-TABLE 1

Comparison between Present, Adopted and PG&E Proposed Revenue Requirement(thousands of dollars)

PG&EPrq)O8ed

Ack)pt8d 2004 2004 T oIaITotal (see Note 2)

-

"'DifferenceAdopted and

PG&EProposed

% DifferenceAdopted and

Present

Revenue at PresentRates

(see Note 1)-

LNNo. Description---

$411,347 $423.821 $441,160(12.576) (12.576) (12,576)423.923 436.397 453.736

REVENUE:Revenue at Effective RatesLess Non-General Revenues

General Rate Case Revenue

123 2.94%

000

78,101365

2,2151,~7,024

51.~4,~

0000

000

78.761365

2.2151.0917,618

52.3184,211

0000

000

81,126365

2,2151,1347,618

53,1~4,378

0000

4567681011121314151617

OPERATING EXPENSES:Energy CostsOtt1er~StorageTransmissionDistributionCustomer AccountsUncoIectillesCustomer ServicesAdmi~tratlve and GeneralFranchise RequirementsProject AmortizationWage Change ImpactsOther Price Change ImpactsOther Adjustments

144,652 146,579 149.966 1.33%18 Subtotal Expenses

0 0 016,011 15.969 16,0174.143 4.208 4.~

38 39 4021 22 22

I 7,724 9.252 9.96542,199 47,538 51,041-70,137 77.025 81,414

1920212223242526

TAXES:Supelfw1dPropertyPayrolBusinessOtherSta. Corporatk)n FraId1iseFederallncome

Total Taxes 9.82%

79,14300

272829

79.02800

78.69200

DepreciationFossil DecommissioningNLk:lear Decorrvnissioni1g

Total Operating Expenses 293,817 302,296 310.523 2.89% -2.65%~

31 Net for Return 130,106 134.101 143,214 3.07% -6.36%

1,545,629 1.452.043 1.550.720:R Rate Base

RATE OF RETURNOn Rate BaseOn Equity

3334

8.42%9.30%

9.24%11.22%

9.24%1122%

Note 1: PG&E January 17. 2003 Amendment to Amended ApplicationNote 2: PG&E Exhi>it 3. Table 12.2.

PAGE 1

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-NOTES TO TABLES 1 AND 2

ADJUSTMENTS TO PG&E GAS ACCORD n~ULTS OF OPERATION MODEL. VERSION 03-03-14

The following lists entries made to PG&E Results of Operation Model, version 03-03-14identified by worksheet, tab, and cell reference.

..

I. Ratebase ad1ustments:

1) ProjectDetail Worksheet. CapExp Tab:

a. Pipeline Safety Law Compliance (Row 867. Column AI)Value inputted = $4125.5

All adjustments to PSRS No. 9774. 10595. 10596 (refer to PG&E Exhibir 42.Workpapers Supporting Chapter 10 - Capital Expenditures. p. 44) included inspreadsheet cell referred to above.

$9.627 + 696 + 680 = $11.003/2 = $5501.5$9.627 - 5501.5 = $4125.5

b. Power Plant Connections (Row 265. Column AI)Value inputted = $3537.5

C. Power Plant Metering ('Row 1182, Columns AI through AT)Value inputted = $275/ month.

d. Large Power Generator Meters (RowValue inputted = $125/ month

181, Columns W through AH)

e. Winter Reliability Standard (Row 856, Columns J through AT)Value inputted = $0

f. Gerber Compressor Replace~nt:l. (Row 885. Column AG)

Value inputted = ($2,985)

2. (Row 886. Column AG)Value inputted = ($2.985)

3 (Row 885, Colul1U1 AH)Value inputted = ($15)

4, (Row 886. Column AH)Value inputted = (SI5)

2) Depreciation Worksheet, Cush Gas-StanPac-Non Cycle Tab:

a. Non Cycle Working Gas (Row 10. Columns C through F)Value inputted = SO

PAGE 4

NOTES TO TABLES 1 AND 2ADJUSTMENTS TO PG&E GAS ACCORD U

RESULTS OF OPERA nON MODEL. VERSION 03-03-14 (con't)

The following lists entries made to PG&E Results of Operation Model, version 03-03-14identified by worksheet, tab, and cell reference.

u. Ooeratine: & Maintenance exoense adjustments:

