA= 80,640 KWHR /MO
75 HP x 0.745 KW /HP x30 DA /MO x 6 HR /DA= 10,080 KWHR /MO
•
Total 90,720 KWHR /MO
Energy Charge:
1st Month
Total Energy Consumption = 180,220 KWHR/MONTH
910 KW Demand x 150 KWHR = - 136,500 KWHR /MONTH
- 32 -
Remainder
43,720 KWHR/MONTH
15,000
KWHR
x $0.015 =
$ 225
121,500
KWHR
x $0.012 =
$1,458
43,720
KWHR
x $0.008 =
$ 350
180,220
KWHR
Total
$2,033 /MONTH .
- 32 -
• Energy Charge: (cont'd)
Next 11 Months
Total Energy Consumption = 90,720 KWHR /MONTH
455 KW Demand x 150 KWHR =-r68:,250 KWHR /MONTH
Remainder = 22,470 KWHR /MONTH
15,000
KWHR
x $0.015
= $
225
53,250
KWHR
x $0.012
= $
639
22,470
KWHR
x $0.008
= $
180
90,720 KWHR Total $1,044
Estimated Annual Power Cost:
Demand Charge $51414
1st Month Energy $2,033
Next 11 Months
Energy $11,484
Annual Total $18,931
r Schedule PA -2 will be used in the operation cost estimate.
If the Zone III station is not operated to its full capacity,
the demand charges will be less than assumed above for the
following 11 months and will, therefore, result in a more
favorable yearly power cost.
0
33 -
I
• OPERATING COST FOR NATURAL GAS ENGINES ZONE III AND IV
A. Operating Conditions - same as electric motors.
B. Energy Demand
1st Month
1,000 HP x 10 CF /HP -HR x 24 HR /DA x 5 DA /MO = 12.0 x 105 CF /MO
150 HP x 10 CF /HP -HR x 24 HR /DA x 30 DA /MO = 10.8 x 105 CF /MO
75 HP x 10 CF /HP -HR x 6 HR /DA x 30 DA /MO = 1 ..35x 105 CF /MO
24.15x 105 CF /MO
Next 11 Months /Month
150 HP x 10 CF /HP -HR x 24 HR /DA x 30 DA /MO = 10.8 x 105 CF /MO
75 HP x 10 CF /HP -HR x 6 HR /DA x 30 DA /MO = 1.35x.105 CF /MO
12.15x 105 CF /MO
C. Estimated Annual Energy Cost
• Schedule No. G -46, firm service
1st Month
1.0 x 105 CF x $0.0619/100 CF =$ 61.93
4.0 x 105 CF x $0.05623/100 CF =$ 224.92
5.0 x 105 Cr x $0.05103/100 CF =$ 255.15
14.15 x 105 CF x $0.04813/100 CF =$ 681.04
24.15 x 105 CF Total $1,223.
Next 11 Months /Month
1.0 x 105 CF x $0.06193/100 CF = $ 61.93
4.0 x 105 CF x $0.05623/100 CF = $ 224.92
5.0 x> 105 Cr x $0.05103/100 CF = $ 255.15
2.15x 105 CF x $0.04813/100 CF = $ 103.48
. 12.15 x 105CF Total $ 645
ANNUAL ENERGY COST - $8,318
- 34 -
• OPERATING COST FOR NATURAL GAS ENGINES ZONE III AND IV
A. Operating Conditions - same as electric motors.
B. Energy Demand
1st Month
1,000 HP x 10 CF /HP -HR x 24 HR /DA x 5 DA /MO = 12.0 x 105 CF /MO
150 HP x 10 CF /HP -HR x 24 HR /DA x 30 DA /MO = 10.8 x 105 CF/MO
75 HP x 10 CF /HP -HR x'6 HR /DA x 30 DA /MO = 1.35x 105 CF /MO
24.15x 105 CF /MO
Next 11 Months /Month
150 HP x 10 CF /HP -HR x 24 HR /DA x 30 DA /MO = 10.8 x 105 CF /MO
75 HP x 10 CF /HP -HR x 6 HR /DA X.30 DA /MO = 1.35x 105 CF /MO
12.15x 105 CF /MO
C. Estimated Annual Energy Cost
• Schedule No. G -46, firm service
1st Month
1.0 x 105 CF x $0.0619'/100 CF =$ 61.93
4.0 x 105 CF x $0.05623/100 CF =$ 224.92
5.0 x 105 CF x $0.05103/100 CF =$ 255.15
14.15 x 105 CF x $0.04813/100 CF =$ 681.04
24.15 x 105 Cr Total $1,223.
Next 11 Months /Month
1.0 x 105 CF x $0.06193/100 CF = $ 61.93
4.0 x 105 CF x $0.05623/100 CF = 224.92
5.0 x 105 CF x $0.05103/100 CF = $ 255.15
2.15x 105 CF x $0.04813/100 CF = $ 103.48
12.15 x 105CF Total $ 645
ANNUAL ENERGY COST = $8,318
34 -
•
D. Estimated Annual Energy Cost
Schedule
No.
G -51,
Interruptible gas
service
1st Month
2.0 x
105
CF x
$0.05578/100 CF =
$ 111.56
8.0 x
105
CF x
$0.05148/100 CF =
$ 411.84
14.15 x
105
CF x
$0.04958/100 CF =
$ 701.56
24.15 x
105
CF
Total
$1,225.
Next 11 Months /Month
2.0 x
105 -CF
x
$0.05578/100 CF =
$ 111.56
8.0 x
105
CF x
$0.05148/100 CF =.$
411.84
2.15 x
105
CF x
$0.04958/100 CF =
$ 106.60
12.15 x
105
CF
Total
$ 630.
