Watsonville City Council
September 8, 2026

r040102
the fuel stream for specific guidance.

11. Reference: Biogas CH4 concentration
Please refer to this table to correlate volume % of
CH4 to the lower heating value to determine the
minimum required supply pressure in biogas
application. This assumes that the balance of the
fuel gas is inert (e.g. CO2,N2). For reference
purposes, the approximate fuel flow rate per
generator is also included. This flow rate assumes
the generator is operating at 44% efficiency.

Environmental conditions such as elevation and
ambient temperature can impact the flow rate
and should be accounted for in the fuel supply
design.

CH4
Volume
Fraction
LHV
[BTU/scf]
Min Supply
Pressure [psig]
Expected
Fuel Flow
Rate [SCFM]
40% 360 17.6 87
45% 405 14.8 77
50% 450 12.7 69
55% 495 11.1 63
60% 540 9.9 58
65% 585 8.8 53
70% 630 8.2 49
75% 675 7.7 46
80% 720 7.2 43
85% 765 6.8 41
90% 810 6.4 38
95% 855 6.1 36
100% 900 5.6 35
— end of document
This document is proprietary and confidential and may contain legally privileged information. No part of this document may be distributed, disseminated, published, or otherwise disclosed in any manner to a third party without prior written consent of Mainspring Energy, Inc.

Attachment 1

Radically simple. Factory built.

The Mainspring Linear Generator runs on any fuel, is fully dispatchable, uses no water, and emits near-zero NOx. No other primary power solution can match the flexibility, affordability, and low emissions of a linear generator.
y PERFORMANCE SPECS: MODEL NO. LGEN 3
For more product information,
scan the QR Code or visit
MAINSPRINGENERGY.COM
Up to 18 MW per
acre scalability
Each package
contains two linear
generator cores,
operated in tandem
OUTPUTS1 Power (net AC) 250 kW
Electrical 400/480 V, 3 Phase, 50/60 Hz
INPUTS Fuels Any blend of Biogas2, Natural
Gas, Hydrogen, and Propane
Input Pressure 5–20 psig (15 psig nominal)
Water Consumption None
EFFICIENCY3 Electrical (LHV, net AC) 46%
Heat Rate (HHV, net AC) 8,233 BTU/kWh
EMISSIONS4 NOx <1.5 ppm (<0.05 lb/MWh)
Noise <70 dBA @ 3m, <65 dBA @10m
PHYSICAL Weight 20 tonnes
Dimensions (L x W x H) 20.5' × 8.5' × 9.5'
ENVIRONMENT Temperature Range -30° to 50° C
Humidity 0 to 100%
OPERATIONS Power Output Range 0 to 100% power output
Grid Parallel to Island Transfer5 <10 sec
Maximum Step Load 300 kVA for up to 10 sec
Building Soft Start Capability Yes
OTHER UL 2200 package Remote monitoring
UL 1741 SB grid-tie inverter Secure customer portal
Compliant with CA Rule 21 Modbus interface

1. Rated capacity may vary by fuel type. 2. Refer to Mainspring Fuel Specifications for details. 3. Measured according to ASME PTC 5O at 15 C and 1 atm on natural gas and biogas.

Rated efficiency may vary by fuel type. 4. Products comply with emissions limits in South Coast AQMD. All data is subject to technical development and modification. R30312 y PRODUCT FEATURES
01 Fuel Flexible
Seamlessly switch between
natural gas, RNG, biogas,
propane, and hydrogen.
02 Dispatchable
Quickly ramp output to
meet variable workloads
and enable grid independent
operations.
03 Low emissions
Produce electricity with nearzero NOx and meet even the most stringent air quality
standards.
04 Modular
Enable faster deployment
timelines with factory-built
units that are quick to install.
05 Low maintenance
Minimize downtime with
modular design, only two
moving parts and no oil.
y MAINSPRING LINEAR GENERATOROR
Attachment 1

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49 50
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53 54
55 56
57 58
59 60
61 62
63 A B C D E F
Digester Waste
Gas
Digester Waste
Gas meter
reading
1701 1702
k cfd k cfd
1 Wed 187187.00 67178607.00
2 Thu 37604.00 67216211.00
3 Fri 53694.00 67269905.00
4 Sat 8677.00 67278582.00
5 Sun 99992551.00 67271133.00
6 Mon 2454.00 67273587.00
7 Tue 2533.00 67276120.00
8 Wed 4088.00 67280208.00
9 Thu 19981.00 67300189.00
10 Fri 35878.00 67336067.00
11 Sat 36776.00 67372843.00
12 Sun 31299.00 67404142.00
13 Mon 27288.00 67431430.00
14 Tue 22543.00 67453973.00
15 Wed 18749.00 67472722.00
16 Thu 26636.00 67499358.00
17 Fri 25740.00 67525098.00
18 Sat 21705.00 67546803.00
19 Sun 5572.00 67552375.00
20 Mon 1100.00 67553475.00
21 Tue 4208.00 67557683.00
22 Wed 13940.00 67571623.00
23 Thu 11172.00 67582795.00
24 Fri 18636.00 67601431.00
25 Sat 20000.00 67621431.00
26 Sun 20000.00 67641431.00
27 Mon 16503.00 67657934.00
28 Tue 25933.00 67683867.00
29 Wed 26231.00 67710098.00
30 Thu 23764.00 67733862.00
31 Fri 30959.00 67764821.00
1 Sat 37263.00 67802084.00
2 Sun 13974.00 67816058.00
3 Mon 7842.00 67823900.00
4 Tue 13878.00 67837778.00
5 Wed 20049.00 67857827.00
6 Thu 18571.00 67876398.00
7 Fri 21190.00 67897588.00
8 Sat 27923.00 67925511.00
9 Sun 32214214.40 139725.40
10 Mon 67851538.60 67991264.00
11 Tue 29330.00 68020594.00
12 Wed 19322.00 68039916.00
13 Thu 2836.00 68042752.00
14 Fri 5497.00 68048249.00
15 Sat 10658.00 68058907.00
16 Sun 6798.00 68065705.00
17 Mon 13502.00 68079207.00
18 Tue 13230.00 68092437.00
19 Wed 38979.00 68131416.00
20 Thu 30662.00 68162078.00
21 Fri 24699.00 68186777.00
22 Sat 13157.00 68199934.00
23 Sun 5992.00 68205926.00
24 Mon 12183.00 68218109.00
25 Tue 8466.00 68226575.00
26 Wed 14253.00 68240828.00
27 Thu 195274.00 68436102.00
28 Fri 22355.00 68458457.00 Daily Com
WWTP\Utilities
Jan
Feb
File: Waste gas data.pdf
Received: January 7th, 2026
Description: Reflective of full year 2025 Daily biogas flow data Data Type: Raw daily Data
Source: City of Watsonville Operator
Purpose: Linear Gen and Gas Scrubber Sizing
Attachment 1

64 65
66 67
68 69
70 71
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128

A B C D E F
1 Sat 13977.00 68472434.00
2 Sun 2523.00 68474957.00
3 Mon 31527818.00 2775.00
4 Tue 68478264.00 68481039.00
5 Wed 9144.00 68490183.00
6 Thu 5517.00 68495700.00
7 Fri 26056.00 68521756.00
8 Sat 18999.00 68540755.00
9 Sun 30170.00 68570925.00
10 Mon 12770.00 68583695.00
11 Tue 21692.00 68605387.00
12 Wed 25316.00 68630703.00
13 Thu 19456.00 68650159.00
14 Fri 24847.00 68675006.00
15 Sat 34063837.00 2738843.00
16 Sun 65983332.00 68722175.00
17 Mon 25272.00 68747447.00
18 Tue 19505.00 68766952.00
19 Wed
20 Thu 37187.00 68804139.00
21 Fri
22 Sat 42233.00 68846372.00
23 Sun 9034.00 68855406.00
24 Mon 16520.00 68871926.00
25 Tue 19644.00 68891570.00
26 Wed
27 Thu
28 Fri
29 Sat 154048.00 69045618.00
30 Sun 51720.00 69097338.00
31 Mon 34355.00 69131693.00
1 Tue 31055.00 69162748.00
2 Wed
3 Thu
4 Fri
5 Sat 164807.00 69327555.00
6 Sun 26605.00 69354160.00
7 Mon 36917.00 69391077.00
8 Tue 31873.00 69422950.00
9 Wed 29088.00 69452038.00
10 Thu 18128.00 69470166.00
11 Fri
12 Sat 50069.00 69520235.00
13 Sun 24974.00 69545209.00
14 Mon 39389.00 69584598.00
15 Tue 33701.00 69618299.00
16 Wed 26682.00 69644981.00
17 Thu 34721.00 69679702.00
18 Fri
19 Sat 38628.00 69718330.00
20 Sun 23498.00 69741828.00
21 Mon 11853.00 69753681.00
22 Tue 16880.00 69770561.00
23 Wed 27643.00 69798204.00
24 Thu 204161.00 70002365.00
25 Fri 22895.00 70025260.00
26 Sat 19830.00 70045090.00
27 Sun 19012.00 70064102.00
28 Mon 28822.00 70092924.00
29 Tue 27669.00 70120593.00
30 Wed 29618.00 70150211.00
1 Thu 30983.00 70181194.00
2 Fri 24414.00 70205608.00
3 Sat 18546.00 70224154.00
4 Sun 16834.00 70240988.00
Apr
Mar
Attachment 1

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A B C D E F
5 Mon 14536.00 70255524.00
6 Tue 15936.00 70271460.00
7 Wed 6805.00 70278265.00
8 Thu 14232.00 70292497.00
9 Fri 18057.00 70310554.00
10 Sat 16608.00 70327162.00
11 Sun 7636.00 70334798.00
12 Mon 125052.00 70459850.00
13 Tue 255125.00 70714975.00
14 Wed 268385.00 70983360.00
15 Thu 19347.00 71002707.00
16 Fri 2481.00 71005188.00
17 Sat 2390.00 71007578.00
18 Sun 41584217.00 12591795.00
19 Mon 58421567.00 71013362.00
20 Tue 2915.00 71016277.00
21 Wed 42722.00 71058999.00
22 Thu 23945.00 71082944.00
23 Fri 208354.00 71291298.00
24 Sat 58310.00 71349608.00
25 Sun 10324.00 71359932.00
26 Mon 11633.00 71371565.00
27 Tue 17644.00 71389209.00
28 Wed 22009.00 71411218.00
29 Thu 20733.00 71431951.00
30 Fri 15664.00 71447615.00
31 Sat 19782.00 71467397.00
1 Sun 6182.00 71473579.00
2 Mon 11425.00 71485004.00
3 Tue 29285.00 71514289.00
4 Wed 62563.00 71576852.00
5 Thu 17314.00 71594166.00
6 Fri 11092.00 71605258.00
7 Sat 15975.00 71621233.00
8 Sun 6225.00 71627458.00
9 Mon 3915.00 71631373.00
10 Tue 11794.00 71643167.00
11 Wed 24809.00 71667976.00
12 Thu 109167.00 71777143.00
13 Fri 43887.00 71821030.00
14 Sat 26802.00 71847832.00
15 Sun 46017683.00 17865515.00
16 Mon 54016952.00 71882467.00
17 Tue 3290.00 71885757.00
18 Wed 7154.00 71892911.00
19 Thu 105066.00 71997977.00
20 Fri 11349.00 72009326.00
21 Sat 10410.00 72019736.00
22 Sun 10021.00 72029757.00
23 Mon 2914.00 72032671.00
24 Tue 16166.00 72048837.00
25 Wed 184946.00 72233783.00
26 Thu 110436.00 72344219.00
27 Fri 33600.00 72377819.00
28 Sat 19045.00 72396864.00
29 Sun 224680.00 72621544.00
30 Mon 126511.00 72748055.00
1 Tue 289989.00 73038044.00
2 Wed 252162.00 73290206.00
3 Thu 276044.00 73566250.00
4 Fri 224645.00 73790895.00
5 Sat 237757.00 74028652.00
6 Sun 237030.00 74265682.00
7 Mon 91475.00 74357157.00
8 Tue 17247.00 74374404.00
May
Jun
Attachment 1

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A B C D E F
9 Wed 17380.00 74391784.00
10 Thu 4172.00 74395956.00
11 Fri 2667.00 74398623.00
12 Sat 4265.00 74402888.00
13 Sun 2638.00 74405526.00
14 Mon 2744.00 74408270.00
15 Tue 5660.00 74413930.00
16 Wed 17483.00 74431413.00
17 Thu 8577.00 74439990.00
18 Fri 7350.00 74447340.00
19 Sat 3540.00 74450880.00
20 Sun 2844.00 74453724.00
21 Mon 2742.00 74456466.00
22 Tue 3672.00 74460138.00
23 Wed 19074.00 74479212.00
24 Thu 20263.00 74499475.00
25 Fri 45429.00 74544904.00
26 Sat 23665.00 74568569.00
27 Sun 10409.00 74578978.00
28 Mon 21038.00 74600016.00
29 Tue 34416.00 74634432.00
30 Wed 16648.00 74651080.00
31 Thu 23450.00 74674530.00
1 Fri 20865.00 74695395.00
2 Sat 17218.00 74712613.00
3 Sun 9791.00 74722404.00
4 Mon 63086.00 74785490.00
5 Tue 99972326.00 74757816.00
6 Wed 2756.00 74760572.00
7 Thu 63424.00 74823996.00
8 Fri 3474.00 74827470.00
9 Sat 2501.00 74829971.00
10 Sun 2640.00 74832611.00
11 Mon 21151.00 74853762.00
12 Tue 23519.00 74877281.00
13 Wed 23696.00 74900977.00
14 Thu 2573.00 74903550.00
15 Fri 2752.00 74906302.00
16 Sat 2530.00 74908832.00
17 Sun 2784.00 74911616.00
18 Mon 133631.00 75045247.00
19 Tue 196647.00 75241894.00
20 Wed 165406.00 75407300.00
21 Thu 219300.00 75626600.00
22 Fri 224478.00 75851078.00
23 Sat 202162.00 76053240.00
24 Sun 106779.00 76160019.00
25 Mon 63340.00 76223359.00
26 Tue 2738.00 76226097.00
27 Wed 2687.00 76228784.00
28 Thu 2536.00 76231320.00
29 Fri 2677.00 76233997.00
30 Sat 2474.00 76236471.00
31 Sun 2505.00 76238976.00
1 Mon 2618.00 76241594.00
2 Tue 2386.00 76243980.00
3 Wed 2645.00 76246625.00
4 Thu 2375.00 76249000.00
5 Fri 2700.00 76251700.00
6 Sat 2737.00 76254437.00
7 Sun 2811.00 76257248.00
8 Mon 2939.00 76260187.00
9 Tue 52143.00 76312330.00
10 Wed 20650.00 76332980.00
11 Thu 7276.00 76340256.00
Jul
Aug
Attachment 1

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A B C D E F
12 Fri 2236.00 76342492.00
13 Sat 2126.00 76344618.00
14 Sun 2384.00 76347002.00
15 Mon 2329.00 76349331.00
16 Tue 2441.00 76351772.00
17 Wed 2404.00 76354176.00
18 Thu 2506.00 76356682.00
19 Fri 2086.00 76358768.00
20 Sat 2247.00 76361015.00
21 Sun 2340.00 76363355.00
22 Mon 2335.00 76365690.00
23 Tue 2323.00 76368013.00
24 Wed 2387.00 76370400.00
25 Thu 6912.00 76377312.00
26 Fri 7422.00 76384734.00
27 Sat 2668.00 76387402.00
28 Sun 2527.00 76389929.00
29 Mon 8234.00 76398163.00
30 Tue 2804.00 76400967.00
1 Wed 4627.00 76405594.00
2 Thu 3943.00 76409537.00
3 Fri 8103.00 76417640.00
4 Sat 2616.00 76420256.00
5 Sun 2397.00 76422653.00
6 Mon 2571.00 76425224.00
7 Tue 2685.00 76427909.00
8 Wed 2666.00 76430575.00
9 Thu 2688.00 76433263.00
10 Fri 2903.00 76436166.00
11 Sat 8826.00 76444992.00
12 Sun 2673.00 76447665.00
13 Mon 10085.00 76457750.00
14 Tue 2917.00 76460667.00
15 Wed 7164.00 76467831.00
16 Thu 19986.00 76487817.00
17 Fri 27801.00 76515618.00
18 Sat 33714.00 76549332.00
19 Sun 13720.00 76563052.00
20 Mon 15581.00 76578633.00
21 Tue 69237.00 76647870.00
22 Wed 304397.00 76952267.00
23 Thu 214158.00 77166425.00
24 Fri 30482.00 77196907.00
25 Sat 29208.00 77226115.00
26 Sun 28599.00 77254714.00
27 Mon 17522.00 77272236.00
28 Tue 27170.00 77299406.00
29 Wed 23743.00 77323149.00
30 Thu 18216.00 77341365.00
31 Fri 8623.00 77349988.00
1 Sat 8713.00 77358701.00
2 Sun 6474.00 77365175.00
3 Mon 3719.00 77368894.00
4 Tue 11050.00 77379944.00
5 Wed 25702.00 77405646.00
6 Thu 33046.00 77438692.00
7 Fri 37125.00 77475817.00
8 Sat 35580.00 77511397.00
9 Sun 24375.00 77535772.00
10 Mon 27786.00 77563558.00
11 Tue 36219.00 77599777.00
12 Wed 26429.00 77626206.00
13 Thu 18125.00 77644331.00
14 Fri 14380.00 77658711.00
15 Sat 5111.00 77663822.00
Sep
Oct
Nov
Attachment 1

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369 370
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A B C D E F
16 Sun 2963.00 77666785.00
17 Mon 3120.00 77669905.00
18 Tue 3176.00 77673081.00
19 Wed 3139.00 77676220.00
20 Thu 5173.00 77681393.00
21 Fri 4417.00 77685810.00
22 Sat 4734.00 77690544.00
23 Sun 2746.00 77693290.00
24 Mon 2869.00 77696159.00
25 Tue 3210.00 77699369.00
26 Wed 61133.00 77760502.00
27 Thu 25356.00 77785858.00
28 Fri 26002.00 77811860.00
29 Sat 33504.00 77845364.00
30 Sun 12299.00 77857663.00
1 Mon 14157.00 77871820.00
2 Tue 13800.00 77885620.00
3 Wed 15378.00 77900998.00
4 Thu 20896.00 77921894.00
5 Fri 17027.00 77938921.00
6 Sat 23719.00 77962640.00
7 Sun 10679.00 77973319.00
8 Mon 8833.00 77982152.00
9 Tue 31874.00 78014026.00
10 Wed 51301.00 78065327.00
11 Thu 33374.00 78098701.00
12 Fri 47330.00 78146031.00
13 Sat 46477.00 78192508.00
14 Sun 19125.00 78211633.00
15 Mon 42496.00 78254129.00
16 Tue 50901.00 78305030.00
17 Wed 168944.00 78473974.00
18 Thu 18948.00 78492922.00
19 Fri 19044.00 78511966.00
20 Sat 20501.00 78532467.00
21 Sun 15907.00 78548374.00
22 Mon 22097.00 78570471.00
23 Tue 35617.00 78606088.00
24 Wed 2643.00 78608731.00
25 Thu 40270.00 78649001.00
26 Fri 3116.00 78652117.00
27 Sat 3031.00 78655148.00
28 Sun 110670.00 78765818.00
29 Mon 34548.00 78800366.00
30 Tue 6691.00 78807057.00
31 Wed 2974.00 78810031.00
1,100.0 2,775.0
99,992,551.0 78,810,031.0
2,005,122.8 72,191,929.9
711,818,611.0 25,628,135,110.4

MAXIMUM

AVERAGE
SUM
Nov
Dec

MINIMUM
Attachment 1

January 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Tue 11700 2432 1123 268 14132 0.09683 109 0 1.026 0 109 0 2 Wed 3000 1536 227 9864 4236 0.09683 22 6 1.026 62 22 40 3 Thu 3300 8320 7012 2780 11020 0.09683 679 11 1.026 113 679 0 4 Fri 0 10112 8804 4288 9212 0.09683 852 0 1.026 0 852 0 5 Sat 7500 5632 4324 1268 13132 0.09683 419 45 1.026 462 419 43 6 Sun 8400 5760 4452 240 14160 0.09683 431 62 1.026 636 431 205 7 Mon 5700 7680 6372 1020 13380 0.09683 617 62 1.026 636 617 19 8 Tue 7800 6784 5476 -184 14584 0.09683 530 3 1.026 31 530 0 9 Wed 3900 8704 7396 1796 12604 0.09683 716 0 1.026 0 716 0 10 Thu 2100 9984 8676 2316 11784 0.09683 840 0 1.026 0 840 0 11 Fri 600 10496 9187 3304 10196 0.09683 890 0 1.026 0 890 0 12 Sat 0 10880 9571 3520 9980 0.09683 927 0 1.026 0 927 0 13 Sun 600 11264 9955 2536 11264 0.09683 964 0 1.026 0 964 0 14 Mon 1500 10880 9571 2020 12380 0.09683 927 0 1.026 0 927 0 15 Tue 1500 5632 4323 7268 6832 0.09683 419 0 1.026 0 419 0 16 Wed 600 15872 14563 -2072 16172 0.09683 1410 0 1.026 0 1410 0 17 Thu 0 11136 11136 3264 10536 0.09683 1078 0 1.026 0 1078 0 18 Fri 300 11776 11768 2324 10576 0.09683 1139 0 1.026 0 1139 0 19 Sat 0 11008 11008 3392 10108 0.09683 1066 19 1.026 195 1066 0 20 Sun 4500 8960 8960 940 13160 0.09683 868 46 1.026 472 868 0 21 Mon 2400 10112 10112 1888 12512 0.09683 979 36 1.026 369 979 0 22 Tue 3600 10240 8931 560 13540 0.09683 865 0 1.026 0 865 0 23 Wed 3000 9856 9856 1544 12556 0.09683 954 0 1.026 0 954 0 24 Thu 4200 9344 8036 856 13544 0.09683 778 0 1.026 0 778 0 25 Fri 900 11904 11904 1596 12504 0.09683 1153 0 1.026 0 1153 0 26 Sat 300 13184 13184 916 12884 0.09683 1277 0 1.026 0 1277 0 27 Sun 1200 8320 8320 4880 9520 0.09683 806 0 1.026 0 806 0 28 Mon 600 8320 8320 5480 8320 0.09683 806 0 1.026 0 806 0 29 Tue 300 22912 21604 -8812 22912 0.09683 2092 0 1.026 0 2092 0 30 Wed 1800 11392 10084 1208 12892 0.09683 976 0 1.026 0 976 0 31 Thu 3300 8832 7524 2268 12132 0.09683 729 9 1.026 92 729 0 MIN 0 1536 227 -8812 4236 0.09683 22 0 0 22 0
MAX 11700 22912 21604 9864 22912 0.09683 2092 62 636 2092 205 AVG 2729.0 9653.677 8767.065 2017 12025 0.09683 849 9.6 99 849 10 SUM 84600 299264 271779 62536 372764 26316 299 3068 26316 307 Non-allowed therms 0

File: CoGenGas_2025.pdf
Received: January 7th, 2026
Description: Existing Cogen run hours and fuel blending ratio Data Type: Raw daily Data
Source: City of Watsonville Operator
Purpose: Linear Gen and Gas Scrubber Sizing
Attachment 1

January 2025
D
A
T
E
D
A
Y
1 Tue
2 Wed
3 Thu
4 Fri
5 Sat
6 Sun
7 Mon
8 Tue
9 Wed
10 Thu
11 Fri
12 Sat
13 Sun
14 Mon
15 Tue
16 Wed
17 Thu
18 Fri
19 Sat
20 Sun
21 Mon
22 Tue
23 Wed
24 Thu
25 Fri
26 Sat
27 Sun
28 Mon
29 Tue
30 Wed
31 Thu
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $4 $22 $26 0.017 0.015 300 $4.44 28.6 5900 168500 21.5

0.18700 0.24104 0.01733 0.31300 $23 $0 $23 0.003 0.029 600 $17.54 15.5 10900 169000 20.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 164900 22.3

0.18700 0.24104 0.01733 0.31300 $86 $24 $109 0.019 0.013 0 $0.00 4.4 44700 195700 24.2

0.18700 0.24104 0.01733 0.31300 $88 $114 $202 0.035 -0.003 0 $0.00 3.1 62100 191000 23.4

0.18700 0.24104 0.01733 0.31300 $126 $11 $137 0.018 0.014 0 $0.00 3.8 61700 233300 24.4

0.18700 0.24104 0.01733 0.31300 $6 $0 $6 0.001 0.031 0 $0.00 48.8 3400 165900 21.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 176200 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 182100 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 175000 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 176700 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 180100 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 185000 24.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 169700 24.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 180500 24.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 175400 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1500 $0.00 #DIV/0! 0 182300 24.4

0.18700 0.24104 0.01733 0.31300 $40 $0 $40 0.004 0.028 900 $25.54 10.4 19400 202300 24.0

0.18700 0.24104 0.01733 0.31300 $96 $0 $96 0.011 0.021 300 $6.37 4.7 46000 216900 23.6

0.18700 0.24104 0.01733 0.31300 $75 $0 $75 0.007 0.025 0 $0.00 6.2 35700 222200 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 186300 25.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 171900 23.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 174100 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 188000 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 166200 23.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 776500 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 183300 25.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 177600 23.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 186000 25.0

0.18700 0.24104 0.01733 0.31300 $19 $0 $19 0.002 0.030 0 $0.00 17.6 8700 152700 21.3 $0 $0 $0 0.000 -0.003 0 $0.00 #DIV/0! 0 0 0
$126 $114 $202 0.035 0.031 1500 $25.54 #DIV/0! 62100 776500 25.1 $18 $5 $24 0.004 0.007 358 $1.74 #DIV/0! 9629.0 195977.4 22.9 $564 $170 $734 11100 $53.89 298500 6075300 709.6

Attachment 1

February 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Fri 1800 11008 9699 1592 12208 0.09683 939 9.5 1.026 97 939 0 2 Sat 600 10752 9443 3048 10752 0.09683 914 0 1.026 0 914 0 3 Sun 300 11648 10339 2452 11048 0.09683 1001 0 1.026 0 1001 0 4 Mon 2400 10240 8931 1760 12340 0.09683 865 0 1.026 0 865 0 5 Tue 1200 10112 8803 3088 10712 0.09683 852 0 1.026 0 852 0 6 Wed 600 11136 9828 2664 10836 0.09683 952 0 1.026 0 952 0 7 Thu 600 11264 9955 2536 10964 0.09683 964 0 1.026 0 964 0 8 Fri 0 11136 9827 3264 10236 0.09683 952 0 1.026 0 952 0 9 Sat 0 11392 10083 3008 10192 0.09683 976 0 1.026 0 976 0 10 Sun 0 11520 10212 2880 10320 0.09683 989 0 1.026 0 989 0 11 Mon 0 11392 10083 3008 9892 0.09683 976 0 1.026 0 976 0 12 Tue 1200 11520 10212 1680 12120 0.09683 989 0 1.026 0 989 0 13 Wed 1500 10752 9443 2148 11952 0.09683 914 0 1.026 0 914 0 14 Thu 900 10624 9315 2876 11224 0.09683 902 0 1.026 0 902 0 15 Fri 300 11776 10470 2324 11476 0.09683 1014 0 1.026 0 1014 0 16 Sat 300 10880 9571 3220 9980 0.09683 927 0 1.026 0 927 0 17 Sun 600 11364 9955 2436 11364 0.09683 964 0 1.026 0 964 0 18 Mon 300 11264 9955 2836 10964 0.09683 964 0 1.026 0 964 0 19 Tue 1500 10624 9315 2276 11224 0.09683 902 0 1.026 0 902 0 20 Wed 0 11648 10339 2752 10748 0.09683 1001 0 1.026 0 1001 0 21 Thu 0 11008 9699 3392 9808 0.09683 939 0 1.026 0 939 0 22 Fri 300 11520 10211 2580 10320 0.09683 989 0 1.026 0 989 0 23 Sat 0 11136 9827 3264 9636 0.09683 952 0 1.026 0 952 0 24 Sun 5100 9216 7907 84 14316 0.09683 766 20 1.026 205 766 0 25 Mon 5400 8064 6755 936 12864 0.09683 654 0 1.026 0 654 0 26 Tue 300 11392 10083 2708 11392 0.09683 976 0 1.026 0 976 0 27 Wed 4800 10880 9571 -1280 14780 0.09683 927 7700 1.026 79002 927 78075 28 Thu 4800 8448 7139 1152 12948 0.09683 691 0 1.026 0 691 0 MIN 0 8064 6755 -1280 9636 0.09683 654 0 0 654 0
MAX 5400 11776 10470 3392 14780 0.09683 1014 7700 79002 1014 78075 AVG 1242.9 10847 9534.643 2310 11308 0.09683 923 276.1 2832 923 2788 SUM 34800 303716 266970 64684 316616 25851 7729.5 79305 25851 78075 Non-allowed therms 53454

February 2025
D
A
T
E
D
A
Y
1 Fri
2 Sat
3 Sun
4 Mon
5 Tue
6 Wed
7 Thu
8 Fri
9 Sat
10 Sun
11 Mon
12 Tue
13 Wed
14 Thu
15 Fri
16 Sat
17 Sun
18 Mon
19 Tue
20 Wed
21 Thu
22 Fri
23 Sat
24 Sun
25 Mon
26 Tue
27 Wed
28 Thu
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $20 $0 $20 0.002 0.030 600 $18.11 17.8 9500 169263 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 166800 22.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 185700 25.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 182400 24.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 170500 22.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 178700 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 180700 24.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 174500 23.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 178100 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 378000 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1500 $0.00 #DIV/0! 0 178300 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 182100 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 174400 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 177000 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 187000 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 169900 23.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 176900 23.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 177900 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 183500 24.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 183800 24.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 171800 23.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1500 $0.00 #DIV/0! 0 177300 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1500 $0.00 #DIV/0! 0 186300 24.6

0.18700 0.24104 0.01733 0.31300 $42 $0 $42 0.005 0.027 0 $0.00 9.6 20100 193400 22.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 180200 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 174900 23.6

0.18700 0.24104 0.01733 0.31300 $189 $43,257 $43,446 3.993 -3.961 900 $0.00 5.5 7700 42400 17.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 170200 25.3 $0 $0 $0 0.000 -3.961 0 $0.00 #DIV/0! 0 42400 17.5
$189 $43,257 $43,446 3.993 0.030 1500 $18.11 #DIV/0! 20100 378000 25.3 $9 $1,545 $1,554 0.143 -0.139 782 $0.65 #DIV/0! 1332.1 180427.3 23.7 $251 $43,257 $43,508 21900 $18.11 37300 5051963 664.1

March 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Fri 600 10496 9188 3304 10796 0.09683 890 0 1.026 0 890 0 2 Sat 300 10496 9187 3604 9896 0.09683 890 1 1.026 10 890 0 3 Sun 2400 9836 8527 2164 11936 0.09683 826 12 1.026 123 826 0 4 Mon 4200 10368 9059 -168 14568 0.09683 877 0 1.026 0 877 0 5 Tue 2700 7552 6243 4148 10252 0.09683 605 0 1.026 0 605 0 6 Wed 900 9984 8675 3516 10584 0.09683 840 0 1.026 0 840 0 7 Thu 4200 9088 7779 1112 12988 0.09683 753 0 1.026 0 753 0 8 Fri 1200 10240 11549 2960 11140 0.09683 1118 0 1.026 0 1118 0 9 Sat 2700 9798 8524 1902 11898 0.09683 825 13 1.026 133 825 0 10 Sun 300 11520 10153 2580 11220 0.09683 983 0 1.026 0 983 0 11 Mon 0 11648 10293 2752 10448 0.09683 997 0 1.026 0 997 0 12 Tue 300 11008 9661 3092 10408 0.09683 935 0 1.026 0 935 0 13 Wed 300 11136 9776 2964 10536 0.09683 947 0 1.026 0 947 0 14 Thu 0 11392 10034 3008 10492 0.09683 972 0 1.026 0 972 0 15 Fri 0 10880 9551 3520 9680 0.09683 925 0 1.026 0 925 0 16 Sat 300 11264 9960 2836 10664 0.09683 964 0 1.026 0 964 0 17 Sun 600 10880 9600 2920 10580 0.09683 930 0 1.026 0 930 0 18 Mon 600 11564 9915 2236 11564 0.09683 960 0 1.026 0 960 0 19 Tue 300 11008 9651 3092 10708 0.09683 935 0 1.026 0 935 0 20 Wed 600 11392 10046 2408 11392 0.09683 973 0 1.026 0 973 0 21 Thu 300 11264 9911 2836 10964 0.09683 960 0 1.026 0 960 0 22 Fri 600 10752 9417 3048 10452 0.09683 912 2 1.026 21 912 0 23 Sat 0 11392 10037 3008 10492 0.09683 972 0 1.026 0 972 0 24 Sun 600 8500 7141 5300 8500 0.09683 691 0 1.026 0 691 0 25 Mon 300 11648 10280 2452 11348 0.09683 995 0 1.026 0 995 0 26 Tue 1500 10496 9124 2404 11396 0.09683 883 0 1.026 0 883 0 27 Wed 1500 10880 9510 2020 12080 0.09683 921 0 1.026 0 921 0 28 Thu 600 11264 9894 2536 11264 0.09683 958 0 1.026 0 958 0 29 Fri 300 10704 9327 3396 10404 0.09683 903 0 1.026 0 903 0 30 Sat 1200 10697 9440 2503 11297 0.09683 914 3 1.026 31 914 0 31 Sun 900 11500 10197 2000 11800 0.09683 987 5 1.026 51 987 0 MIN 0 7552 6243 -168 8500 0.09683 605 -900 0 605 0
MAX 4200 11648 11549 5300 14568 0.09683 1118 13 133 1118 0 AVG 977.4 10666.03 9408.032 2757 11024 0.09683 911 1.2 12 911 0 SUM 30300 330647 291649 85453 341747 28240 36 369 28240 0 Non-allowed therms 0

Attachment 1

Marc h 2025 2025
D
A
T
E
D
A
Y
1 Fri
2 Sat
3 Sun
4 Mon
5 Tue
6 Wed
7 Thu
8 Fri
9 Sat
10 Sun
11 Mon
12 Tue
13 Wed
14 Thu
15 Fri
16 Sat
17 Sun
18 Mon
19 Tue
20 Wed
21 Thu
22 Fri
23 Sat
24 Sun
25 Mon
26 Tue
27 Wed
28 Thu
29 Fri
30 Sat
31 Sun
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 169200 22.6

0.18700 0.24104 0.01733 0.31300 $2 $0 $2 0.000 0.032 900 $28.62 102.8 1600 164400 23.6

0.18700 0.24104 0.01733 0.31300 $25 $0 $25 0.003 0.029 300 $8.83 13.3 12100 160600 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 439.5 400 175800 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 181100 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 173400 23.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 187600 25.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 167000 22.4

0.18700 0.24104 0.01733 0.31300 $27 $0 $27 0.003 0.029 600 $17.53 13.3 13200 175400 22.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 181600 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 185000 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 176200 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 176800 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 181000 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 171700 23.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 178900 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 171000 23.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 180700 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 175200 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 181400 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 178600 24.0