I) GasTrans Worksheet, 863 Tab:

a. Increased pipeline inspections, labor (Row 78, Column K)Value inputted = $856.5

b. Increased pipeline inspections, M&S (Row 79, Column K)Value inputted = $576

c. Pipeline Corrosion, labor (Row 84, Column K)Value inputted = $198

d. Pipeline Corrosion, M&S (Row 85, Column K)Value inputted = $577

PAGE 5

-Table 3

Adopted 2004Firm Backbone Transportation

Annual Rates (AFT) - SFV Rate DesignOn-System Transportation Service

$

ChangeAdopted vs.GA II 2003

GAil2003

Adopted2004

PG&E Proposed2004

Redwood-Core- --

Reservation Charge

Usage ChargeTotal

($/dth/mo)($/dth)($/dth @ FullContract)

3.5170.0090.125

I 3.8460.0020.129

0.330(0.007)0.004

5.2640.0030.176

I

RedwoodPaU1Reservation Charge

Usage ChargeTotal

I($/dth/mo)($/dth)($/dth @ FullContract)

7.9610.0070.269

9.0600.0020.300

1.099(0.006)0.031

9.9430.0020.329I

I

Baja PathReservation ChargeUsage ChargeTotal

($/dth/mo)($/dth)($/dth @ FullContract)

5.1920.0040.175

5.7220.0040.192

0.530(0.000)0.017

6.5920.0040.221

ISilverado and Mission PathsReservation Charge ($/dth/mo)Usage Charge ($/dth)Total ($/dth @ Full

Contract)

3.4260.0030.116

3.4520.0010.115

0.026(0.002)(0.001)

3.9780.0020.132

II.

Notes:a) Rates are only the backbone transmission charge component of the

transmission service. They exclude local transmission charges, customerclass charges, customer access Charges, distribution charges, storagecharges, and shrinkage charges.

b) Backbone transmission charges are based on a 77.02 percent load factor.

c) The "Total" rows represent the average backbone transmission chargeincurred by a firm shipper that uses its full contract quantity at a 1 00percent load factor.

d) Customers delivering gas to storage pay the applicable backbonetransmission on-system rate from Redwood, Baja and Silverado.

e) Rates are subject to change pursuant to D.03-12-XXX

PAGE 6

~

Table 4Adopted 2004

Firm Backbone TransportationAnnual Rates (AFT) - MFV Rate Design

On-System Transportation Service$

ChangeAdopted vs.GA II 2003

GAil2003

Adopted2004

PG&E Proposed2004I

Redwood-CoreReservation ChargeUsage ChargeTotal

2.4140.0450.125

($ldth/mo)($ldth)($ldth @ FullContract)

2.9620.0310.129

0.548(0.014)0.004

3.8080.0500.176I

Redwood PathReservation ChargeUsage ChargeTotal

($Idth/mo)($Idth)($Idth @ FullContract)

4.6870.1150.269

5.3570.1240.300

0.6700.0090.031

5.9510.1330.329I

I

Baja PathReservation ChargeVsage ChargeTotal'

($ldth/mo)($ldth)($ldth @ FullContract)

3.9100.0460.175

.

4.4680.0450.192

0.558(0.001)0.017

4.8710.0610.221

III

Silverado and Mission PathsReservation Charge ($ldth/mo)Usage Charge ($ldth)Total ($ldth @ Full

Contract)

2.3280.0390.116

2.4980.0330.115

0.170(0.007)(0.001)

2.8340.0390.132

I

I

Notes:a) Rates are only the backbone transmission charge component of the

transmission service. They exclude local transmission charges,customer class charges, customer access charges, distribution charges,storage charges, and shrinkage charges.

b) Backbone transmission charges are based on a 77.02 percent load factor.

c) The "Total" rows represent the average backbone transmission chargeincurred by a firm shipper that uses its full contract quantity at a 100percent load factor.

d) Customers delivering gas to storage pay the applicable backbonetransmission on-system rate from Redwood, Baja and Silverado.

e) Rates are subject to change pursuant to D.03-12-XXX

PAGE 7

~

Table 5Adopted 2004

Firm Backbone TransportationSeasonal Rates (SFT) - SFV Rate Design

On-System Transportation Service$

ChangeAdopted Ys.GA II 2003

GAil2003

Adopted2004

PG&E Proposed2004I

Redwood Path--,

Reservation Charge

Usage ChargeTotal

($ldth/mo)($ldth)($Idth @ FullContract)

9.5530.0090.323

10.8710.0020.360

1.318(0.007)0.037

11.9320.0030.395

Baja PathReservation ChargeUsage ChargeTotal

II

($ldth/mo)($Idth)($ldth @ FullContract)

6.2310.0050.210

6.8660.0040.230

0.635(0.000)0.021

7.9110.0050.265

.