ANNUAL ENERGY COST
TOTAL
•
f
-. 35
$8,155
PUMP STATION ZONE III, ELECTRIC MOTORS
• COST ESTIMATE
I
i
h
Item
Unit
Total
No.
Description
Quantity
Cost
Cost
1
14"
Gate Valve
2
725
$1,450
1
18"
Butterfly Valve
2
700
1,400
2
Precast Manhole
4
600
2,400
3
2700
gpm Turbine Pump,
150
HP Motor
2
4,900
9,800
4
10"
Flexible Coupling
2
35
70
4
16"
Flexible Coupling
2
40
80
4
14"
Flexible Coupling C.I.
2
93
186
4
18"
Flexible Coupling C.I.
2
130
260
5
Check Valve, Clayton #81 C
10"
2
1,360
2,720
•
5
Check Valve, Clayton #81 C
16"
2
3,400
6,400
6
10"
Gate Valve
2
335
670
6 .16"
Gate Valve
2
970
1,940
8
24"
Flexible Coupling, Steel
1
63
63
11
36"
Intake Header
L.S.
8,000
8,000
12
12"
Dia.Pipe
L.S.
1,920
1,920
13
12"
Gate Valve
3
435
1;305
14
36"
Flexible Coupling
1
115
115
15
36"
Butterfly Valve
1
3,100
3,100
16
24"
Discharge Header
Z.S.
4,300
4,300
17
24"
Butterfly Valve
3
700
2,100
19
18"
Can
4
800
3,200
•
-
36
-
I
i
h
•
I •
•
PUMP STATION ZONE III, ELECTRIC MOTORS
- CONTINUED
COST ESTIMATE
Item
Unit
Total
No.
Description Quantity
Cost
Cost
20
24" Meter
1
3,200
3,200
21
Control Panel
L.S.
3,000
3,000
37
Residential Lighting Standard
1
700
700
38
5500 gpm, Turbine Pump,
350 HP Motor
2
11,000
22,000
Variable Speed Drive
1
4,000
4,000
Installation
L.S.
.20,000.
20,000
$104,379
Engineering and Contingencies
25%
$ 26,095
$130,474
37 -
PUMP STATION ZONE IV, ELECTRIC MOTORS
COST ESTIMATE
Item
No.
Description Quantity
Unit
Cost
Total
Cost
22
800 gpm Turbine with
75 HP Electric Motor
4
3,300
13,200
24
8" Coupling C.I.
4
30
120
25
6" Coupling
4
23
92
26
6" Check Valve Clayton #81C
4
600
21400
27
6" Gate Valve
4
136
544
28
24" Intake Header
L.S.
1,480
1,480
29
16" Discharge Header
L.S.
1,200
1,200
30
Conc. Pad ..L.S.
800
800
31
Conc. Vault
1
300
300
•
32
8" Gate Valve
4
210
840
33
12" Can
4
400
1,600
34
24" Flexible Coupling, Steel
1
63
63
35
16" Meter
1
1,940
.1,940
36
16" Gate Valve
1
969
969
37
Residential Lighting Standard
1
700
700
Control Panel
L.S.
6,000
Installation
L.S.
9,500
9,500
$41,748
Engineering and Contingencies
25%
$10,437
Total*
$52,185
*Add
$10,000 for substituting a 1500
gpm
Turbine
powered
by Internal Combustion Engine for
one of
the 800
gpm Electric
Motor driven Turbines.
•
- 38
-
• PUMP STATION ZONE III, NATURAL GAS ENGINES
COST ESTIMATE
Item
11
36" Intake Header
1
Unit
Total
No.
12
Description
Quantity
Cost
Cost
•
1
18"
Butterfly Valve
3
700
$ 2,100
2
Precast Manhole
3
600
1,800
3
5500 gpm Turbine with
Drive 3
8,000
.24,000
4
18"
Flexible Coupling,
C.I. 3
130
390
5
16"
Check Valve
3
1,300
3,900
6
16"
Gate Valve
3
970
2,910
8
24"
Flexible Coupling,
Steel 1
63
63
11
36" Intake Header
1
L.S.
8,000
12
16" Pipe
18 ft.
20
360
•
13.
16" Flexible Coupling
3
40
120
14
36 "Flexible Coupling
1
115
115
15
36" Butterfly Valve
1
3,100
3,100
16
24" Discharge Header
1
L.S.
4,300
17
24" Butterfly Valve
2
700
1,400
Weatherproof Enclosure for
Engines
3
1,000
3,000
19
18" Can
3
800
2,400
20
24" Meter
1
3,200
3,200
21
300 HP Natural Gas Engine
3
.16,400
.49,200
22
Residential Lighting Standard 1
700
700
23
. Standard Fire Hydrant
1
500
500
24
18" Pipe
36 ft.
22
792
•
-.
39 -
' • PUMP STATION ZONE III, NATURAL GAS ENGINES - CONTINUED
S
COST ESTIMATE
0
Item Unit Total
No. Description Quantity Cost Cost
Control Device for I.C.
Engines 1 L.S. 2,000
Installation L.S. 27,000
$141,350
Engineering and Contingencies 25% 35,338
Total $176,688
STAND BY L.P.G. SYSTEM
5,000 gal system
With vaporizer, installed $ 12,300
- 40 -
•
r 1
\J
ZONE IV NATURAL GAS ENGINES
COST ESTIMATE
Item
Unit
Total
No.