0.18700 0.24104 0.01733 0.31300 $4 $0 $4 0.000 0.032 900 $28.45 63.0 2800 176400 23.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 179700 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 175400 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 184000 24.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 175300 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 183400 24.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 178100 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 161700 24.0

0.18700 0.24104 0.01733 0.31300 $6 $0 $6 0.001 0.031 600 $18.85 49.1 3400 167100 23.2

0.18700 0.24104 0.01733 0.31300 $10 $0 $10 0.001 0.031 600 $18.65 43.4 4500 195300 24.4 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 160600 22.4
$27 $0 $27 0.003 0.032 1200 $28.62 #DIV/0! 13200 195300 25.2 $2 $0 $2 0.000 0.006 619 $3.90 #DIV/0! 1225.8 176419.4 23.9 $75 $0 $75 19200 $120.93 38000 5469000 740.3

Attachment 1

April 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Mon 300 10880 9494 3220 10280 0.09683 919 0 1.026 0 919 0 2 Tue 300 11008 9535 3092 10408 0.09683 923 0 1.026 0 923 0 3 Wed 1500 11008 9632 1892 11908 0.09683 933 0 1.026 0 933 0 4 Thu 600 11008 9604 2792 11308 0.09683 930 0 1.026 0 930 0 5 Fri 0 11136 9803 3264 9936 0.09683 949 0 1.026 0 949 0 6 Sat 0 11264 9954 3136 10064 0.09683 964 0 1.026 0 964 0 7 Sun 900 11392 10030 2108 11992 0.09683 971 0 1.026 0 971 0 8 Mon 600 11008 9642 2792 11008 0.09683 934 0 1.026 0 934 0 9 Tue 300 10752 9383 3348 10452 0.09683 909 0 1.026 0 909 0 10 Wed 600 11776 10364 2024 12076 0.09683 1004 0 1.026 0 1004 0 11 Thu 900 11264 9880 2236 11864 0.09683 957 0 1.026 0 957 0 12 Fri 300 11264 9891 2836 10664 0.09683 958 0 1.026 0 958 0 13 Sat 0 10880 9529 3520 9980 0.09683 923 0 1.026 0 923 0 14 Sun 600 11136 9777 2664 11436 0.09683 947 0 1.026 0 947 0 15 Mon 1500 11264 9867 1636 12464 0.09683 955 0 1.026 0 955 0 16 Tue 300 11264 9912 2836 11264 0.09683 960 0 1.026 0 960 0 17 Wed 600 11392 10068 2408 11392 0.09683 975 0 1.026 0 975 0 18 Thu 900 10752 9414 2748 11352 0.09683 912 0 1.026 0 912 0 19 Fri 600 12160 10733 1640 12160 0.09683 1039 0 1.026 0 1039 0 20 Sat 0 10368 8959 4032 9468 0.09683 867 0 1.026 0 867 0 21 Sun 900 11264 9904 2236 11864 0.09683 959 0 1.026 0 959 0 22 Mon 300 11904 10535 2196 11904 0.09683 1020 0 1.026 0 1020 0 23 Tue 300 10496 9125 3604 10196 0.09683 884 0 1.026 0 884 0 24 Wed 9000 5760 5011 -360 14760 0.09683 485 44 1.026 451 485 0 25 Thu 900 11136 9795 2364 11736 0.09683 948 0 1.026 0 948 0 26 Fri 300 11776 10389 2324 10876 0.09683 1006 0 1.026 0 1006 0 27 Sat 0 10368 8984 4032 8868 0.09683 870 0 1.026 0 870 0 28 Sun 300 10752 9387 3348 10452 0.09683 909 0 1.026 0 909 0 29 Mon 600 11264 9896 2536 11264 0.09683 958 0 1.026 0 958 0 30 Tue 600 11520 10156 2280 11820 0.09683 983 0 1.026 0 983 0 MIN 0 5760 5011 -360 8868 0.09683 485 0 0 485 0
MAX 9000 12160 10733 4032 14760 0.09683 1039 44 451 1039 0 AVG 800.0 10973.87 9621.767 2626 11174 0.09683 932 1.5 15 932 0 SUM 24000 329216 288653 78784 335216 27950 44 451 27950 0 Non-allowed therms 0

Attachment 1

April 2025 2025
D
A
T
E
D
A
Y
1 Mon
2 Tue
3 Wed
4 Thu
5 Fri
6 Sat
7 Sun
8 Mon
9 Tue
10 Wed
11 Thu
12 Fri
13 Sat
14 Sun
15 Mon
16 Tue
17 Wed
18 Thu
19 Fri
20 Sat
21 Sun
22 Mon
23 Tue
24 Wed
25 Thu
26 Fri
27 Sat
28 Sun
29 Mon
30 Tue
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 171400 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 174700 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 164100 22.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 179500 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 175300 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 177000 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 182500 24.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 175600 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 171300 23.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 186100 25.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 180900 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 177600 23.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 171800 23.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 174900 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 185600 25.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 179400 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 181100 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 171800 23.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 183100 24.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 173300 25.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 177000 21.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 190900 25.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 168900 22.7

0.18700 0.24104 0.01733 0.31300 $92 $0 $92 0.016 0.016 0 $0.00 2.2 44400 99300 17.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 179800 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 181800 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1500 $0.00 #DIV/0! 0 171400 23.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 168600 22.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 184800 24.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 180900 24.3 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 99300 17.7
$92 $0 $92 0.016 0.016 1500 $0.00 #DIV/0! 44400 190900 25.7 $3 $0 $3 0.001 0.001 600 $0.00 #DIV/0! 1480.0 174680.0 23.7 $92 $0 $92 18000 $0.00 44400 5240400 710.8

Attachment 1

May 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Wed 300 10880 9522 3220 10580 0.09683 922 0 1.026 0 922 0 2 Thu 300 11904 10519 2196 11604 0.09683 1019 0 1.026 0 1019 0 3 Fri 900 10752 9257 2748 11652 0.09683 896 0 1.026 0 896 0 4 Sat 0 13824 12400 576 13224 0.09683 1201 0 1.026 0 1201 0 5 Sun 600 8320 6972 5480 8320 0.09683 675 0 1.026 0 675 0 6 Mon 600 10496 9132 3304 10796 0.09683 884 0 1.026 0 884 0 7 Tue 300 11776 10420 2324 11476 0.09683 1009 0 1.026 0 1009 0 8 Wed 300 11520 10157 2580 11220 0.09683 984 0 1.026 0 984 0 9 Thu 1800 10496 9090 2104 11996 0.09683 880 0 1.026 0 880 0 10 Fri 300 11264 9769 2836 10964 0.09683 946 0 1.026 0 946 0 11 Sat 300 11648 10258 2452 11348 0.09683 993 0 1.026 0 993 0 12 Sun 9300 10752 9605 -5652 19752 0.09683 930 10 1.026 103 930 0 13 Mon 23100 0 0 14400 23100 0.09683 0 0 1.026 0 0 0
14 Tue 36300 0 0 14400 36300 0.09683 0 0 1.026 0 0 0
15 Wed 2700 9728 8780 1972 12128 0.09683 850 0 1.026 0 850 0 16 Thu 2700 9984 8754 1716 12384 0.09683 848 8 1.026 82 848 0 17 Fri 300 11008 9614 3092 10408 0.09683 931 0 1.026 0 931 0 18 Sat 0 12544 11130 1856 10144 0.09683 1078 0 1.026 0 1078 0 19 Sun 0 12288 10894 2112 10488 0.09683 1055 0 1.026 0 1055 0 20 Mon 900 10496 9069 3004 10796 0.09683 878 0 1.026 0 878 0 21 Tue 3900 8448 7282 2052 12348 0.09683 705 0 1.026 0 705 0 22 Wed 1800 10496 9163 2104 12296 0.09683 887 1 1.026 10 887 0 23 Thu 10200 4608 3610 -408 14508 0.09683 350 0 1.026 0 350 0 24 Fri 2100 9856 8889 2444 11956 0.09683 861 0 1.026 0 861 0 25 Sat 900 10752 9441 2748 11652 0.09683 914 12 1.026 123 914 0 26 Sun 3300 9600 8352 1500 12600 0.09683 809 15 1.026 154 809 0 27 Mon 700 9600 8295 4100 10000 0.09683 803 17 1.026 174 803 0 28 Tue 300 10496 9100 3604 10496 0.09683 881 0 1.026 0 881 0 29 Wed 0 11008 9621 3392 10408 0.09683 932 0 1.026 0 932 0 30 Thu 1500 11904 10441 996 12504 0.09683 1011 0 1.026 0 1011 0 31 Fri 1200 11008 9557 2192 10408 0.09683 925 0 1.026 0 925 0 MIN 0 0 0 -5652 8320 0.09683 0 0 0 0 0
MAX 36300 13824 12400 14400 36300 0.09683 1201 17 174 1201 0 AVG 3448.4 9917.935 8680.419 2950 12834 0.09683 841 2.0 21 841 0 SUM 106900 307456 269093 91444 397856 26056 63 646 26056 0 Non-allowed therms 0

Attachment 1

May 2025 2025
D
A
T
E
D
A
Y
1 Wed
2 Thu
3 Fri
4 Sat
5 Sun
6 Mon
7 Tue
8 Wed
9 Thu
10 Fri
11 Sat
12 Sun
13 Mon
14 Tue
15 Wed
16 Thu
17 Fri
18 Sat
19 Sun
20 Mon
21 Tue
22 Wed
23 Thu
24 Fri
25 Sat
26 Sun
27 Mon
28 Tue
29 Wed
30 Thu
31 Fri
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 175000 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 188800 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 163400 23.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 196500 26.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 164400 22.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 181400 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 176000 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 182100 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 181700 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 177200 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 179900 24.2

0.18700 0.24104 0.01733 0.31300 $21 $0 $21 0.002 0.030 300 $9.02 8.6 10300 88600 11.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 4000 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 166300 23.6

0.18700 0.24104 0.01733 0.31300 $17 $0 $17 0.002 0.030 300 $9.10 22.6 8000 181100 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 167500 22.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 2400 $0.00 #DIV/0! 0 186300 25.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1800 $0.00 #DIV/0! 0 170500 22.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 183200 24.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 179.5 800 143600 22.2

0.18700 0.24104 0.01733 0.31300 $2 $0 $2 0.000 0.032 0 $0.00 #DIV/0! 0 181900 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 53500 21.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 165400 23.6

0.18700 0.24104 0.01733 0.31300 $25 $0 $25 0.002 0.030 0 $0.00 13.1 15200 199700 24.1

0.18700 0.24104 0.01733 0.31300 $31 $0 $31 0.003 0.029 300 $8.62 11.5 16500 189700 25.3

0.18700 0.24104 0.01733 0.31300 $36 $0 $36 0.004 0.028 300 $8.49 #DIV/0! 0 168200 22.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 175900 23.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 185600 25.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 18600 25.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1800 $0.00 #DIV/0! 0 164600 22.1 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 0 0
$36 $0 $36 0.004 0.032 2400 $9.10 #DIV/0! 16500 199700 26.4 $4 $0 $4 0.000 0.006 532 $1.14 #DIV/0! 1638.7 153567.7 21.9 $132 $0 $132 16500 $35.21 50800 4760600 678.67

Attachment 1

June 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Sat 900 11648 10265 1852 10148 0.09683 994 4 1.026 41 994 0 2 Sun 300 11648 10282 2452 11048 0.09683 996 2 1.026 21 996 0 3 Mon 1800 12160 10754 440 13660 0.09683 1041 0 1.026 0 1041 0 4 Tue 4200 7168 6146 3032 10468 0.09683 595 7 1.026 72 595 0 5 Wed 1200 11136 9692 2064 11736 0.09683 938 0 1.026 0 938 0 6 Thu 900 10880 9382 2620 11480 0.09683 908 0 1.026 0 908 0 7 Fri 1500 11008 9568 1892 12208 0.09683 926 0 1.026 0 926 0 8 Sat 1500 10880 9504 2020 12080 0.09683 920 2 1.026 21 920 0 9 Sun 30000 10112 8778 -25712 40112 0.09683 850 16 1.026 164 850 0 10 Mon 4200 9984 8604 216 13884 0.09683 833 0 1.026 0 833 0 11 Tue 1500 11008 9598 1892 12208 0.09683 929 0 1.026 0 929 0 12 Wed 5100 7680 6481 1620 12780 0.09683 628 35 1.026 359 628 0 13 Thu 1500 8265 7041 4635 8565 0.09683 682 3 1.026 31 682 0 14 Fri 0 2304 803 12096 504 0.09683 78 0 1.026 0 78 0
15 Sat 2400 6528 5123 5472 7428 0.09683 496 3 1.026 31 496 0 16 Sun 3300 9344 8163 1756 12344 0.09683 790 12 1.026 123 790 0 17 Mon 2400 11008 9704 992 13408 0.09683 940 12 1.026 123 940 0 18 Tue 1500 10368 9004 2532 11568 0.09683 872 0 1.026 0 872 0 19 Wed 4800 7552 6508 2048 12352 0.09683 630 0 1.026 0 630 0 20 Thu 3000 12800 11351 -1400 15500 0.09683 1099 0 1.026 0 1099 0 21 Fri 300 10240 8769 3860 9940 0.09683 849 0 1.026 0 849 0 22 Sat 600 11264 9882 2536 10964 0.09683 957 7 1.026 72 957 0 23 Sun 2400 10240 8956 1760 12340 0.09683 867 32 1.026 328 867 0 24 Mon 3300 10112 8883 988 13112 0.09683 860 14 1.026 144 860 0 25 Tue 13200 2048 1256 -848 15248 0.09683 122 0 1.026 0 122 0 26 Wed 10200 5120 4325 -920 15320 0.09683 419 0 1.026 0 419 0 27 Thu 2400 10624 9670 1376 12724 0.09683 936 0 1.026 0 936 0 28 Fri 300 11008 9624 3092 10408 0.09683 932 0 1.026 0 932 0 29 Sat 12900 2560 1824 -1060 15460 0.09683 177 0 1.026 0 177 0 30 Sun 6600 7424 6704 376 13724 0.09683 649 0 1.026 0 649 0 14400 0 0.09683 0 1.026 0 0 0
MIN 0 2048 803 -25712 0 0.09683 0 0 0 0 0
MAX 30000 12800 11351 14400 40112 0.09683 1099 35 359 1099 0 AVG 4140.0 9137.3667 7888.133 1551 12346 0.09683 739 5.0 49 739 0 SUM 124200 274121 236644 48079 382721 22914 149 1529 22914 0 Non-allowed therms 0

Attachment 1

June 2025 2025
D
A
T
E
D
A
Y
1 Sat
2 Sun
3 Mon
4 Tue
5 Wed
6 Thu
7 Fri
8 Sat
9 Sun
10 Mon
11 Tue
12 Wed
13 Thu
14 Fri
15 Sat
16 Sun
17 Mon
18 Tue
19 Wed
20 Thu
21 Fri
22 Sat
23 Sun
24 Mon
25 Tue
26 Wed
27 Thu
28 Fri
29 Sat
30 Sun
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $8 $0 $8 0.001 0.031 2400 $75.07 45.1 4000 180400 23.7

0.18700 0.24104 0.01733 0.31300 $4 $0 $4 0.000 0.032 900 $28.48 96.0 1900 182400 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 104700 24.3

0.18700 0.24104 0.01733 0.31300 $15 $0 $15 0.002 0.030 900 $26.96 32.9 6600 216900 23.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 178800 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 171300 23.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 177800 23.9

0.18700 0.24104 0.01733 0.31300 $4 $0 $4 0.000 0.032 300 $9.48 105.8 1800 190400 24.7

0.18700 0.24104 0.01733 0.31300 $34 $0 $34 0.003 0.029 0 $0.00 12.3 15700 193800 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 603.0 300 180900 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 179600 24.2

0.18700 0.24104 0.01733 0.31300 $73 $0 $73 0.010 0.022 0 $0.00 #DIV/0! 0 34500 23.7

0.18700 0.24104 0.01733 0.31300 $6 $0 $6 0.001 0.031 1200 $37.49 50.3 3100 156000 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1800 $0.00 #DIV/0! 0 165200 22.2

0.18700 0.24104 0.01733 0.31300 $6 $0 $6 0.001 0.031 1500 $46.55 57.3 2700 154600 21.2

0.18700 0.24104 0.01733 0.31300 $25 $0 $25 0.003 0.029 300 $8.79 63.5 12400 787900 25.4

0.18700 0.24104 0.01733 0.31300 $25 $0 $25 0.002 0.030 0 $0.00 17.7 11900 210600 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 160100 21.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 130900 17.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 194100 26.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 155200 20.9

0.18700 0.24104 0.01733 0.31300 $15 $0 $15 0.001 0.031 900 $27.63 29.3 6500 190400 24.1

0.18700 0.24104 0.01733 0.31300 $67 $0 $67 0.007 0.025 300 $7.63 7.4 31800 234000 24.4

0.18700 0.24104 0.01733 0.31300 $29 $0 $29 0.003 0.029 300 $8.73 13.5 14100 190200 28.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 15200 19.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 97500 22.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 167300 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 170900 23.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 4500 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 118300 17.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 4500 0
$73 $0 $73 0.010 0.032 2400 $75.07 #DIV/0! 31800 787900 28 $10 $0 $10 0.001 0.012 503 $8.93 #DIV/0! 3760.0 176480.0 22.4 $312 $0 $312 15600 $276.82 112800 5294400 672.8

Attachment 1

July 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Mon 111000 6985 6150 -103585 117985 0.09683 596 0 1.026 0 596 0 2 Tue 13200 2816 2409 -1616 16016 0.09683 233 0 1.026 0 233 0 3 Wed 13500 2304 1952 -1404 15804 0.09683 189 0 1.026 0 189 0 4 Thu 2432 2432 2086 9536 4864 0.09683 202 0 1.026 0 202 0 5 Fri 13200 2432 2082 -1232 15632 0.09683 202 0 1.026 0 202 0 6 Sat 12900 2176 1803 -676 15076 0.09683 175 0 1.026 0 175 0 7 Sun 6600 7296 6681 504 13596 0.09683 647 29 1.026 298 647 0 8 Mon 8400 6144 4969 -144 14544 0.09683 481 12 1.026 123 481 0 9 Tue 5700 8320 7426 380 14020 0.09683 719 6 1.026 62 719 0 10 Wed 3300 9984 8615 1116 13284 0.09683 834 0 1.026 0 834 0 11 Thu 3000 9856 8418 1544 12856 0.09683 815 0 1.026 0 815 0 12 Fri 2700 9472 8142 2228 12172 0.09683 788 0 1.026 0 788 0 13 Sat 2700 9728 8452 1972 12428 0.09683 818 6 1.026 62 818 0 14 Sun 4500 8832 7607 1068 13332 0.09683 737 16 1.026 164 737 0 15 Mon 4200 9984 8779 216 14184 0.09683 850 0 1.026 0 850 0 16 Tue 5700 8832 7619 -132 14532 0.09683 738 4 1.026 41 738 0 17 Wed 9984 9984 8664 -5568 19968 0.09683 839 0 1.026 0 839 0 18 Thu 6000 8960 7663 -560 14960 0.09683 742 18 1.026 185 742 0 19 Fri 5400 9088 7881 -88 14488 0.09683 763 0 1.026 0 763 0 20 Sat 6900 7808 6651 -308 14708 0.09683 644 45 1.026 462 644 0 21 Sun 8700 6912 5739 -1212 15612 0.09683 556 35 1.026 359 556 0 22 Mon 9900 6528 5339 -2028 16428 0.09683 517 55 1.026 564 517 47 23 Tue 8400 6784 7870 -784 15184 0.09683 762 17 1.026 174 762 0 24 Wed 5400 9856 8567 -856 15256 0.09683 830 0 1.026 0 830 0 25 Thu 8400 8009 6728 -2009 16409 0.09683 651 0 1.026 0 651 0 26 Fri 6900 9088 8100 -1588 15988 0.09683 784 7 1.026 72 784 0 27 Sat 5400 9007 7627 -7 14407 0.09683 739 0 1.026 0 739 0 28 Sun 5400 9324 8077 -324 14724 0.09683 782 0 1.026 0 782 0 29 Mon 4800 9984 8732 -384 14784 0.09683 846 0 1.026 0 846 0 30 Tue 3300 9472 8212 1628 12472 0.09683 795 0 1.026 0 795 0 31 Wed 3600 9856 8604 944 13456 0.09683 833 0 1.026 0 833 0 MIN 2432 2176 1803 -103585 4864 0.09683 175 0 0 175 0
MAX 111000 9984 8779 9536 117985 0.09683 850 55 564 850 47 AVG 10048.9 7685.581 6698.194 -3334 17715 0.09683 649 8.1 83 649 2 SUM 311516 238253 207644 -103369 549169 20106 250 2565 20106 47 Non-allowed therms 0

Attachment 1

July 2025 2025
D
A
T
E
D
A
Y
1 Mon
2 Tue
3 Wed
4 Thu
5 Fri
6 Sat
7 Sun
8 Mon
9 Tue
10 Wed
11 Thu
12 Fri
13 Sat
14 Sun
15 Mon
16 Tue
17 Wed
18 Thu
19 Fri
20 Sat
21 Sun
22 Mon
23 Tue
24 Wed
25 Thu
26 Fri
27 Sat
28 Sun
29 Mon
30 Tue
31 Wed
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 44400 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 198000 4.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 2000 2.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $61 $0 $61 0.008 0.024 300 $7.10 54.8 28600 1566000 16.2

0.18700 0.24104 0.01733 0.31300 $25 $0 $25 0.004 0.028 0 $0.00 9.3 12300 114500 24.4

0.18700 0.24104 0.01733 0.31300 $13 $0 $13 0.002 0.030 0 $0.00 28.9 5600 161900 20.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 181000 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 180700 24.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 168500 22.7

0.18700 0.24104 0.01733 0.31300 $13 $0 $13 0.001 0.031 0 $0.00 3.3 5700 18600 24.1

0.18700 0.24104 0.01733 0.31300 $34 $0 $34 0.004 0.028 0 $0.00 12.2 16000 195300 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 177400 24.3

0.18700 0.24104 0.01733 0.31300 $8 $0 $8 0.001 0.031 0 $0.00 38.9 4400 171000 22.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 185100 26.0

0.18700 0.24104 0.01733 0.31300 $38 $0 $38 0.004 0.028 0 $0.00 10.8 18000 193600 23.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 200800 24.8

0.18700 0.24104 0.01733 0.31300 $94 $0 $94 0.012 0.020 0 $0.00 4.7 45100 210700 23.7

0.18700 0.24104 0.01733 0.31300 $73 $0 $73 0.011 0.021 0 $0.00 5.4 35400 190400 22.8

0.18700 0.24104 0.01733 0.31300 $106 $26 $132 0.020 0.012 0 $0.00 4.1 55400 224600 25.4

0.18700 0.24104 0.01733 0.31300 $36 $0 $36 0.005 0.027 0 $0.00 8.8 17300 151400 19.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 178800 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 113800 23.6

0.18700 0.24104 0.01733 0.31300 $15 $0 $15 0.002 0.030 0 $0.00 27.3 6800 185300 23.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 176400 24.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 184900 24.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 170700 23.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 178000 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 177900 23.4 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 0 0
$106 $26 $132 0.020 0.031 300 $7.10 #DIV/0! 55400 1566000 26 $17 $1 $17 0.002 0.010 19 $0.23 #DIV/0! 8083.9 190377.4 19.8 $514 $26 $541 600 $7.10 250600 5901700 615.3

Attachment 1

August 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Thur 3300 9344 8068 1756 12644 0.09683 781 0 1.026 0 781 0 2 Wed 3300 9472 8238 1628 12772 0.09683 798 0 1.026 0 798 0 3 Thu 3300 10752 9529 348 14052 0.09683 923 0 1.026 0 923 0 4 Fri 3900 5248 4094 5252 9148 0.09683 396 23 1.026 236 396 0 5 Sat 6900 7296 6217 204 14196 0.09683 602 30 1.026 308 602 0 6 Sun 5400 9088 7883 -88 14488 0.09683 763 18 1.026 185 763 0 7 Mon 2400 8557 7348 3443 10957 0.09683 712 0 1.026 0 712 0 8 Tue 4200 8704 7672 1496 12904 0.09683 743 12 1.026 123 743 0 9 Wed 2400 9856 8598 2144 12256 0.09683 833 0 1.026 0 833 0 10 Thu 7200 9344 8121 -2144 16544 0.09683 786 18 1.026 185 786 0 11 Fri 900 9600 8461 3900 10500 0.09683 819 3 1.026 31 819 0 12 Sat 4500 8923 7754 977 13423 0.09683 751 0 1.026 0 751 0 13 Sun 3300 8832 7624 2268 12132 0.09683 738 0 1.026 0 738 0 14 Mon 3900 9600 8376 900 13500 0.09683 811 4 1.026 41 811 0 15 Tue 10200 6528 5402 -2328 16728 0.09683 523 31 1.026 318 523 0 16 Wed 7500 6400 5244 500 13900 0.09683 508 37 1.026 380 508 0 17 Thu 7800 5632 4489 968 13432 0.09683 435 29 1.026 298 435 0 18 Fri 13200 0 0 14400 13200 0.09683 0 0 1.026 0 0 0
19 Sat 13200 0 0 14400 13200 0.09683 0 0 1.026 0 0 0
20 Sun 12900 0 0 14400 12900 0.09683 0 0 1.026 0 0 0
21 Mon 14400 0 0 14400 14400 0.09683 0 0 1.026 0 0 0
22 Tue 15900 0 0 14400 15900 0.09683 0 0 1.026 0 0 0
23 Wed 11700 0 0 14400 11700 0.09683 0 0 1.026 0 0 0
24 Thu 12600 0 0 14400 12600 0.09683 0 0 1.026 0 0 0
25 Fri 8100 5760 5127 540 13860 0.09683 496 13 1.026 133 496 0 26 Sat 6300 7168 6002 932 13468 0.09683 581 14 1.026 144 581 0 27 Sun 7200 7040 5862 160 14240 0.09683 568 38 1.026 390 568 0 28 Mon 6300 7296 6103 804 13596 0.09683 591 33 1.026 339 591 0 29 Tue 8100 6912 5820 -612 15012 0.09683 564 39 1.026 400 564 0 30 Wed 6000 8448 7381 -48 14448 0.09683 715 36 1.026 369 715 0 31 Thu 8100 5120 4042 1180 13220 0.09683 391 35 1.026 359 391 0 MIN 900 0 0 -2328 9148 0.09683 0 0 0 0 0
MAX 15900 10752 9529 14400 16728 0.09683 923 39 400 923 0 AVG 7238.7 6158.71 5272.742 4032 13397 0.09683 511 13.3 137 511 0 SUM 224400 190920 163455 124980 415320 15827 413 4237 15827 0 Non-allowed therms 0

Attachment 1

August 2025 st 2025
D
A
T
E
D
A
Y
1 Thur
2 Wed
3 Thu
4 Fri
5 Sat
6 Sun
7 Mon
8 Tue
9 Wed
10 Thu
11 Fri
12 Sat
13 Sun
14 Mon
15 Tue
16 Wed
17 Thu
18 Fri
19 Sat
20 Sun
21 Mon
22 Tue
23 Wed
24 Thu
25 Fri
26 Sat
27 Sun
28 Mon
29 Tue
30 Wed
31 Thu
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 171000 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 175500 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 185200 24.9

0.18700 0.24104 0.01733 0.31300 $48 $0 $48 0.009 0.023 0 $0.00 8.4 22800 191300 24.1

0.18700 0.24104 0.01733 0.31300 $63 $0 $63 0.009 0.023 0 $0.00 6.1 30300 186300 23.4

0.18700 0.24104 0.01733 0.31300 $38 $0 $38 0.004 0.028 0 $0.00 10.4 18400 190800 23.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 185300 18.7

0.18700 0.24104 0.01733 0.31300 $25 $0 $25 0.003 0.029 0 $0.00 9.9 11600 114600 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 174900 23.0

0.18700 0.24104 0.01733 0.31300 $38 $0 $38 0.004 0.028 0 $0.00 11.0 18000 197500 24.8

0.18700 0.24104 0.01733 0.31300 $6 $0 $6 0.001 0.031 0 $0.00 45.2 3300 149300 23.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 162000 23.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 171400 23.3

0.18700 0.24104 0.01733 0.31300 $8 $0 $8 0.001 0.031 0 $0.00 44.0 3900 171700 24.0

0.18700 0.24104 0.01733 0.31300 $65 $0 $65 0.010 0.022 0 $0.00 3.6 30900 111800 24.4

0.18700 0.24104 0.01733 0.31300 $78 $0 $78 0.012 0.020 0 $0.00 3.8 37300 141300 25.2

0.18700 0.24104 0.01733 0.31300 $61 $0 $61 0.011 0.021 0 $0.00 3.6 29300 105800 20.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $27 $0 $27 0.005 0.027 0 $0.00 10.9 13200 144000 17.3

0.18700 0.24104 0.01733 0.31300 $29 $0 $29 0.004 0.028 0 $0.00 9.7 13500 130300 23.4

0.18700 0.24104 0.01733 0.31300 $80 $0 $80 0.011 0.021 0 $0.00 3.1 38100 116400 25.2

0.18700 0.24104 0.01733 0.31300 $69 $0 $69 0.009 0.023 0 $0.00 3.7 32500 121800 23.2

0.18700 0.24104 0.01733 0.31300 $82 $0 $82 0.012 0.020 0 $0.00 3.1 38800 119500 25.0

0.18700 0.24104 0.01733 0.31300 $75 $0 $75 0.009 0.023 0 $0.00 5.9 35600 211400 23.8

0.18700 0.24104 0.01733 0.31300 $73 $0 $73 0.014 0.018 0 $0.00 3.1 35000 108200 23.2 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 0 0
$82 $0 $82 0.014 0.031 0 $0.00 #DIV/0! 38800 211400 25.2 $28 $0 $28 0.004 0.013 0 $0.00 #DIV/0! 13306.5 120558.1 18.0 $866 $0 $866 0 $0.00 412500 3737300 557.9

Attachment 1

September 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Sun 7500 6784 5755 116 14284 0.09683 557 69 1.026 708 557 151 2 Mon 8100 6144 5049 156 14244 0.09683 489 56 1.026 575 489 86 3 Tue 6600 7296 6180 504 13896 0.09683 598 49 1.026 503 598 0 4 Wed 7500 6400 5285 500 13900 0.09683 512 25 1.026 257 512 0 5 Thu 7200 7168 5942 32 14368 0.09683 575 42 1.026 431 575 0 6 Fri 7200 6784 5573 416 13984 0.09683 540 37 1.026 380 540 0 7 Sat 9300 5376 4268 -276 14676 0.09683 413 35 1.026 359 413 0 8 Sun 8700 6016 4984 -316 14716 0.09683 483 57 1.026 585 483 102 9 Mon 12300 3328 2485 -1228 15628 0.09683 241 10 1.026 103 241 0 10 Tue 9000 4736 4092 664 13736 0.09683 396 19 1.026 195 396 0 11 Wed 10200 4992 4013 -792 15192 0.09683 389 24 1.026 246 389 0 12 Thu 10200 4992 3964 -792 15192 0.09683 384 48 1.026 492 384 109 13 Fri 105000 4096 3126 -94696 109096 0.09683 303 47 1.026 482 303 180 14 Sat 9600 4992 3991 -192 14592 0.09683 386 51 1.026 523 386 137 15 Sun 9600 4736 3736 64 14336 0.09683 362 40 1.026 410 362 49 16 Mon 7800 6400 5279 200 14200 0.09683 511 45 1.026 462 511 0 17 Tue 8700 5888 4781 -188 14588 0.09683 463 43 1.026 441 463 0 18 Wed 9300 5632 4646 -532 14932 0.09683 450 40 1.026 410 450 0 19 Thu 9000 5760 4694 -360 14760 0.09683 455 29 1.026 298 455 0 20 Fri 9000 4992 3915 408 13992 0.09683 379 98 1.026 1005 379 626 21 Sat 5400 6528 5439 2472 11928 0.09683 527 53 1.026 544 527 17 22 Sun 7800 5760 4738 840 13560 0.09683 459 37 1.026 380 459 0 23 Mon 3600 7552 6345 3248 11152 0.09683 614 17 1.026 174 614 0 24 Tue 4800 7936 6702 1664 12736 0.09683 649 29 1.026 298 649 0 25 Wed 4200 8960 7652 1240 13160 0.09683 741 6 1.026 62 741 0 26 Thu 4500 9344 8073 556 13844 0.09683 782 27 1.026 277 782 0 27 Fri 7500 8064 6887 -1164 15564 0.09683 667 34 1.026 349 667 0 28 Sat 11100 4992 3911 -1692 16092 0.09683 379 36 1.026 369 379 0 29 Sun 11100 4736 3841 -1436 15836 0.09683 372 16 1.026 164 372 0 30 Mon 10200 6144 4977 -1944 16344 0.09683 482 29 1.026 298 482 0 14400 0 0.09683 0 1.026 0 0 0
MIN 3600 3328 2485 -94696 0 0.09683 0 6 0 0 0
MAX 105000 9344 8073 14400 109096 0.09683 782 98 1005 782 626 AVG 11400.0 6084.267 5010.767 -2520 16920 0.09683 470 38.3 380 470 47 SUM 342000 182528 150323 -78128 524528 14556 1148 11778 14556 1456 Non-allowed therms 0

Attachment 1

September 2025 mber 2025
D
A
T
E
D
A
Y
1 Sun
2 Mon
3 Tue
4 Wed
5 Thu
6 Fri
7 Sat
8 Sun
9 Mon
10 Tue
11 Wed
12 Thu
13 Fri
14 Sat
15 Sun
16 Mon
17 Tue
18 Wed
19 Thu
20 Fri
21 Sat
22 Sun
23 Mon
24 Tue
25 Wed
26 Thu
27 Fri
28 Sat
29 Sun
30 Mon
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $114 $83 $197 0.029 0.003 0 $0.00 2.9 69400 200700 24.1

0.18700 0.24104 0.01733 0.31300 $100 $47 $147 0.024 0.008 0 $0.00 4.1 55800 226700 24.0

0.18700 0.24104 0.01733 0.31300 $103 $0 $103 0.014 0.018 0 $0.00 4.9 49200 241300 24.5

0.18700 0.24104 0.01733 0.31300 $52 $0 $52 0.008 0.024 0 $0.00 5.5 25000 138000 23.0

0.18700 0.24104 0.01733 0.31300 $88 $0 $88 0.012 0.020 0 $0.00 3.7 42000 155000 24.5

0.18700 0.24104 0.01733 0.31300 $78 $0 $78 0.011 0.021 0 $0.00 4.1 36900 149900 25.1

0.18700 0.24104 0.01733 0.31300 $73 $0 $73 0.014 0.018 0 $0.00 2.8 34900 99000 22.7

0.18700 0.24104 0.01733 0.31300 $99 $57 $155 0.026 0.006 0 $0.00 3.7 57000 212300 21.8

0.18700 0.24104 0.01733 0.31300 $21 $0 $21 0.006 0.026 0 $0.00 4.9 9700 47100 7.8