Silverado Path~ =

Reservation Charge

Usage ChargeTotal

($Idth/mo)($Idth)($Idth @ FullContract)

4.1110.0040.139

4.1420.0020.138

0.031(0.002)(0.001)

4.7740.0020.159

II

Notes:a) Firm Seasonal rates are 120 percent of Firm Annual rates.

b) Rates are only the backbone transmission charge component of thetransmission service. They exclude local transmission charges, customerclass charges, customer access charges, distribution charges, storagecharges, and shrinkage charges.

c) The "Total" rows represent the average backbone transmission chargeincurred by a firm shipper that uses its full contract quantity at a 100percent load factor.

d) Customers delivering gas to storage pay the applicable backbonetransmission on-system rate from Redwood, Baja and Silverado.

e) Firm seasonal service is available to on-system paths for a minimum termof three consecutive months in one season. Winter season is Novemberthrough March. Summer season is April through October.

f) Rates are subject to change pursuant to D.O3-12-XXX

PAGE 8

..

Table 6Adopted 2004

Firm Backbone TransportationSeasonal Rates (SFT) -- MFV Rate Design

On-System Transportation Service$

ChangeAdopted Ys.

GA II 2003GAil2003

Adopted2004

PG&E Proposed2004

Redwood PathReservation ChargeUsage ChargeTotal

($Idth/mo)($ldth)($ldth @ FullContract)

5.6250.1380.323

6.4280.1480.360

0.8030.0100.037

7.1410.1600.395

I

II

Baja PathReservation ChargeUsage ChargeTotal

($ldth/mo)($ldth)($ldth @ FullContract)

4.6920.0550.210

5.3610.0540.230

0.669(0.001)0.021

5.8450.0730.265

Silverado PathReservation ChargeUsage ChargeTotal

($ldth/mo)($ldth)($ldth @ FullContract)

2.7930.0470.139

2.9970.0390.138

0.204

(O.OO~)(0.001)

3.4010.0470.159I

I.

Notes:a) Firm Seasonal rates are 120 percent of Firm Annual rates.

b) Rates are only the backbone transmission charge component of thetransmission service. They exclude local transmission charges,customer class charges, customer access charges, distribution charges,storage charges, and shrinkage charges.

c) The "Total" rows represent the average backbone transmission chargeincurred by a firm shipper that uses its full contract quantity at a 100percent load factor.

d) Customers delivering gas to storage pay the applicable backbonetransmission on-system rate from Redwood, Baja and Silverado.

e) Firm seasonal service is available to on-system paths for a minimumterm of three consecutive months in one season. Winter season isNovember through March. Summer season is April through October.

f) Rates are subject to change pursuant to D.O3-12-XXX

PAGE 9

..

Table 7Adopted 2004

As-Available Backbone TransportationOn-System Transportation Service

$

ChangeAdopted V5.GA \I 2003

III

PG&E Proposed2004

Adopted2004

.GA "2003

Redwood PathUsage Charge

.I($ldth) 0.323 0.360 0.037

Baja PathUsage Charge 0.021($Idth) 0.210 0.230

Silverado PathUsage Charge I. (0.001) 0.159($ldth) 0.139 0.138

Mission PathUsage Charge

.

.($Idth) 0.000 0.000 0.000

Notes:a) As-Available rates are 120 percent of Firm Annual rates.

b) Rates are only the backbone transmission charge component ofthe transmission service. They exclude local transmissioncharges, customer class charges, customer access charges,distribution charges, storage charges, and shrinkage charges.

c) Mission path service represents on-system storage to on-systemtransportation. Customers delivering gas to storage facilities paythe applicable backbone transmission on-system rate fromRedwood, Baja or Silverado.

d) Rates are subjed to change pursuant to D.O3-12-)()()(

PAGE 10

~

Table 8Adopted 2004

Finn Backbone TransportationAnnual Rates (AFT -Off)Off-System Deliveries

$ ChangeAdopted Y5.

GA 1\ 2003

PG&EProposed2004

III

Adopted2004

GAil2003

9.9430.0020.329

(0.765)(0.002)(0.027)

9.0600.0020.2998

III

SFV Rate DesionRedwood, Silverado and Mission Paths orr-system

Reservation Charge ($/dthJmo) 9.825Usage Charge ($ldth) 0.004Tota ($/dth @ Full 0.327

Contract)

Baja Path orr-systemReservation ChargeUsage ChargeTotal

6.5920.0040.221

IIIII

0.530(0.000)0.017

5.7220.0040.192

5.1920.0040.175

($ldth/mo)($ldth)($ldth @ Ftodl

Contract)