Description
Quantity
Cost
Cost
27
800 gpm Pump
4
1,200
4,800
28
100 HP Natural Gas Engine
4
5,500
22,000
29
8" Gate Valve
4
210
840
30
8" Flexible Coupling
4
30
120
31
6" Flexible Coupling
4
23
92
32
6" Check Valve
4
210
840
34
12" Discharge Header
L.S.
3,100
3,100
35
12" Gate Valve
2
435
870
36
6" Pipe
L.S.
400
400
37
8" Pipe
L.S.
200
200
38
24" Intake Header
L.S.
1;480
1,480
39
24" Meter
1
3,200
3,200
40
24" Flexible Coupling
1
63
63
Residential Lighting Standard 1
700
700
Right Angle Drive
4
800
3,200
Installation
L.S.
13,000
13,000
Weatherproof Enclosure
for Engines
4
1,000
4,000
Pump Controls
L.S.
4,000
4,000
Engineering and Contingencies 25%
- 41 -
$62,905
15,726
$78,631
"PHASE.I" CONSTRUCTION ESTIMATE
li •
Item
Unit
Total
No.
Description Quantity
,Cost
Cost
Pump Station Zone III;
1
18" Butterfly Valve
3
700
2,100
2
Precast Manhole
3
600
1,800
3
2700 gpm Turbine Pump,
150 HP Motor
1
4,900
4,900
3
2700 gpm Turbine Pump
150 HP Variable Speed Motor
1
8,900
8,900
4
10" Flexible Coupling
2
35
70
4
14" Flexible Coupling C.I.
2
93
186
4
18" Flexible Coupling C.I:
2
130
260
5
Check Valve, Clayton #81 C
2
1,360
2,720
•
6
10" Gate Valve
2
335
670
8
24" Flexible Coupling, Steel
1
63
63
11
36" Intake Header
L.S.
8,000
8,000
12
12" Pipe
L.S.
1,920
1,920
13
12" Gate Valve
3
435
1,305
14
36" Flexible Coupling
1
115
115
15
36" Butterfly Valve
1
3,100
31100
16
24" Discharge Header
L.S.
4,300
41300
17
24" Butterfly Valve
3
700
2,100
19
18" Can
4
800
3,200
20
24" Meter
1
3,200
3,200
21
Control Panel
L.S.
3,000
3,000
37
Residential Lighting Standard
1
700
700
•
installation
L.S.
15,000
15,000
.42 -
•
•
E
"PHASE I" CONSTRUCTION ESTIMATE - CONTINUED
Item Unit Total
No. Description Quantity Cost Cost
Sitework L.S. 1,900 1,900
$69,509
Engineering and Contingencies 25% 17,380
Total $87,000
- 43 -
6,600
60
46,
1,200
272
1,480
1,200
800
300
420
800
63
1,940
969
700
6,000
7,500
Pump Station Zone IV
22
800 gpm Turbine,
75 HP Motor
2
3,300
24
8" Coupling C.I.
2
30
25
6" Coupling
2
23
26
6" Check Valve, Clayton #SIC
2
600
27
6" Gate Valve
2
136
28
24" Intake Header
L.S.
11480
29
16" Discharge Header
L.S.
1,200
30
Conc. Pad
L.S.
800
31
Conc. Vault
1
300
32
8" Gate Valve
2'
210
33
12" Can
.2
400
34
24" Flexible Coupling
11
63
35
16" Meter
1
1,940
36
16" Gate Valve
1
969
37
Residential Lighting Standard
1
700
Control Panel
L.S.
6,000
Installation
L.S.
7,500
- 43 -
6,600
60
46,
1,200
272
1,480
1,200
800
300
420
800
63
1,940
969
700
6,000
7,500
• "PHASE I" CONSTRUCTION ESTIMATE - CONTINUED
Item Unit Total
No. Description Quantity Cost Cost
Site Work L.S. 1,900 1,900
$32,250
Engineering and Contingencies 25% 8,060
Total $40,300
i •
44
SITEWORK PUMP STATION ZONE III AND IV
• - 45 -
Unit
Total
Description
Quantity
Cost
Cost
Grading
2,000 c.yds.
0.50
$1,000
A.C. Paving
6,500 s.ft.
0.20
1,300
Slope Planting
3,000 s.ft.
0.50
1,500
$3,800
• - 45 -
J
PRESSURE REDUCING STATION ZONE III TO ZONE II
COST ESTIMATE
Item
Unit
Total
No.
Description Quantity
Cost
Cost
7
12" Pressure Reducing Valve,
Clayton #92
2
2,100
4,200
9
12" Gate Valve
4
435
1,740
10
12 Flexible Coupling, Steel
2
20
40
12" Pipe
L.S.
500
500
Installation
L.S..
1,500
.1,500
$7,980
Engineering and Contingencies
25$
1,995
$10,000
- 46 -
0
RESERVOIRS
Cost Estimate
1.0 MG Reservoir 25' high, 83' diameter
Steel Tank, 2 coats
of paint, above ground
$100,000
Prestressed Concrete
Tank,
above ground
$140,000
Prestressed Concrete
Tank,
buried to top of tank
$162,000
Prestressed Concrete
Tank,
buried with 3'.
earth cover
$181,000
1.5 MG Reservoir 25'
high,
101' diameter
Steel Tank, 2 coats
of paint, above ground
$114,000
Prestressed Concrete
Tank,
above ground
$156,000
Prestressed Concrete
Tank,
buried to top of tank
$184,000
Prestressed.Concrete
Tank,
buried.with
3' earth cover
$209,000
• The above estimates include inlet and outlet
valves and structures, backfilling and a 25% allowance
for engineering and contingencies, but do not include site
preparation or landscaping.