0.18700 0.24104 0.01733 0.31300 $40 $0 $40 0.008 0.024 0 $0.00 4.2 19400 81600 19.1

0.18700 0.24104 0.01733 0.31300 $50 $0 $50 0.010 0.022 0 $0.00 6.3 23900 149600 24.8

0.18700 0.24104 0.01733 0.31300 $78 $60 $139 0.028 0.004 0 $0.00 4.3 48200 207700 23.7

0.18700 0.24104 0.01733 0.31300 $62 $99 $161 0.039 -0.007 0 $0.00 4.1 46900 190400 23.3

0.18700 0.24104 0.01733 0.31300 $79 $76 $155 0.031 0.001 0 $0.00 4.0 51300 207700 24.3

0.18700 0.24104 0.01733 0.31300 $74 $27 $101 0.021 0.011 0 $0.00 4.1 39500 161500 23.3

0.18700 0.24104 0.01733 0.31300 $94 $0 $94 0.015 0.017 0 $0.00 4.1 44900 182600 24.9

0.18700 0.24104 0.01733 0.31300 $90 $0 $90 0.015 0.017 0 $0.00 3.5 43300 152000 24.4

0.18700 0.24104 0.01733 0.31300 $84 $0 $84 0.015 0.017 0 $0.00 4.6 39500 181300 26.1

0.18700 0.24104 0.01733 0.31300 $61 $0 $61 0.011 0.021 0 $0.00 4.8 29300 141500 21.8

0.18700 0.24104 0.01733 0.31300 $77 $347 $425 0.085 -0.053 0 $0.00 1.7 98200 169100 22.7

0.18700 0.24104 0.01733 0.31300 $108 $9 $117 0.018 0.014 0 $0.00 3.6 52600 191600 24.4

0.18700 0.24104 0.01733 0.31300 $78 $0 $78 0.013 0.019 0 $0.00 4.7 37200 173700 19.8

0.18700 0.24104 0.01733 0.31300 $36 $0 $36 0.005 0.027 0 $0.00 11.9 17100 203800 24.2

0.18700 0.24104 0.01733 0.31300 $61 $0 $61 0.008 0.024 0 $0.00 24.7 29100 718100 24.0

0.18700 0.24104 0.01733 0.31300 $13 $0 $13 0.001 0.031 0 $0.00 31.9 5600 178900 23.6

0.18700 0.24104 0.01733 0.31300 $57 $0 $57 0.006 0.026 0 $0.00 8.2 26900 219700 24.2

0.18700 0.24104 0.01733 0.31300 $71 $0 $71 0.009 0.023 0 $0.00 6.0 33600 200700 25.5

0.18700 0.24104 0.01733 0.31300 $75 $0 $75 0.015 0.017 0 $0.00 4.0 36000 144800 22.0

0.18700 0.24104 0.01733 0.31300 $34 $0 $34 0.007 0.025 0 $0.00 5.9 16400 96600 18.9

0.18700 0.24104 0.01733 0.31300 $61 $0 $61 0.010 0.022 0 $0.00 6.2 28700 177400 24.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 $0 $0 $0 0.000 -0.053 0 $0.00 1.7 5600 47100 7.8
$114 $347 $425 0.085 0.031 0 $0.00 31.9 98200 718100 26.1 $68 $26 $94 0.017 0.014 0 $0.00 6.3 38250.0 186676.7 22.9 $2,109 $807 $2,916 0 $0.00 1147500 5600300 687.1

Attachment 1

Octobert 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 T 9300 6272 5098 -1172 15572 0.09683 494 12 1.026 123 494 0 2 Wed 9000 6400 5189 -1000 15400 0.09683 502 6 1.026 62 502 0 3 Thu 4500 7680 6543 2220 12180 0.09683 634 7 1.026 72 634 0 4 Fri 3900 9344 8084 1156 12944 0.09683 783 1 1.026 10 783 0 5 Sat 5100 7296 6120 2004 12396 0.09683 593 37 1.026 380 593 0 6 Sun 3000 9472 8256 1928 12472 0.09683 799 25 1.026 257 799 0 7 Mon 2100 9728 8446 2572 11828 0.09683 818 0 1.026 0 818 0 8 Tue 2400 9472 8146 2528 11872 0.09683 789 0 1.026 0 789 0 9 Wed 3000 18560 17269 -7160 21560 0.09683 1672 0 1.026 0 1672 0 10 Thu 2100 5929 4640 6371 7729 0.09683 449 0 1.026 0 449 0 11 Fri 2400 9600 8328 2400 12000 0.09683 806 2 1.026 21 806 0 12 Sat 2400 9088 7906 2912 11488 0.09683 766 48 1.026 492 766 0 13 Sun 4800 9127 8174 473 13927 0.09683 791 8 1.026 82 791 0 14 Mon 1800 9836 8679 2764 11636 0.09683 840 20 1.026 205 840 0 15 Tue 2400 9600 8314 2400 11700 0.09683 805 0 1.026 0 805 0 16 Wed 1800 10496 9210 2104 12296 0.09683 892 0 1.026 0 892 0 17 Thu 1800 9344 8053 3256 11144 0.09683 780 0 1.026 0 780 0 18 Fri 2400 10112 8840 1888 12512 0.09683 856 0 1.026 0 856 0 19 Sat 1200 10496 9233 2704 11396 0.09683 894 0 1.026 0 894 0 20 Sun 2100 9600 8359 2700 11700 0.09683 809 0 1.026 0 809 0 21 Mon 6000 7040 5748 1360 13040 0.09683 557 0 1.026 0 557 0 22 Tue 11400 0 0 14400 11400 0.09683 0 0 1.026 0 0 0
23 Wed 9300 4864 4512 236 14164 0.09683 437 40 1.026 410 437 0 24 Thu 5100 7936 7035 1364 13036 0.09683 681 0 1.026 0 681 0 25 Fri 2400 10112 9360 1888 12512 0.09683 906 0 1.026 0 906 0 26 Sat 3600 8829 7626 1971 12429 0.09683 738 0 1.026 0 738 0 27 Sun 3300 9836 8604 1264 13136 0.09683 833 0 1.026 0 833 0 28 Mon 2700 9728 8546 1972 12428 0.09683 828 4 1.026 41 828 0 29 Tue 2100 10624 9389 1676 12724 0.09683 909 0 1.026 0 909 0 30 Wed 2100 8704 7457 3596 10804 0.09683 722 0 1.026 0 722 0 31 Thu 1800 9856 8642 2744 11656 0.09683 837 0 1.026 0 837 0 MIN 1200 0 0 -7160 7729 0.09683 0 0 0 0 0
MAX 11400 18560 17269 14400 21560 0.09683 1672 48 492 1672 0 AVG 3783.9 8870.355 7735.677 2114 12616 0.09683 749 6.8 70 749 0 SUM 117300 274981 239806 65519 391081 23220 210 2155 23220 0 Non-allowed therms 0

Attachment 1

October 2025 ert 2025
D
A
T
E
D
A
Y
1 T
2 Wed
3 Thu
4 Fri
5 Sat
6 Sun
7 Mon
8 Tue
9 Wed
10 Thu
11 Fri
12 Sat
13 Sun
14 Mon
15 Tue
16 Wed
17 Thu
18 Fri
19 Sat
20 Sun
21 Mon
22 Tue
23 Wed
24 Thu
25 Fri
26 Sat
27 Sun
28 Mon
29 Tue
30 Wed
31 Thu
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $25 $0 $25 0.004 0.028 0 $0.00 14.6 12200 178200 24.2

0.18700 0.24104 0.01733 0.31300 $13 $0 $13 0.002 0.030 0 $0.00 25.9 6300 163400 22.2

0.18700 0.24104 0.01733 0.31300 $15 $0 $15 0.002 0.030 0 $0.00 24.2 6900 167000 23.8

0.18700 0.24104 0.01733 0.31300 $2 $0 $2 0.000 0.032 300 $9.53 152.6 1200 183100 24.0

0.18700 0.24104 0.01733 0.31300 $78 $0 $78 0.011 0.021 0 $0.00 5.7 36500 209000 23.8

0.18700 0.24104 0.01733 0.31300 $52 $0 $52 0.006 0.026 0 $0.00 8.6 24500 211700 24.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 188900 25.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 169500 22.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 169500 22.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 176000 23.7

0.18700 0.24104 0.01733 0.31300 $4 $0 $4 0.000 0.032 0 $0.00 81.1 2300 186600 24.6

0.18700 0.24104 0.01733 0.31300 $101 $0 $101 0.011 0.021 0 $0.00 5.0 47800 237000 23.0

0.18700 0.24104 0.01733 0.31300 $17 $0 $17 0.002 0.030 0 $0.00 17.7 8000 141500 25.0

0.18700 0.24104 0.01733 0.31300 $42 $0 $42 0.004 0.028 0 $0.00 10.2 19700 200100 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 19600 23.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 187400 25.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 172000 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 180300 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 186400 25.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 169100 23.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 119200 23.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $84 $0 $84 0.017 0.015 0 $0.00 1.6 39800 65400 20.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 133200 22.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 181900 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 155300 23.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 177200 23.8

0.18700 0.24104 0.01733 0.31300 $8 $0 $8 0.001 0.031 0 $0.00 51.9 3500 181500 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 188300 25.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 163800 22.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 179600 24.1 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 0 0
$101 $0 $101 0.017 0.032 300 $9.53 #DIV/0! 47800 237000 25.4 $14 $0 $14 0.002 0.010 39 $0.31 #DIV/0! 6732.3 162635.5 22.9 $440 $0 $440 1200 $9.53 208700 5041700 711.4

Attachment 1

November 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Tue 1800 10496 9269 2104 12296 0.09683 898 0 1.026 0 898 0 2 Wed 1300 9472 8272 3628 10472 0.09683 801 1 1.026 10 801 0 3 Thu 3000 14848 13645 -3448 17848 0.09683 1321 12 1.026 123 1321 0 4 Fri 1800 5120 3873 7480 6920 0.09683 375 0 1.026 0 375 0 5 Sat 1800 8832 7594 3768 10632 0.09683 735 0 1.026 0 735 0 6 Sun 2700 9856 8626 1844 12556 0.09683 835 0 1.026 0 835 0 7 Mon 900 9984 8748 3516 10584 0.09683 847 0 1.026 0 847 0 8 Tue 1500 9472 8250 3428 10972 0.09683 799 0 1.026 0 799 0 9 Wed 1500 9728 8504 3172 11228 0.09683 823 0 1.026 0 823 0 10 Thu 1800 10112 8884 2488 11912 0.09683 860 0 1.026 0 860 0 11 Fri 1500 10752 9509 2148 12252 0.09683 921 0 1.026 0 921 0 12 Sat 2100 9088 7832 3212 11188 0.09683 758 0 1.026 0 758 0 13 Sun 3600 9600 8345 1200 12900 0.09683 808 0 1.026 0 808 0 14 Mon 1800 10112 8867 2488 11912 0.09683 859 0 1.026 0 859 0 15 Tue 1800 9472 8250 3128 11272 0.09683 799 0 1.026 0 799 0 16 Wed 2100 9600 8394 2700 11700 0.09683 813 0 1.026 0 813 0 17 Thu 4300 8832 7667 1268 13132 0.09683 742 17 1.026 174 742 0 18 Fri 3300 9600 8403 1500 12900 0.09683 814 10 1.026 103 814 0 19 Sat 3900 8832 7685 1668 12732 0.09683 744 19 1.026 195 744 0 20 Sun 3300 8576 7923 2524 11876 0.09683 767 6 1.026 62 767 0 21 Mon 2400 10112 8873 1888 12512 0.09683 859 2 1.026 21 859 0 22 Tue 1800 9258 8157 3342 11058 0.09683 790 2 1.026 21 790 0 23 Wed 3600 9201 8118 1599 12501 0.09683 786 10 1.026 103 786 0 24 Thu 5400 8064 6911 936 13464 0.09683 669 27 1.026 277 669 0 25 Fri 2400 9728 8524 2272 12128 0.09683 825 0 1.026 0 825 0 26 Sat 4200 9088 7994 1112 13288 0.09683 774 0 1.026 0 774 0 27 Sun 2100 23040 21781 -10740 25140 0.09683 2109 0 1.026 0 2109 0 28 Mon 1200 9472 8248 3728 10672 0.09683 799 0 1.026 0 799 0 29 Tue 1500 9984 8756 2916 11484 0.09683 848 0 1.026 0 848 0 30 Wed 1300 9344 8130 3756 10344 0.09683 787 0 1.026 0 787 0 31 Thu 0 0.09683 0 1.026 0 0 0
MIN 900 5120 3873 -10740 0 0.09683 0 0 0 0 0
MAX 5400 23040 21781 7480 25140 0.09683 2109 27 277 2109 0 AVG 2390.0 9989.167 8801.067 2021 11931 0.09683 825 3.5 35 825 0 SUM 71700 299675 264032 60625 369875 25566 106 1088 25566 0 Non-allowed therms 0

Attachment 1

November 2025 mber 2025
D
A
T
E
D
A
Y
1 Tue
2 Wed
3 Thu
4 Fri
5 Sat
6 Sun
7 Mon
8 Tue
9 Wed
10 Thu
11 Fri
12 Sat
13 Sun
14 Mon
15 Tue
16 Wed
17 Thu
18 Fri
19 Sat
20 Sun
21 Mon
22 Tue
23 Wed
24 Thu
25 Fri
26 Sat
27 Sun
28 Mon
29 Tue
30 Wed
31 Thu
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 190800 24.8

0.18700 0.24104 0.01733 0.31300 $2 $0 $2 0.000 0.032 300 $9.53 213.5 800 170800 23.8

0.18700 0.24104 0.01733 0.31300 $25 $0 $25 0.002 0.030 0 $0.00 16.0 12300 196200 24.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 193800 26.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 2161700 21.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 176800 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 174500 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 179000 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 175600 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 182400 24.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 197200 26.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 162000 21.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 177300 23.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 182400 24.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 174000 23.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 173100 23.2

0.18700 0.24104 0.01733 0.31300 $36 $0 $36 0.004 0.028 0 $0.00 112.5 1770 199200 24.6

0.18700 0.24104 0.01733 0.31300 $21 $0 $21 0.002 0.030 0 $0.00 19.3 10200 196500 25.0

0.18700 0.24104 0.01733 0.31300 $40 $0 $40 0.005 0.027 0 $0.00 9.8 19600 192800 23.6

0.18700 0.24104 0.01733 0.31300 $13 $0 $13 0.001 0.031 0 $0.00 29.3 6200 181700 23.6

0.18700 0.24104 0.01733 0.31300 $4 $0 $4 0.000 0.032 0 $0.00 89.6 2100 188100 25.0

0.18700 0.24104 0.01733 0.31300 $4 $0 $4 0.000 0.032 0 $0.00 66.9 2800 187200 24.9

0.18700 0.24104 0.01733 0.31300 $21 $0 $21 0.002 0.030 300 $8.92 17.0 10300 175200 22.0

0.18700 0.24104 0.01733 0.31300 $57 $0 $57 0.007 0.025 0 $0.00 7.5 27300 204700 23.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 178800 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 163000 21.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 175800 23.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 179200 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 179900 24.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 168400 22.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 162000 21.7
$57 $0 $57 0.007 0.032 300 $9.53 #DIV/0! 27300 2161700 26.5 $7 $0 $7 0.001 0.010 48 $0.60 #DIV/0! 3112.3 247936.7 23.9 $222 $0 $222 1500 $18.45 93370 7438100 717.4

Attachment 1

December 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Mon 1800 10112 8923 2488 11912 0.09683 864 0 1.026 0 864 0 2 Tue 2100 9984 8772 2316 12084 0.09683 849 0 1.026 0 849 0 3 Wed 2400 9728 8477 2272 12128 0.09683 821 0 1.026 0 821 0 4 Thur 2100 9856 8604 2444 11956 0.09683 833 0 1.026 0 833 0 5 Fri 2100 9472 8227 2828 11572 0.09683 797 0 1.026 0 797 0 6 Sat 1500 10112 8876 2788 11612 0.09683 859 0 1.026 0 859 0 7 Sun 1200 9472 8258 3728 10372 0.09683 800 0 1.026 0 800 0 8 Mon 1500 9856 8612 3044 11356 0.09683 834 0 1.026 0 834 0 9 Tue 2100 9600 8366 2700 11700 0.09683 810 0 1.026 0 810 0 10 Wed 1500 21760 16031 -8860 23260 0.09683 1552 0 1.026 0 1552 0 11 Thur 1800 8448 7216 4152 9948 0.09683 699 0 1.026 0 699 0 12 Fri 1800 9989 8762 2611 11789 0.09683 848 0 1.026 0 848 0 13 Sat 1500 9216 1237 3684 10716 0.09683 120 0 1.026 0 120 0 14 Sun 1200 9856 8620 3344 10756 0.09683 835 0 1.026 0 835 0 15 Mon 1800 9728 8507 2872 11528 0.09683 824 0 1.026 0 824 0 16 Tue 2100 9600 8336 2700 11700 0.09683 807 0 1.026 0 807 0 17 Wed 8100 6272 7114 28 14372 0.09683 689 0 1.026 0 689 0 18 Thur 1800 9984 8769 2616 11484 0.09683 849 0 1.026 0 849 0 19 Fri 1200 9216 8009 3984 10416 0.09683 776 0 1.026 0 776 0 20 Sat 1200 9984 8738 3216 10884 0.09683 846 0 1.026 0 846 0 21 Sun 1500 9216 7954 3684 10716 0.09683 770 0 1.026 0 770 0 22 Mon 1800 9728 8450 2872 11228 0.09683 818 0 1.026 0 818 0 23 Tue 2700 9618 8372 2082 12318 0.09683 811 0 1.026 0 811 0 24 Wed 2100 7168 6108 5132 9268 0.09683 591 0 1.026 0 591 0 25 Thurs 5700 6784 5643 1916 12484 0.09683 546 7 1.026 72 546 0 26 Fri 6000 8192 7039 208 13892 0.09683 682 7 1.026 72 682 0 27 Sat 6600 6656 5522 1144 13256 0.09683 535 8 1.026 82 535 0 28 Sun 10800 2944 2052 656 13744 0.09683 199 1 1.026 10 199 0 29 Mon 5400 7424 6515 1576 12824 0.09683 631 5 1.026 51 631 0 30 Tue 1200 9728 8484 3472 10628 0.09683 822 0 1.026 0 822 0 31 Wed 1800 8192 6915 4408 9992 0.09683 670 0 1.026 0 670 0 MIN 1200 2944 1237 -8860 9268 0.09683 120 0 0 120 0
MAX 10800 21760 16031 5132 23260 0.09683 1552 8 82 1552 0 AVG 2787.1 9286.935 7790.581 2326 11997 0.09683 754 0.9 9 754 0 SUM 86400 287895 241508 72105 371895 23385 28 287 23385 0 Non-allowed therms 0

Attachment 1

December 2025 mber 2025
D
A
T
E
D
A
Y
1 Mon
2 Tue
3 Wed
4 Thur
5 Fri
6 Sat
7 Sun
8 Mon
9 Tue
10 Wed
11 Thur
12 Fri
13 Sat
14 Sun
15 Mon
16 Tue
17 Wed
18 Thur
19 Fri
20 Sat
21 Sun
22 Mon
23 Tue
24 Wed
25 Thurs
26 Fri
27 Sat
28 Sun
29 Mon
30 Tue
31 Wed
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 186600 24.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 179800 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 177200 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 178400 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 179000 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 178000 23.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 171500 23.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 177600 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 195900 24.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 499200 28.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 151900 20.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 182400 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 166700 22.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 178500 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 17450 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 171700 23.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 71.1 1700 120800 15.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 180900 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 167000 22.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 182800 24.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 169400 23.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 179800 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 153700 26.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 156900 21.6

0.18700 0.24104 0.01733 0.31300 $15 $0 $15 0.002 0.030 0 $0.00 27.7 6900 191400 23.8

0.18700 0.24104 0.01733 0.31300 $15 $0 $15 0.002 0.030 300 $9.06 30.8 7200 221960 25.9

0.18700 0.24104 0.01733 0.31300 $17 $0 $17 0.003 0.029 0 $0.00 26.0 7900 205700 23.2

0.18700 0.24104 0.01733 0.31300 $2 $0 $2 0.001 0.031 0 $0.00 23.2 1800 41800 4.5

0.18700 0.24104 0.01733 0.31300 $10 $0 $10 0.001 0.031 0 $0.00 36.1 5400 195200 23.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 178800 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 179900 24.2 $0 $0 $0 0.000 0.000 0 $0.00 0 17450 4.5
$17 $0 $17 0.003 0.031 300 $9.06 7900 499200 28.6
$2 $0 $2 0.000 0.005 77 $0.29 #DIV/0! 996.8 177997.1 23.0 $59 $0 $59 2400 $9.06 30900 5517910 714.2

Attachment 1

January 2013

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Tue 12000 0 0 14400 12760 0.09683 0 0 1.026 0 0 0
2 Wed 12600 512 -264 1288 13376 0.09683 -26 11 1.026 113 -26 138 3 Thu 14400 0 0.09683 0 1.026 0 0 0
4 Fri 14400 0 0.09683 0 1.026 0 0 0
5 Sat 14400 0 0.09683 0 1.026 0 0 0
6 Sun 14400 0 0.09683 0 1.026 0 0 0
7 Mon 14400 0 0.09683 0 1.026 0 0 0
8 Tue 14400 0 0.09683 0 1.026 0 0 0
9 Wed 14400 0 0.09683 0 1.026 0 0 0
10 Thu 14400 0 0.09683 0 1.026 0 0 0
11 Fri 14400 0 0.09683 0 1.026 0 0 0
12 Sat 14400 0 0.09683 0 1.026 0 0 0
13 Sun 14400 0 0.09683 0 1.026 0 0 0
14 Mon 14400 0 0.09683 0 1.026 0 0 0
15 Tue 14400 0 0.09683 0 1.026 0 0 0
16 Wed 14400 0 0.09683 0 1.026 0 0 0
17 Thu 14400 0 0.09683 0 1.026 0 0 0
18 Fri 14400 0 0.09683 0 1.026 0 0 0
19 Sat 14400 0 0.09683 0 1.026 0 0 0
20 Sun 14400 0 0.09683 0 1.026 0 0 0
21 Mon 14400 0 0.09683 0 1.026 0 0 0
22 Tue 14400 0 0.09683 0 1.026 0 0 0
23 Wed 14400 0 0.09683 0 1.026 0 0 0
24 Thu 14400 0 0.09683 0 1.026 0 0 0
25 Fri 14400 0 0.09683 0 1.026 0 0 0
26 Sat 14400 0 0.09683 0 1.026 0 0 0
27 Sun 14400 0 0.09683 0 1.026 0 0 0
28 Mon 14400 0 0.09683 0 1.026 0 0 0
29 Tue 14400 0 0.09683 0 1.026 0 0 0
30 Wed 14400 0 0.09683 0 1.026 0 0 0
31 Thu 14400 0 0.09683 0 1.026 0 0 0
MIN 12000 0 -264 1288 0 0.09683 -26 0 0 -26 0
MAX 12600 512 0 14400 13376 0.09683 0 11 113 0 138
AVG 12300.0 256 -132 13977 843 0.09683 -1 5.5 4 -1 4
SUM 24600 512 -264 433288 26136 -26 11 113 -26 138
Non-allowed therms 138

Attachment 1

Januaryry 2013 2013
D
A
T
E
D
A
Y
1 Tue
2 Wed
3 Thu
4 Fri
5 Sat
6 Sun
7 Mon
8 Tue
9 Wed
10 Thu
11 Fri
12 Sat
13 Sun
14 Mon
15 Tue
16 Wed
17 Thu
18 Fri
19 Sat
20 Sun
21 Mon
22 Tue
23 Wed
24 Thu
25 Fri
26 Sat
27 Sun
28 Mon
29 Tue
30 Wed
31 Thu
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 -760 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 ($5) $77 $71 0.140 -0.108 -264 $0.00 10600 0 3.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 ($5) $0 $0 0.000 -0.108 -760 $0.00 0.0 0 0 0
$0 $77 $71 0.140 0.000 0 $0.00 0.0 10600 0 3.9
($0) $2 $2 0.005 -0.003 -33 $0.00 #DIV/0! 5300.0 0.0 2.0 ($5) $77 $71 -1024 $0.00 10600 0 3.9

Attachment 1

ALS Environmental
2655 Park Center Dr., Suite A
Simi Valley, CA 93065
T +1 805 526 7161
alsglobal.com

LABORATORY REPORT
________________________________________________________________________________ December 10, 2024
Bryan Condy
City of Watsonville
500 Clearwater Lane
Watsonville, CA 95076
RE: Sphere Gas Siloxane
Dear Bryan:

Enclosed are the results of the sample submitted to our laboratory on November 25, 2024. For your reference, this analysis has been assigned our service request number P2404802.

All analyses were performed according to our laboratory’s NELAP and DoD-ELAP-approved quality assurance program. The test results meet requirements of the current NELAP and DoD-ELAP standards, where applicable, and except as noted in the laboratory case narrative provided. For a specific list of NELAP and DoD-ELAP-accredited analytes, refer to the certifications section at www.alsglobal.com.

Results are intended to be considered in their entirety and apply only to the samples analyzed and reported herein.

If you have any questions, please call me at (805) 526-7161.

ALS | Environmental
Sue Anderson
Project Manager
1 of 9
By Sue Anderson at 2:42 pm, Dec 10, 2024
File: 2404802 Siloxane.pdf
Received: May 18th, 2026
Description: Digester Gas Siloxane content
Data Type: Lab Report (Gas Assay)
Source: City of Watsonville Operator
Purpose: Inform gas conditioning equipment design specifications and sizing Attachment 1

ALS Environmental
2655 Park Center Dr., Suite A
Simi Valley, CA 93065
T +1 805 526 7161
alsglobal.com
Client: City of Watsonville Service Request No: P2404802 Project: Sphere Gas Siloxane

CASE NARRATIVE
____________________________________________________________________________________ The sample was received intact under chain of custody on November 25, 2024 and was stored in accordance with the analytical method requirements. Please refer to the sample acceptance check form for additional information. The results reported herein are applicable only to the condition of the sample at the time of sample receipt.

Siloxanes Analysis
The sample was analyzed for siloxanes according to ASTM D8230-19 using an analytical system comprised of a gas chromatograph/mass spectrometer (GC/MS). This method is not included on the laboratory’s NELAP or DoD-ELAP scope of accreditation.
________________________________________________________________________________ The results of analyses are given in the attached laboratory report. All results are intended to be considered in their entirety, and ALS Environmental (ALS) is not responsible for utilization of less than the complete report.

Use of ALS Environmental (ALS)’s Name. Client shall not use ALS’s name or trademark in any marketing or reporting materials, press releases or in any other manner (“Materials”) whatsoever and shall not attribute to ALS any test result, tolerance or specification derived from ALS’s data (“Attribution”) without ALS’s prior written consent, which may be withheld by ALS for any reason in its sole discretion. To request ALS’s consent, Client shall provide copies of the proposed Materials or Attribution and describe in writing Client’s proposed use of such Materials or Attribution. If ALS has not provided written approval of the Materials or Attribution within ten (10) days of receipt from Client, Client’s request to use ALS’s name or trademark in any Materials or Attribution shall be deemed denied. ALS may, in its discretion, reasonably charge Client for its time in reviewing Materials or Attribution requests. Client acknowledges and agrees that the unauthorized use of ALS’s name or trademark may cause ALS to incur irreparable harm for which the recovery of money damages will be inadequate. Accordingly, Client acknowledges and agrees that a violation shall justify preliminary injunctive relief. For questions contact the laboratory. 2 of 9
Attachment 1

ALS Environmental
2655 Park Center Dr., Suite A
Simi Valley, CA 93065
T +1 805 526 7161
alsglobal.com

CERTIFICATIONS, ACCREDITATIONS, AND REGISTRATIONS
Agency Web Site Number
Alaska DEC https://dec.alaska.gov/spar/csp/lab-approval/list-of-approved-labs 17-019 Arizona DHS http://www.azdhs.gov/preparedness/state-laboratory/lab-licensurecertification/index.php#laboratory-licensure-home AZ0694 Florida DOH
(NELAP)
http://www.floridahealth.gov/licensing-and-regulation/environmentallaboratories/index.html E871020 Louisiana DEQ
(NELAP)
https://internet.deq.louisiana.gov/portal/divisions/lelap/accreditedlaboratories 203013 Maine DHHS http://www.maine.gov/dhhs/mecdc/environmentalhealth/dwp/professionals/labCert.shtm CA01627 Minnesota DOH
(NELAP) http://www.health.state.mn.us/accreditation 006-999-456 New Jersey DEP
(NELAP) https://dep.nj.gov/dsr/oqa/certified-laboratories/ CA009 New York DOH
(NELAP) http://www.wadsworth.org/labcert/elap/elap.html 11221 Oklahoma DEQ
(NELAP) labaccreditation.deq.ok.gov/labaccreditation/ 2207 Oregon PHD
(NELAP) https://orelap.state.or.us/searchLabs 4068-012
Pennsylvania DEP hhttp://www.dep.pa.gov/Business/OtherPrograms/Labs/Pages/LaboratoryAccreditation-Program.aspx 68-03307
(Registration)
PJLA
(DoD ELAP) http://www.pjlabs.com/search-accredited-labs 65818(Testing) Texas CEQ
(NELAP) http://www.tceq.texas.gov/agency/qa/env_lab_accreditation.html T104704413 Utah DOH
(NELAP) https://uphl.utah.gov/certifications/environmental-laboratory-certification/ CA016272024-16 Washington DOE http://www.ecy.wa.gov/programs/eap/labs/lab-accreditation.html C946 Analyses were performed according to our laboratory’s NELAP and DoD-ELAP approved quality assurance program.

A complete listing of specific NELAP and DoD-ELAP certified analytes can be found in the certifications section at www.alsglobal.com, or at the accreditation body’s website.

Each of the certifications listed above have an explicit Scope of Accreditation that applies to specific matrices/methods/analytes; therefore, please contact the laboratory for information corresponding to a particular certification.
3 of 9
Attachment 1

P2404802_Detail Summary_2412101042_DP.xls - DETAIL SUMMARY Client: City of Watsonville Service Request: P2404802
Project ID: Sphere Gas Siloxane
Date Received: 11/25/2024
Time Received: 09:22
Client Sample ID Lab Code Matrix
Date
Collected
Time
Collected
Sphere Bomb Gas P2404802-001 Air 11/21/2024 13:12 X

ALS ENVIRONMENTAL

DETAIL SUMMARY REPORT
ASTM D8230 - Siloxanes Tube
4 of 9
Attachment 1

5 of 9
Attachment 1

ALS Environmental
Sample Acceptance Check Form
Client: City of Watsonville Work order:

Project: Sphere Gas Siloxane
Sample(s) received on: 11/25/2024 Date opened: 11/25/2024 by:

Note: This form is used for all samples received by ALS. The use of this form for custody seals is strictly meant to indicate presence/absence and not as an indication of compliance or nonconformity. Thermal preservation and pH will only be evaluated either at the request of the client and/or as required by the method/SOP.

Yes No N/A
1 Were sample containers properly marked with client sample ID? x o o 2 Did sample containers arrive in good condition? x o o 3 Were chain-of-custody papers used and filled out? x o o 4 Did sample container labels and/or tags agree with custody papers? x o o 5 Was sample volume received adequate for analysis? x o o 6 Are samples within specified holding times? x o o
7 Was proper temperature (thermal preservation) of cooler at receipt adhered to? o o x 8 Were custody seals on outside of cooler/Box/Container? o x Location of seal(s)? Sealing Lid? o o x
Were signature and date included? o o x
Were seals intact? o o x
9 o o x
Is there a client indication that the submitted samples are pH preserved? o o x Were VOA vials checked for presence/absence of air bubbles? o o x o o x
10 Tubes: Are the tubes capped and intact? x o o
11 Badges: Are the badges properly capped and intact? o o x Are dual bed badges separated and individually capped and intact? o o x 12 Lab Notification: Analyst and PM were alerted of Short HT or RUSH samples? o o x 13 Client Notification: Client has been notified regarding HT exceedances and/or other CoC discrepancies? o o x Lab Sample ID Container Required Received Adjusted VOA Headspace Description pH * pH pH (Presence/Absence) Comments
Tube, Siloxane
Sulfur (pH>4)
P2404802
ANTHONY.VASQUEZ
Do containers have appropriate preservation, according to method/SOP or Client specified information? Does the client/method/SOP require that the analyst check the sample pH and if necessary alter it? Receipt / Preservation
P2404802-001.01
Explain any discrepancies: (include lab sample ID numbers):

P2404802_City of Watsonville_Sphere Gas Siloxane - Page 1 of 1 11/25/2024 2:29 PM 6 of 9
Attachment 1

P2404802_Siloxanes_2412041345_SC.xls - Sample Siloxanes-Total.xls - Page No.:

ALS ENVIRONMENTAL

RESULTS OF ANALYSIS

Client: City of Watsonville
Sphere Bomb Gas ALS Project ID: P2404802
Sphere Gas Siloxane ALS Sample ID: P2404802-001
Test Code: ASTM D8230-19 Date Collected: 11/21/24
Instrument ID: Agilent 5977C/HP8890/MS30 Date Received: 11/25/24 Analyst: Braden Kalous Date Analyzed: 12/2/24
Sample Type: Siloxane Tube Desorption Volume: 3.0 ml
Test Notes: BC, DE Volume Sampled: 12.40 Liter(s)
CAS # Compound Result MRL MRL Data
µg/Tube µg/m³ µg/m³ Qualifier
1066-40-6 Trimethylsilanol 3.6 290 47 92 15
107-46-0 Hexamethyldisiloxane (L2) < 0.54 ND 44 ND 15
541-05-9 Hexamethylcyclotrisiloxane (D3) < 0.58 ND 46 ND 18 107-51-7 Octamethyltrisiloxane (L3) < 0.55 ND 45 ND 16
556-67-2 Octamethylcyclotetrasiloxane (D4) 13 1,000 44 380 17 141-62-8 Decamethyltetrasiloxane (L4) 1.0 84 44 30 16
541-02-6 Decamethylcyclopentasiloxane (D5) 64 5,100 44 1,900 17 141-63-9 Dodecamethylpentasiloxane (L5) 0.94 76 44 28 16 540-97-6 Dodecamethylcyclohexasiloxane (D6) 1.9 160 45 59 17 Total Silicon 2,500
ND = Compound was analyzed for, but not detected above the laboratory reporting limit.

MRL = Method Reporting Limit - The minimum quantity of a target analyte that can be confidently determined by the referenced method.

BC = Results reported are not blank corrected.