MFV Rate DesianRedwood, Silvera do and Mission Paths Off-System

Reservation Charge ($ldth/mo) 5.182Usage Charge ($ldth) 0.165Total ($ldth @ FuR 0.335

Contract)

5.9510.1330.329

0.176(0.041)(0.036)

I 5.3570.1240.300

Baja Path orr-systemReservation ChargeUsage ChargeTotal

I

III

4.8710.0610.221

0.558(0.001)0.017

4.4680.0450.192

3.9100.0460.175

($/dth/mo)($ldih)($/dth @ FuR

Contract)

As-Available ServiceRedwood, Silverado and Mission Paths Off-System

Usage Charge ($/dth) 0.403 I 0.395(0.044)0.360

Baja Pad1 Off-System

Usage Charge0.265I

.0.0210.2300.210($/dtt1)

Notes:a) Rates are only the backbone b"ansmission charge component of U1e

transmission service. They exclude local b"a1Smission chwges, customer classcharges, customer access charges, distribution charges, storage charges, and

shmkage charges.b) Backbone v-mission charges are based on a 77.02 percent load factor.

c) The "Totar rows represent U1e average backbone transmission chargeincI.ITed by a fIm shipper U1at uses its fldl contract quantity at a 1 00 percent

load factor.d) Caifomia gas and storage to off-'5ystem are assumed to flow on Redwood

paU1 and are priced at U1e Redwood paU1 rate.

e) Rates .-e Stbject to change pursuant to D.O3-12-XXX

PAGE 11

~

Table 9Adopted 2004

Firm TransportationExpansion Shippers - Annual Rates (G-XF)

SFV Rate DesignOff-System Deliveries

$

ChangeAdopted vs.GA \I 2003

PG&E Proposed2004

.I Adopted2004

GAil2003

7.9320.0010.262

(1.926)(0.003)(0.066)

7.9000.0010.261

9.8250.0040.327

SFV Rate DesionReservation Charge ($ldth/mo)Usage Charge ($ldth)Total ($ldth @ Full

Contract) .

Notes: .a) Rates are only the backbone transmission charge component of the

transmission service. They exclude local transmission charges,customer class charges. customer access charges, distributioncharges, storage charges, and shrinkage charges.

b) The "Total" rows represent the average backbone transmissioncharge incurred by a firm shipper that uses its full contract quantityat a 100 percent load factor.

c) G-XF charges are based on the embedded cost of Line 401 and a

95 percent load factor.

d) Rates are subject to change pursuant to D.O3-12->OO<

PAGE 12

-Table 10

Adopted 2004Storage Services

$ ChangeAdopted V5.GA II 2003

PG&E Proposed2004

I

I Adopted2004

GAil2003

Core Firm StoraGe lG-CFS)Reservation Charge

O.1~(0.012)o.~O.1~($/dtt]fmo)

Standard Firm StoraGe IG-SFS)Reservation Charge

Capacity ChargeWithdraw! Charge

o.~0.118n/an/a

nIa0.0700.910

($ldth/mo)

5.8261.(&

18.(B)

4.4850.1264.763

13.7071.42110.334

9.2231.2955.572

~eaoUated Firm StoraGe fG-NFSlInjection ($/dth/d)Inventory ($ldth/mo)Wilt1drawal ($/dth/d)

Negotiated As-Available StoraGe Ig-~~\ - Maxim~~~Injection ($/dth/d) 9.223Witt1drawal ($/dth/d) 5.572

5.82618.060

4.4854.763

13.70710.334

o.~$57.00

(0.184)O.CXX>

0.820$ 57.00

Market Center Services (ParkinG and Lendlna Services)

Usage Charge:Maximum Daily Charge ($/Dth/day) 1.004Minimum Rate (per transaction) $ 57.00

Notes: 4

a) Rates for storage services are b88ed on h CX)8ts of storage injection.inventory and withdrawal.

b) Core Fnn StDfBge (G-CFS) and Standard Firm Storage (G-SFS) rates 818 amonthly reservation charge designed to recover CK'e twelfth of tt1e annual~~ requirement of w,jecticx1, inventory and wiUUawaI sta'age.

c) N.--18d Firm rates may be one-part rates (volumetric) or two"f)8rt rates(~ and volumetric). as negotiated between parties. The voIOO1etr1ceq~ is stX7Nn above.

d) Negotiated As-Available Storage Injection and Withdrawal rates 818 recovered

tt1rough a voIumebic charge only.e) N~ rates (NFS 81d NAS) are capped at tt1e price which will cdlect