•
- 47 -
• TRANSMISSION MAINS
Cost Estimate
$70,450
•
•
48
Unit
Total
Description
Quantity
Cost
Cost
24"
Water Pipe Class
150
500 ft.
20.50
$10,250
16"
Water Pipe Class
200
2,000 ft.
14.00
28,000
16"
Water Pipe Class
150
1,200 ft.
12.50
15,000
18"
Butterfly Valve
1
1,000
1,000
16°
Gate Valve Class
200
1
1,400
1,400
12"
Gate Valve
1
700
700
$56,350
Engineering and Contingencies
256
$14,100
$70,450
•
•
48
17J
0
s
bUuidERN CAW- Ui(NiA EUISON COMPANY
Edison Building
Los Angeles, California
Revised Cal. P.U.C. Sheet No. 4186 -E
Cancelling Revised Cal. P.U.C. Sheet No. 4064 -E
Schedule No. PA -1
POWER — AGRICULTURAL AND PUMPING
CONNECTED LOAD BASIS
APPLICABILITY
Applicable to power service for general agricultural purposes or for general water or sewerage pumping.
TERRITORY
Within the entire territory served, excluding Santa Catalina Island.
RATES
Annual
Service Charge
Horsepower of
Connected Load Per Hp
2 to AN .......... ............................... $9.25
5 to 14. 9 .......... .......................... . .... 8.25
15 to 49. 9 ...... _ ....... .. ........ _.............. 7.75
50 to 99.9.......... ............. 7.25
100 and Over ....................... _ .......... .. 6.75
Energy Charge to Be Added to Service Charge
Rate per Kwhr for Annual Consumption of,
First 1000
Next 1000
All Over 2000
Kwhr per Hp
Kwhr per His
Kwhr per Hp
2.00
0.900
0.600
1.80
0.900
0.600
.1.70
0.900
0.600.
1.60
0.900
0.600
1.50
0.900
0.600
Minimum Charge: The annual minimum charge shall be the annual Service Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard power voltage.
2. Connected Load: Connected load is the sum of the rated capacities of all of the customer's equipment
that it is possible to connect to the utility's lines at the same time, determined to the nearest 1 /10 hp. In no case
will charges be based on less than 2 hp for single -phase service or on less than 3 hp for three -phase service. The
rated capacity of the customer's equipment will be the rated horsepower output of standard rated motors, the rated
horsepower of welders determined in accordance with the section designated Welder Service in Rule No. 2, and the
rated kilovolt- ampere input capacity of other equipment, with each kilovolt- ampere of input considered equal to one
horsepower. Normally such ratings will be based on the manufacturer's rating as shown on the nameplate or elsewhere
but may, at the option of the utility, be based on tests or other reliable information.
3. Overloaded Motors: Whenever, upon test, any motor under normal operating conditions is found to be
delivering more than 115 per cent of its capacity as indicated by its nameplate rating, the utility may disregard the
nameplate rating and base its charges upon the output as calculated from test. Any motor which is billed on a basis
in excess of its nameplate rating in accordance with this special condition shall be tested at intervals to be determined
by the utility or upon notification by the customer of a permanent change in operating conditions.
4. Guarantee of Larger Connected Load: Any customer may obtain the rates for a larger connected load
by guaranteeing the service charges and energy charges applicable to the larger connected load.
5. Temporary Reduction of Connected Load: Where the use of energy is seasonal or intermittent, no
adjustment will be made for any temporary reduction of connected load. Any customer resuming service on such
connected load within 12 months after it was disconnected,. will be required to pay all charges which would have
been billed if the temporary reduction of connected load had not been made. -
6. Payment of Service Charges: The annual service charge will be payable in six equal monthly install-
ments beginning with the first month of each contrar,,t year.
(CanNnwd)
(To be inserted by utility) . Issued by (To be incited by W. P.U.C.)
Advice Letter No. 351 -E
Decision No. 77700
William M. Marriott
Nsrot
Manager of Reventu Requiremients
Date Filed September 11, 1970
Effective September 11, 1970
Reodutioa No.
9
•
J
Suv+rmRN CAUfQRNVA WlSON COMPANY
Edison Building
Los Angeles, California
Revised . Cal. P.U.C. Sheet No. 4187 -E
Cancelling Revised Cal. P.U.C. Sheet No. 4065 -E
Schedule No. PA -1
POWER — AGRICULTURAL AND PUMPING
CONNECTED LOAD BASIS
(Continued)
SPECIAL CONDITIONS (Continued)
7. Contracts: A contract for a period of one year will be required for service under this schedule and will
remain in effect from year to year thereafter unless cancelled. When service is first rendered under this schedule, the
contract year and billing basis shall commence with the first regular meter reading date after the date service is begun.
8. Change of Customer: Any customer taking over service on a premises which has previously been served
under this schedule shalt have the option of (a) assuming the benefits and liabilities of the former customer's contract
by paying all charges which would have accrued for continuous service, in which case the beginning date of the
contract year and billing basis shall remain the same as that established in the former customer's contract, or (b) the
new customer may elect to have the contract year and billing basis commence with the first regular meter reading
date after the date service is changed to his account.
9. Change of Connected Load: When there is an increase or decrease in connected load during a contract
year, no adjustment in billing to date of change will be made. For the period subsequent to date of change, billing
shall be made on the following basis: (a) Any remaining service charge installments shall be based on the new
connected load, and (b) energy charge billing will be based on the new connected load using the full annual energy
blocks less the adjusted kilowatt -hour use to date of change. The adjusted kilowatt -hour use to date of change is
determined by multiplying the kilowatt -hours to date of change by the ratio of the new connected load to the old
connected load.