DE = Results reported are corrected for desorption efficiency. µg/m³ µg/m³
Result
Result as Silicon
Client Sample ID:

Client Project ID:
7 of 9
Attachment 1

P2404802_Siloxanes_2412041345_SC.xls - MBlank Siloxanes-Total.xls - Page No.:

ALS ENVIRONMENTAL

RESULTS OF ANALYSIS

Client: City of Watsonville
Method Blank ALS Project ID: P2404802
Sphere Gas Siloxane ALS Sample ID: P241202-MB
Test Code: ASTM D8230-19 Date Collected: NA
Instrument ID: Agilent 5977C/HP8890/MS30 Date Received: NA Analyst: Braden Kalous Date Analyzed: 12/2/24
Sample Type: Siloxane Tube Desorption Volume: 3.0 ml
Test Notes: BC, DE Volume Sampled: NA Liter(s)
CAS # Compound Result MRL MRL Data
µg/Tube µg/m³ µg/m³ Qualifier
1066-40-6 Trimethylsilanol < 0.58 NA NA NA NA
107-46-0 Hexamethyldisiloxane (L2) < 0.54 NA NA NA NA
541-05-9 Hexamethylcyclotrisiloxane (D3) < 0.58 NA NA NA NA 107-51-7 Octamethyltrisiloxane (L3) < 0.55 NA NA NA NA
556-67-2 Octamethylcyclotetrasiloxane (D4) < 0.55 NA NA NA NA 141-62-8 Decamethyltetrasiloxane (L4) < 0.55 NA NA NA NA 541-02-6 Decamethylcyclopentasiloxane (D5) < 0.55 NA NA NA NA 141-63-9 Dodecamethylpentasiloxane (L5) < 0.55 NA NA NA NA 540-97-6 Dodecamethylcyclohexasiloxane (D6) < 0.56 NA NA NA NA Total Silicon NA
ND = Compound was analyzed for, but not detected above the laboratory reporting limit.

MRL = Method Reporting Limit - The minimum quantity of a target analyte that can be confidently determined by the referenced method.

NA = Not applicable.

BC = Results reported are not blank corrected.

DE = Results reported are corrected for desorption efficiency.

Client Sample ID:

Client Project ID:

Result
µg/m³ µg/m³
Result
as Silicon
8 of 9
Attachment 1

P2404802_Siloxanes_2412041345_SC.xls - DLCS Siloxanes-Total.xls - Page No.:

ALS ENVIRONMENTAL

LABORATORY CONTROL SAMPLE / DUPLICATE LABORATORY CONTROL SAMPLE SUMMARY

Client: City of Watsonville
Duplicate Lab Control Sample ALS Project ID: P2404802
Sphere Gas Siloxane ALS Sample ID: P241202-DLCS
Test Code: ASTM D8230-19 Date Collected: NA
Instrument ID: Agilent 5977C/HP8890/MS30 Date Received: NA Analyst: Braden Kalous Date Analyzed: 12/02/24
Sampling Type: Siloxane Tube Volume(s) Analyzed: NA Liter(s) Test Notes:

Spike Amount ALS
CAS # Compound LCS / DLCS LCS DLCS % Recovery Acceptance RPD RPD Data µg/ml µg/ml µg/ml LCS DLCS Limits Limit Qualifier
1066-40-6 Trimethylsilanol 10.0 8.90 9.59 89 96 70-130 8 25 107-46-0 Hexamethyldisiloxane 10.1 10.7 12.0 106 119 70-130 12 25 541-05-9 Hexamethylcyclotrisiloxane 9.51 8.89 9.12 93 96 70-130 3 25 107-51-7 Octamethyltrisiloxane 9.60 10.2 10.7 106 111 70-130 5 25 556-67-2 Octamethylcyclotetrasiloxane 9.00 10.0 10.0 111 111 70-130 0 25 141-62-8 Decamethyltetrasiloxane 9.59 10.9 10.7 114 112 70-130 2 25 541-02-6 Decamethylcyclopentasiloxane 8.85 10.3 9.83 116 111 70-130 4 25 141-63-9 Dodecamethylpentasiloxane 9.46 11.4 10.6 121 112 70-130 8 25 540-97-6 Dodecamethylcyclohexasiloxane 8.40 10.2 9.38 121 112 70-130 8 25 Result
Client Sample ID:

Client Project ID:
9 of 9
Attachment 1

ALS Environmental
2655 Park Center Dr., Suite A
Simi Valley, CA 93065
T +1 805 526 7161
alsglobal.com

LABORATORY REPORT
________________________________________________________________________________ February 6, 2025
Bryan Condy
City of Watsonville
500 Clearwater Lane
Watsonville, CA 95076
RE: Air Board Analysis
Dear Bryan:

Enclosed are the results of the samples submitted to our laboratory on January 28, 2025. For your reference, these analyses have been assigned our service request number P2500291.

All analyses were performed according to our laboratory’s NELAP and DoD-ELAP-approved quality assurance program. The test results meet requirements of the current NELAP and DoD-ELAP standards, where applicable, and except as noted in the laboratory case narrative provided. For a specific list of NELAP and DoD-ELAP-accredited analytes, refer to the certifications section at www.alsglobal.com.

Results are intended to be considered in their entirety and apply only to the samples analyzed and reported herein.

If you have any questions, please call me at (805) 526-7161.

ALS | Environmental
Sue Anderson
Project Manager
1 of 9
By Sue Anderson at 3:34 pm, Feb 06, 2025
File: Gas_Composition_Assay_P25000291.pdf
Received: November 2025
Description: Digester Gas BTU & CHONS Analysis
Data Type: Lab Report (Gas Assay)
Source: City of Watsonville Operator
Purpose: Inform gas conditioning equipment design specifications and sizing Attachment 1

ALS Environmental
2655 Park Center Dr., Suite A
Simi Valley, CA 93065
T +1 805 526 7161
alsglobal.com
Client: City of Watsonville Service Request No: P2500291 Project: Air Board Analysis

CASE NARRATIVE
____________________________________________________________________________________ The samples were received intact under chain of custody on January 28, 2025 and were stored in accordance with the analytical method requirements. Please refer to the sample acceptance check form for additional information. The results reported herein are applicable only to the condition of the samples at the time of sample receipt.

BTU and CHONS Analysis
The results for BTU and CHONS were generated according to ASTM D 3588-98. The following analyses were performed and used to calculate the BTU and CHONS results. This method is not included on the laboratory’s NELAP or DoD-ELAP scope of accreditation.

C2 through C6 Hydrocarbon Analysis
The samples were analyzed according to modified EPA Method TO-3 for C2 through >C6 hydrocarbons using a gas chromatograph equipped with a flame ionization detector (FID). This method is included on the laboratory’s DoD-ELAP scope of accreditation, however it is not part of the NELAP accreditation.

Fixed Gases Analysis
The samples were also analyzed for fixed gases (hydrogen, oxygen/argon, nitrogen, carbon monoxide, methane and carbon dioxide) according to modified EPA Method 3C (single injection) using a gas chromatograph equipped with a thermal conductivity detector (TCD). This method is included on the laboratory’s DoD-ELAP scope of accreditation, however it is not part of the NELAP accreditation.

Hydrogen Sulfide Analysis
The samples were also analyzed for hydrogen sulfide per modified SCAQMD Method 307-91 and ASTM D 5504-20 using a gas chromatograph equipped with a sulfur chemiluminescence detector (SCD). Method ASTM D 5504-20 is included on the laboratory’s NELAP scope of accreditation, however it is not part of the DoD-ELAP accreditation. Method SCAQMD 307-91 is not included on the laboratory’s NELAP or DoD-ELAP accreditation.

The samples were received with insufficient hold time remaining to complete the analysis within the recommended limit. The analysis was performed as soon as possible after receipt by the laboratory and the data flagged to indicate the holding time exceedance.
________________________________________________________________________________ The results of analyses are given in the attached laboratory report. All results are intended to be considered in their entirety, and ALS Environmental (ALS) is not responsible for utilization of less than the complete report.

Use of ALS Environmental (ALS)’s Name. Client shall not use ALS’s name or trademark in any marketing or reporting materials, press releases or in any other manner (“Materials”) whatsoever and shall not attribute to ALS any test result, tolerance or specification derived from ALS’s data (“Attribution”) without ALS’s prior written consent, which may be withheld by ALS for any reason in its sole discretion. To request ALS’s consent, Client shall provide copies of the proposed Materials or Attribution and describe in writing Client’s proposed use of such Materials or Attribution. If ALS has not provided written approval of the Materials or Attribution within ten (10) days of receipt from Client, Client’s request to use ALS’s name or trademark in any Materials or Attribution shall be deemed denied. ALS may, in its discretion, reasonably charge Client for its time in reviewing Materials or Attribution requests. Client acknowledges and agrees that the unauthorized use of ALS’s name or trademark may cause ALS to incur irreparable harm for which the recovery of money damages will be inadequate. Accordingly, Client acknowledges and agrees that a violation shall justify preliminary injunctive relief. For questions contact the laboratory. 2 of 9
Attachment 1

ALS Environmental
2655 Park Center Dr., Suite A
Simi Valley, CA 93065
T +1 805 526 7161
alsglobal.com

CERTIFICATIONS, ACCREDITATIONS, AND REGISTRATIONS
Agency Web Site Number
Alaska DEC https://dec.alaska.gov/spar/csp/lab-approval/list-of-approved-labs 17-019 Arizona DHS http://www.azdhs.gov/preparedness/state-laboratory/lab-licensurecertification/index.php#laboratory-licensure-home AZ0694 Florida DOH
(NELAP)
http://www.floridahealth.gov/licensing-and-regulation/environmentallaboratories/index.html E871020 Louisiana DEQ
(NELAP)
https://internet.deq.louisiana.gov/portal/divisions/lelap/accreditedlaboratories 203013 Maine DHHS http://www.maine.gov/dhhs/mecdc/environmentalhealth/dwp/professionals/labCert.shtm CA012627 Minnesota DOH
(NELAP) http://www.health.state.mn.us/accreditation 006-999-456 New Jersey DEP
(NELAP) https://dep.nj.gov/dsr/oqa/certified-laboratories/ CA009 New York DOH
(NELAP) http://www.wadsworth.org/labcert/elap/elap.html 11221 Oklahoma DEQ
(NELAP) labaccreditation.deq.ok.gov/labaccreditation/ 2207 Oregon PHD
(NELAP)
http://www.oregon.gov/oha/ph/LaboratoryServices/EnvironmentalLaboratoryA ccreditation/Pages/index.aspx 4068
Pennsylvania DEP hhttp://www.dep.pa.gov/Business/OtherPrograms/Labs/Pages/LaboratoryAccreditation-Program.aspx 68-03307
(Registration
only)
PJLA
(DoD ELAP) http://www.pjlabs.com/search-accredited-labs 65818(Testing) Texas CEQ
(NELAP) http://www.tceq.texas.gov/agency/qa/env_lab_accreditation.html T104704413 Utah DOH
(NELAP) https://uphl.utah.gov/certifications/environmental-laboratory-certification/ CA01627 Washington DOE http://www.ecy.wa.gov/programs/eap/labs/lab-accreditation.html C946 Analyses were performed according to our laboratory’s NELAP and DoD-ELAP approved quality assurance program.

A complete listing of specific NELAP and DoD-ELAP certified analytes can be found in the certifications section at www.alsglobal.com, or at the accreditation body’s website.

Each of the certifications listed above have an explicit Scope of Accreditation that applies to specific matrices/methods/analytes; therefore, please contact the laboratory for information corresponding to a particular certification.
3 of 9
Attachment 1

P2500291_Detail Summary_2502061439_DP.xls - DETAIL SUMMARY Client: City of Watsonville Service Request: P2500291
Project ID: Air Board Analysis
Date Received: 1/28/2025
Time Received: 09:59
Client Sample ID Lab Code Matrix
Date
Collected
Time
Collected
Sphere P2500291-001 Air 1/27/2025 11:10 X X X
Digester 1 P2500291-002 Air 1/27/2025 10:55 X X X
Digester 2 P2500291-003 Air 1/27/2025 11:00 X X X

ALS ENVIRONMENTAL

DETAIL SUMMARY REPORT
TO-3 Modified - C1C6+ Bag
3C Modified - Fxd Gases Bag
ASTM D5504-01 - H2S Bag
4 of 9
Attachment 1

5 of 9
Attachment 1

ALS Environmental
Sample Acceptance Check Form
Client: City of Watsonville Work order:

Project: Air Board Analysis
Sample(s) received on: 1/28/2025 Date opened: 1/28/2025 by:

Note: This form is used for all samples received by ALS. The use of this form for custody seals is strictly meant to indicate presence/absence and not as an indication of compliance or nonconformity. Thermal preservation and pH will only be evaluated either at the request of the client and/or as required by the method/SOP.

Yes No N/A
1 Were sample containers properly marked with client sample ID? x o o 2 Did sample containers arrive in good condition? x o o 3 Were chain-of-custody papers used and filled out? x o o 4 Did sample container labels and/or tags agree with custody papers? x o o 5 Was sample volume received adequate for analysis? x o o 6 Are samples within specified holding times? x o o
7 Was proper temperature (thermal preservation) of cooler at receipt adhered to? o o x 8 Were custody seals on outside of cooler/Box/Container? o x Location of seal(s)? Sealing Lid? o o x
Were signature and date included? o o x
Were seals intact? o o x
9 o o x
Is there a client indication that the submitted samples are pH preserved? o o x Were VOA vials checked for presence/absence of air bubbles? o o x o o x
10 Tubes: Are the tubes capped and intact? o o x
11 Badges: Are the badges properly capped and intact? o o x Are dual bed badges separated and individually capped and intact? o o x 12 Lab Notification: Analyst and PM were alerted of Short HT or RUSH samples? o o x 13 Client Notification: Client has been notified regarding HT exceedances and/or other CoC discrepancies? o o x ##### ##### ######
Lab Sample ID Container Required Received Adjusted VOA Headspace Description pH * pH pH (Presence/Absence) Comments

1.0 L Tedlar Bag

1.0 L Tedlar Bag

1.0 L Tedlar Bag
Sulfur (pH>4)
P2500291
ANTHONY.VASQUEZ
P2500291-002.01
P2500291-003.01
Do containers have appropriate preservation, according to method/SOP or Client specified information? Does the client/method/SOP require that the analyst check the sample pH and if necessary alter it? Receipt / Preservation
P2500291-001.01
Explain any discrepancies: (include lab sample ID numbers):

P2500291_City of Watsonville_Air Board Analysis - Page 1 of 1 1/28/2025 10:24 AM 6 of 9
Attachment 1

P2500291_ASTMD3588_2502051449_SC.xls - Sample BTU-ppm-wi.xls - Page No.:

ALS ENVIRONMENTAL

RESULTS OF ANALYSIS

Client: City of Watsonville
Client Sample ID: Sphere ALS Project ID: P2500291
Client Project ID: Air Board Analysis ALS Sample ID: P2500291-001 Test Code: ASTM D3588-98
Analyst: Gilbert Gutierrez/Stephanie Reynoso/Braden Kalous Date Collected: 1/27/25 Sample Type: 1.0 L Tedlar Bag Date Received: 1/28/25
Test Notes: Date Analyzed: 1/28 - 29/25
Components MRL Data
ppmV Qualifier
Hydrogen < 0.01 ND 1,000
Oxygen 0.53 5,300 1,000
Nitrogen 1.76 17,600 1,000
Carbon Monoxide < 0.01 ND 1,000
Methane 63.64 637,000 1,000
Carbon Dioxide 34.04 340,000 1,000
Hydrogen Sulfide 0.01 100 0.17 H1
C2 as Ethane < 0.01 ND 5.0
C3 as Propane < 0.01 ND 5.0
C4 as n-Butane < 0.01 5.5 5.0
C5 as n-Pentane < 0.01 11 5.0
C6 as n-Hexane < 0.01 6.4 5.0
> C6 as n-Hexane < 0.01 32 30
TOTALS 99.99
Data
Components Qualifier
Carbon 22.99 45.38
Hydrogen 59.92 9.93
Oxygen 16.26 42.77
Nitrogen 0.83 1.91
Sulfur < 0.10 < 0.10 H1
Specific Gravity (Air = 1) 0.8930
Specific Volume 14.67
Gross Heating Value (Dry Gas @ 60 F, 14.696 psia) 645.1 Net Heating Value (Dry Gas @ 60 F, 14.696 psia) 580.8
Gross Heating Value (Water Saturated at 0.25636 psia) 632.0 Net Heating Value (Water Saturated at 0.25636 psia) 569.0 Gross Heating Value (Dry Gas @ 60 F, 14.696 psia) 9,465.3 Net Heating Value (Dry Gas @ 60 F, 14.696 psia) 8,522.7 Compressibility Factor "Z" (60 F, 14.696 psia) 0.9970
WOBBE Index 682.7
H1 = Sample analysis performed past holding time. See case narrative.

BTU/lb
Result
Volume %
Mole %
BTU/ft3
BTU/ft3
BTU/ft3
BTU/lb
BTU/ft3
Result
Weight %
ft3/lb
ppmV
7 of 9
Attachment 1

P2500291_ASTMD3588_2502051449_SC.xls - Sample (2) BTU-ppm-wi.xls - Page No.:

ALS ENVIRONMENTAL

RESULTS OF ANALYSIS

Client: City of Watsonville
Client Sample ID: Digester 1 ALS Project ID: P2500291
Client Project ID: Air Board Analysis ALS Sample ID: P2500291-002 Test Code: ASTM D3588-98
Analyst: Gilbert Gutierrez/Stephanie Reynoso/Braden Kalous Date Collected: 1/27/25 Sample Type: 1.0 L Tedlar Bag Date Received: 1/28/25
Test Notes: Date Analyzed: 1/28 - 29/25
Components MRL Data
ppmV Qualifier
Hydrogen < 0.01 ND 1,000
Oxygen 0.33 3,320 1,000
Nitrogen 1.03 10,300 1,000
Carbon Monoxide < 0.01 ND 1,000
Methane 66.03 660,000 1,000
Carbon Dioxide 32.59 326,000 1,000
Hydrogen Sulfide < 0.01 59 0.17 H1
C2 as Ethane < 0.01 ND 5.0
C3 as Propane < 0.01 ND 5.0
C4 as n-Butane < 0.01 ND 5.0
C5 as n-Pentane < 0.01 9.7 5.0
C6 as n-Hexane < 0.01 6.1 5.0
> C6 as n-Hexane < 0.01 44 30
TOTALS 99.99
Data
Components Qualifier
Carbon 22.90 46.76
Hydrogen 61.33 10.51
Oxygen 15.28 41.58
Nitrogen 0.48 1.14
Sulfur < 0.10 < 0.10 H1
Specific Gravity (Air = 1) 0.8749
Specific Volume 14.98
Gross Heating Value (Dry Gas @ 60 F, 14.696 psia) 669.2 Net Heating Value (Dry Gas @ 60 F, 14.696 psia) 602.6
Gross Heating Value (Water Saturated at 0.25636 psia) 655.6 Net Heating Value (Water Saturated at 0.25636 psia) 590.3 Gross Heating Value (Dry Gas @ 60 F, 14.696 psia) 10,022.2 Net Heating Value (Dry Gas @ 60 F, 14.696 psia) 9,024.1 Compressibility Factor "Z" (60 F, 14.696 psia) 0.9971
WOBBE Index 715.5
H1 = Sample analysis performed past holding time. See case narrative.

BTU/ft3
BTU/ft3
ft3/lb
Result
Weight %
ppmV
BTU/lb
BTU/ft3
BTU/ft3
BTU/lb
Result
Volume %
Mole %
8 of 9
Attachment 1

P2500291_ASTMD3588_2502051449_SC.xls - Sample (3) BTU-ppm-wi.xls - Page No.:

ALS ENVIRONMENTAL

RESULTS OF ANALYSIS

Client: City of Watsonville
Client Sample ID: Digester 2 ALS Project ID: P2500291
Client Project ID: Air Board Analysis ALS Sample ID: P2500291-003 Test Code: ASTM D3588-98
Analyst: Gilbert Gutierrez/Stephanie Reynoso/Braden Kalous Date Collected: 1/27/25 Sample Type: 1.0 L Tedlar Bag Date Received: 1/28/25
Test Notes: Date Analyzed: 1/28 - 29/25
Components MRL Data
ppmV Qualifier
Hydrogen < 0.01 ND 1,000
Oxygen 0.18 1,810 1,000
Nitrogen 0.59 5,940 1,000
Carbon Monoxide < 0.01 ND 1,000
Methane 65.17 652,000 1,000
Carbon Dioxide 34.03 340,000 1,000
Hydrogen Sulfide < 0.01 80 0.17 H1
C2 as Ethane < 0.01 ND 5.0
C3 as Propane < 0.01 ND 5.0
C4 as n-Butane < 0.01 ND 5.0
C5 as n-Pentane < 0.01 12 5.0
C6 as n-Hexane < 0.01 5.4 5.0
> C6 as n-Hexane < 0.01 36 30
TOTALS 99.99
Data
Components Qualifier
Carbon 23.10 46.44
Hydrogen 60.70 10.24
Oxygen 15.93 42.66
Nitrogen 0.28 0.65
Sulfur < 0.10 < 0.10 H1
Specific Gravity (Air = 1) 0.8862
Specific Volume 14.79
Gross Heating Value (Dry Gas @ 60 F, 14.696 psia) 660.5 Net Heating Value (Dry Gas @ 60 F, 14.696 psia) 594.7
Gross Heating Value (Water Saturated at 0.25636 psia) 647.1 Net Heating Value (Water Saturated at 0.25636 psia) 582.6 Gross Heating Value (Dry Gas @ 60 F, 14.696 psia) 9,766.2 Net Heating Value (Dry Gas @ 60 F, 14.696 psia) 8,793.6 Compressibility Factor "Z" (60 F, 14.696 psia) 0.9970
WOBBE Index 701.7
H1 = Sample analysis performed past holding time. See case narrative.

BTU/lb
BTU/ft3
BTU/ft3
BTU/lb
Result
Volume %
Mole %
BTU/ft3
BTU/ft3
ft3/lb
Result
Weight %
ppmV
9 of 9
Attachment 1

1 Reso No. ______ (CM)
Meeting Date: 090826 SWZ ______ TV ______ PWU ______
RESOLUTION NO. (CM)

A RESOLUTION OF THE CITY COUNCIL OF THE CITY OF

WATSONVILLE AUTHORIZING FOR IMPLEMENTING THE CITY OF

WATSONVILLE ENERGY INFRASTRUCTURE MODERNIZATION
PROGRAM PURSUANT TO GOVERNMENT CODE SECTIONS 4217.10
THROUGH 4217.18, MAKING CERTAIN FINDINGS AND AUTHORIZING

AND DIRECTING CITY MANAGER TO EXECUTE THE FIRST

AMENDMENT TO THE ENERGY SERVICE AGREEMENT WITH

CLIMATEC AND RELATED DOCUMENTS AND FUNCTIONS AS

NECESSARY TO CARRY OUT THE PROGRAM CONTEMPLATED

THEREIN, SUBJECT TO SUCH MINOR CHANGES THERETO AS THE

CITY MANAGER OR CITY ATTORNEY MAY REQUIRE AND APPROVE
WHEREAS, it is the policy of the State of California and the intent of the State Legislature to promote all feasible means of energy conservation, efficiency and renewable energy generation; and
WHEREAS, Government Code sections 4217.10 through 4217.18 allows local governments the greatest possible flexibility to structure alternate energy and energy conservation projects when the governing body determines that such an agreement is in the best interest of the public agency; and
WHEREAS, the City of Watsonville ("City") finds it to be in the best interests of the City to implement projects to promote energy efficiency and renewable energy to achieve reduction of greenhouse gas emissions and other threats to overall environmental health and viability; and
WHEREAS, Government Code sections 4217.10 through 4217.18 authorize the City to enter into an energy service agreement if the anticipated implementation cost is less than the anticipated marginal cost of thermal, electrical, or other energy that would have been consumed by the City in the absence of the agreement; and WHEREAS, on September 24, 2024, the City issued a public Request for Proposals for Citywide Energy Savings and Infrastructure Modernization Program

2 Reso No. ______ (CM)
Meeting Date: 090826
Services with a proposal submission deadline of October 11, 2024; and WHEREAS, the City received four responsive proposals prior to the submission deadline, and one additional proposal after the submission deadline which was deemed non-responsive and not reviewed further; and
WHEREAS, after careful review and evaluation of all proposals received in accordance with the RFP selection guidelines, the proposal submitted by Bosch Building Technologies, LLC, by and through its wholly owned brand Climatec (“Climatec”) was found to be the most qualified, best approach to energy savings program development and implementation, and to provide the best value to the City; and
WHEREAS, after review by City Attorney, City Manager approved an Energy Services Agreement (“Agreement”) with Climatec on January 28th, 2025, authorizing program development with the intent to amend the agreement for implementation once the scope of work was defined; and
WHEREAS, Climatec collaborated with City staff to assess the feasibility of various energy conservation measures to reduce the City’s energy consumption and cost and coauthored an implementation scope of work and funding plan (“Program”) to meet the City’s needs as set forth in the First Amendment and Program Overview; and
WHEREAS, consistent with the requirements of Government Code Section 4217.12, the “Program Overview” (attached hereto as Exhibit A, and incorporated herein by reference), as well as the staff report accompanying this resolution identifies the anticipated cost to provide the program of approximately $30,908,268 (over 23

3 Reso No. ______ (CM)
Meeting Date: 090826
years) is less than the anticipated cost savings over the same period of approximately $36,455,257; and
WHEREAS, the City prepared the First Amendment to the Energy Services Agreement with Climatec to authorize implementation of the Program which includes design, equipment procurement, and construction for the not-to-exceed price stated therein; and
WHEREAS, based on Climatec’s analysis, City staff determined the anticipated cost to implement the Program will be less than the anticipated marginal cost to the City for thermal, electrical, and other energy that would have been consumed in absence of the Program; and
WHEREAS, a public hearing has been held, public notice of which was given for at least two (2) weeks in advance, to receive public comment on the proposed Program and associated Agreement, as required by Government Code section 4217.12; and

NOW, THEREFORE, BE IT RESOLVED BY THE CITY COUNCIL OF THE CITY OF WATSONVILLE, CALIFORNIA, AS FOLLOWS:

1. The Council finds and declares that all the recitals contained herein are true and correct, and adopted by this reference as findings of the Council.

2. The Council finds, as summarized in the Program Overview (Exhibit A), that the anticipated cost of the First Amendment to the Energy Services Agreement for the Program provided by Climatec, including costs for thermal or electrical energy or conservation services, will be less than the anticipated marginal cost to the City of thermal, electrical, or other energy that would have been consumed by the City in the absence of the Program and that it is in the best interest of the City to approve and enter into the First

4 Reso No. ______ (CM)
Meeting Date: 090826
Amendment to the Energy Services Agreement.

3. The forms of the First Amendment to the Energy Services Agreement by and between the City and Bosch Building Technologies LLC, by and through its wholly owned brand Climatec, attached hereto and incorporated herein by this reference, are hereby approved, subject to final approval by the City Manager and City Attorney. City Manager is hereby authorized and directed, for and in the name of and on behalf of the City, to execute the First Amendment to the Energy Services Agreement and related documents and functions as necessary to carry out the Program contemplated therein, subject to such minor changes thereto as the City Manager may require and approve. ********************************

CITY OF WATSONVILLE | WASTEWATER TREAMENT F ACILITY

ENERGY INFRASTRUCTURE MODERNIZATION PROGRAM
August 24, 2026
PROGRAM OVERV IE W | FINAL SCOPE & FUNDING PLAN

ENERGY GENERATION MEASURES
− On-Site Energy Generation
o Install Mainspring linear generators to generate on-site power and offset PG&E consumption utilizing wastewater-generated biogas as the primary fuel source − Biogas Conditioning System
o To ensure reliable linear generator operation and maximize energy savings, a biogas conditioning system must be installed to remove moisture and contaminants

ENERGY EFFICIENCY MODERNIZATIONS
− New High-Efficiency Turbo Blower
o Replace existing aeration blower with a high-efficiency dual-core turbo blower, including associated controls, valves, startup, and training − Aeration System Improvements
o Replace existing coarse-bubble diffuser system in Aeration Basin No. 4 with a new fine-bubble diffuser system to improve oxygen transfer and treatment efficiency. − Sludge Dewatering Modernization
o Replace existing energy-intensive belt press and polymer pumping system with a new, energy-efficient screw press, polymer preparation and feed pump systems − Secondary Treatment Optimization
o Develop a process model to optimize treatment operations and equipment sizing, reduce airflow demand and blower energy, and identify future savings measures TOTAL INFRASTRUCTURE MODERNIZATIONS $ 20.8 Million
LIFECYCLE SAVINGS $ 36.5 Million

FUNDINGS SOURCES
− Revenue Bond
− Guaranteed Savings
− Federal Incentives
− Utility Incentives
ENVIRONMENTAL BENEFITS 120.3 Million Pounds of CO2Greenhouse Gas (GHG) Emissions Reductions Attachment A

CITY OF WATSONVILLE · WASTEWATER TREATMENT PLANT
How program savings are quantified
The Energy Infrastructure Modernization Program generates two kinds of savings. Energy savings lower the plant's utility bills; operations & maintenance (O&M) savings lower its day-to-day operating costs — such as chemicals, maintenance, and parts, not staffing. Each measure below shows how its savings were calculated and what data was utilized to ascertain guaranteed savings thresholds.

YEAR 1 ENERGY SAVINGS
$795,009
Escalates 5% annually
YEAR 1 O&M SAVINGS
$413,376
Held flat across the term (conservative)
YEAR 1 COMBINED
$1,208,385
Verified annually under M&V
Energy savings O&M savings What the number is based on
1 Renewable Biogas Generation System
On-site energy generation. Three 250 kW Mainspring linear generators produce on-site power from the plant's own wastewater biogas — instead of flaring it — offsetting the majority of the plant's PG&E electricity. A biogas conditioning system removes moisture and contaminants so the generators run reliably. This measure is the largest share of total savings, because it's designed to replace the majority of the plant's purchased power.

ENERGY SAVINGS
On-site generation from biogas offsets the
majority of purchased power.

O&M SAVINGS
Not calculated for this measure (see O&M
note below).

BASIS
Actual PG&E interval data, current
cogen output, available biogas; assumes
≥90% uptime.
2 New High-Efficiency Turbo Blower
Replace the existing ~30-year-old aeration blower with a highefficiency dual-core turbo blower, including associated controls, valves, startup, and training. Because it has two cores and variable speed, it matches airflow to the plant's actual demand and runs efficiently across changing loads — running most of the time while the existing blowers stay on standby for highload periods.

ENERGY SAVINGS
Airflow matched to real demand; far less wasted
blower energy.

O&M SAVINGS
Estimated at 2% of the project amount annually (see O&M note below).

BASIS
Actual 2025 plant and blower load data from facilities staff. 3 Aeration System Improvements
Replace the existing coarse-bubble diffuser system in Aeration Basin No. 4 with a new fine-bubble diffuser system to improve oxygen transfer and treatment efficiency. Smaller bubbles create more surface area and contact time between air and
wastewater, so the biological process reaches its required oxygen levels with less blower airflow — and less energy.

ENERGY SAVINGS
Higher oxygen-transfer efficiency lets blowers run less.

O&M SAVINGS
Estimated at 2% of the project amount annually (see O&M note below).

BASIS
Process model of airflow required versus oxygen demand. 4 Sludge Dewatering Modernization
Replace the existing energy-intensive and aging belt press and polymer pumping system with a new, energy-efficient screw press and polymer preparation and feed pump systems. This is the one measure that saves on both sides: it draws less power than the 40-year-old belt press, and it uses less polymer (a treatment chemical) while requiring less maintenance.

ENERGY SAVINGS
Higher-efficiency press uses less power than the belt press.

O&M SAVINGS
Less polymer use and lower maintenance than the
old press.

BASIS
City's own cost data plus engineering-firm pilot testing. 5 Secondary Treatment Optimization
Develop a wastewater process model to optimize treatment operations and equipment sizing, reducing airflow demand and aeration blower energy while identifying future energy and operational savings. Tuning setpoints — solids retention time, dissolved oxygen, and mixed-liquor suspended solids — lowers the airflow the plant demands.

ENERGY SAVINGS
Optimized setpoints cut airflow demand and blower energy.

O&M SAVINGS
Not separately claimed for this measure.

BASIS
Wastewater process model of optimal operating setpoints.

On the shared O&M estimate. Turbo blower and fine-bubble diffuser O&M savings are estimated at 2% of the project amount annually. The California Energy Commission's (CEC) guidelines allow 3–4% for stipulated assumptions; 2% was applied as a conservative estimate and held flat as a stipulated assumption across the program term.

On the linear generators. No O&M savings are calculated; the existing cogeneration O&M is offset by the O&M required to run the new linear generator.

Verification. Actual savings are measured and verified against these projections each year under the program's Measurement & Verification Agreement and energy savings performance guarantee.

Attachment A

CITY OF WATSONVILLE | WASTEWATER TREATMENT FACILITY 8/24/2026 ENERGY INFRASTRUCTURE MODERNIZATION PROGRAM | CASH FLOW ANALYSIS Total Program Amount $20,849,967
Lifecycle Savings & Grants $36,455,257
Net Program Savings After Debt Service $5,546,989
Construction Duration (months) 36 months
Finance Term (years) 20 years
Annual Escalation of Electricity Cost 5%
Operation & Maintenance (O&M) Savings Assumption | % of Project Amount Per Year ~2% Measurement & Verification (M&V) Escalator Starting in FY 33 4% YEAR
Annual Utility Savings Annual O&M Savings Anticipated Grants Total Inflows Revenue Bond M&V Total Outflows Net Program Impact (Annually)
Net Program Impact
(Cumulatively)
FY 27 $0 $0 $0 $1,203,133 $1,203,133 ($1,203,133) ($1,203,133) FY 28 $0 $0 $0 $1,527,750 $1,527,750 ($1,527,750) ($2,730,883) FY 29 $0 $0 $0 $1,527,500 $1,527,500 ($1,527,500) ($4,258,383) FY 30 $795,009 $413,376 $1,208,385 $1,525,750 $25,000 $1,550,750 ($342,365) ($4,600,748) FY 31 $834,760 $413,376 $1,900,000 $3,148,136 $1,527,500 $25,000 $1,552,500 $1,595,636 ($3,005,112) FY 32 $876,498 $413,376 $1,289,874 $1,527,500 $25,000 $1,552,500 ($262,626) ($3,267,739) FY 33 $920,323 $413,376 $1,333,699 $1,525,750 $26,000 $1,551,750 ($218,051) ($3,485,790) FY 34 $966,339 $413,376 $1,379,715 $1,527,250 $27,040 $1,554,290 ($174,575) ($3,660,365) FY 35 $1,014,656 $413,376 $1,428,032 $1,526,750 $28,122 $1,554,872 ($126,840) ($3,787,206) FY 36 $1,065,388 $413,376 $1,478,764 $1,529,250 $29,246 $1,558,496 ($79,732) ($3,866,937) FY 37 $1,118,658 $413,376 $1,532,034 $1,524,500 $30,416 $1,554,916 ($22,882) ($3,889,820) FY 38 $1,174,591 $413,376 $1,587,967 $1,527,500 $31,633 $1,559,133 $28,834 ($3,860,986) FY 39 $1,233,320 $413,376 $1,646,696 $1,528,500 $32,898 $1,561,398 $85,298 ($3,775,688) FY 40 $1,294,986 $413,376 $1,708,362 $1,525,750 $34,214 $1,559,964 $148,398 ($3,627,290) FY 41 $1,359,736 $413,376 $1,773,112 $1,527,500 $35,583 $1,563,083 $210,029 ($3,417,261) FY 42 $1,427,722 $413,376 $1,841,098 $1,525,500 $37,006 $1,562,506 $278,592 ($3,138,669) FY 43 $1,499,108 $413,376 $1,912,484 $1,525,750 $38,486 $1,564,236 $348,248 ($2,790,420) FY 44 $1,574,064 $413,376 $1,987,440 $1,528,000 $40,025 $1,568,025 $419,415 ($2,371,006) FY 45 $1,652,767 $413,376 $2,066,143 $1,527,000 $41,627 $1,568,627 $497,516 ($1,873,490) FY 46 $1,735,405 $413,376 $2,148,781 $1,529,000 $43,292 $1,572,292 $576,489 ($1,297,000) FY 47 $1,822,176 $413,376 $2,235,552 $45,024 $45,024 $2,190,528 $893,527 FY 48 $1,913,284 $413,376 $2,326,660 $46,825 $46,825 $2,279,835 $3,173,363 FY 49 $2,008,949 $413,376 $2,422,325 $48,698 $48,698 $2,373,627 $5,546,989 TOTALS $26,287,737 $8,267,520 $1,900,000 $36,455,257 $30,217,133 $691,135 $30,908,268 $5,546,989 $5,546,989

PROGRAM INFLOWS PROGRAM OUTFLOWS CASH FLOW
Attachment A

ALL INCLUDED CONTENTS PRODUCED BY CLIMATEC ARE AGREED TO BE PROPRIETARY AND CONFIDENTIAL AND NOT TO BE SHARED WITH ANY NON-CITY PERSONNEL

C ITY OF W ATSONVILLE

E NERGY INFRASTRUCTURE MODERNIZATION P ROGRAM
U TILITY A NALYSIS |W ATER , W ASTEWATER & S TREET L IGHTING 8/26/2026 U TILITY B ASELINE P ERIOD : J ANUARY 2024 - D ECEMBER 2024 Site Name Square
Footage
PG&E Electric PG&E Gas All Utilities
Dollars kWh $/ kWh Dollars Therms $/ Therms Dollars
$/ Ft²
(Elec/ Gas)
Booster Stations - $89,981 185,806 $0.48 $41,790 29,846 $1.40 $131,771 - Corralitos Water Filter Plant - $128,707 334,933 $0.38 $119 10 $11.94 $128,826 - Irrigation Controllers - $1,542 1,110 $1.39 - - - $1,542 - Landfill 2,460 $14,029 34,203 $0.41 - - - $14,029 $5.70 Misc. Lighting (B) - $27,026 60,580 $0.45 $99 - - $27,125 - Sewer Pumps - $47,688 112,265 $0.42 - - - $47,688 -
Stom Pumps - $36,960 73,073 $0.51 - - - $36,960 -
Street Lights (LS1) - $3,890 4,114 $0.95 - - - $3,890 - Street Lights (LS2) - $241,988 678,927 $0.36 - - - $241,988 - Street Lights (TC1) - $35,312 85,193 $0.41 - - - $35,312 - Wastewater Treatment Plant - $1,555,030 5,885,828 $0.26 $18,424 41,402 $0.44 $1,573,454 - Water Resource Center 16,000 $56,978 161,330 $0.35 - - - $56,978 $3.56 Water Wells - $997,498 2,927,734 $0.34 $502 262 $1.92 $998,000 - Totals 461,931 $4,250,679 13,529,565 $0.31 $171,680 136,636 $1.26 $4,422,359 - Attachment A

ALL INCLUDED CONTENTS PRODUCED BY CLIMATEC ARE AGREED TO BE PROPRIETARY AND CONFIDENTIAL AND NOT TO BE SHARED WITH ANY NON-CITY PERSONNEL

C ITY OF W ATSONVILLE

E NERGY INFRASTRUCTURE MODERNIZATION P ROGRAM
U TILITY A NALYSIS |T OP C ONSUMER S 8/26/2026
T OTAL U TILITY E XPENDITURES |T OP 1 0 S ITES
Site Name PG&E
Electric
PG&E
Gas
All
Utilities
Wastewater Treatment Plant $1,555,030 $18,424 $1,573,454 Water Wells $997,498 $502 $998,000
Civic Plaza / Library $407,793 $46,755 $454,548
Streetlights (LS2) $241,988 - $241,988
Airport Facilities $134,050 $4,708 $138,758
Booster Stations $89,981 $41,790 $131,771
Corralitos Water Filter Plant $128,707 $119 $128,826
Police Station $115,558 $10,600 $126,158
Civic Plaza Parking Structure $60,805 - $60,805
Water Resource Center $56,978 - $56,978
TOTALS $3,788,388 $122,898 $3,911,286
Wastewater
Treatment Plant
$1,573,454
Water Wells
$998,000
Civic Plaza /
Library
$454,548
Streetlights (LS2)
$241,988
Airport Facilities
$138,758
Booster Stations
$131,771
Corralitos Water Filter Plant
$128,826
Police Station
$126,158
Civic Plaza Parking Structure
$60,805
Water Resource Center
$56,978
T OTAL U TILITY E XPENDITURES | TOP 10 S ITES
Attachment A

ALL INCLUDED CONTENTS PRODUCED BY CLIMATEC ARE AGREED TO BE PROPRIETARY AND CONFIDENTIAL AND NOT TO BE SHARED WITH ANY NON-CITY PERSONNEL

C ITY OF W ATSONVILLE

E NERGY INFRASTRUCTURE MODERNIZATION P ROGRAM
U TILITY A NALYSIS |T OTAL S PE ND BY U TILITY & C ATEGORY 8/26/2026 PG&E Gas
$171,680
PG&E Electric
$4,250,679

A NNUAL E XPENDITURE BY U TILITY
Parks
$48,361
Buildings
$989,882 Street Lights
$308,315
Wastewater
$1,672,131 Water
$1,315,575
Parking
Structures
$88,095

A NNUAL E XPEDITURE BY C ATEGORY
T OTAL U TILITIES : $ 4,422,359 Attachment A

C ITY OF W ATSONVILLE

E NERGY INFRASTRUCTURE MODERNIZATION P RO GRAM
E NERGY MASTER P LAN |D ETAILED A SSESSMENT 08/25/2026

WASTE WATER TREATMENT PLANT & SYSTEM
Phase I
Future
Phase
Secondary
Treatment
Optimization
New High
Efficiency
Turbo Blower
Aeration System
Improvements
Modernize
Digester Mixing
Systems
Expand
Digester
Heating
System
New Bladder
Style Tank
System
(2W System &
Effluent Pump
Station)
New UF/NF
Member System
(Recycling
Plant)
New High
Efficiency
Thickener
Pump VFDs &
Control
Upgrades
(Gravity
Thickener)
Add New FOG
Receiving
Station
(Digester 1)
New High
Efficiency
Pumps w/ VFDs
(Trickling
Filters)
Biosolids
Master Plan
(Class A vs
Class B)
Sludge
Dewatering
Modernization
Wastewater
Treatment
Plant
            

WATER DISTRIBUTION SYSTEM
FOWLE (Freedom)
Booster Pump Station
Airport (Burchell)
Booster Pump Station
Hames
Booster Pump Station
Hydraulic
Model
   
Renewable
Biogas
Generation
System
Attachment A

Prioritized Infrastructure Needs
Sludge Dewatering
System Fine Bubble
Diffusers
Biogas
Conditioning/ Gas
Scrubber System
High Efficiency
Aeration Turbo
Blowers
Secondary System
Process Model
Linear
Generators (LG) to
Replace Cogen
Attachment A

Blower
Blower Room
Fine Bubbles Coarse Bubbles
Existing Infrastructure
Attachment A

Existing Infrastructure
Belt Press
Polymer Tank
Polymer Pumps
Attachment A

Existing Infrastructure
Cogeneration System Attachment A

City of Watsonville
First Amendment

First Amendment
To
Energy Services Agreement
Between
City of Watsonville
and
Bosch Building Technologies LLC
This First Amendment to the Energy Services Agreement is between City of Watsonville (“City”) and Bosch Building Technologies LLC, by and through its wholly owned brand Climatec (“Contractor”), collectively the (“Parties”), dated January 28, 2025 (“Agreement”) is made effective as of September 8, 2026 (“Effective Date”).

The CITY and CONTRACTOR each may be referred to herein as a “Party” and collectively as the “Parties.”
WHEREAS the Parties desire to amend the Agreement to include additional services for the Project (Implementation/Construction) as described in “Attachment A” to this First Amendment, which is attached hereto and incorporated by this reference.

A. The Contractor will furnish all the Work described in “Attachment A” to this First Amendment.

B. All other terms of the Agreement not referenced in this First Amendment shall remain unchanged; in full force and effect. In the event of a conflict between a provision of the Agreement and this First Amendment, this First Amendment shall prevail.

C. This First Amendment and the Agreement, together with any attachments or other documents described or incorporated therein, if any, constitute the entire Agreement and understanding of the Parties, and there are no other terms or conditions, written or oral, controlling this matter.

D. This First Amendment may be executed on separate counterparts that, upon completion, may be assembled into and shall be construed as one document. Delivery of an executed signature page of this First Amendment by electronic means, including an attachment to an email, shall be effective as delivery of an executed original.

NOW, THEREFORE, in consideration of the mutual covenants, promises, terms, and conditions set forth in the original Energy Services Agreement and in the First Amendment, the Parties hereby agree as follows:

1. INSTALLATION. Contractor shall provide City with an Energy Infrastructure

City of Watsonville
First Amendment

Modernization and Utility Savings Program, as identified in Attachment(s) A and B (the “Work”) and incorporated herein by reference at the total fixed price of Twenty million eight hundred forty-nine thousand nine hundred sixty-seven dollars and 00/100 ($20,849,967.00) including required taxes and performance bond.

Contractor is responsible for the design, engineering, permits, fees, approvals, project management, installation, startup, training, checkout, warranty, and insurance specifically associated with the Work to be performed. Contractor is not responsible for any equipment, systems, controls, comfort problems, balancing, duct cleaning, existing deficient conditions, etc. not specifically included in this Agreement. Contractor will provide submittals and engineered drawings (if required), for City’s technical review and written approval, prior to initiating construction. All construction and associated cleanup shall be performed and scheduled to minimize any disruption with any ongoing City activities. Contractor shall keep the Site(s) in order and shall maintain a reasonably clean condition and always provide the City with safe and proper access to all Work.

2. TERM. The term of this agreement shall be from the Effective Date of the Agreement through Final Completion, which shall be date mutually agreed upon by the Parties based on the construction schedule of the project. This will be determined once the initial design is completed and materials are ordered, but shall not exceed thirty-six (36) months from the date of the execution of this amendment, unless otherwise modified by an executed change order or further amendment.

3. SCOPE OF WORK. The Scope of Work is more fully described in “Attachment A”. Once this Agreement is executed by the City and Contractor, Contractor may not revise the Agreement in any way except by mutual written agreement with the City.

Contractor shall keep the Site(s) in order when Work is being performed and shall maintain the Site(s) in a reasonably clean condition. The City shall always have access to the Work. Contractor will maintain safety in the performance of the Work and shall erect and maintain, as required by conditions and progress of Work, all necessary safeguards including necessary permits, signs, barriers, lights, and security persons for protection of workers and the public and shall post danger signs warning against hazards created by the Work.

This Agreement is based upon the use of straight time labor only unless stated otherwise in this Agreement. The City agrees to provide Contractor with required field utilities (electricity and water) without charge. Contractor is responsible for running electricity from the source to the construction site and providing portable toilet facilities and having them serviced. Contractor agrees to keep the job site clean of debris arising out of its own operations. Except as provided herein, City shall not back charge Contractor for any cost or expenses without Contractor’s written consent. Unless specifically noted in “Attachment A” or services undertaken by Contractor under this Agreement, Contractor’s obligations under this Agreement expressly exclude any work or service of any nature associated or connected with the identification, abatement, clean up, control, removal or disposal of environment hazards or dangerous substances, to include but not to be limited to asbestos, PCBs, or mold discovered in or on the premises. However, if any hazardous materials are found the City has the option to have a third party remediate the hazardous materials or under a separate agreement the Contractor provide

City of Watsonville
First Amendment

remediation at the job site(s). Any language or provision of the Agreement elsewhere contained which may authorize or empower the City to change, modify, or alter the scope of work or services to be performed by Contractor shall not operate to compel Contractor to perform any work relating to hazards without Contractor’s express written consent.

4. INVOICING & PAYMENTS. Contractor may invoice the City for any equipment and/or materials installed at a job site. City may require statutory conditional waivers and releases on progress payments for the current payment and statutory unconditional waivers and releases on progress payments for amounts previously paid, in the forms required by Civil Code sections 8132 and 8134, as applicable.. City shall pay any undisputed and properly submitted progress payment request within thirty (30 days after receipt. Any payment request that the City reasonably determines is not a proper payment request shall be returned to Contractor as soon as practicable , with a written statement of the reason(s) the payment request is not proper, in accordance with Public Contract Code 20104.50. Except for amounts in dispute, City shall retain 5% from all payments as retention in accordance with Public Contract Code Section 7107. Final Payment, including retention withheld, will be due in accordance with Public Contract Code 7107, or as otherwise provided by law. If Contractor’s undisputed invoice is not paid within forty-five (45) days of its issuance, interest shall accrue at the legal rate specified in that section.

5. SUBCONTRACTORS. Contractor shall submit to the City in writing a list of any subcontractors engaged by the Contractor for any Work for the City’s prior written approval, not to be unreasonably withheld. Contractor agrees to bind every subcontractor by the terms of this Contract, including, without limitation, indemnification, insurance, business license, and warranty requirements. Contractor shall be fully responsible to City for the Work of its subcontractors and persons directly or indirectly employed by them. The Contract shall not create any contractual relationship between any subcontractor and City.

Contractor and all subcontractors performing the work shall not employ any person who is unfit or unskilled in assigned Work. Contractor and/or subcontractor shall dismiss any person whom City deems incompetent or unfit.

6. MATERIALS. All materials shall be new, in compliance with all applicable laws and codes, and shall be covered by a manufacturer’s warranty, if appropriate. If the materials or equipment included in this Agreement become temporarily or permanently unavailable, the time for performance of the Work shall be extended to the extent thereof, and in case of permanent unavailability, Contractor shall (a) be excused from furnishing said materials or equipment, and (b) be reimbursed for the difference between the cost of the materials or equipment permanently unavailable and the cost of a reasonable substitute, therefore. In the case of the linear generators which are proprietary equipment only available from one vendor, should the equipment become permanently unavailable, any deposit paid by the City for the procurement of this equipment shall be returned.

7. OWNERSHIP. Title to the Equipment/Materials (or portion thereof) shall pass free and clear to the City from the Contractor upon final payment by the City for the Equipment/Materials, Work or Services corresponding to such Equipment.

8. COMPLETION. The Work shall be considered completed upon approval by the City,

City of Watsonville
First Amendment

provided that the City’s approval shall not be unreasonably withheld. The nature of the Work is that it consists of multiple projects and/or sites, as noted in Attachment A. Once work on a project or a site is deemed by Contractor to be substantially complete (that is available for beneficial use by the City with the Scope of Work for that site or project functioning as required) except for minor items (a punch list), Contractor will provide a Notice of Substantial Completion for that site or project to the City for acceptance. Final Completion, as previously noted, will occur once the entire Scope of Work is complete for all sites and projects and City has provided written acceptance of Final Completion.

9. SITE ACCESS. City shall provide Contractor with reasonable and uninterrupted access to the Project site(s) during the hours necessary to perform the Work efficiently and in accordance with the Project schedule. The City has a Headworks and Influent Pump Station project set to begin in the spring of 2027; the Contractor will need to coordinate with the City and other contractor for site access and staging space. Unless otherwise specified in the Contract Documents, Contractor shall have access to the site during normal working hours, Monday through Friday, and during such additional hours, including evenings, weekends, or holidays, as may be reasonably required to maintain the Project schedule and approved by the City. If access to the site is restricted, delayed, or otherwise limited by Owner or third parties beyond Contractor's control, Contractor shall be entitled to an equitable adjustment of the Contract Time and, where applicable, the Contract Sum for any resulting impacts, delays, inefficiencies, or additional costs.

10. CORRECTION OF ERRORS. Contractor shall perform, at its own cost, without reimbursement from the City, any work necessary to correct errors or omissions caused by Contractor’s failure to comply with the standard of care required herein.

11. WARRANTY. Contractor warrants that the equipment and systems provided under this Agreement shall be free from defects in material and workmanship arising from normal usage for a period of one (1) year from the date of beneficial use. Within the warranty period, if City provides written notice to Contractor of any such defects within thirty (30) days after the appearance or discovery of such defect, Contractor shall, at its option, repair or replace the defective equipment and return said equipment to City. These warranties do not extend to any equipment which has been repaired by others, abused, altered, misused, or which has not been properly and reasonably maintained. All transferable manufacturer warranties associated with the equipment will be transferred to the City. Nothing in this Section limits any other express warranty, guarantee, performance obligation, or standard required by the Agreement or other Contract Documents.

12. TERMINATION.
a. Termination for Cause - The City may terminate the Contractor and/or this Contract for the following reasons: persistently or repeatedly refuses or fails to supply enough properly skilled workers or proper materials; persistently or repeatedly is absent, without excuse, from the job site; fails to make payment to subcontractors, suppliers, materialmen, etc.; persistently disregards laws, ordinances, rules, regulations, or orders of a public authority having jurisdiction; falls behind on the Project and refuses or fails to undertake a recovery schedule; if the Contractor has been debarred from performing work; becomes bankrupt or insolvent, including the filing of a general

City of Watsonville
First Amendment

assignment for the benefit of creditors; Contractor or any of its subcontractors are not properly registered with the Department of Industrial Relations (“DIR”) at all times; or is otherwise in breach of a provision of the Contract Documents. If any of the above reasons exist, the City may, without prejudice to any other rights or remedies of the City and after giving the Contractor written notice of five (5) days, terminate the Contractor and/or this Contract. If the City terminates the Contract for one of the reasons stated above, the Contractor shall not be entitled to receive further payment until the Project is complete. All costs associated with the termination and completion of the Project shall be the responsibility of the Contractor. If the unpaid balance of the Contract Sum exceeds costs of completing the Project, including compensation for services and expenses made necessary thereby, such excess shall be paid to the Contractor. If such costs exceed the unpaid balance, the Contractor shall pay the difference to the City. The amount to be paid to the Contractor, or City shall be certified upon application. This payment obligation shall survive completion of the Contract.
b. Termination for Convenience - City may terminate the Contract upon thirty (30) days written notice to the Contractor and use any reasonable method the City deems expedient to complete the Project, including contracting with replacement contractor or contractors, if it is found that reasons beyond the control of either the City or Contractor make it impossible or against the City’s interest to complete the Project. In such case, the Contractor shall have no claims against the City except for: (1) the actual cost for approved labor, materials, and services performed in accordance with the Contract Documents which have not otherwise been previously paid for and which are supported and documented through timesheets, invoices, receipts, or otherwise; and (2) profit and overhead of ten percent (10%) of the approved costs in item (1); and (3) termination cost of five percent (5%) of the approved costs in item (1).

13. DELAYS. Contractor shall not be liable for any delay in the performance of the Work resulting from or attributed to acts of circumstance beyond Contractor’s control, including but not limited to acts of God, riots, labor disputes, conditions of the premises, acts or omissions of the City, or other contractors or delays caused by suppliers or subcontractors of Contractor, etc. If City delays project for greater than sixty (60) days, Contractor can recover any cost inflation on un-billed materials that were either stored or yet to be purchased.

14. REBATES & UTILITY INCENTIVES. Unless otherwise stated in the Agreement, or cash flow analysis, any and all rebates, incentives that are earned through the course of this project from public or private utilities, municipalities, development agencies, or state funding, except for lighting rebates, are one hundred percent (100%) the property of the City or their designee.

Lighting rebates are one hundred percent (100%) the property of Contractor and are used to reduce the project cost to the City. The paperwork, inspections and verification required to collect these monies (except for lighting rebates) are the sole responsibility of the City.

15. LABOR CODE REQUIREMENTS. If the Contract Price is more than $1,000, and the Work is a “public works” as defined in the Labor Code including, without limitation, §§ 1720 - 1720.6 and 1771 then this subsection applies. City hereby provides notice of the requirements

City of Watsonville
First Amendment

described in Labor Code § 1771.1(a) that a contractor or subcontractor shall not be qualified to bid on, be listed in a bid proposal, or engage in the performance of any contract for public work, unless currently registered and qualified to perform public work pursuant to Labor Code § 1725.5. Contractor acknowledges that all or a portion of the Services under this Contract are a public work, and that it and its subcontractors have complied with Labor Code § 1725.5, including, without limitation, the registration requirements thereof. Contractor shall post all required job site notices and shall comply with all applicable requirements prescribed thereby, including but not limited to Labor Code § 1771.4. Contractor shall comply with all applicable provisions of Chapter 1 of Part 7 of Division 2 of the Labor Code (Section 1720 et seq.) and California Code of Regulations, Title 8, Chapter 8, Subchapters 3-6 (Section 16000 et seq.) Willful failure to comply may result in penalties, including loss of the right to bid on or receive public works contracts. Copies of the prevailing rate of per diem wages are on file with the City and available on the DIR website. Monitoring and enforcement of the prevailing wage laws and related requirements will be performed by the Labor Commissioner/ Department of Labor Standards Enforcement (DLSE). The Contractor and all subcontractors shall furnish certified payroll records as required pursuant Labor Code § 1776 directly to the Labor Commissioner in accordance with Labor Code § 1771.4 on at least a monthly basis (or more frequently if required by the City or the Labor Commissioner) and in a format prescribed by the Labor Commissioner.

The Contractor and all Subcontractors shall comply with the provisions of California Labor Code including, but not limited to sections 1777.5, 1777.6, and 1777.7 concerning the employment of apprentices. The Contractor and all subcontractors shall comply with the requirements of said sections, including applicable portions of all subsequent amendments in the employment of apprentices; however, the Contractor shall have full responsibility for compliance with said Labor Code sections, for all apprenticeable occupations, regardless of any other contractual or employment relationships alleged to exist.

Contractor and each subcontractor shall comply with Labor Code section 1775 and sections 1810 through 1815. Pursuant to Labor Code section 1813, Contractor or subcontractor shall, as a penalty to the City, forfeit twenty-five dollars ($25) for each worker for each calendar day during which the worker is required or permitted to work more than eight (8) hours in any one calendar day or forty (40) hours in any one calendar week in violation of those provisions.

Overtime work may be performed as permitted by Labor Code section 1815. Before commencing Work, Contractor shall sign and file with the City the certification required by Labor Code section 1861.

16. DISPUTES. All labor related disputes shall be governed by the Project Labor Agreement that is in effect. For all other disputes, the Dispute Resolution Provisions require that each Claim be in writing, served on the other party, describing specific details of the dispute relating to changes in Work or claim for additional compensation, within seven (7) days of the occurrence of the condition. This notice must be provided via certified mail. For a reasonable period commencing on the day written notice of dispute was provided, but not to exceed thirty (30) days, the parties shall in good faith attempt to resolve the dispute. If the parties are unable to resolve the Dispute during this period, the parties shall proceed as required by Public Contract Code Sections 9204 and 20104, et seq. Effective January 1, 1991, Section 20104 et seq., of the Public Contract Code prescribes a process utilizing informal conferences, non-binding judicial supervised mediation, and judicial arbitration to resolve disputes on construction claims of $375,000 or less. Effective

City of Watsonville
First Amendment

January 1, 2017, Section 9204 of the Public Contract Code prescribes a process for negotiation and mediation to resolve disputes on construction claims. The intent of this Section is to require that the parties hereto proceed to resolve any disputes in accordance with the procedures set forth in Sections 9204 and 20104.

In addition to any and all contract requirements pertaining to notices of and requests for compensation or payment for extra work, disputed work, claims and/or changed conditions, Contractor must comply with the claim procedures set forth in Government Code section 900, et seq., prior to filing any lawsuit against the City.

17. CHANGE ORDER (Mid-Performance Amendments).

Contractor and the City recognize that:
a. City may desire a mid-job change in the specifications or scope that would add time and cost to the specified work or inconvenience Contractor. b. Other provisions of the Agreement may be difficult to carry out because of unforeseen events, such as material shortage or force majeure events.

If these or other events beyond the control of the parties require adjustments to this Agreement, the parties shall make a good faith attempt to agree on all necessary particulars.

Such agreements shall be put in writing, signed by the parties, and added to this Agreement.

Failure to reach agreement shall be deemed a dispute to be resolved as agreed in section 16 of this Agreement.

18. PAYMENT & PERFORMANCE BONDS. Contractor shall not commence Work until it has provided to the City, a Payment (Labor and Material) Bond and a Performance Bond, each in an amount equivalent to 100% of the Contract Price issued by an admitted surety as defined in Code of Civil Procedure § 995.120.

19. OCCUPANCY. City may occupy buildings before Contract completion and occupancy shall not constitute acceptance of any Work, nor shall occupancy extend the Contract completion date.

20. PROTECTION OF WORK & PROPERTY. Contractor shall erect and properly maintain, as required by conditions and progress of the Work, all necessary safeguards, signs, barriers, lights, and security persons for protection of workers and the public, and shall post danger signs warning against hazards created by the Work. In an emergency affecting life and safety of life or of Work or of adjoining property, Contractor, without special instruction or authorization from the City, is permitted to act at its reasonable discretion to prevent such threatened loss or injury. In the event of such action, once action has been taken, Contractor shall notify the City in writing as soon as reasonably possible of the action it took and the reasons for such action. City maintenance staff shall have access to perform their duties at all times. Any shutdowns or tie ins shall be coordinated with the City. The Contractor shall not operate any valves or any City owned equipment.

Once equipment is installed and permanently affixed to the property and the City has provided written acceptance of beneficial use, it should be treated as the City's property and secured accordingly, even if title has not passed.

City of Watsonville
First Amendment

21. ENTIRE AGREEMENT. This Amendment along with the Agreement, upon acceptance, shall constitute the entire Agreement between the Parties and supersedes any prior representations or understandings.

22. CHANGES. No change or modification of any of the terms and conditions stated herein shall be binding upon either Party unless accepted by both Parties in writing

23. SEVERABILITY. If one or more of the provisions of this Agreement are held to be unenforceable under laws, such provision(s) shall be excluded from these terms and conditions and the remaining terms and conditions shall be interpreted as if such provision were so excluded and shall be enforced in accordance with their terms and conditions.

24. COUNTERPARTS. This Agreement may be executed in multiple counterparts, each of which shall be deemed an original and all of which together shall constitute one and the same instrument. A signature on a copy of this Agreement received by either party by facsimile or portable document format (PDF) is binding upon the other party as an original. The Parties shall treat a photocopy of such facsimile as a duplicate original.

25. ASSIGNMENT. Contractor retains the right to assign its rights and obligations of this Agreement with written consent of City.

26. CONFIDENTIALITY. Contractor shall maintain confidentiality of all information, documents, procedures, and other items Contractor encounters while performing Work to the extent allowed by law. This requirement shall survive expiration or termination of the Contract and includes sensitive municipal and personnel information.

27. ANTI-TRUST CLAIM. Contractor and its subcontractor(s) assign to City all rights, title, and interest to all causes of action under § 4 of the Clayton Act (15 U.S.C. Sec. 15) or under the Cartwright Act (Chapter 2 (commencing with § 16700) of Part 2 of Division 7 of the Business and Professions Code), arising from purchases of goods, services, or materials pursuant to a contract or subcontract. This assignment shall become effective when City tenders final payment to Contractor, without further acknowledgment.

28. GOVERNING LAW. The Contract shall be governed by and construed in accordance with California laws with venue in the City’s County.

29. PROVISIONS REQUIRED BY LAW DEEMED INSERTED. Every provision required by law to be in the Contract shall be deemed to be inserted and the Contract shall be read and enforced as though included.

30. ANTI-DISCRIMINATION. In connection with any City Contract, there shall be no discrimination against any employee because of race, religious creed, color, national origin, ancestry, physical disability, mental disability, medical condition, genetic information, marital status, sex, gender, gender identity, gender expression, age, sexual orientation, or military and veteran status. Contractor agrees to comply with applicable laws including, but not limited to, the California Fair Employment and Housing Act (Gov. Code § 12900 et seq.) and Labor Code

City of Watsonville
First Amendment

§ 1735. Contractor shall require like compliance by all subcontractor(s).

31. INVALID TERM. If a Court determines any Contract term to be illegal, invalid, or unenforceable (“Illegal Term”), the legality of the remaining terms shall not be affected, and the Illegal Term will not be part of the Contract.

WHEREFORE, this First Amendment and the Agreement, together with any attachments or other documents described or incorporated therein, if any, constitute the entire agreement and understanding of the Parties, and there are no other terms or conditions, written or oral, controlling this matter.

WHEREFORE, this First Amendment may be executed on separate counterparts that, upon completion, may be assembled into and shall be construed as one document. Delivery of an executed signature page of this First Amendment by electronic means, including an attachment to an email, shall be effective as delivery of an executed original.

WHEREFORE, unless a different date is provided in this First Amendment, the effective date of this First Amendment shall be the latest date of execution set forth by the names of the signatories below.

IN WITNESS WHEREOF, this First Amendment is executed by the Parties or their duly authorized representatives as of the Effective Date
City of Watsonville Bosch Building Technologies LLC
_____________________________ _______________________________ Signature Signature
_____________________________ _______________________________ Printed Name Printed Name
_____________________________ _______________________________ Title Title
_____________________________ _______________________________ Date Date

City of Watsonville
Attachment A - Scope of Work

Attachment “A”
Scope of Work

City of Watsonville
Attachment A - Scope of Work

Wastewater Infrastructure Upgrades
Secondary Treatment System Optimization Model: Develop and calibrate a steady-state process model for the existing WWTP that allows for evaluation of operational optimization strategies for the secondary treatment system, which includes both trickling filters and activated sludge systems. Model to include confirmation of new blower sizing and account for Aeration Basin #4 diffuser replacement
• The model will be developed using GPS-X wastewater process simulator. • The process model will be used to simulate up to three (3) operational scenarios within the secondary treatment system to identify potential cost savings while complying with regulatory requirements.
• Draft and final versions of a process model report will be prepared and submitted to document the model development, input parameters, assumptions, water quality, and operational data used for calibration, as well as process modeling results. The final report will also summarize the results of simulated operational scenarios with associated cost savings.

Assumptions:
• Data to be provided by City (minimum one-year of data and up to three years)
• Raw wastewater influent BOD, cBOD, COD, TKN, ammonia, and TSS. • BOD, cBOD, COD, TKN, ammonia, and TSS upstream and downstream of major unit processes.
• Daily influent flows (in MGD).
• Influent wastewater temperatures (daily or continuous) • Influent TSS, BOD (or COD), ammonia, and TKN.
• Activated sludge system SRT (or MCRT), DO concentrations, and MLSS concentrations.
• Primary sludge, RAS, and WAS rates and concentrations. • Physical (dimensional) characteristics of each process area. • Belt filter filtrate flowrate and water quality data, and dewatering schedule. • At a minimum, the process model requires influent COD and nitrogen data, data to evaluate TSS removal efficiencies in the primary clarifiers, data to understand WAS mass loading, and MLSS within the process tanks. In addition, a diurnal sampling program may be requested to understand model peak loading conditions for final blower sizing during detailed design to evaluate diurnal equalization scenarios.

City of Watsonville
Attachment A - Scope of Work

• If there is insufficient data to provide accurate model inputs, a sampling plan implementation may be requested by the City. A composite sampler can be provided for use by the City.

Aeration Blowers Upgrades: Replace one existing aeration blower with one (1) NX150D-C070 dual core blower
• Replace one (1) 150 hp blower (F-ME-7 or F-ME-6) with one (1) new Neuros dual core blower. Existing blower and control panel to be demolished and disposed of. • VFDs to be provided with blower package, blower to have PLC based local control panel for control and monitoring.
• Existing soft-start panel to be demolished, existing blower breaker to be used for new blower
• Check valves, butterfly valves, and expansion joints to be supplied by APG Neuros.

Product data and technical information to be provided as a submittal. • Installation review, Start-up, and Training services provided by blower manufacturer Clarifications:
• Existing Master PLC for blowers to be reconfigured to communicate with APG Neuros control panel, programming by others.
• Exclusions:
• Modifications to existing blower building HVAC and ventilation systems.
• Modifications to the existing 100 hp blower and 150hp Neuros Turbo Blower (F-ME-5 & F-ME-4)
• SCADA programming
Aeration Basin #4 Coarse Bubble Diffuser Replacement
• Demolish and dispose of existing coarse bubble diffuser system, including piping and supports, up to isolation valve for aeration zone.
• Add gate isolation valve at air supply (above basin) similar to existing basins #5 & #6.
• Replace coarse bubble diffusers with fine bubble diffusers including piping and supports (SSI Aeration 9” AFD270) – Aeration Basin 4.
• Manufacturer Field Services: Installation inspection, and operator training.

City of Watsonville
Attachment A - Scope of Work

Clarifications:
• Existing isolation values at basin will provide adequate seal for construction purposes.
• Existing aeration drop piping to bottom of basin can be reused.

Exclusions:
• Preparation of basin for work including draining, removing accumulated debris, and washing down.
• Replacing or repairing inoperable isolation gates. Assumption is that existing isolation gates to each basin provide adequate seal for construction purposes. • Repair of existing leaks, cracks, spalling, corrosion, deterioration, or other structural deficiencies.

Dewatering Screw Press
• Demolition of one (1) Alfa Laval Belt Press that is currently not in service (P-ME12) • Staged demolition of polymer mixing tanks and pumps.
o Four (4) existing day tanks (Tanks 1-4) and pump pads to be demolished. • Installation of one (1) PWTech Volute Dewatering Press ES-354 with four (4) dewatering drum and gear motors, solids to be discharged to existing dewatered sludge conveyor
• Manufacturer Field Services: Installation inspection, commissioning, testing, and operator training.
• Installation of four (4) VeloDyne Polymer Preparation Units • Demolition of existing polymer system will be phased to allow for continued operation of other belt presses.
• The new screw press and remaining belt presses will be fed polymer with the new Polymer Preparation Units.
• Installation of two (2) polymer tote scales.
• Connection of PWTech control panel to plant SCADA via ethernet Clarifications:
• Work to be completed with aeration blowers and aeration basin #4 activities. • Polymer Preparation Units and Tote Scales will connect to PWTech Control Panel
Exclusions:
• SCADA Programming
• Existing liquid polymer bulk storage and day tanks and transfer pumps to be abandoned in place.

City of Watsonville
Attachment A - Scope of Work

• No modifications to existing belt press feed pumps beyond new polymer injection connections.