10. Change of Contract Year: Any contract may, at the customer's option, be superseded by a new con-
tract beginning with the regular meter reading date in April of any year and covering the balance of the original
contract period, in which case the annual service charge and the size of the energy blocks will be prorated according
to the proportion that the number of days from date of beginning of the contract year to the April reading date bears
to 365 days, and credit for any excess payments will be applied in the new contract year.
(To be formal by utility) luacd by (To be inurted by Cil. P.U.C.)
Advice Letter No. 351 -E
Decision No. 77700
William M. Marriott
eme
Manager of Revenue Requirements
Date Filed September 11, 1970
Effective September 11, 1970
Raclud= No. .:
•
•
•
cdi,i CAWURNIA EUISON COMPANY
Edison Building
Los Angeles, California
Revised Cal. P.U.C. Sheet No. 4188 -E
Cancelling Revised CaL P.U.C. Sheet No. 4066 -E
Schedule No. PA -2
POWER —AGRICULTURAL AND PUMPING
DEMAND BASIS
APPLICABILITY
Applicable to power service for general agricultural .purposes or for general water or sewerage pumping.
TERRITORY
Within the entire territory served, excluding Santa Catalina Island.
RATES
Per Motor
Demand Charge: Per Month
First 75 kw or less of billing demand ....................... ............................... $75.00
All excess kw of billing demand, per kw .................... ............................... 0.90
Energy Charge (to be added to Demand Charge):
First 150 kwhr per kw of billing demand:
First 15,000 kwhr, per kwhr ..................................... ............................... 1.50¢
All excess kwhr, per kwhr ....................................... ............................... 1.20¢
Next 150 kwhr per kw of billing demand, per kwhr. ............................... 0.80¢
Allexcess kwhr, per kwhr ................. _ .... _.................................................... 0.60¢
Minimum Charges
The monthly minimum charge shall be the monthly Demand Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard voltage.
2. Billing Demandt The billing demand shall be the kilowatts of maximum demand but not less than SOgb of
the highest maximum demand established in the preceding eleven months, however, in no case shall the billing demand
be less than 75 kw. Billing demand shall be determined to the nearest 1/10 kw.
9. Maximum Demand: The maximum demand in any month shall be the measured maximum average kilowatt
input, indicated or recorded by instruments to be supplied by the utility, during any 15- minute metered interval in the
month, but not less than the diversified resistance welder load computed in accordance with the section designated
Welder Service in Rule No. 2. Where demand is intermittent or subject to violent fluctuations, a 5- minute interval
may be used.
4. Power Factor Adjustment; When the billing demand has exceeded 200 kw for three consecutive months,
a kilovar -hour meter will be installed as soon as practical, and, thereafter, until the billing demand has been less than
ISO kw for twelve consecutive months, the charges will be adjusted each month for power factor, as follows:
The charges will be decreased by 20 cents per kilowatt of measured maximum demand and will be increased by
20 cents per kilovar of reactive demand. However, in no case shall the number of kilovare used for the adjust-
ment be less than one -fifth the number of kilowatts.
The kilovars of reactive demand shall be calculated by multiplying the kilowatts of measured maximum demand
by the ratio of the kilovar -hours to the kilowatt- hours. Demands in kilowatts and kilovars shall be determined
to the nearest one -tenth (0.1) unit. iA ratchet device will be installed on the kilovar-hour meter to prevent its
reverse operation on leading power factors.
S. Temporary Discontinuance of Service: Where the use of energy is seasonal or intermittent, no adjust-
ments will be made for a temporary discontinuance of service. Any customer resuming service within twelve months
after such service was discontinued will be required to pay all charges which would have been billed if service had
not been discontinued.
(To be inrened br UWAT)
Advice Letter No. 351 -E
Decision No. 77700
laced ar M be fnwftd br Cal. P.U.G)
William M. Marriott Date Filed September 11, 1970
Neae
Effective September 11, 1970
Manager of Revenue Requirements
+fps
40
•
Revised CAL. P.U.C. SHEET NO. 11777 -G
SOUTHERN CALIFORNIA GAS COMPANY
LOS ANGELES. CALIFORNIA CANCELING. Original CAL. F.U.C. SHEET NO. 1.1429 -G
loft)
Schedule No. G-46
GAS ENGINE NATURAL GAS SERVICE
Applicable to firm service for stationary internal combustion engines only.
Within Rate Areas 12 thru 28 as specified on rate area maps.
Commodity Charge
Per Meter Per Month
First 1,000 thermal units,
per unit...........
6.1930
Next 4,000 thermal units,
per unit...........
5.623
Next 5,000 thermal units,
per unit...........
5.103
Over 10,000 thermal units,
per unit...........
4.813
The number of thermal units to be billed shall be determined in accordance with
Rule 2 (1).
Minimum Charge
Initial meter installation, per month.......... $7.00
To be made cumulative only when total billing exceeds $84.00 per meter at
any time during the contract year.
1. All gas consumed during the entire year at all meter locations, by any
customer may be aggregated, provided (15 in addition to the rate quoted
above an annual meter charge of $25.00 will be made for each meter
installation in excess of one, and (2) the minimum charge will be $100.00
per customer per month, to be made cumulative only when total billing .
exceeds $1)200.00 per customer at any time during the contract year.