Biogas Conditioning Equipment
• Provide and install a new turnkey digester gas pretreatment conditioning system consisting of the following:
o (1) Booster Blower (with VFD)
o (1) Low Pressure Cooler, Moisture Separator, and Reheater o (2) Lead Lag H2S Removal Vessels and Media
o (1) Lead Lag Piping and Valves for H2S Removal Vessels o (2) Particulate Filters
o (1) Siloxane and VOC Vessel
o (1) Regenerative Desiccant Drying System
o (1) Chiller Package (Vendor TBD)
o (1) Control Panel (Main and Remote I/O) with Touchscreen HMI The location of the biogas conditioning equipment is proposed in the vacant lot north of the new Main Electrical Switch gear facility and on the east end of the existing solids drying beds. This location will comply with permanent and scheduled clearances, not conflict with fire lanes or parking, and is assumed to be outside of floodways. Systems will be designed to condition digester gas to meet the gas quality requirements provided by Mainspring for reliable linear generator operation. Scope extends from the outlet flanges of the existing digester system to the inlet flange of the Mainspring Linear Generators. Installation will include necessary turnkey design, engineering, procurement, installation, integration, startup, testing, commissioning, and owner training. Please refer to Attachment B for additional details on scope, location, system sizing, and point(s) of interconnection.

Assumptions:
• Project would fall under CEQA categorical exemption.
• New chiller package system low pressure cooler and separator condensate line will route to existing 12-inch drainage line to headworks. • Digester gas pretreatment conditioning equipment was sized to 250-SCFM1 of biogas expected flow and 2024 and 2025 gas composition assays. The following digester gas related data and reports provided by the City of Watsonville treatment plant operators and referenced for the preliminary basis of design.

Please refer to Appendix A for report and dataset references. a. Digester Waste Gas Data (Waste gas data.pdf) Received on January 7th, 2026, and reflective of full year 2025 Daily biogas flow data.
1 Standard Cubic Feet per Minute (SCFM)

City of Watsonville
Attachment A - Scope of Work

b. Existing Cogeneration Gas Cost Analysis (CoGenGas_2025.pdf).

Received on January 7th, 2026, and reflective of system run hours and fuel (NG or biogas) blending ratios for full year 2025.
c. ALS Environmental Siloxanes Gas Composition Lab Report (P2404802 Siloxane.pdf). Received May 18th, 2026, and reflective of digester gas siloxane content as tested according to ASTM D8230-19. Report published December 10th, 2024.
d. ALS Environmental Siloxanes Gas Composition Lab Report (Gas_Composition_Assay_P25000291.pdf). Received November 2025, and reflective of digester gas BTU and CHONS Analysis as tested according to ASTM D 3588-98.
e. A dry gas flow rate of 250 SCFM has been assumed based on requirements of the (3) 250-kWe Linear generators operating with a methane concentration of 50-60%, including a 20% design margin2.
f. Should more recent Y2026 gas flow or analysis identify gas flows, contaminant concentrations, or operating conditions that significantly deviate from the reports above, equipment configuration, scope, schedule, and pricing are subject to change.

Scope of work includes:
• Development of a Basis of Design (BOD) document to serve as the primary engineering reference for the gas conditioning equipment project and establish technical assumptions, design criteria, project boundaries, and applicable codes. • Project management, engineering coordination, and construction management. • Engineering and Procurement Project Management to support throughout the design phase to coordinate project execution, maintain schedule, manage project interfaces, and facilitate timely decision making.
• Design and construction of concrete pad and skid anchorage for gas conditioning system.
• Mechanical and process engineering design to define the pretreatment systems and integration between existing owner-furnished interfaces. a. Process Flow Diagram (PFD) illustrating the entire process flow. b. Piping and Instrumentation Diagrams (P&IDs) covering process piping, utility connections, vent systems, drains, and control points 2 20% design margin to account for variations in gas flow rate and methane content as a function of both plant such as sludge loading and digester maintenance, as well as seasonal variability.

City of Watsonville
Attachment A - Scope of Work

to support coordination and integrations with identified utilities and existing facility interface points.
c. Heat and Mass Balance (HMBL) to quantify material flows, energy requirements, and heat transfer across the process.
d. Equipment Layout to show major pipe runs, process equipment locations, and technical building preliminary arrangements. e. Equipment and bill of materials lists, equipment and vendor data sheets, interface and tie point verifications, and mechanical 3D modeling.
• Electrical Engineering Design to define the electrical infrastructure required to power the gas conditioning system.
a. Development of single-line diagrams for systems, electrical load lists to document power requirements, power and utility requirements required to support powering of equipment, hazardous area classifications drawings, and tie-in point plans.
• Instrumentation and Controls System Designs to ensure safe, reliable, and efficient operation of the facility. Key scope items include preliminary control block diagrams, network architecture, final control block diagram, coordination meetings, I/O and interface lists, cause and effect matrix, and control narratives.
• Hazard and Operability (HAZOP) study based on industry-standard methodologies to identify and evaluate potential process and operability risks.
• Permitting support to provide engineering documentation and technical inputs where reasonably required for permit applications for the biogas conditioning system project. Specific responsibilities include:
a. Air permitting assistance to the lead air permitting consultant to provide support, documentation, and technical input to ensure compliance with applicable regulations.
b. Operational safety permits to support documentation where reasonably required for procurement of operational and safety-related permits.
• 3D Model and Preparation and Reviews at critical stages of the project will be designed and conducted to ensure the thorough integration of mechanical, structural, instrumentation, civil and electrical systems. This review process will ensure the biogas conditioning system layout and equipment configuration meet operational, maintenance, and safety requirements while allowing for optimal space management and ease of access.
• Procurement, fabrication, assembly, testing, delivery, and installation of the biogas conditioning system required to condition digester gas for use by the

City of Watsonville
Attachment A - Scope of Work

Mainspring Linear Generators. Project package consists of the following six (6) process systems:

1. Digester Gas Blower and Blower Inlet Scrubber

2. Hydrogen Sulfide Removal

3. Regenerative Desiccant Dryer System

4. VOC and Siloxane Removal

5. Chiller Package System

6. Control Panel System Design and Supply
• Mechanical Construction including installation of process piping, pipe supports, process equipment, insulation, heat tracing, and associated mechanical system necessary for operation of the biogas conditioning system.
• Provide construction, trenching, and backfill of gas line to the connection point by the biogas conditioning system.
• Condensate line from new chiller package system to existing 12-inch drainage line to headworks.
• New piping to existing flare. Pipe will originate from downstream of the H2S removal system.
• Interconnection to newly installed Eaton 4000A City-owned switchgear (SWGR-MEB) through a load-side (breaker) arrangement.
• Electrical and Controls Systems Construction including installation of electrical distribution equipment, controls systems, instrumentation, cable and conduit, grounding, field wiring, and system integration required for operation of the biogas conditioning system.
• Sand back filled duct banks with concrete caps for all conduits, piping, and communications runs.
• All electrical conductors are specified as copper power cabling (conductors). • All enclosure are to be outdoor rated for coastal and corrosive environments.
• All enclosures are assumed to be NEMA 3RX. (coastal and corrosive outdoor rated)
Scope of work excludes:
• Procurement and installation associated with any required unforeseen substantial upgrades or overhaul of the existing control, controls, or I/O hardware at the existing facility that may be lacking to properly integrate the biogas conditioning equipment control.

City of Watsonville
Attachment A - Scope of Work

• Environmental impact of traffic studies
• Geotechnical risk due to unforeseen geotechnical conditions that materially affect the design, construction, or installation of the biogas conditioning system. • Major layout, plant capacity, or engineering changes after design has been finalized. • Undisclosed electrical, structural, and utility-required upgrades/modifications. • Relocation, repair, or modification of undocumented underground utilities, abandoned infrastructure, or subsurface obstructions.
• Fire hydrant upgrades, fire water system modifications, or other fire protection improvements.
• Right-of-way or easement permitting
• Special studies such as traffic analysis, ADA requirements, sound studies, environmental approval requirements, or public comment and hearing processes. • Any additional planning, environmental, and/or fire department requirements • Special foundation requirements, concrete-encased trenching, erosion control, retaining walls and screenings, or other site improvements such as lighting, fencing, gates, signage, and integration with existing security systems. • Hazardous materials identification, testing, remediation, abatement, handling, or disposal, including but not limited to contaminated soils, asbestos, lead-containing materials, unsuitable soils, buried debris, undocumented underground utilities, archaeological resources, or other unforeseen subsurface conditions discovered during construction.
• Operations and Maintenance agreement or services for the new biogas conditioning system.
• Change out of activated carbon or other media for the VOC and Siloxane removal vessel.

Mainspring Linear Generators
• Provide and install a new turnkey 750 kWe on-site power generation system consisting of three (3) 250 kWe Mainspring Linear Generators sized for a 250 SCFM (dry basis) biogas source. The location of the linear generators is proposed in the vacant lot north of the new Main Electrical Switch gear facility and on the east end of the existing solids drying beds. This location will comply with permanent and scheduled clearances, not conflict with fire lanes or parking, and is assumed to be outside of floodways. The completed system shall operate in a grid-following mode only and utilize the existing anaerobic digester biogas from the plant as the primary fuel source and PG&E natural gas as the secondary fuel source through a manual fuel switch. The system will operate in parallel with the existing PG&E electrical service under an approved non-export operating mode. Installation will include necessary turnkey design, engineering, procurement, installation, integration, startup,

City of Watsonville
Attachment A - Scope of Work

testing, commissioning, and owner training. Please refer to Attachment B for additional details on scope, location, system sizing, and point(s) of interconnection.

Assumptions:
• Project would fall under CEQA categorical exemption.
• HDPE piping is allowed by the utility for underground gas piping. • Fuel source (biogas) for the linear generator units must meet Mainspring minimum requirements as outlined in Mainspring’s Fuel Specifications Form Appendix A. The City must submit a fuel test report that validates compliance with fuel specifications prior to the commissioning of the system. • Linear Generator sizing and inlet gas conditioning requirements were sized to 250-SCFM of biogas expected flow and 2024 and 2025 Gas composition assays.

The following digester gas related data and reports provided by the City of Watsonville treatment plant operators and referenced for the preliminary basis of design. Please refer to Appendix A for report and dataset references. a. Digester Waste Gas Data (Waste gas data.pdf). Received on January 7th, 2026, and reflective of full year 2025 daily biogas flow data. b. Existing Cogeneration Gas Cost Analysis (CoGenGas_2025.pdf).

Received on January 7th, 2026, and reflective of system run hours and fuel (NG or biogas) blending ratios for full year 2025. c. ALS Environmental Siloxanes Gas Composition Lab Report (P2404802 Siloxane.pdf). Received May 18th, 2026, and reflective of digester gas siloxane content as tested according to ASTM D8230-19. Report published December 10th, 2024.
d. ALS Environmental Siloxanes Gas Composition Lab Report (Gas_Composition_Assay_P25000291.pdf). Received November 2025, and reflective of digester gas BTU and CHONS Analysis as tested according to ASTM D 3588-98.
e. A dry gas flow rate of 250 SCFM has been assumed based on requirements of the (3) 250-kWe Linear generators operating with a methane concentration of 50-60%, including a 20% design margin3.
f. Should more recent Y2026 gas flow or analysis identify gas flows, contaminant concentrations, or operating conditions that significantly deviate from the reports above, equipment configuration, scope, schedule, and pricing are subject to change.
3 20% design margin to account for variations in gas flow rate and methane content as a function of both plant such as sludge loading and digester maintenance, as well as seasonal variability.

City of Watsonville
Attachment A - Scope of Work

• If at any time updated digester gas flow data or gas composition testing is obtained by the City of Watsonville, it is the City’s responsibility to share this data in a timely manner with Contractor in order to verify that flows and gas compositions have not deviated from the original data sets utilized for generator sizing and gas conditioning specifications.

Scope of work includes:
• Provide and install equipment, materials, engineering, permitting, soils testing, construction, commissioning, closeouts, and monitoring necessary for installation of the new 750 kWe Mainspring Linear Generator system.
• Project management, engineering coordination, and construction management. • Site topographic and geotechnical surveys.
• Critical issues analysis provisioned for an environmental study to determine appliable regulations that may need to be accounted for in permitting. • Air, building, electrical, plumbing and utility permitting package deliverables, applications, and management to obtain final permits.
• Electrical and gas utility interconnection application management and support through submission and permission to operate inclusive of application submittals, interconnection approvals, Initial study, and supplemental review fees. a. One (1) PG&E utility interconnection application, net generation output meter (NGOM), and study fees for the utility requirements b. Installation of (1) natural gas line from existing City owned portion of the gas line to the linear generator system location (City owned gas line from PG&E meter on Beach St., south and along Panabaker Rd.) It is assumed that PG&E will install a new meter near the linear generator’s new gas riser. Proposed gas point of interconnection is preliminary, and finalization point of interconnection will be determined during detailed engineering. A fifty (50) foot linear length is assumed from the City owned pipe to the new gas riser. line
• Design and construction of concrete pads for linear generator units and Balance of Plant (BOP) equipment.
• Site civil scope inclusive of grading, duct bank construction, backfill, trenching, compaction, and site preparation.
• Sand back filled duct banks with concrete caps for all conduits, piping, and communications runs.
• Trenching and backfill shall be conducted under normal soil conditions; duct bank trenching and backfill is based on a 4-foot maximum depth with compacted, stabilized sand.

City of Watsonville
Attachment A - Scope of Work

• Provide and install anchors, site signage, and site equipment craning. • Provide and install protective bollards (where required) by the final design. • Provide construction trenching and backfill of biogas distribution system from new linear generator unit gas riser to linear generator stub-ups. • Provide construction trenching and backfill of utility natural gas distribution system from new linear generator unit gas riser to linear generator stub-ups. • Design and installation for piping and instrumentation of a manual gas switching manifold, two (2) gas regulators, and (1) gas flow meter to accommodate the switch between on-site biogas and Utility natural gas.
• Provide and install one new gas riser to be located near the linear generator units. • Interconnection to newly installed existing Eaton 4000A City-owned switchgear (SWGR-MEB) through load-side (breaker) interconnection via a power conversion station fed through new 1000 kVA Isolation Transformer. • 1200A, 3-phase AC disconnect as per NEC requirements. • Utilize spare 1600AF/1600AT power circuit breaker in Section 5 of SWGR-MEB. • Utilize four (4) 4-inch spare conduits that route from SWG-MEB Section 5 to pull box PB-101P as per the existing Hazard Mitigation Project bid documents provision. • Digester biogas tap point will be located at the outlet of the biogas conditioning systems VOCs and siloxane removal vessel, pending detailed design engineering. No more than a 300-foot linear length of piping is assumed from this outlet point to new gas riser.
• Civil design, construction, and electrical BOP engineering and install labor based on the proposed linear generator location in the lot space next to the solids drying bed and across from the new Main Electrical Switchgear building. • Electrical BOP includes permanent and schedulable clearance areas. • Control and reverse power protection scope is included in the form of relays required to satisfy utility reverse power protection requirements. • Linear Generators will be dispatched via the Mainspring provided Power Monitoring cabinet (PMC). A site meter within the PMC will monitor power from the utility and use this data to dispatch the linear generators to offset the utility power purchases. • All electrical conductors are specified as copper power cabling (conductors). • All enclosures are assumed to be NEMA 3RX. (coastal and corrosive outdoor rated). • Mainspring-provided equipment programming and bench testing. • Startup, commissioning, owner training, O&M manuals, warranties, and as-built documentation.

Scope of work excludes:
• Operation of linear generators as a backup power source in the event of a Utility outage.

City of Watsonville
Attachment A - Scope of Work

• Site generation or load management (microgrid) site controller, island-able system, or grid-forming capability, and parallel or stand-alone load controllers. • Integration with existing site-level controllers such as PLCs, monitoring systems, BMS, microgrids, or other distributed generation assets. • Procurement and installation associated with any required unforeseen substantial upgrades or overhaul of the existing control, controls, or I/O hardware at the existing facility that may be lacking to properly integrate the linear generator(s) equipment control.
• Digester biogas cleanup, pressure, and flow regulation • Maintenance of on-site biogas flow, pressure, and quality. • Availability of biogas provided to the linear generators and any fuel switching from biogas to natural gas.
• Automated fuel switching from biogas to utility natural gas to power linear generators.
• PG&E electrical interconnection Detailed Study fees, if required. • Installation of gas piping from PG&E utility gas distribution line to utility gas meter and procurement and installation of utility gas meter.
• Main switchgear protection and control equipment programming and bench testing for utility parallel inspection and approvals.
• Existing switch gear line-side tap and associated busbar recertification. • Corrosion-resistant rated equipment.
• Environmental impact, traffic studies, or additional permitting requirements resulting from the critical issues analysis.
• Geotechnical risk due to unforeseen geotechnical conditions that materially affect the design, construction, or installation of the biogas conditioning system. • Major layout, plant capacity, or engineering changes after design has been finalized. • Undisclosed electrical, structural, and utility-required upgrades/modifications. • Relocation, repair, or modification of undocumented underground utilities, abandoned infrastructure, or subsurface obstructions.
• Fire hydrant upgrades, fire water system modifications, or other fire protection improvements.
• Right-of-way or easement permitting
• Special studies such as traffic analysis, ADA requirements, sound studies, environmental approval requirements, or public comment and hearing processes. • Any additional planning, environmental, and/or fire department requirements • Special foundation requirements, concrete-encased trenching, erosion control, retaining walls and screenings, or other site improvements such as lighting, fencing, gates, signage, and integration with existing security systems.

City of Watsonville
Attachment A - Scope of Work

• Hazardous materials identification, testing, remediation, abatement, handling, or disposal, including but not limited to contaminated soils, asbestos, lead-containing materials, unsuitable soils, buried debris, undocumented underground utilities, archaeological resources, or other unforeseen subsurface conditions discovered during construction.
• Operations and Maintenance agreement or services for the Mainspring Linear Generator system.

City of Watsonville
Attachment B – Technical Appendix
Attachment “B”
Technical Appendix

SSI 9” AFD270 DISC

DIFFUSER SYSTEM

APG-NEUROS NX150DC070 TURBO BLOWER

APG-Neuros Turbo Blower Core
Proposal Reference# 00813-6532 R1 (2 x 75HP)
APG-Neuros Turbo Blower Scope of Supply Proposal
Watsonville, CA, ph.II
Prepared By APGN Inc. dba APG-Neuros
June 11, 2026
APGN proprietary Information
APGN Inc.
1270 Michele-Bohec, Blainville, QC, J7C-5S4
Tel: 450-939-0799 Fax: 450 939 2115
www.apg-neuros.com
APGN-PM-FORM-193-E.06, February 20, 2019

Application
Blower Installation Location
Working Fluid
Ambient Pressure psia
Customer Design Requirements DP1 DP2
Inlet Pressure 14.45 14.45 psia
Inlet Temperature 100.0 28.0 °F
Relative Humidity 70 70 %
Duty Discharge Pressure 8.00 8.00 psig
System Flow Rate 1,407 1,407 SCFM
Flow Rate per Blower 1,407 1,407 SCFM
Blower Units on Duty 1 1 Units
Model
Rated Motor Output Power HP
Power @ Design Condition per Blower 61 51 bhp
Wire-to-Air Power @ Design Condition per Blower 49 41 kW Maximum Air Flow @ Duty Discharge Pressure per Blower 3,382 3,760 SCFM Minimum Air Flow @ Duty Discharge Pressure per Blower 556 618 SCFM Turndown from Maximum to Minimum 83.6% 83.6% %
Discharge Temperature @ Design Condition 199.3 114.1 °F Maximum Discharge Pressure 11.85 11.85 psig
Rise-to-Surge 3.85 3.85 psig
Note:

SCFM defined at 68 Deg F,14.696 psia and 36% relative humidity Noise Level : +/- 2dB
Wire power figures are reported based on ASME PTC-10 Performance Test Code standard 75x2
Available Blower Performance
NX150D-C070

14.65 Watsonville, CA, ph.II - APG- Neuros Turbo Blower - Performance Data Ambient Conditions
Aeration
Indoor
Air
APGN Inc. proprietary Information
APGN Inc.
1270 Michèle-Bohec, Blainville, QC, J7C-5S4
Tel: 450-939-0799 Fax: 450 939 2115

Blower Length 83 Inches
Blower Width 59 Inches
Blower Height 71 Inches
Weight per Unit 4503 lbs.

Blower Inlet Air Entry type Louvered
Inlet Flange Size (Optional, if louvered inlet does not apply) - Inches Discharge Flange Size 2×8 Inches
Maximum Noise Level @ 3 feet 80 dBA
Input Voltage/Phase/Frequency 480/3/60 V/Phase/Hz
Full Load Amperage 81×2 Amps
Watsonville, CA, ph.II - APG- Neuros Turbo Blower - Performance Data Dimensions and Specification
APGN Inc. proprietary Information
APGN Inc.
1270 Michèle-Bohec, Blainville, QC, J7C-5S4
Tel: 450-939-0799 Fax: 450 939 2115

Watsonville, CA, ph.II - APG - Neuros Turbo Blower - Performance Curves APGN proprietary Information
APGN Inc.
1270 Michele-Bohec, Blainville, QC, J7C-5S4
Tel: 450-939-0799 Fax: 450 939 2115 Page 287 of 400 www.apg-neuros.com APGN-PM-FORM-193-E.06 February 20, 2019 Watsonville, CA, ph.II - APG - Neuros Turbo Blower - Performance Curves APGN proprietary Information
APGN Inc.
1270 Michele-Bohec, Blainville, QC, J7C-5S4
Tel: 450-939-0799 Fax: 450 939 2115 Page 288 of 400 www.apg-neuros.com APGN-PM-FORM-193-E.06 February 20, 2019

PWTECH VOLUTE
DEWATERING PRESS –
ES354 – 4 DRUM

VOLUTE™

DEWATERING PRESS
SCREW PRESS 2.0

COMPACT

INSTALLATION

FOR MUNICIPAL
& INDUSTRIAL

SLUDGES
ENERGY

EFFICIENT

ABOUT US
Process Water Technologies LLC (PWTech) is based in Rosedale, MD. Along with our flagship Volute technology for sludge dewatering and thickening, we supply sludge handling and CSO/SSO products that are simple, effective and easy to maintain.

Volute and the AMCON, Inc. logo are registered with the U.S. Patent and Trademark Office as trademarks of AMCON, Inc., Yokohama, Japan.

1.833.888.2651 [email protected] pwtech.us

A REVOLUTION IN MUNICIPAL AND INDUSTRIAL SOLIDS HANDLING The Volute Dewatering Press is a groundbreaking advancement in municipal biosolids handling, offering a compact, efficient, and highly reliable solution for sludge dewatering. Originally developed in Japan and now used in thousands of installations worldwide, this revolutionary screw press features a Volute Drum that allows for a much more compact and efficient installation with significantly lower operator and maintenance requirements than other screw presses and more conventional dewatering technologies.

Because of the efficiency of the design, the Volute Press is particularly suited to dewatering thin sludges and can be installed to handle both wasting and dewatering duties – taking sludge as dilute as 0.1% solids directly from a treatment process, such as an oxidation ditch or clarifier, and producing a fully dewatered cake. The unique Dewatering Drum design is also useful when sludges have a high oil and fat content that would blind filter materials.

DEWATERING DRUM DESIGN
Standard screw presses have a static casing with openings to allow fluid release from the sludge that continually plug with the solids in the sludge. This results in an oversized, inefficient dewatering operation and maintenance-intensive cleaning systems. The superior design of the Volute Press Dewatering Drum consists of a casing made of rings that constantly move preventing plugging of the openings allowing for a much more compact and efficient dewatering operation while minimizing and simplifying maintenance requirements.

FULLY AUTOMATIC SYSTEM
The Volute Dewatering Press was developed to operate in unmanned treatment plants and is capable of starting up, operating and shutting down with no operator intervention. Standard controls for the Volute are supplied by PWTech to provide a full dewatering system that operates with a minimum of operator attention (pumps, polymer dosing, solids conveying, etc.).

PWTECH VOLUTE™ DEWATERING PRESS – COMPACT FOOTPRINT
Features Dewatering Drum Designed for Efficiency

KEY BENEFITS
Compact Installation due to
Volute Drum efficiency
Up to 95% less power
consumption than other
dewatering processes
Requires minimal
maintenance
No need for regular operator
attendance
Expandability and built-in
redundancy
High-quality filtrate
Dewaters fatty and oily
sludge, organic and inorganic
sludges; thin <0.2% and thick
>5% sludges
Learn
more.

PROUDLY REPRESENTED BY:

Process Wastewater Technologies, LLC.

Volute Dewatering Press
Data Sheet
Model ES-354
Volute Dewatering Press Data Sheet: ES-354
Over All Dimensions: 217" x 123" x 88" (L x W x H)
Optimal Space requirement of installation: 276" x 219" (L x W) Minimum Opening dimensions for installation: 81" x 84"
Empty: 15,000 lbs
Max: 27,500 lbs
MAX Solids throughput: 2600 Dry pounds per hour
MAX Hydraulic throughput: 260 GPM
Power use: 18 HP
Washwater use: @40 PSI 12GPM intermittent, 60 GPH total Dimension: 13.75" diameter x 72" long
Quantity: 4
Fixed & Moving Rings: Type 304 Stainless Steel
Screw: 304 Stainless Steel with CoCr coating
Gear Motor Supplier: SEW Eurodrive
Model: KH97 R57DRN100L4-342
Motor Power: 2.24 kW (3.0HP) 4-Pole
Enclosure: TEFC / IP55
Gear Reduction: 342:1
Dimensions: 24" x 39" x 43" (L x W x H)
Volume 174.4 Gallons
Working Volume: 154.6 Gallons
Material Type 304 Stainless Steel
Gear Motor Supplier: Brother
Model: F3S45S10-WB15TAVEN
Motor Power: 1.5 kW (2 HP) 4-Pole
Enclosure: TENV / IP65
Gear Reduction: 10 : 1
Please note- All information here is generic and for preliminary reference only. Detailed throughput and other data is very project specific and this sheet has not been altered to relect that. Project specific data would be available from PWTech at the appropriate time.

General Information
Model Information
Weight
Dewatering Drum
General
Material:

Drive info
Flash mixing tanks
General Drive Info

Dimensions: 39" x 39" x 43" (L x W x H)
Volume 290.6 Gallons
Working Volume: 154.6 Gallons
Material Type 304 Stainless Steel
Gear Motor Supplier: Brother
Model: FS55S60-WD22TAVEN
Motor Power: 2.24 kW (3.0HP) 4-Pole
Enclosure: TEFC / IP65
Gear Reduction: 60 : 1
Supply Voltage: 208/240/440/480 VAC
Service: 3-Phase, 3-Wire (No Neutral)
Control Voltage: Dual - 24VDC & 115VAC
Minimum Required Breaker Size:* 39 Amps * 480 VAC
Panel Size: 48"(w) x 48"(h) x 12"(d)
Panel Material: Type 304 Stainless Steel
Panel Rating: NEMA 4X
Unitronics Unistream 10.2 PLC/
CompactLogix #5069-L306
Supplier: Velocity Dynamics, Inc.

Model: VM-10P-1200-X0D
Mixing Type: Variable - Mechanical & Hydraulic
Feed Pump Type: Progressive Cavity
Polymer Feed Capacity: 0.5 - 10 Gallons per hour
Water Use: 120 - 1200 Gallons per hour
Dimensions: 24" x 40" x 40" (L x W x H)
Weight: ~300 lbs
Minimum Supply Pressure: 30 PSI
Feed Sludge: 3" or 4" ANSI 150# Flange**
Filtrate: 2 x 6" ANSI 150# Flange
Drain: 4" ANSI 150# Flange
Water: 3/4" FNPT Coupling
Press Polymer Inlet: 1" FNPT
Polymer Water Inlet: 1" FNPT or 1.5" FNPT
Polymer Solutions Outlet. 1" FNPT or 1.5" FNPT
Raw Polymer Feed Inlet: 1" FNPT
** Inlet connection size will vary based on anticipated feed sludge concentration. Drive Info Polymer System
Control Module:

General
STD. Electrical
General Panel
Connections Flocculation tank

GAS CONDITIONING
SYSTEM

LEGEND:

BIOGAS ENG. DESIGN SCOPE

CONDENSATE BGE SCOPE

CLIENT SCOPECHILLED WATER LINES BGE SCOPE

BLOWER INLET

SCRUBBER
B/L

CLIENT BGE
BLOWER

LOW PRESSURE

COOLER AND

SEPARATOR

VOCS AND

SILOXANE

REMOVAL VESSEL

CHILLED WATER
(CHW) SYSTEM
1 2 3
7 B/L

BGE CLIENT
10 11
4A

DIGESTER GAS

FROM DIGESTER

PRODUCT GAS TO

ELECTRICITY

GENERATORS
9 DRYER SYSTEM
8 REHEATER
4 5 H2S REMOVAL

AND POLISHING

VESSELS
6 BLOCK FLOW DIAGRAM
A 06-24-2026 ISSUED FOR PROPOSAL NP NJ AS
P1.01

REV DATE DESCRIPTION CHK BY APRV BY
DRAWING NO.

ENGINEER:

DG PRE-TREATMENT FACILITY
BIOGAS

ENGINEERING
OWNER:

C:\Users\RavinderSingh\Biogas Engineering Dropbox\BD\BGE Proposal\Climatec\Wattsonville WWTP Facility\D-drawing\P1.01.dwg 02-04-2025 RavinderSingh PRELIMINARY 1 2
3 4
5 6
1 2
3 4
5 6

A B C D E F G H J KA B C D E F G H J K
DRN BY
STAMP:
3816 STINEMAN CT, SUITE 203
LONG BEACH, CA 90808
EMAIL: [email protected]

CONFIDENTIAL

Owner:

Project: DG Pre-treatmentLocation: Watsonville, California Prep. by Chk by App by Rev.Engineer: BIOGAS ENGINEERING AW NJ AS A Stream # 1 2 3 4 4A 5 6 7 8 9 10 11Stream Name

DIGESTOR GAS FROM

DIGESTERS TO BLOWER

INLET SCRUBBER

BLOWER INLET SCRUBBER

TO DG BLOWER

DG BLOWER TO REHEATER

FROM REHEATER TO LOW

PRESSURE

COOLER/SEPARATOR

CONDENSATE FROM LOW

PRESSURE SEPERATOR

LOW PRESSURE
COOLER/SEPARATOR TO H2S

REMOVAL VESSELS
H2S REMOVAL VESSELS TO

REHEATER

REHEATER TO DRYER
SYSTEM

FROM DRYER SYSTEM TO

VOC/SILOXANE REMOVAL
BED

FROM VOC/SILOXANE

REMOVAL BED TO

MAINSPRING GENERATORS

CHW SUPPLY TO LOW

PRESSURE COOLER

CHW RETURN FROM LOW

PRESSURE COOLER
Pressure psig 0.0 0.0 16.0 15.0 14.0 14.0 13.0 12.0 11.5 11.0 80.0 70.0Temperature ºF 100 100 320 303 91 70 91 91 100 100 30 40Total Gas Flow SCFM 267 267 267 267 - 253 253 253 250 250 - -Actual Gas Flow ACFM 288 288 192 194 - 132 142 148 151 154 - -Mass Flow lb/hr 1,061 1,061 1,061 1,061 40 1,021 1,020 1,020 1,012 1,012 18,796 18,796Gas Avg Mol. Wt 25 25 25 25 - 25 25 25 26 26 - -Compressibility Factor z 1.00 1.00 1.00 1.00 - 1.00 1.00 1.00 1.00 1.00 - -Actual Gas Density lb/ft3 0.06 0.06 0.09 0.09 61.80 0.13 0.12 0.12 0.11 0.11 64.23 64.23Heat Capacity (Cp) BTU/lb ºF 0.42 0.42 0.48 0.47 - 0.41 0.41 0.41 0.41 0.41 0.93 0.93Heat Gain / Loss BTU/hr 0 0 111,773 -8,700 - -144,934 8,677 0 -3,885 -7,725 0 173,920Relative Humidity % 100 100 2 3 0 98 48 47 4 4 0 0Condensate Removed lb/hr 0 0 0 0 40 0 0 8 8 0 0ComponentsMethane (CH4) Vol% 60.7 60.7 60.7 60.7 0.0 64.1 64.1 64.1 64.9 64.9 0.0 0.0Carbon Dioxide (CO2) Vol% 31.2 31.2 31.2 31.2 0.0 32.9 32.9 32.9 33.3 33.3 0.0 0.0Nitrogen (N2) Vol% 1.4 1.4 1.4 1.4 0.0 1.5 1.5 1.5 1.5 1.5 0.0 0.0Oxygen (O2) Vol% 0.2 0.2 0.2 0.2 0.0 0.2 0.2 0.2 0.2 0.2 0.0 0.0Hydrogen Sulfide (H2S) Vol% 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Water (H2O) Vol% 6.5 6.5 6.5 6.5 100.0 1.2 1.2 1.2 0.1 0.1 0.0 0.0Chilled Water Vol% 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 100.0 100.0 Climatec

1. STANDARD CONDITIONS: 60 oF, 14.696 PSIA, 0% RH
24-Jun-26
Rev. A
NOTES:

PRELIMINARY HEAT AND MASS BALANCE_250 SCFM(DRY)

MAINSPRING LINEAR

GENERATORS

PROJECT TEAM
ELECTRICAL ENGINEER:

STRUCTURAL ENGINEER:

PROJECT DATA
PROJECT ADDRESS:
500 CLEARWATER LN, WATSONVILLE, CA 95076
COUNTY:

XXXXXXX
EQUIPMENT SUPPLIER:

PROJECT DIRECTORY

AGENCY DEPARTMENT
PLANNING:

BUILDING:

FIRE DEPT:

NATURAL GAS:

ELECTRICITY:

CROSS STREETS:

AREA DISTURBED
GENSET PAD AREA : SIDE
BUILDING CODES & STANDARDS:

PHONE NUMBER
PROJECT DESCRIPTION:

ISSUE DATES

DATE DESCRIPTION

DRAWING INDEX

PAGE NUMBER

OVERALL SITE PLAN

LOCATION
750 kW LINEAR GENERATOR SYSTEM

CITY OF WATSONVILLE WWTP
500 CLEARWATER LN, WATSONVILLE, CA 95076

ABBREVIATIONS GENERAL NOTES
LEGEND
P:\EtaGen (Mainspring)\West Hills, CA (22915 Victory Blvd)-ETA.31433\Design Files\Electrical\Drawings\West Hills, CA (22915 Victory Blvd.)-ETA.31433 - 1.0 Cover Sheet.dwg Thursday, July 1, 2021 12:51:00 PM

DESCRIPTION

1.0 COVER SHEET

2.0 PLOT PLAN # ℄ #
DETAIL NUMBER #
###
###
## #

SHEET NUMBER

SHEET NUMBER

ELEVATION NUMBER

SHEET NUMBER

SECTION NUMBER

KEYNOTE

REVISION TARGET

NORTH ARROW

CENTER LINE
DEPT. = DEPARTMENT
DR. = DOOR
DN. = DOWN
DIM. = DIMENSION
DIA. = DIAMETER
DET. = DETAIL
DS = DISCONNECT SWITCH
DWG. = DRAWING
D.S. = DOWNSPOUT
ELEC. = ELECTRICAL
EL. = ELEVATION
EA. = EACH
(E) = EXISTING
EPO = EMERGENCY SHUT-OFF SWITCH
EXT. = EXTERIOR
EXP. = EXPANSION
EQ. = EQUAL
F = FIXED BOLLARD
FLASH'G = FLASHING
FG = FINISH GRADE
FDN. = FOUNDATION
FNPT = FEMALE NOMINAL PIPE THREAD
F.O.C. = FACE OF CURB
F.O.C. = FACE OF CONCRETE
FO&T. = FIBER OPTIC & TELEPHONE
FUT. = FUTURE
FTG. = FOOTING
G = GAS
GALV. = GALVANIZED
G.A. = GAUGE
GB = GRADE BREAK
GR. = GRADE
GL. = GLASS
HDPE = HIGH DENSITY POLYETHYLENE
H.B. = HOSE BIBB
HORIZ. = HORIZONTAL
H.M. = HOLLOW METAL
INSUL. = INSULATION
I.D. = INSIDE DIAMETER
IE = INVERT ELEVATION
INT. = INTERIOR
ISP = INTERNET SERVICE PROVIDER
LAV. = LAVATORY
LAM. = LAMINATE
JT. = JOINT TRENCH
LIP = EDGE OF SWALE OR GUTTER
UGE = UNDERGROUND ELECTRIC
U.G. = UNDERGROUND
ULD = UTILITY LOCKABLE DISCONNECT
U.O.N. = UNLESS OTHERWISE NOTED
UNF. = UNFINISHED
UPS = INTERRUPTIBLE POWER SUPPLY
VERT = VERTICAL
W = WATER
HDD = HORIZONTAL DIRECTIONAL DRILLING
O.D. = OUTSIDE DIAMETER
O.C. = ON CENTER
OPP. = OPPOSITE
OPNG. = OPENING
REQ'D = REQUIRED
REINF. = REINFORCED
REF. = REFERENCE
R.D. = ROOF DRAIN
R OR RAD. = RADIUS
R.O. = ROUGH OPENING
RM. = ROOM
R.O.W. = RIGHT OF WAY
R.S.A. = REGULATED SET ASSEMBLY
SECT. = SECTION
SCHED. = SCHEDULE
S.F. = SQUARE FOOTAGE
SPEC. = SPECIFICATION
SIM. = SIMILAR
SHT. = SHEET
SS = STAINLESS STEEL
SQ. = SQUARE
ST = STORM DRAIN
STD. = STANDARD
STL. = STEEL
STS = STATIC TRANSFER SWITCH
SYM. = SYMMETRICAL
STRL. = STRUCTURAL
STOR. = STORAGE
TB = TERMINAL BLOCK
T.& G. = TONGUE & GROOVE
TG = TOP OF GRATE
T.C. = TOP OF CURB
THK. = THICK
T.I.P. = TIE-IN POINT
TYP. = TYPICAL
TW = TOP OF WALK
TS = TELEMETRY SECTION
TP = TOP OF PAVEMENT
TOW = TOP OF WALL
T.O. = TOP OF
MAX. = MAXIMUM
MDPE = MEDIUM DENSITY POLYETHYLENE
MFR. = MANUFACTURER
MEMB. = MEMBRANE
MECH. = MECHANICAL
MISC. = MISCELLANEOUS
MIN. = MINIMUM
MNPT = MALE NOMINAL PIPE THREAD
MPOE = MAIN POINT OF ENTRY
MSA = METER SET ASSEMBLY
MSB = MAIN SWITCHBOARD
MUL. = MULLION
MTD. = MOUNTED
(N) = NEW
NETA = NATIONAL ELECT. TESTING ASSOC.

NTS = NOT TO SCALE
NOM. = NOMINAL
NO. OR # = NUMBER
N.I.C. = NOT IN CONTRACT
A.B. = ANCHOR BOLT
AC = ASPHALT CONCRETE
A.F.S. = ABOVE FINISH SURFACE
A.G. = ABOVE GRADE
AGGR. = AGGREGATE
AL. = ALUMINUM
AM. APPROX. = APPROXIMATE
AN. ASPH. = ASPHALT
AO. ATS = AUTOMATIC TRANSFER SWITCH
BD. = BOARD
BESS = BATTERY ENERGY

STORAGE SYSTEM
BE. BLDG. = BUILDING
BF. BOT. = BOTTOM
BG. BW = BACK OF WALK
CEM. = CEMENT
CNTR. = CONTRACTOR
C.I. = CAST IRON
CLR. = CLEAR
CNTR. = CONTRACTOR
C.O. = CLEAN OUT
CONC. = CONCRETE
CONSTR. = CONSTRUCTION
CONT. = CONTINUOUS
CU = COPPER
CTR. = CENTER (P) = PROPOSED
PB = LEVEL PAVEMENT AT DISPENSER

PIT BOX
PCC = PORTLAND CEMENT CONCRETE
PCS = POWER CONVERSION SYSTEM
P.I.P. = PROTECT IN PLACE
PL. = PLATE
P.LAM. = PLASTIC LAMINATE
PLYWD. = PLYWOOD
POI = POINT OF INTERCONNECTION
PVC = POLYMERIZED VINYL CHLORIDE PIPE

1. IN THE EVENT OF DISCREPANCIES BETWEEN THE DRAWINGS, SPECIFICATIONS,

OR SCOPE OF WORK SUMMARY IN THIS PACKAGE, NOTIFY CORE STATES GROUP IMMEDIATELY.

2. THE CONTRACTOR IS RESPONSIBLE TO SEE THAT WORK IN FIELD IS DONE IN

ACCORDANCE WITH ALL CURRENT APPLICABLE NATIONAL, STATE, & LOCAL CODES, ORDINANCES & REQUIREMENTS BY GOVERNING AGENCIES. WHETHER OR NOT SAID CODES, ORDINANCES, REQUIREMENTS, ETC. ARE SPECIFICALLY SHOWN ON DRAWINGS AND/OR CALLED FOR IN SPECIFICATIONS.

3. THE CONTRACTOR SHALL PROTECT ALL EXISTING ITEMS AND FACILITIES TO REMAIN THROUGHOUT CONSTRUCTION. CONTRACTOR SHALL REPAIR AND/OR

REPLACE, AT CONTRACTOR'S EXPENSE, ANY EXISTING ITEMS AND FACILITIES

TO REMAIN THAT ARE DAMAGED BY THE CONTRACTOR'S OPERATIONS, TO THE SATISFACTION OF PROJECT OWNER, ETAGEN AND CORE STATES GROUP.

4. PRIOR TO EXCAVATION, DETERMINE AND VERIFY LOCATION OF UTILITY SERVICES IN ALL AREAS TO BE EXCAVATED.

5. THE CONTRACTOR SHALL COMPLY WITH ALL PERTINENT LAWS, CODES,

REGULATIONS, CBC, GOVERNING AGENCIES & MANUFACTURER

SPECIFICATIONS, UNLESS GREATER REQUIREMENTS ARE INDICATED, AND/OR ARE NECESSARY FOR THE SAFETY OF THE PROJECT.

6. THE CONTRACTOR SHALL BE RESPONSIBLE FOR NOTIFYING JURISDICTIONS AS REQUIRED FOR INSPECTIONS.

7. THE CONTRACTOR SHALL PROVIDE MAINSPRING ENERGY WITH A

CONSTRUCTION SCHEDULE PRIOR TO STARTING THE WORK, A QUALIFIED JOB

SUPERINTENDENT THROUGHOUT THE WORK, PHOTOS SHOWING, TRENCHES

PRIOR TO BACKFILL, SLOPE OF PRECAST PADS AND RECORD DRAWINGS OF ALL UNDERGROUND CONSTRUCTION.

8. THE CONTRACTOR SHALL PROVIDE BARRICADES AND SAFETY SIGNS PER OSHA REQUIREMENTS.

9. THE CONTRACTOR IS RESPONSIBLE FOR OVERALL CONSTRUCTION SITE

CLEANLINESS, INCLUDING PROVISIONS OF A DEBRIS BOX WITH WEEKLY

SERVICING, REMOVAL OF ALL CONTRACTOR/SUBCONTRACTOR REFUSE AND

DEBRIS, AND SWEEPING OF THE ENTIRE YARD AREA AT THE COMPLETION OF THE WORK.

10. UNLESS STATED OTHERWISE IN THE SCOPE OF WORK SUMMARY, ALL OTHER

PROCEDURES, TESTING, MATERIALS AND EQUIPMENT SHOWN ON THE PLANS SHALL BE FURNISHED AND INSTALLED BY THE CONTRACTOR.

11. EACH CONTRACTOR SHALL BE RESPONSIBLE FOR REPAIR OF DAMAGE TO THE WORK OF OTHER TRADES CAUSED BY HIS OPERATIONS. THE NATURE OF SUCH

REPAIR WORK MUST RECEIVE THE PRIOR APPROVAL OF THE AUTHORIZED AGENT.

12. CONSTRUCTION MATERIAL, ASSEMBLIES AND PROCEDURES SHALL FOLLOW LOCALLY ADOPTED BUILDING CODES AND SUPPLEMENTARY ORDINANCES.

WHEN A CONFLICT OCCURS BETWEEN SUCH LOCAL CODE AND INFORMATION

SHOWN ON THE PLANS, CONSULT CORE STATES GROUP FOR RESOLUTION PRIOR TO COMMENCING WORK.

13. THE CONTRACTOR SHALL NOTIFY MAINSPRING ENERGY IF SITE CONDITIONS OR DIMENSIONS DISAGREE WITH INFORMATION SHOWN ON THE DRAWINGS.

WORK IS NOT TO PROCEED UNTIL SUCH DIFFERENCES ARE RESOLVED.

14. DO NOT USE THE BUILDING PERMIT SET FOR CONSTRUCTION OR FIELD REFERENCE. THE PERMIT SET GENERALLY LACKS CERTAIN DRAWINGS AND

SPECIFICATIONS, WHICH ARE IN THE BID AND CONSTRUCTION SETS IN ADDITION TO REVISIONS MADE AFTER THE PERMIT PROCESS. FOR

CONSTRUCTION AND FIELD REFERENCE, CONTRACTOR SHALL USE ONLY THE SET, WHICH IS CLEARLY SIGNED AND DATED "ISSUED FOR CONSTRUCTION".

THE APPROVED PERMIT SET SHALL BE KEPT ON SITE.

15. THE CONTRACTOR SHALL EXAMINE THE SITE AND FAMILIARIZE THEMSELF WITH

ALL EXISTING CONDITIONS, AND BE PREPARED TO PERFORM THE WORK WITHIN THE EXISTING CONDITIONS.

16. THE CONTRACTOR AND EACH SUBCONTRACTOR SHALL INSPECT WORK

PREVIOUSLY PREPARED OR INSTALLED BY OTHERS BEFORE APPLYING SUBSEQUENT MATERIALS OR FINISHES. IF UNSATISFACTORY, NOTIFY MAINSPRING ENERGY. DO NOT PROCEED UNTIL THE DEFECTIVE WORK HAS BEEN CORRECTED.

17. NEITHER FINAL ACCEPTANCE, FINAL CERTIFICATION, FINAL PAYMENT NOR ANY

PROVISION UNDER THIS CONTRACT SHALL RELIEVE THE CONTRACTOR OF

RESPONSIBILITY FOR FAULTY MATERIALS OR WORKMANSHIP, WHICH THE CONTRACTOR HEREBY WARRANTS. THE CONTRACTOR SHALL REMEDY AT

THEIR OWN EXPENSE ANY DEFECTS OR DAMAGE WHICH APPEAR WITHIN ONE YEAR FROM THE FINAL RETENTION PAYMENT. IN THE EVENT REPAIRS OR

REPLACEMENTS ARE MADE WITHIN THIS PERIOD THEY SHALL BE FURTHER GUARANTEED FOR ONE YEAR FROM DATE OF ACCEPTANCE.

18. IN ACCORDANCE WITH GENERALLY ACCEPTED CONSTRUCTION PRACTICES

AND OSHA REQUIREMENTS, THE CONTRACTOR WILL BE SOLELY AND

COMPLETELY RESPONSIBLE FOR CONDITIONS OF THE JOB SITE, INCLUDING

SAFETY OF ALL PERSONS AND PROPERTY DURING PERFORMANCE OF THE WORK. THIS REQUIREMENT WILL APPLY CONTINUOUSLY AND WILL NOT BE

LIMITED TO NORMAL WORKING HOURS

19. CONTRACTOR TO VERIFY LATEST MAINSPRING INSTALLATION MANUAL PRIOR TO INSTALLATION.

THE PROJECT CONSISTS OF THE INSTALLATION OF (3) 250kW RATED MAINSPRING LINEAR GENERATOR SYSTEM FUELED BY PIPELINE NATURAL GAS OR BIOGAS. THE TOTAL GENERATION CAPACITY IS 750kW. THE GENERATOR SYSTEM IS USED FOR ELECTRICAL UTILITY LOAD REDUCTION PURPOSES. THE GENERATOR IS NOT AN EMERGENCY GENERATOR.
2022 CALIFORNIA BUILDING CODE (CBC)
2022 CALIFORNIA ELECTRICAL CODE (CEC)
2022 CALIFORNIA ENERGY EFFICIENCY STANDARD (CEES)
2022 CALIFORNIA FIRE CODE (CFC)
2022 CALIFORNIA GREEN BUILDING CODE (CALGREEN)
2022 CALIFORNIA MECHANICAL CODE (CMC)
2022 CALIFORNIA PLUMBING CODE (CPC)
2022 NATIONAL FIRE PROTECTION ASSOCIATION (NFPA 853)
2018 INSTITUTE OF ELECTRICAL AND ELECTRONIC ENGINEERS (IEEE 1547) 2022 UNDERWRITERS LABORATORIES (UL 1741)

SITE LOCATION

SITE LOCATION

3.0 PLOT PLAN

5.0 GAS SYSTEM DETAILS

4.0 SINGLE LINE DIAGRAM

ENGINEER OF RECORD

1.0 SHEET TITLE

PROJECT INFORMATION

ISSUE DESCRIPTION

COVERSHEET
DATEMAINSPRING LINEAR GENERATOR PROPRIETARY AND CONFIDENTIAL THE INFORMATION CONTAINED IN THIS DRAWING IS THE SOLE PROPERTY OF MAINSPRING ENERGY INCORPORATED. ANY REPRODUCTION IN PART OR AS A WHOLE WITHOUT THE WRITTEN PERMISSION OF MAINSPRING ENERGY INCORPORATED IS PROHIBITED.

32'-4" 49'-10" INTAKE FRONT REAR EXHAUST ELECTRIC GAS GAS DATA INTAKE FRONT REAR EXHAUST ELECTRIC GAS GAS DATA INTAKE FRONT REAR EXHAUST ELECTRIC GAS GAS DATA UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE UGE UGE

UGE UGE UGE

UGE UGE UGE UGE

UGE UGE UGE

UGE UGE UGE UGE

UGE UGE UGE

UGE UGE UGE UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE UGE UGE

UGE UGE UGE

UGE UGE UGE UGE

UGE UGE UGE

UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE
G

G G G G G G
G G G

G G G G

G G G G
G

G G G G G G

G G G G G

G G G G G G G G G G G G G G G G G G G G G
G G G G G 105'
80'
33' 20' UGE
32'-4" 49'-10" INTAKE FRONT REAR EXHAUST ELECTRIC GAS GAS DATA INTAKE FRONT REAR EXHAUST ELECTRIC GAS GAS DATA INTAKE FRONT REAR EXHAUST ELECTRIC GAS GAS DATA UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE

G G G G G G G
G
G
G
G

G G G G G G G G G
G
G G

G G G G G G G G G G G G G G
G

G G G G G G G G G G G
G G G G G G G G G G G G G G G G G G G G G G 105'
33' 20' UGE UGE UGE

UGE UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE UGE UGE

UGE UGE UGE

UGE UGE UGE UGE

UGE UGE UGE

UGE UGE UGE UGE

UGE UGE UGE
UGE G
G
G
G

G G G G G G G G G G G

G G G G G G G G
SCALE

ENGINEER OF RECORD

2.0 SHEET TITLE

PROJECT INFORMATION

ISSUE DATE DESCRIPTION
1:1
LAYOUT
(N) 21KV PG&E XFMR
(N) LGEN ELEC POI
(N) 4000A MSB
(N) PG&E GAS
LINE
(N) LGEN BOP
AREA
(N) GAS TRAIN
(N) PG&E GAS
METER
(N) BIOGAS
LINE
(N) FUEL SWITCHING

MANIFOLD
(N) 5FT

ELEVATED PAD
(N) ACCESS
RAMP
(N) PMC
(N) LGEN ELEC CABLE
(N) LGEN COMS CABLE
(N) PG&E GAS
LINE
(N) LGEN BOP
AREA
(N) GAS TRAIN
(N) PG&E GAS
METER
(N) 5FT

ELEVATED PAD
(N) BIOGAS
LINE
(N) FUEL SWITCHING

MANIFOLD
(N) ACCESS
RAMP
(N) BIOGAS
LINE
(N) 21KV PG&E XFMR
(N) LGEN ELEC POI
(N) 4000A MSB
(N) SITE CONTROLLER
(N) LGEN ELEC CABLE
(N) LGEN COMS CABLE
(N) BIOGAS
LINE MAINSPRING LINEAR GENERATOR PROPRIETARY AND CONFIDENTIAL THE INFORMATION CONTAINED IN THIS DRAWING IS THE SOLE PROPERTY OF MAINSPRING ENERGY INCORPORATED. ANY REPRODUCTION IN PART OR AS A WHOLE WITHOUT THE WRITTEN PERMISSION OF MAINSPRING ENERGY INCORPORATED IS PROHIBITED.

LGEN

ELECTRICAL

BOP AREA
LGEN

ELECTRICAL

BOP AREA
(N) NGOM DISCO
2 (N) NGOM
(N) NGOM DISCO
1

E UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE

UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE M M M
120VAC C
F

UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE

G UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE UGE LGEN 1 LGEN 2 LGEN 3
1 1 1

CTRL CTRL CTRL
A
D
B
400A
3P
400A
3P
400A
3P UGE UGE GFD
I UGE UGE UGE UGE UGE UGE UGE UGE 2
J
3 NEW PG&E

PAD-MOUNTED SERVICE

TRANSFORMER
21K-27/480,30, 4W
NEW 21kV PG&E SERVICE DROP P-GENMEB-1 P-GENMEB-2 P-GENMEB-3 P-GENMEB-4 P-GENMEB-5 P-GENMEB-6 P-GENMEB-7 P-GENMEB-8 P-GENMEB-9 (N) 4000A BUSWAY
NEMA 3Ø, 30, 4W
480-120V
NEW 2,000kW/2,5000kVA DIESEL STANDBY GENERATOR
(IN OUTDOOR, WALK-IN ENCLOSURE) 4000AF
3200AT 3

GEN-MEB
KWH

NEW PG&E REVENUE METER

UTILITY SERVICE

ENTRANCE SECTION
4000:5
3 FUT RELAYS
SEE NOTE 4
4000AF
4000AT
27 47
59 4000:5
3 3
480-208V
1 POWER MONITOR
4000:5
3 FUT RELAYS

AUTOMATIC TRANSFER

CONTROLS
(BREAK-BEFORE-MAKE)
27 59
480-120V
3200AF
3200AT
480-120V
27 47
59 81O/U
800AF
800AT
1600AF
1600AT
800AF
800AT
800AF
800AT
800AF
800AT
800AF
800AT
800AF
600AT
800AF
700AT
800AF
400AT
800AF
400AT
800AF
600AT
800AF
600AT
800AF
400AT
1600AF
1000AT
800AF
800AT
800AF
800AT
800AF
800AT
800AF
800AT
1600AF
1600AT
480V, 3Ø, 3W, 4000A, 85KA
3200AF
3200AT 2
480-120V
27 47
59 81O/U

PORTABLE GENARATOR

TERMINAL BOX
(2000KW MAX)

TB-PORTGEN

SWGR-MEB NEW PLANT MAIN SERVICE ENTRANCE

INDOOR SWITCHGEAR
(NEW MAIN ELECTRICAL BLDG)

TYP FOR ALL NEW SWGR-MEB POWER CIRCUIT BREAKERS

SCHEMATIC
DIAGRAM NO.(TYP)
SEE NOTE 3
(TYP) P-MEBMCC1-1 P-MEBMCC1-2 P-MEBMCC1-3 P-MEBMCC2-1 P-MEBMCC2-2 P-MEBMCC2-3 P-BBMCCN-1 P-BBMCCN-2 P-BBMCCE-1 P-BBMCCE-2 P-BBMCCE-3 P-ERBMCCC 800AF
800AT
600A 300A 600A 800A
MEB-MCC1 NEW MCC
(NEW MAIN ELECTRICAL BLDG)
MEB-MCC3 FUTURE MCC
(NEW MAIN ELECTRICAL BLDG)

BB-MCCN
(E)MCC
(BLOWER BLDG)

ERB-MCC
(E)MCC
(ENERGY RECOVERY P-TBPORTGEN-1 P-TBPORTGEN-2 P-TBPORTGEN-3 P-TBPORTGEN-4 P-TBPORTGEN-5 P-TBPORTGEN-6 P-TBPORTGEN-7 P-TBPORTGEN-8 P-TBPORTGEN-9 SPARE BREAKER 800AF
800AT 300A 600A
800A
MEB-MCC2 MEB-MCC4 BB-MCCE
TB-TEMP1 TEMPORARY LOAD
TERMINAL BOX NO.1
TB-TEMP2 TEMPORARY LOAD
TERMINAL BOX NO.2

PT-MCCB
(E) MCC
(HEADWORKS ELECTRICAL BLDG)

EPSA-MCC
400A
(E) MCC
(EFFLUENT PUMP STATION)

RPS-MCCB
(E) MCC
(ROUGHING FILTER BLDG)

SDB-MCC
(E) MCC
(SOLIDS DEWAT BLDG)
(E) MCC
(BLOWER BLDG) FUTURE MCC
(NEW MAIN ELECTRICAL BLDG)
(E) MCC
(ROUGHING FILTER BLDG)

RPS-MCCA
(E) MCC
(EFFLUENT PUMP STATION)

EPS-MCC
700A

NEW MCC
(NEW MAIN ELECTRICAL BLDG) SPARE BREAKER SPARE BREAKER 800AF/800AT EQUIPPED SPACE P-SDBMCC P-RPSMCCA-1 P-RPSMCCA-2 P-RPSMCCB-1 P-RPSMCCB-2 P-PTMCCB P-ATSA-1 P-ATSA-2 P-ATSA-3 P-EPSMCC-1 P-EPSMCC-2 P-EPSMCC-3 P-TBTEMP1-1 P-TBTEMP1-2 P-TBTEMP1-3 P-TBTEMP1-1 P-TBTEMP1-2 P-TBTEMP1-3 SEL 751
32R
M
120VAC
K
ST

CURRENT AND VOLTAGE SENSING ON

LINE SIDE OF MAIN BREAKER FOR

LOAD TRACKING CAPABILITIES AND
REVERSE POWER PROTECTION. UGE UGE G UGE UGE G

MUGE UGE
L

ENGINEER OF RECORD

3.0 SHEET TITLE

PROJECT INFORMATION

ISSUE DATE DESCRIPTION

GRID FOLLOWING

SINGLE LINE DIAGRAM

SYSTEM MODES OF OPERATION (GRID FOLLOWING)

1. NORMAL - GRID FOLLOWING:
· LGEN RUNS IN PARALLEL WITH THE GRID UNTIL STOP COMMAND IS GIVEN OR UTILITY POWER IS LOST.
· LGEN PROVIDES PEAK SHAVING AND POWER DEMAND OFFSET FUNCTIONS TO FACILITY.

2. UTILITY OUTAGE - GRID FOLLOWING:
· LGEN OPERATION STOPS.

3. RETURN TO NORMAL - GRID FOLLOWING:
· UTILITY POWER RETURNS PERIOD.
· CUSTOMER MAIN BREAKER CLOSES RE-CONNECTING FACILITY TO GRID. · FACILITY LOAD BROUGHT UP ON LINE.
· LGEN RESUMES OPERATION IN PARALLEL WITH THE GRID AS IN SECTION 1 ABOVE.

BOP EQUIPMENT SCHEDULE

ID EQUIPMENT RATING
(V)
RATING
(A) QTY.

A MSE LINEAR

GENERATOR
250KVA AC, 480V, 3P,
300A
3 B

UTILITY

INTERACTIVE

INVERTER

DYNAPOWER
COMANY
MPS-125EHV [480]
3P, 3W, 60HZ,
UL1741-SB, (QTY 2

PER LGEN)
6 C

EXTERNAL

PRODUCTION
METER
- - 3
D

EMERGENCY
STOP
- - 3

E NODE CONTROL

CABINET
120V - 1
F AC

SWITCHBOARD
480V 1200A 1
G

UTILITY AC

DISCONNECT
SWITCH
480V 1200A 3
H LGEN BREAKER 480V 1200A 1

I ISO XFMR
480VΔ:
480VY
- 1

J GROUND FAULT

DETECTION
- - 1
K
POWER

MONITERING

CABINET (PMC)
120V - 1
L NGOM PANEL - - 1

FEEDER SCHEDULE

CIRCUIT
NUMBER

FROM TO

CONDUCTOR

SIZE / TYPE
#CABLES IN

PARALLEL/PHASE

ONE-WAY

CIRCUIT
LENGTH
SECTION 1 LGEN 1-3 DC SKID 250 KCMIL 2 50
SECTION 2 DC SKID XFMR 500 KCMIL 4 25
SECTION 3 XFMR NGOM AC DISCO 1 500 KCMIL 4 25
SECTION 4 NGOM DISCO 1 NGOM 500 KCMIL 4 10
SECTION 5 NGOM NGOM DISCO 2 500 KCMIL 4 10
SECTION 6 NGOM DISCO 2 4000A SWGR 500 KCMIL 4 300 MAINSPRING LINEAR GENERATOR PROPRIETARY AND CONFIDENTIAL THE INFORMATION CONTAINED IN THIS DRAWING IS THE SOLE PROPERTY OF MAINSPRING ENERGY INCORPORATED. ANY REPRODUCTION IN PART OR AS A WHOLE WITHOUT THE WRITTEN PERMISSION OF MAINSPRING ENERGY INCORPORATED IS PROHIBITED.

LEGEND
COMMUNICATION CABLE (CAT 6)

CONTROL CABLE (STRANDED WIRE)

POWER CABLE

EXISTING CABLE

UGE UGE UGE UGE UGE UGE UGE UGE

1 GSD INDICATIVE NATURAL GAS SUPPLY DIAGRAM

LINEAR GENERATOR
GRD
2 GAS UTILITY METER GAS RISER

SHUT OFF VALVE
(INTERNAL)

FINISH GRADE CONCRETE PAD CONCRETE PAD CONCRETE PAD

SYMBOLS
SYMBOL
GENERAL NOTES:

1. GAS METER PROVIDED BY UTILITY.

2. SYSTEM TO COMPLY WITH NFPA 54, NFPA 37,

AND ANY OTHER APPLICABLE REGIONAL OR LOCAL
CODES.

3. VALVES, PIPING, FITTINGS, AND INSTRUMENTS
SHALL BE QUALIFIED FOR NATURAL GAS SERVICE.

4. CONCRETE DETAILS AND OTHER INSTALLATION

REQUIREMENTS WILL BE PRESENT IN THE MSE
INSTALLATION MANUAL.

DESCRIPTION

SHUT OFF VALVE

REGULATOR
METER

Y-STRAINER
ECAD

PRESSURE GAUGE WITH SHUT OFF VALVE

PRESSURE COMPENSATOR

EQUIPMENT SUPPORT

ABOVE GROUND PIPE OR CONDUIT

UNDERGROUND OR WITHIN AN

ENCLOSURE PIPE OR CONDUIT
1 GSD
1 5
2 3

FINISH GRADE
4 CONCRETE PAD
4 1

INDICATIVE GAS RISER DIAGRAM
LEGEND:
6 3
2 1. PRESSURE REGULATORS (n+1)

2. PRESSURE GAUGE

3. SHUT-OFF VALVE

4. 2" UNION (TYPICAL, AS REQUIRED)

5. CALIFORNIA SEISMIC VALVE (AS REQUIRED)

6. EQUIPMENT SUPPORT (AS REQUIRED)
GENERAL NOTES:

1. THE REGULATOR SET ASSEMBLY
DESIGN IS FOR INFORMATION ONLY.

2. THIS DRAWING DOES NOT EXCUSE

THE CONTRACTOR FROM

INSTALLATION PER APPLICABLE

BUILDING CODES OR MANUFACTURE
REQUIREMENTS.

ENGINEER OF RECORD

4.0 SHEET TITLE

PROJECT INFORMATION

ISSUE DATE DESCRIPTION
GAS SYSTEM MAINSPRING LINEAR GENERATOR PROPRIETARY AND CONFIDENTIAL THE INFORMATION CONTAINED IN THIS DRAWING IS THE SOLE PROPERTY OF MAINSPRING ENERGY INCORPORATED. ANY REPRODUCTION IN PART OR AS A WHOLE WITHOUT THE WRITTEN PERMISSION OF MAINSPRING ENERGY INCORPORATED IS PROHIBITED.

r040102
MSE3-250 Fuel specifications
This document specifies the fuel gas quality
supplied to a Mainspring linear generator,
including its composition, humidity level, and inlet
pressure. This specification covers the capability of
the linear generator to efficiently and reliably
convert these fuels to electric power.

1. Applicable fuels
This specification applies to natural gas, hydrogen,
propane, biogas, synthesis gas, and other
organically derived fuel gases.

2. Fuel gas temperature
Maximum 50 degrees Celsius (122 °F).

3. Energy Content and Supply Pressure
The minimum fuel supply pressure at the
generator inlet is 5 psig (0.35 barg) for pipeline
natural gas and propane, with a preferred inlet
pressure of at least 10 psig (0.69 barg). This is the
minimum required pressure at the generator inlet
- pressure drop from the point of regulation needs
to be accounted for separately - and is needed to
ensure sufficient flow of fuel into the pressurized
intake to attain the desired power output..

Fuel supplied to the linear generator must remain
under the maximum allowable operating pressure
(MAOP) 20 psig (1.38 barg) in order for the
generator to operate. Pressure in excess of the
maximum allowable working pressure (MAWP) 42
psig (2.90 barg) may result in damage to the fuel
system. External fuel pressure controls are
required to ensure the supply pressure does not
exceed the MAWP.

Fuels with lower energy content require an
increased supply pressure in order to obtain full
rated power. Fuel heating value should be based
on a composition analysis of the fuel according to
ASTM D1945 and calculation of the lower heating
value (LHV) according to ASTM D3588. The
minimum required supply pressure as a function
of LHV is:

LHV [BTU/scf]
Min Supply Pressure
[psig]
360 17.6
405 14.8
450 12.7
495 11.1
540 9.9
585 8.8
630 8.2
675 7.7
720 7.2
765 6.8
810 6.4
855 6.1
900 5.6
950 5
Note that fuel LHV above 950 BTU/scf is allowed
(subject to the other requirements in this
specification document), but the minimum supply
pressure remains 5 psig.

This document is proprietary and confidential and may contain legally privileged information. No part of this document may be distributed, disseminated, published, or otherwise disclosed in any manner to a third party without prior written consent of Mainspring Energy, Inc.

r040102

4. Diluent gases
Provided that the supply pressure and energy
content of the fuel meets the requirements listed
in this document, there are no limitations to the
amount of non-condensable diluent gases such as
O2, N2 or CO2 present in the fuel supply.

5. Moisture and Other Condensable Liquids
The linear generator is designed to handle a range
of gaseous fuels, but the fuel system is not
tolerant of condensed liquids. Fuel supplied to
the linear generator must have a dew point at
least 5 degrees Celsius below the minimum
expected ambient temperature, and must be free
of condensed water, oil or other liquids.

6. Particulate contamination
Fuel supplied to the generator should be free of
solid debris or particulate matter above 10 micron
in diameter. The linear generator is equipped with
a straining screen that is serviced on an annual
basis. If this screen becomes overloaded due to
excessive particulate contamination, the system
may encounter operational issues.

Particulate matter below 10 micron in diameter
may impact emissions compliance. Please consult
with Mainspring Energy if this may be present in
the fuel stream for specific guidance.

7. Sulfur
Sulfur content in the fuel should be maintained
below 5 ppmv as H2S, normalized to an LHV of
900 BTU/scf. The H2S content should be
determined using ASTM D4084.

For example, if the LHV is 450 BTU/SCF, then the
fuel content should remain under 2.5 ppmv.

8. Siloxanes
Siloxanes should be maintained below the
non-detect limit (< 100 ppb silica content)
normalized to an LHV of 35.33 MJ/m
3 (900
BTU/scf). The level of siloxanes should be
determined by analyzing a fuel sample according
to ASTM D8230 or D8455.

9. Other contaminants
Ionic compounds (e.g. Chloride, Potassium,
Sodium) and heavy metals (e.g. Mercury,
Chromium) can result in damage to equipment. If
these may be present in the fuel stream, please
consult with Mainspring Energy for specific
guidance.

10. Toxic Air Contaminants and Volatile
Organic Compounds
The presence of toxic air contaminants (e.g.
formaldehyde,etc) and volatile organic
compounds (e.g. propane, etc) in the fuel stream
may impact emissions compliance. Please consult
with Mainspring Energy if these may be present in
This document is proprietary and confidential and may contain legally privileged information. No part of this document may be distributed, disseminated, published, or otherwise disclosed in any manner to a third party without prior written consent of Mainspring Energy, Inc.

r040102
the fuel stream for specific guidance.

11. Reference: Biogas CH4 concentration
Please refer to this table to correlate volume % of
CH4 to the lower heating value to determine the
minimum required supply pressure in biogas
application. This assumes that the balance of the
fuel gas is inert (e.g. CO2,N2). For reference
purposes, the approximate fuel flow rate per
generator is also included. This flow rate assumes
the generator is operating at 44% efficiency.

Environmental conditions such as elevation and
ambient temperature can impact the flow rate
and should be accounted for in the fuel supply
design.

CH4
Volume
Fraction
LHV
[BTU/scf]
Min Supply
Pressure [psig]
Expected
Fuel Flow
Rate [SCFM]
40% 360 17.6 87
45% 405 14.8 77
50% 450 12.7 69
55% 495 11.1 63
60% 540 9.9 58
65% 585 8.8 53
70% 630 8.2 49
75% 675 7.7 46
80% 720 7.2 43
85% 765 6.8 41
90% 810 6.4 38
95% 855 6.1 36
100% 900 5.6 35
— end of document
This document is proprietary and confidential and may contain legally privileged information. No part of this document may be distributed, disseminated, published, or otherwise disclosed in any manner to a third party without prior written consent of Mainspring Energy, Inc.

Radically simple. Factory built.