Meter readings will not be aggregated for associations or combinations of
customers, where, in the judgment of the Company, the operation of one or
more plants has been transferred from one customer to another customer
for this purpose.
2. Customers served ufider this schedule shall have priority in the use of gas
over customers served under interruptible schedules, at.timee when there is
insufficient gas to supply the demands of all customers.
(continued)
(TO BE INSERTED BY UTILITY) (TO BE INSERTED BY CAL F.U.C.)
ADVICE LETTER NO 813 DATE FILED December 41 1970
HARVEY A. PROCTOR
DECISION NO. .77976 EXECUTIVE VICE PRESIDENT EFFECTIVR December 8. 1910
►.bI Ap. 11 /M RESOLUTION NO
r�
L.J
•
•
Original CAL. P.U.C. SHEET NO. 1143O-G
SOUTHERN CALIFORNIA GAS COMPANY
LOS ANGELES. CALIFORNIA CANCELING Revised CAL. P.U.C. SHEET NO. So-Co. 5420 -G
(Sheet 2 of 2)
Schedule No. G-46
GAS ENGINE NATURAL GAS SERVICE
Continued
ECIAL CONDITIONS (Continued)
3. A contract (Form 881 -L) covering the fuel requirements of the customer for
a period of at least one (1) year will be required as a condition precedent
to service under this schedule and shall continue in force and effect
thereafter until either the Company or the customer shall give the other
party thirty (30) days' written notice.of a desire to terminate same,
whereupon at the expiration of said thirty (30) days it shall cease and
determine; provided, however, if the customer permanently ceases operations
at any time such contract shall not thereafter continue in force.
4. Contingent Offset Charges Related to F.P.C. Dockets
The rates include offset charges as shown below related to increases and
decreases in cost of gas from El Paso Natural Gas Company and Pacific
Lighting Service Company (including California gas) as a result of F.P.C.
Dockets Nos. RP69 -6, RP69 -20 and RP70 -11 of E1 Paso Natural Gas Company
and RP69 -27 and RP70 -19 of Transwestern Pipeline Company.
F.P.C. Docket
Offset Charge
0.202¢ per thermal unit
0.084 per thermal unit
0.079¢ per thermal. unit
0.185¢ per thermal unit
0.188¢ per.thermal unit
To the extent that the F.P.C. in these dockets orders reduction in the
rates for E1 Paso or Transwestern gas with the resulting effect on cost
of gas from the above -noted sources, the offsets will be reduced related,
to the reduction in cost of gas from these sources.
5. Refunds of Contingent Offset Charges Related to F.P.C. Dockets Nos.
RP69 -6, RP69 -2o, RP69 -27, RP70-11 and RP70 -19
Refunds received from E1 Paso Natural Gas Company and Pacific Lighting
Service Company as related to these dockets will be made to various
customer classes in proportion to the contingent offset charges collected
during the periods tQ,VAd cb tbq, roftift apply.
ADVICE LETTER NO 810
DECISION NO. 1 6/ 1 1./010
860.1, 11". 11/60
HARVEY A. PROCTOR
EXECUTIVE VICE PREE1DENT
DATE FILED October 29, 1970
EFFECTIVE November 28, 1970
RESOLUTION NO
•
0
Revised CAL, F.U.C. SNEET NO. 11782 -G
SOUTHERN CALIFORNIA GAS COMPANY
LOS ANGELES. CALIFORNIA CANCELING Original CAL. IsM.C. SHEET NO. 11433 -G
Schedule No. G-51 I (Sheet 1 of 3)
INTERRUPTIBLE NATURAL GAS SERVICE
Applicable, subject to interruptions in supply, to natural gas service to
commercial and industrial customers, exclusive of retail service for utility
steam - electric generating stations and cement plants, where such customers are
located near existing mains having a delivery capacity and supply in excess of
the then existing requirements of present customers.
Within Rate Areas 12 thru 28 as specified on rate area maps.
Commodity Charge
Regular Usage:
First 21000 thermal. units,
Next 8,000 thermal units,
Next 20,000 thermal units,
Next 30,000 thermal units,
Next 401000 thermal units,
Next 100,000 thermal. units,
Over 200,000 thermal units,
Per Meter Per Month
per unit...........
per unit...........
per unit...........
per unit...........
per unit...........
per unit...........
per unit...........
5.578¢
5.148
4.958
4.777
4.59T
4.457
4.347
First Z,000 thermal units, per. unit........... 4.1741
Next 8,000 thermal units, per unit........... 3.804
Over 10,000 thermal units, per unit........... 3.714
Upon application, customers who have installed and are using gas air
conditioning equipment will be billed under the air conditioning rate
for monthly consumption up to 53 thermal units per rated hill ton of
such equipment.
The number of thermal units to be billed shall be determined in accordance with
Rule 2 (i).
Minimum Charge
Per Meter Per Month .... ....... ................$100.00
To be made cumulative only when total billing exceeds $1,200.00 per meter at
any time during the contract year.
In the event of curtailment, the foregoing monthly minimum charge and the rate
blocks will be prorated in the proportion of the number of equivalent.days gas
is offered during the billing period to the total number of days in the billing
period.