The Mainspring Linear Generator runs on any fuel, is fully dispatchable, uses no water, and emits near-zero NOx. No other primary power solution can match the flexibility, affordability, and low emissions of a linear generator.
y PERFORMANCE SPECS: MODEL NO. LGEN 3
For more product information,
scan the QR Code or visit
MAINSPRINGENERGY.COM
Up to 18 MW per
acre scalability
Each package
contains two linear
generator cores,
operated in tandem
OUTPUTS1 Power (net AC) 250 kW
Electrical 400/480 V, 3 Phase, 50/60 Hz
INPUTS Fuels Any blend of Biogas2, Natural
Gas, Hydrogen, and Propane
Input Pressure 5–20 psig (15 psig nominal)
Water Consumption None
EFFICIENCY3 Electrical (LHV, net AC) 46%
Heat Rate (HHV, net AC) 8,233 BTU/kWh
EMISSIONS4 NOx <1.5 ppm (<0.05 lb/MWh)
Noise <70 dBA @ 3m, <65 dBA @10m
PHYSICAL Weight 20 tonnes
Dimensions (L x W x H) 20.5' × 8.5' × 9.5'
ENVIRONMENT Temperature Range -30° to 50° C
Humidity 0 to 100%
OPERATIONS Power Output Range 0 to 100% power output
Grid Parallel to Island Transfer5 <10 sec
Maximum Step Load 300 kVA for up to 10 sec
Building Soft Start Capability Yes
OTHER UL 2200 package Remote monitoring
UL 1741 SB grid-tie inverter Secure customer portal
Compliant with CA Rule 21 Modbus interface

1. Rated capacity may vary by fuel type. 2. Refer to Mainspring Fuel Specifications for details. 3. Measured according to ASME PTC 5O at 15 C and 1 atm on natural gas and biogas.

Rated efficiency may vary by fuel type. 4. Products comply with emissions limits in South Coast AQMD. All data is subject to technical development and modification. R30312 y PRODUCT FEATURES
01 Fuel Flexible
Seamlessly switch between
natural gas, RNG, biogas,
propane, and hydrogen.
02 Dispatchable
Quickly ramp output to
meet variable workloads
and enable grid independent
operations.
03 Low emissions
Produce electricity with nearzero NOx and meet even the most stringent air quality
standards.
04 Modular
Enable faster deployment
timelines with factory-built
units that are quick to install.
05 Low maintenance
Minimize downtime with
modular design, only two
moving parts and no oil.
y MAINSPRING LINEAR GENERATOROR

1 2
3 4
5 6
7 8
9 10
11 12
13 14
15 16
17 18
19 20
21 22
23 24
25 26
27 28
29 30
31 32
33 34
35 36
37 38
39 40
41 42
43 44
45 46
47 48
49 50
51 52
53 54
55 56
57 58
59 60
61 62
63 A B C D E F
Digester Waste
Gas
Digester Waste
Gas meter
reading
1701 1702
k cfd k cfd
1 Wed 187187.00 67178607.00
2 Thu 37604.00 67216211.00
3 Fri 53694.00 67269905.00
4 Sat 8677.00 67278582.00
5 Sun 99992551.00 67271133.00
6 Mon 2454.00 67273587.00
7 Tue 2533.00 67276120.00
8 Wed 4088.00 67280208.00
9 Thu 19981.00 67300189.00
10 Fri 35878.00 67336067.00
11 Sat 36776.00 67372843.00
12 Sun 31299.00 67404142.00
13 Mon 27288.00 67431430.00
14 Tue 22543.00 67453973.00
15 Wed 18749.00 67472722.00
16 Thu 26636.00 67499358.00
17 Fri 25740.00 67525098.00
18 Sat 21705.00 67546803.00
19 Sun 5572.00 67552375.00
20 Mon 1100.00 67553475.00
21 Tue 4208.00 67557683.00
22 Wed 13940.00 67571623.00
23 Thu 11172.00 67582795.00
24 Fri 18636.00 67601431.00
25 Sat 20000.00 67621431.00
26 Sun 20000.00 67641431.00
27 Mon 16503.00 67657934.00
28 Tue 25933.00 67683867.00
29 Wed 26231.00 67710098.00
30 Thu 23764.00 67733862.00
31 Fri 30959.00 67764821.00
1 Sat 37263.00 67802084.00
2 Sun 13974.00 67816058.00
3 Mon 7842.00 67823900.00
4 Tue 13878.00 67837778.00
5 Wed 20049.00 67857827.00
6 Thu 18571.00 67876398.00
7 Fri 21190.00 67897588.00
8 Sat 27923.00 67925511.00
9 Sun 32214214.40 139725.40
10 Mon 67851538.60 67991264.00
11 Tue 29330.00 68020594.00
12 Wed 19322.00 68039916.00
13 Thu 2836.00 68042752.00
14 Fri 5497.00 68048249.00
15 Sat 10658.00 68058907.00
16 Sun 6798.00 68065705.00
17 Mon 13502.00 68079207.00
18 Tue 13230.00 68092437.00
19 Wed 38979.00 68131416.00
20 Thu 30662.00 68162078.00
21 Fri 24699.00 68186777.00
22 Sat 13157.00 68199934.00
23 Sun 5992.00 68205926.00
24 Mon 12183.00 68218109.00
25 Tue 8466.00 68226575.00
26 Wed 14253.00 68240828.00
27 Thu 195274.00 68436102.00
28 Fri 22355.00 68458457.00 Daily Com
WWTP\Utilities
Jan
Feb
File: Waste gas data.pdf
Received: January 7th, 2026
Description: Reflective of full year 2025 Daily biogas flow data Data Type: Raw daily Data
Source: City of Watsonville Operator
Purpose: Linear Gen and Gas Scrubber Sizing

64 65
66 67
68 69
70 71
72 73
74 75
76 77
78 79
80 81
82 83
84 85
86 87
88 89
90 91
92 93
94 95
96 97
98 99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
123
124
125
126
127
128

A B C D E F
1 Sat 13977.00 68472434.00
2 Sun 2523.00 68474957.00
3 Mon 31527818.00 2775.00
4 Tue 68478264.00 68481039.00
5 Wed 9144.00 68490183.00
6 Thu 5517.00 68495700.00
7 Fri 26056.00 68521756.00
8 Sat 18999.00 68540755.00
9 Sun 30170.00 68570925.00
10 Mon 12770.00 68583695.00
11 Tue 21692.00 68605387.00
12 Wed 25316.00 68630703.00
13 Thu 19456.00 68650159.00
14 Fri 24847.00 68675006.00
15 Sat 34063837.00 2738843.00
16 Sun 65983332.00 68722175.00
17 Mon 25272.00 68747447.00
18 Tue 19505.00 68766952.00
19 Wed
20 Thu 37187.00 68804139.00
21 Fri
22 Sat 42233.00 68846372.00
23 Sun 9034.00 68855406.00
24 Mon 16520.00 68871926.00
25 Tue 19644.00 68891570.00
26 Wed
27 Thu
28 Fri
29 Sat 154048.00 69045618.00
30 Sun 51720.00 69097338.00
31 Mon 34355.00 69131693.00
1 Tue 31055.00 69162748.00
2 Wed
3 Thu
4 Fri
5 Sat 164807.00 69327555.00
6 Sun 26605.00 69354160.00
7 Mon 36917.00 69391077.00
8 Tue 31873.00 69422950.00
9 Wed 29088.00 69452038.00
10 Thu 18128.00 69470166.00
11 Fri
12 Sat 50069.00 69520235.00
13 Sun 24974.00 69545209.00
14 Mon 39389.00 69584598.00
15 Tue 33701.00 69618299.00
16 Wed 26682.00 69644981.00
17 Thu 34721.00 69679702.00
18 Fri
19 Sat 38628.00 69718330.00
20 Sun 23498.00 69741828.00
21 Mon 11853.00 69753681.00
22 Tue 16880.00 69770561.00
23 Wed 27643.00 69798204.00
24 Thu 204161.00 70002365.00
25 Fri 22895.00 70025260.00
26 Sat 19830.00 70045090.00
27 Sun 19012.00 70064102.00
28 Mon 28822.00 70092924.00
29 Tue 27669.00 70120593.00
30 Wed 29618.00 70150211.00
1 Thu 30983.00 70181194.00
2 Fri 24414.00 70205608.00
3 Sat 18546.00 70224154.00
4 Sun 16834.00 70240988.00
Apr
Mar

129
130
131
132
133
134
135
136
137
138
139
140
141
142
143
144
145
146
147
148
149
150
151
152
153
154
155
156
157
158
159
160
161
162
163
164
165
166
167
168
169
170
171
172
173
174
175
176
177
178
179
180
181
182
183
184
185
186
187
188
189
190
191
192
193

A B C D E F
5 Mon 14536.00 70255524.00
6 Tue 15936.00 70271460.00
7 Wed 6805.00 70278265.00
8 Thu 14232.00 70292497.00
9 Fri 18057.00 70310554.00
10 Sat 16608.00 70327162.00
11 Sun 7636.00 70334798.00
12 Mon 125052.00 70459850.00
13 Tue 255125.00 70714975.00
14 Wed 268385.00 70983360.00
15 Thu 19347.00 71002707.00
16 Fri 2481.00 71005188.00
17 Sat 2390.00 71007578.00
18 Sun 41584217.00 12591795.00
19 Mon 58421567.00 71013362.00
20 Tue 2915.00 71016277.00
21 Wed 42722.00 71058999.00
22 Thu 23945.00 71082944.00
23 Fri 208354.00 71291298.00
24 Sat 58310.00 71349608.00
25 Sun 10324.00 71359932.00
26 Mon 11633.00 71371565.00
27 Tue 17644.00 71389209.00
28 Wed 22009.00 71411218.00
29 Thu 20733.00 71431951.00
30 Fri 15664.00 71447615.00
31 Sat 19782.00 71467397.00
1 Sun 6182.00 71473579.00
2 Mon 11425.00 71485004.00
3 Tue 29285.00 71514289.00
4 Wed 62563.00 71576852.00
5 Thu 17314.00 71594166.00
6 Fri 11092.00 71605258.00
7 Sat 15975.00 71621233.00
8 Sun 6225.00 71627458.00
9 Mon 3915.00 71631373.00
10 Tue 11794.00 71643167.00
11 Wed 24809.00 71667976.00
12 Thu 109167.00 71777143.00
13 Fri 43887.00 71821030.00
14 Sat 26802.00 71847832.00
15 Sun 46017683.00 17865515.00
16 Mon 54016952.00 71882467.00
17 Tue 3290.00 71885757.00
18 Wed 7154.00 71892911.00
19 Thu 105066.00 71997977.00
20 Fri 11349.00 72009326.00
21 Sat 10410.00 72019736.00
22 Sun 10021.00 72029757.00
23 Mon 2914.00 72032671.00
24 Tue 16166.00 72048837.00
25 Wed 184946.00 72233783.00
26 Thu 110436.00 72344219.00
27 Fri 33600.00 72377819.00
28 Sat 19045.00 72396864.00
29 Sun 224680.00 72621544.00
30 Mon 126511.00 72748055.00
1 Tue 289989.00 73038044.00
2 Wed 252162.00 73290206.00
3 Thu 276044.00 73566250.00
4 Fri 224645.00 73790895.00
5 Sat 237757.00 74028652.00
6 Sun 237030.00 74265682.00
7 Mon 91475.00 74357157.00
8 Tue 17247.00 74374404.00
May
Jun

194
195
196
197
198
199
200
201
202
203
204
205
206
207
208
209
210
211
212
213
214
215
216
217
218
219
220
221
222
223
224
225
226
227
228
229
230
231
232
233
234
235
236
237
238
239
240
241
242
243
244
245
246
247
248
249
250
251
252
253
254
255
256
257
258

A B C D E F
9 Wed 17380.00 74391784.00
10 Thu 4172.00 74395956.00
11 Fri 2667.00 74398623.00
12 Sat 4265.00 74402888.00
13 Sun 2638.00 74405526.00
14 Mon 2744.00 74408270.00
15 Tue 5660.00 74413930.00
16 Wed 17483.00 74431413.00
17 Thu 8577.00 74439990.00
18 Fri 7350.00 74447340.00
19 Sat 3540.00 74450880.00
20 Sun 2844.00 74453724.00
21 Mon 2742.00 74456466.00
22 Tue 3672.00 74460138.00
23 Wed 19074.00 74479212.00
24 Thu 20263.00 74499475.00
25 Fri 45429.00 74544904.00
26 Sat 23665.00 74568569.00
27 Sun 10409.00 74578978.00
28 Mon 21038.00 74600016.00
29 Tue 34416.00 74634432.00
30 Wed 16648.00 74651080.00
31 Thu 23450.00 74674530.00
1 Fri 20865.00 74695395.00
2 Sat 17218.00 74712613.00
3 Sun 9791.00 74722404.00
4 Mon 63086.00 74785490.00
5 Tue 99972326.00 74757816.00
6 Wed 2756.00 74760572.00
7 Thu 63424.00 74823996.00
8 Fri 3474.00 74827470.00
9 Sat 2501.00 74829971.00
10 Sun 2640.00 74832611.00
11 Mon 21151.00 74853762.00
12 Tue 23519.00 74877281.00
13 Wed 23696.00 74900977.00
14 Thu 2573.00 74903550.00
15 Fri 2752.00 74906302.00
16 Sat 2530.00 74908832.00
17 Sun 2784.00 74911616.00
18 Mon 133631.00 75045247.00
19 Tue 196647.00 75241894.00
20 Wed 165406.00 75407300.00
21 Thu 219300.00 75626600.00
22 Fri 224478.00 75851078.00
23 Sat 202162.00 76053240.00
24 Sun 106779.00 76160019.00
25 Mon 63340.00 76223359.00
26 Tue 2738.00 76226097.00
27 Wed 2687.00 76228784.00
28 Thu 2536.00 76231320.00
29 Fri 2677.00 76233997.00
30 Sat 2474.00 76236471.00
31 Sun 2505.00 76238976.00
1 Mon 2618.00 76241594.00
2 Tue 2386.00 76243980.00
3 Wed 2645.00 76246625.00
4 Thu 2375.00 76249000.00
5 Fri 2700.00 76251700.00
6 Sat 2737.00 76254437.00
7 Sun 2811.00 76257248.00
8 Mon 2939.00 76260187.00
9 Tue 52143.00 76312330.00
10 Wed 20650.00 76332980.00
11 Thu 7276.00 76340256.00
Jul
Aug

259
260
261
262
263
264
265
266
267
268
269
270
271
272
273
274
275
276
277
278
279
280
281
282
283
284
285
286
287
288
289
290
291
292
293
294
295
296
297
298
299
300
301
302
303
304
305
306
307
308
309
310
311
312
313
314
315
316
317
318
319
320
321
322
323
ABCDEF
12 Fri 2236.00 76342492.00
13 Sat 2126.00 76344618.00
14 Sun 2384.00 76347002.00
15 Mon 2329.00 76349331.00
16 Tue 2441.00 76351772.00
17 Wed 2404.00 76354176.00
18 Thu 2506.00 76356682.00
19 Fri 2086.00 76358768.00
20 Sat 2247.00 76361015.00
21 Sun 2340.00 76363355.00
22 Mon 2335.00 76365690.00
23 Tue 2323.00 76368013.00
24 Wed 2387.00 76370400.00
25 Thu 6912.00 76377312.00
26 Fri 7422.00 76384734.00
27 Sat 2668.00 76387402.00
28 Sun 2527.00 76389929.00
29 Mon 8234.00 76398163.00
30 Tue 2804.00 76400967.00
1 Wed 4627.00 76405594.00
2 Thu 3943.00 76409537.00
3 Fri 8103.00 76417640.00
4 Sat 2616.00 76420256.00
5 Sun 2397.00 76422653.00
6 Mon 2571.00 76425224.00
7 Tue 2685.00 76427909.00
8 Wed 2666.00 76430575.00
9 Thu 2688.00 76433263.00
10 Fri 2903.00 76436166.00
11 Sat 8826.00 76444992.00
12 Sun 2673.00 76447665.00
13 Mon 10085.00 76457750.00
14 Tue 2917.00 76460667.00
15 Wed 7164.00 76467831.00
16 Thu 19986.00 76487817.00
17 Fri 27801.00 76515618.00
18 Sat 33714.00 76549332.00
19 Sun 13720.00 76563052.00
20 Mon 15581.00 76578633.00
21 Tue 69237.00 76647870.00
22 Wed 304397.00 76952267.00
23 Thu 214158.00 77166425.00
24 Fri 30482.00 77196907.00
25 Sat 29208.00 77226115.00
26 Sun 28599.00 77254714.00
27 Mon 17522.00 77272236.00
28 Tue 27170.00 77299406.00
29 Wed 23743.00 77323149.00
30 Thu 18216.00 77341365.00
31 Fri 8623.00 77349988.00
1 Sat 8713.00 77358701.00
2 Sun 6474.00 77365175.00
3 Mon 3719.00 77368894.00
4 Tue 11050.00 77379944.00
5 Wed 25702.00 77405646.00
6 Thu 33046.00 77438692.00
7 Fri 37125.00 77475817.00
8 Sat 35580.00 77511397.00
9 Sun 24375.00 77535772.00
10 Mon 27786.00 77563558.00
11 Tue 36219.00 77599777.00
12 Wed 26429.00 77626206.00
13 Thu 18125.00 77644331.00
14 Fri 14380.00 77658711.00
15 Sat 5111.00 77663822.00
Sep
Oct
Nov

324
325
326
327
328
329
330
331
332
333
334
335
336
337
338
339
340
341
342
343
344
345
346
347
348
349
350
351
352
353
354
355
356
357
358
359
360
361
362
363
364
365
366
367
368
369 370
371
372
373
374

A B C D E F
16 Sun 2963.00 77666785.00
17 Mon 3120.00 77669905.00
18 Tue 3176.00 77673081.00
19 Wed 3139.00 77676220.00
20 Thu 5173.00 77681393.00
21 Fri 4417.00 77685810.00
22 Sat 4734.00 77690544.00
23 Sun 2746.00 77693290.00
24 Mon 2869.00 77696159.00
25 Tue 3210.00 77699369.00
26 Wed 61133.00 77760502.00
27 Thu 25356.00 77785858.00
28 Fri 26002.00 77811860.00
29 Sat 33504.00 77845364.00
30 Sun 12299.00 77857663.00
1 Mon 14157.00 77871820.00
2 Tue 13800.00 77885620.00
3 Wed 15378.00 77900998.00
4 Thu 20896.00 77921894.00
5 Fri 17027.00 77938921.00
6 Sat 23719.00 77962640.00
7 Sun 10679.00 77973319.00
8 Mon 8833.00 77982152.00
9 Tue 31874.00 78014026.00
10 Wed 51301.00 78065327.00
11 Thu 33374.00 78098701.00
12 Fri 47330.00 78146031.00
13 Sat 46477.00 78192508.00
14 Sun 19125.00 78211633.00
15 Mon 42496.00 78254129.00
16 Tue 50901.00 78305030.00
17 Wed 168944.00 78473974.00
18 Thu 18948.00 78492922.00
19 Fri 19044.00 78511966.00
20 Sat 20501.00 78532467.00
21 Sun 15907.00 78548374.00
22 Mon 22097.00 78570471.00
23 Tue 35617.00 78606088.00
24 Wed 2643.00 78608731.00
25 Thu 40270.00 78649001.00
26 Fri 3116.00 78652117.00
27 Sat 3031.00 78655148.00
28 Sun 110670.00 78765818.00
29 Mon 34548.00 78800366.00
30 Tue 6691.00 78807057.00
31 Wed 2974.00 78810031.00
1,100.0 2,775.0
99,992,551.0 78,810,031.0
2,005,122.8 72,191,929.9
711,818,611.0 25,628,135,110.4

MAXIMUM

AVERAGE
SUM
Nov
Dec

MINIMUM

January 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Tue 11700 2432 1123 268 14132 0.09683 109 0 1.026 0 109 0 2 Wed 3000 1536 227 9864 4236 0.09683 22 6 1.026 62 22 40 3 Thu 3300 8320 7012 2780 11020 0.09683 679 11 1.026 113 679 0 4 Fri 0 10112 8804 4288 9212 0.09683 852 0 1.026 0 852 0 5 Sat 7500 5632 4324 1268 13132 0.09683 419 45 1.026 462 419 43 6 Sun 8400 5760 4452 240 14160 0.09683 431 62 1.026 636 431 205 7 Mon 5700 7680 6372 1020 13380 0.09683 617 62 1.026 636 617 19 8 Tue 7800 6784 5476 -184 14584 0.09683 530 3 1.026 31 530 0 9 Wed 3900 8704 7396 1796 12604 0.09683 716 0 1.026 0 716 0 10 Thu 2100 9984 8676 2316 11784 0.09683 840 0 1.026 0 840 0 11 Fri 600 10496 9187 3304 10196 0.09683 890 0 1.026 0 890 0 12 Sat 0 10880 9571 3520 9980 0.09683 927 0 1.026 0 927 0 13 Sun 600 11264 9955 2536 11264 0.09683 964 0 1.026 0 964 0 14 Mon 1500 10880 9571 2020 12380 0.09683 927 0 1.026 0 927 0 15 Tue 1500 5632 4323 7268 6832 0.09683 419 0 1.026 0 419 0 16 Wed 600 15872 14563 -2072 16172 0.09683 1410 0 1.026 0 1410 0 17 Thu 0 11136 11136 3264 10536 0.09683 1078 0 1.026 0 1078 0 18 Fri 300 11776 11768 2324 10576 0.09683 1139 0 1.026 0 1139 0 19 Sat 0 11008 11008 3392 10108 0.09683 1066 19 1.026 195 1066 0 20 Sun 4500 8960 8960 940 13160 0.09683 868 46 1.026 472 868 0 21 Mon 2400 10112 10112 1888 12512 0.09683 979 36 1.026 369 979 0 22 Tue 3600 10240 8931 560 13540 0.09683 865 0 1.026 0 865 0 23 Wed 3000 9856 9856 1544 12556 0.09683 954 0 1.026 0 954 0 24 Thu 4200 9344 8036 856 13544 0.09683 778 0 1.026 0 778 0 25 Fri 900 11904 11904 1596 12504 0.09683 1153 0 1.026 0 1153 0 26 Sat 300 13184 13184 916 12884 0.09683 1277 0 1.026 0 1277 0 27 Sun 1200 8320 8320 4880 9520 0.09683 806 0 1.026 0 806 0 28 Mon 600 8320 8320 5480 8320 0.09683 806 0 1.026 0 806 0 29 Tue 300 22912 21604 -8812 22912 0.09683 2092 0 1.026 0 2092 0 30 Wed 1800 11392 10084 1208 12892 0.09683 976 0 1.026 0 976 0 31 Thu 3300 8832 7524 2268 12132 0.09683 729 9 1.026 92 729 0 MIN 0 1536 227 -8812 4236 0.09683 22 0 0 22 0
MAX 11700 22912 21604 9864 22912 0.09683 2092 62 636 2092 205 AVG 2729.0 9653.677 8767.065 2017 12025 0.09683 849 9.6 99 849 10 SUM 84600 299264 271779 62536 372764 26316 299 3068 26316 307 Non-allowed therms 0

File: CoGenGas_2025.pdf
Received: January 7th, 2026
Description: Existing Cogen run hours and fuel blending ratio Data Type: Raw daily Data
Source: City of Watsonville Operator
Purpose: Linear Gen and Gas Scrubber Sizing

January 2025
D
A
T
E
D
A
Y
1 Tue
2 Wed
3 Thu
4 Fri
5 Sat
6 Sun
7 Mon
8 Tue
9 Wed
10 Thu
11 Fri
12 Sat
13 Sun
14 Mon
15 Tue
16 Wed
17 Thu
18 Fri
19 Sat
20 Sun
21 Mon
22 Tue
23 Wed
24 Thu
25 Fri
26 Sat
27 Sun
28 Mon
29 Tue
30 Wed
31 Thu
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 0 0 0.0

0.18700 0.24104 0.01733 0.31300 $4 $22 $26 0.017 0.015 300 $4.44 28.6 5900 168500 21.5

0.18700 0.24104 0.01733 0.31300 $23 $0 $23 0.003 0.029 600 $17.54 15.5 10900 169000 20.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 164900 22.3

0.18700 0.24104 0.01733 0.31300 $86 $24 $109 0.019 0.013 0 $0.00 4.4 44700 195700 24.2

0.18700 0.24104 0.01733 0.31300 $88 $114 $202 0.035 -0.003 0 $0.00 3.1 62100 191000 23.4

0.18700 0.24104 0.01733 0.31300 $126 $11 $137 0.018 0.014 0 $0.00 3.8 61700 233300 24.4

0.18700 0.24104 0.01733 0.31300 $6 $0 $6 0.001 0.031 0 $0.00 48.8 3400 165900 21.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 176200 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 182100 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 175000 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 176700 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 180100 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 185000 24.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 169700 24.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 180500 24.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 175400 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1500 $0.00 #DIV/0! 0 182300 24.4

0.18700 0.24104 0.01733 0.31300 $40 $0 $40 0.004 0.028 900 $25.54 10.4 19400 202300 24.0

0.18700 0.24104 0.01733 0.31300 $96 $0 $96 0.011 0.021 300 $6.37 4.7 46000 216900 23.6

0.18700 0.24104 0.01733 0.31300 $75 $0 $75 0.007 0.025 0 $0.00 6.2 35700 222200 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 186300 25.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 171900 23.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 174100 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 188000 24.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 166200 23.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 0 $0.00 #DIV/0! 0 776500 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 183300 25.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 177600 23.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 186000 25.0

0.18700 0.24104 0.01733 0.31300 $19 $0 $19 0.002 0.030 0 $0.00 17.6 8700 152700 21.3 $0 $0 $0 0.000 -0.003 0 $0.00 #DIV/0! 0 0 0
$126 $114 $202 0.035 0.031 1500 $25.54 #DIV/0! 62100 776500 25.1 $18 $5 $24 0.004 0.007 358 $1.74 #DIV/0! 9629.0 195977.4 22.9 $564 $170 $734 11100 $53.89 298500 6075300 709.6

February 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Fri 1800 11008 9699 1592 12208 0.09683 939 9.5 1.026 97 939 0 2 Sat 600 10752 9443 3048 10752 0.09683 914 0 1.026 0 914 0 3 Sun 300 11648 10339 2452 11048 0.09683 1001 0 1.026 0 1001 0 4 Mon 2400 10240 8931 1760 12340 0.09683 865 0 1.026 0 865 0 5 Tue 1200 10112 8803 3088 10712 0.09683 852 0 1.026 0 852 0 6 Wed 600 11136 9828 2664 10836 0.09683 952 0 1.026 0 952 0 7 Thu 600 11264 9955 2536 10964 0.09683 964 0 1.026 0 964 0 8 Fri 0 11136 9827 3264 10236 0.09683 952 0 1.026 0 952 0 9 Sat 0 11392 10083 3008 10192 0.09683 976 0 1.026 0 976 0 10 Sun 0 11520 10212 2880 10320 0.09683 989 0 1.026 0 989 0 11 Mon 0 11392 10083 3008 9892 0.09683 976 0 1.026 0 976 0 12 Tue 1200 11520 10212 1680 12120 0.09683 989 0 1.026 0 989 0 13 Wed 1500 10752 9443 2148 11952 0.09683 914 0 1.026 0 914 0 14 Thu 900 10624 9315 2876 11224 0.09683 902 0 1.026 0 902 0 15 Fri 300 11776 10470 2324 11476 0.09683 1014 0 1.026 0 1014 0 16 Sat 300 10880 9571 3220 9980 0.09683 927 0 1.026 0 927 0 17 Sun 600 11364 9955 2436 11364 0.09683 964 0 1.026 0 964 0 18 Mon 300 11264 9955 2836 10964 0.09683 964 0 1.026 0 964 0 19 Tue 1500 10624 9315 2276 11224 0.09683 902 0 1.026 0 902 0 20 Wed 0 11648 10339 2752 10748 0.09683 1001 0 1.026 0 1001 0 21 Thu 0 11008 9699 3392 9808 0.09683 939 0 1.026 0 939 0 22 Fri 300 11520 10211 2580 10320 0.09683 989 0 1.026 0 989 0 23 Sat 0 11136 9827 3264 9636 0.09683 952 0 1.026 0 952 0 24 Sun 5100 9216 7907 84 14316 0.09683 766 20 1.026 205 766 0 25 Mon 5400 8064 6755 936 12864 0.09683 654 0 1.026 0 654 0 26 Tue 300 11392 10083 2708 11392 0.09683 976 0 1.026 0 976 0 27 Wed 4800 10880 9571 -1280 14780 0.09683 927 7700 1.026 79002 927 78075 28 Thu 4800 8448 7139 1152 12948 0.09683 691 0 1.026 0 691 0 MIN 0 8064 6755 -1280 9636 0.09683 654 0 0 654 0
MAX 5400 11776 10470 3392 14780 0.09683 1014 7700 79002 1014 78075 AVG 1242.9 10847 9534.643 2310 11308 0.09683 923 276.1 2832 923 2788 SUM 34800 303716 266970 64684 316616 25851 7729.5 79305 25851 78075 Non-allowed therms 53454

February 2025
D
A
T
E
D
A
Y
1 Fri
2 Sat
3 Sun
4 Mon
5 Tue
6 Wed
7 Thu
8 Fri
9 Sat
10 Sun
11 Mon
12 Tue
13 Wed
14 Thu
15 Fri
16 Sat
17 Sun
18 Mon
19 Tue
20 Wed
21 Thu
22 Fri
23 Sat
24 Sun
25 Mon
26 Tue
27 Wed
28 Thu
MIN
MAX
AVG
SUM

COGENERATION NATURAL GAS COST ANALYSIS
G-COG
Procurement
cost/therm
G-NR2
Procurement
cost/therm

GCOG/GNR
2 TRANSPORTAION
COST
G-NR2
TRANSPORTATIO
N COST
TOTAL

COST OF

ALLOWED
THERMS
TOTAL
COST NONALLOWED
THERMS
TOTAL

COST OF

NATURAL
GAS
NG
COST/
KWH

REVENUE
PER KW

EXPORTED

TOTAL KW

EXPORTED
TOTAL

REVENUE
GENERATED
BLEND
RATIO
FUEL

BLENDING

NG DAILY
TOTAL
FUEL

BLENDING

DG DAILY
TOTAL
RUN
HOURS

0.18700 0.24104 0.01733 0.31300 $20 $0 $20 0.002 0.030 600 $18.11 17.8 9500 169263 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 166800 22.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 185700 25.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 182400 24.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 170500 22.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 178700 24.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 180700 24.3

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 174500 23.4

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 178100 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 378000 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1500 $0.00 #DIV/0! 0 178300 24.0

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 182100 24.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 174400 23.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 177000 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 187000 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 169900 23.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 176900 23.9

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 177900 23.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 183500 24.7

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 900 $0.00 #DIV/0! 0 183800 24.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1200 $0.00 #DIV/0! 0 171800 23.1

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1500 $0.00 #DIV/0! 0 177300 23.6

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 1500 $0.00 #DIV/0! 0 186300 24.6

0.18700 0.24104 0.01733 0.31300 $42 $0 $42 0.005 0.027 0 $0.00 9.6 20100 193400 22.8

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 600 $0.00 #DIV/0! 0 180200 24.2

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 174900 23.6

0.18700 0.24104 0.01733 0.31300 $189 $43,257 $43,446 3.993 -3.961 900 $0.00 5.5 7700 42400 17.5

0.18700 0.24104 0.01733 0.31300 $0 $0 $0 0.000 0.000 300 $0.00 #DIV/0! 0 170200 25.3 $0 $0 $0 0.000 -3.961 0 $0.00 #DIV/0! 0 42400 17.5
$189 $43,257 $43,446 3.993 0.030 1500 $18.11 #DIV/0! 20100 378000 25.3 $9 $1,545 $1,554 0.143 -0.139 782 $0.65 #DIV/0! 1332.1 180427.3 23.7 $251 $43,257 $43,508 21900 $18.11 37300 5051963 664.1

March 2025

COGENERATION NATURAL GAS COST ANALYSIS
D
A
T
E
D
A
Y
TOTAL
KWH
FROM
PG&E
TOTAL
KWH COGENERATED
NET
KWH
GENERATED
CO-GEN
KWH

CAPACITY

NOT USED
PLANT
DEMAND
IN KWH
KWH/
C-COG
THERM
FACTOR
ALLOWABLE
C-COG
THERMS
KCF-NG
USED

COLUMBIA
PG&E
CORRECTION THERM
FACTOR
PG&E
THERMS

DELIVERE
D

MAXIMUM
ALLOWABLE
THERMS
NONALLOWABLE
THERMS
1 Fri 600 10496 9188 3304 10796 0.09683 890 0 1.026 0 890 0 2 Sat 300 10496 9187 3604 9896 0.09683 890 1 1.026 10 890 0 3 Sun 2400 9836 8527 2164 11936 0.09683 826 12 1.026 123 826 0 4 Mon 4200 10368 9059 -168 14568 0.09683 877 0 1.026 0 877 0 5 Tue 2700 7552 6243 4148 10252 0.09683 605 0 1.026 0 605 0 6 Wed 900 9984 8675 3516 10584 0.09683 840 0 1.026 0 840 0 7 Thu 4200 9088 7779 1112 12988 0.09683 753 0 1.026 0 753 0 8 Fri 1200 10240 11549 2960 11140 0.09683 1118 0 1.026 0 1118 0 9 Sat 2700 9798 8524 1902 11898 0.09683 825 13 1.026 133 825 0 10 Sun 300 11520 10153 2580 11220 0.09683 983 0 1.026 0 983 0 11 Mon 0 11648 10293 2752 10448 0.09683 997 0 1.026 0 997 0 12 Tue 300 11008 9661 3092 10408 0.09683 935 0 1.026 0 935 0 13 Wed 300 11136 9776 2964 10536 0.09683 947 0 1.026 0 947 0 14 Thu 0 11392 10034 3008 10492 0.09683 972 0 1.026 0 972 0 15 Fri 0 10880 9551 3520 9680 0.09683 925 0 1.026 0 925 0 16 Sat 300 11264 9960 2836 10664 0.09683 964 0 1.026 0 964 0 17 Sun 600 10880 9600 2920 10580 0.09683 930 0 1.026 0 930 0 18 Mon 600 11564 9915 2236 11564 0.09683 960 0 1.026 0 960 0 19 Tue 300 11008 9651 3092 10708 0.09683 935 0 1.026 0 935 0 20 Wed 600 11392 10046 2408 11392 0.09683 973 0 1.026 0 973 0 21 Thu 300 11264 9911 2836 10964 0.09683 960 0 1.026 0 960 0 22 Fri 600 10752 9417 3048 10452 0.09683 912 2 1.026 21 912 0 23 Sat 0 11392 10037 3008 10492 0.09683 972 0 1.026 0 972 0 24 Sun 600 8500 7141 5300 8500 0.09683 691 0 1.026 0 691 0 25 Mon 300 11648 10280 2452 11348 0.09683 995 0 1.026 0 995 0 26 Tue 1500 10496 9124 2404 11396 0.09683 883 0 1.026 0 883 0 27 Wed 1500 10880 9510 2020 12080 0.09683 921 0 1.026 0 921 0 28 Thu 600 11264 9894 2536 11264 0.09683 958 0 1.026 0 958 0 29 Fri 300 10704 9327 3396 10404 0.09683 903 0 1.026 0 903 0 30 Sat 1200 10697 9440 2503 11297 0.09683 914 3 1.026 31 914 0 31 Sun 900 11500 10197 2000 11800 0.09683 987 5 1.026 51 987 0 MIN 0 7552 6243 -168 8500 0.09683 605 -900 0 605 0
MAX 4200 11648 11549 5300 14568 0.09683 1118 13 133 1118 0 AVG 977.4 10666.03 9408.032 2757 11024 0.09683 911 1.2 12 911 0 SUM 30300 330647 291649 85453 341747 28240 36 369 28240 0 Non-allowed therms 0