• (continued)
(TO BE INURTED BY UTILITY)
ADVICE LETTER NO 813 HARVEY A. PROCTOR DATE FILM _ December 4 1970
DECISION NO. TT6 axaCUTIVa VICE►RaSIDaNT EFFECTIVE December 8, 1970
•M.F REF. IVN .. RESOLUTION NO
•
0
•
original CAL. P.U.C. SHEET NO 11434 -G
SOUTHERN CALIFORNIA GAS COMPANY
LOS ANGELES. CALIFORNIA CANCELING Revised CAL. P.U.C. SHEET NO. SO.Co' 55160 -G
Schedule No. G -51
INTERRUPT23LE NATURAL GAS SERVICE
Continued
SPECIAL CONDITIONS
(Sheet 2 of 3)
1. Service under this schedule is subject to discontinuance without notice in
case the Company has an insufficient quantity of natural.gas produced
directly from oil wells and /or purchased from out -of -state sources to
satisfy its requirements of gas for underground storage and to supply with
natural gas (a) customers under all its Firm Natural Gas Service, General
Service, Firm Industrial and Gas Engine schedules, (b) customers under
special contracts other then those for interruptible service, and (c) other
public utilities, and if the supplying of such gas under this schedule
shall, in the opinion of the Company, jeopardize or threaten the supply to
any of said customers or said public utilities, then the Company shall have
the right, without notice, to discontinue such gas supplied under this
schedule in whole or in part until it again has an amount of such gas
sufficient to supply all of said customers and said public utilities in
addition to supplying the gas provided under this schedule. Curteilment of
interruptible gas service shall be made in compliance with Rule 23.,
2. Except upon an application made to the California Public Utilities
Commission and approval first obtained;
(a) No customer (except as to a.plant on an interruptible gas rate during
all or a portion of the year ended December 16, 1941), applying for
gas service hereunder subsequent to December 16, 1941, shall be
entitled to such gas service, unless such customer shall have adequate
standby fuel and equipment, and qualified attendants ready at all
times to effect mediate change -over from gas to other fuel in the,
event that the supply of gas hereunder-shall be discontinued.
(b) No existing customer using gas hereunder subsequent to December 16,
1941, shall be permitted to increase usage of gas hereunder for
additional equipment (except as to equipment on an interruptible
gas rate during all or a portion of the year ended December 16, 1941)
unless such customer shall have adequate standby fuel and equipment,
and qualified attendants ready at all times to effect mediate
change -over from gas to other fuel in the event that the supply of
gas hereunder shall be. discontinued.
3. Service may be supplied under this.scheduie at the option of the Company f,
short -term operations that are started and completed during the "off- peak"
demand season (May 1 to October 1) without the provisions for standby fuel
and equipment as required in Special Condition 2.
ADVICE LETTER NO 810
DECISION No. 77010
I N•F REE. 11/N
HARVEY A. PROCTOR
EXECUTIVE VICE PRESIDENT
DATE FILED .October 29, 1970
November 28, 1970
EFFECTIVE
RESOLUTION 110
1
U
•
•
SOUTHERN CALIFORNIA GAS COMPANY
LOB ANGELES. CALIFORNIA
Original tAL. P.U.C. SHEET No 11435-G
CANCELING Revised CAL. P.U.C. SHEET NO. So-Co. 5422 -G
(Sheet 3 of 3)
Schedule No. G-51
INTERRUPTIBLE NATURAL GAS SERVICE
Cont ued
ECIAL CONDITIONS (Continued)
4. A contract* covering the fuel requirements of the customer during the
operation of his plant, for a period of at least one (1) year, will be
required as a condition precedent to service under this schedule, except as
otherwise provided in these Special Conditionsp and shall continue in force
and effect thereafter until either the Company or the customer shall give
the other party thirty (30) days' written notice of a desire to terminate
same, whereupon at the expiration of said thirty (30) days it shall cease
and determine. If the customer permanently ceases operations, such contract
shall not thereafter continue in force.
5. In the application of this schedule, gas delivered to the various premises
of a customer can not be aggregated.
6. Customers may receive service under this schedule (a) separately, or (b) in
combination with a firm natural gas service schedule through a single meter
installation. The minimum charge for combination service will be the
minimum charge specified in this schedule.
7. Contingent Offset Charges Related to F.P.C, Dockets
The rates include offset charges as shown below related to increases and
decreases in cost of gas from E1 Paso Natural Gas Company and Pacific
Lighting Service Company (including California gas) as a result of F.P.C.
Dockets Nos. RP69 -6, RP69 -20 snd.RP70 -11 of El Paso Natural Gas Company and
RP69 -27 and RP70 -19 of Transwestern Pipeline Company.
F.P.C. Docket Offset Charge
RP69 6-6 0.202¢ per thermal unit
RP69 -20 0.088¢ per thermal unit
RP69 -27 0.0790 per thermal.unit
RP70 -11 0.1850 per thermal unit
RP70 -19 0.184 per thermal unit
To the extent that the F.P.C. in these dockets orders reduction in the
rates for El Paso or Transwestern gas with the resulting effect on cost
of gas from the above -noted sources, the offsets will be reduced related
to the reduction in cost of gas from these sources.
8. Refunds of Contingent Offset Charges Related to F.P.C. Dockets Nos.
RP69- 6.. RP69.20, RP69 -27, RP70 -11 and RP70 -19
Refunds received from Ei Paso Natural Gas Company and Pacific Lighting
Service Company as related to these dockets will be made to various
customer classes in proportion to the contingent offset charges collected
during the periods to which the refunds apply.
+rSa Interruptible Service -- Form 1438 -H
(b; Combination Firm and Interruptible Service -- Form 623 -F
ITO BE
ADVICE LETTER NO 810 DATE FILED October 292 1970
HARVEY A. PROCTOR
DECISION No. 77010 EXECUTIVE VICE PRgID[NT ErreerrvE November 28, 1970
1 [... RSV. N /BE RESOLUTION No
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See Contract File for
Pump Station — Zones III & IV
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Pump Station — Zones III & IV
Natural Gas Engines Diagram
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PURCHASE ORDER NO. 4 d 5 2
T} 'ry�N�N T NTH INVOICE IN DPLIC+ATE
"�i OF NEVROR.i' B� -" _ /A TN18 ORDER NtlA�#IUBT .=
APPEAR ON AL{ INY BNIP -'
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December 28, 1970
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E=- 1EERING STUDY
WATER SERVICES
HARBOR VIEW HILLS, SECTOR IV
Enclosed are two copies of subject agreement for
Shuirman- Simpson, Civil Engineers, and for your
files.
Please forward one copy to Shuirman- Simpson.
LL:. wk
enc.
cc: City Attorney
Finance Dept.
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AGREEMENT FOR ENGINEERING SERVICES
e- /33s-
(Preliminary study of Pressure Zone III and IV
Water Master Plan Facilities and a pressure reducing
station connecting Pressure Zone III to II)
THIS AGREEMENT is made and entered into this ;23jV0 day of
DEC 1Z , 1970, by and between the CITY OF NEWPORT BEACH, a
(municipal corporation hereinafter referred to as "City ", and the
firm of SHUIRMAN- SIMPSON, CIVIL ENGINEERS, hereinafter referred to
as "Engineer ";
WHEREAS, City recently annexed a hillside area known as j
Harbor View Hills, Section IV, and;
WHEREAS, City proposes to provide domestic water service
to this area which is partially located in three undeveloped water
(pressure zones (Master Plan Zones III, IV, and V), and;
WHEREAS City further proposes to increase the operational
(flexibility of the present water system with a connection from Water
Pressure Zone III to II and a pumping facility from Big Canyon
Reservoir to Water Pressure Zone III, and;
WHEREAS, engineering services are necessary to study and
+analyze various alternatives of providing domestic water service to
iZones IV and V and increasing existing operational flexibility in
iorder to identify the alternative with greatest merit, and;
WHEREAS, Engineer has submitted a proposal to make the
,needed study and are well qualified to furnish such services;
NOW, THEREFORE, the parties agree as follows:
I
1. SERVICES TO BE FURNISHED BY ENGINEER
A. Review the existing schematic designs for the Zone III
and the Zone IV pumping stations to be located
adjacent to Big Canyon Reservoir.
B. Investigate alternative designs for the two stations,
Iusing Big Canyon Reservoir as a suction for the Zone
III station, and the Zone III pumping station and /or
existing 24 -inch Zone III line as suction for the
-1-
,I
1 Zone IV pumping station.
21 C. Recommend the capacities and the number of pumps for
3 each pumping station that would allow for stage
4j construction to meet the required demand as the area
5 to be served increases.
i
6 D. Prepare a preliminary layout for a pressure regulated
7 interconnection between Pressure Zones III and II at
8 Big Canyon Reservoir.
9 E. Prepare preliminary cost estimates for the pressure
10 regulated interconnection and the Zone III and Zone IVI,
11 pumping stations.
12 F. Prepare an economic analysis of electrical motors
13; versus natural gas engines for the pumping station
14'� pumps.
15 G. Determine the capacity and investigate alternative
16 designs for the Zone IV reservoir, including
17' coordination with developer and land owner.
18 H. Prepare cost estimates and preliminary layouts for the
19 16 -inch transmission main and the Zone IV reservoir
20 required to serve Section IV of Harbor View Hills.
2111 I. Prepare alternative preliminary layouts showing the
I�
22111 relationships of the pumping stations, pressure
i1
23: transmission main, and reservoir which
24!, will permit a specific alternative to be chosen.
25i 2. PREPARATION OF REPORT
I
261; Engineer agrees to submit a written report which shall
27 include background information, cost estimates, exhibits,
28 and recommendations, within 60 days after execution of
291 this agreement. City will reimburse Engineer for the
3011 cost of reproducing said report.
3111 3. PAYMENT FOR SERVICES
3211 City agrees to pay Engineer for its services on the basis
I
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2
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of 2 -1/2 times the direct labor costs, at the direct labor
rates as shown in the following fee schedule, but not to
exceed the sum of $6,500.00.
Principal $10.00 per hour
Engineers $7.00 to $8.00 per hour
Designers and Draftsmen $5.00 to $7.00 per hour
Typist $3.50 per hour
Partial payment shall be made each month during the
course of the study, up to a total of 90% of the maximum,
with the balance due upon receipt of the final printed
report.
4.
The scope of the services to be furnished by Engineer may
be changed and the maximum fee increased upon prior
written approval of the Public Works Director.
5. TERMINATION
This agreement may be terminated at any time by City upon
three (3) days written notice to Engineer by placing said
notice in the United States mail, postage prepaid,
addressed to Engineer's business office. In the event of
termination due to the fault of Engineer, City shall be
relieved of any obligation to compensate Engineer. If
this agreement is terminated for any reason other than
the fault of Engineer, City agrees to compensate Engineer
for the actual services performed up to the effective date
of the notice of termination on the basis of the fee
schedule contained in this agreement.
IN WITNESS WHEREOF, the parties hereto have executed this
-3-
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51
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THS:adw 32
12/16/70
rI
agreement as of the date and year first above written.
APPROVED AS TO FORM:
(City A orney
CITY OF NEWPORT BEACH
By: C. . �
Mayor
By' 3 unit. yam" 1��3itca�
Cty Clerk
CITY
SHUIRMAN- SIMPSON, CIVIL ENGINEERS
ENGINEER