100 pen:ent of PG&E's total ~ue requirement for the unoondled sta'ageprogram I.H1der aU tt1ree subfunctions (e.g. inventory, injection, or withdraw8).The maximum rates we based on a rate design assuming an average~j~ period of 30 days and an average withdrawal period of 7 days.

f) Nego"'...tec: Firm ard ~ services are ,~bIe above a price floorI~~~ PG&E's mergNi cos1B of prO'o'idi'1g the service.

g) The ~nun chw"ge for perking and lendng is based on the amual cost ofcyd"W1Q cxe dU1 of Firm StDrage Gas assuming the ftjl 214 day injectionSMSon and 151 day withdrawal season.

h) Gas Storage shmkage will be applied in-kind on storage injections.

i) Ra-. are subject to change pursli81tto D.03-12-XXX

PAGE 13

~

Table 11Adopted 2004

Local Transmission Rates($/dth)

$ ChangeAdopted V5.GA II 2003

Annual Usage(millions of

Thenns/year)

PG&E Proposed2004

Adopted2004

.. GAil2003 I

I 0.4190.367 0.0800.287Core Retail

0.201 - 0.075

(4 TIERS)0.157 0.0090.149Noncore (including Wholesale)

I

Notes:a) Rates are subject to change pursuant to D.O3-12-.)oo(

PAGE 14

-Table 12

Adopted 2004Customer Access Charges Using GA I Structure

$ ChangeAdopted Y5.GAII2003

Rates2003

Adopted2004

PG&E Proposed2004 -

G-EG and G-COG (2003 onlY) ISltherm) la) $0.00080

G-NT and G-EG (S/month)Transmission and Distribution (a)

(Therms/Month )Tier 1 0 to 5,000 30.12 $18.25 $23.79$11.87 $

237.27 $143.75 $187.465,001 to 10,000 $93.52 $

10,001 to 50,000 $354.79 $ 900.15 $545.36 $711.18

50,001 to 200,000 $935.23 $ 2,372.80 $1,437.57 $1,874.87Tier 4

200,001 to 1,000,000 $1,339.02 $ 3,397.26 $2,058.24 $2.684.07

1,000,001 and above $3,892.38 $ 9,875.46 $5,983.08 $7,802.29to $43,148.69

(2 adcition. tiers)

Wholesale ($'month)Alpine $206.71 $ 524.45 $317.74 $182.34

~ $1,028.08 $ 2,608.37 $1,580.29 $3,666.28

Island Energy $580.47 $ 1,421.98 $861.51 $1,399.59

Palo Ala $17,019.19$4,392.60 $11,144.58 $6,751.98

w - CoB G8 - CasUe $482.20 $ 1,223.40 $741.20 $1,448.69

West Coast Gas . Mather $746.87 $ 1,894.90 $1,148.03 $1,183.92

Notes:a) Present rates for Schedule G-EG and G-COG are a volumetric rate per thermo PG&E

proposes a 6 tiered rMe structure ~ to both schedules G-NT and the newcombined schedule G-EG

b) Rates are subject to change pursuant to D.03-12-XXX

PAGE 15

..Table 13

Adopted 2004Self Balancing Credit

$/dth$ Change

Adopted Adopted vs.2004 GA II 2003

. PG&E Proposed2004

GAil. 2003 I

0.005 0.0110.005 0.010Self Balancing Credit

Notes:a) Storage balancing costs are bundled in backbone rates. Customers or

Balancing Agents who elect self balancing on a daily basis can opt out ofPG&E's monthly balancing program and receive a self-balancing credit.

b) Rates are subject to change pursuant to D.O3-12-XXX

PAGE 16

Table 14

Interim EG and Cogeneration Customer Access Charge and Distribution Rate

Interim Period: January 1, 2004 - March 31, 2004Single EG Class Structure will be Impl~rnented beginning April 1, 2004

EG- T Custo~r Access Charge Annual Revenue Require~nt Calculation

. .Il')terlm. Volumetric EG and Cogeneration Customer Acc.ess Charge Calculation

Annual EG- T GAG Revenue Requirement (MS) - 53.018.918

Annual EG/COG Volumes (fII1dth) 272.101

Volumetric Customer Access Charge (S/dtherm) s 0.0111

Equalized EG Distribution Rate Component Calcuiatlon

Adj. Annual Distroution-Level Costs Allocated to Distmution-level Cogen D.O1-11-OO1 (MS) 51,791

22.150~~111

ess: Distnbution Revenues Recovered From Distnbutlon CACDistribution-Level Cogen Volumes (Mth)Volumetric Customer Access Charge ($/Therm)Customer Access Charges Co"~ted from Distribution-Level Gagen Customers (MS) 525

Adjusted Distnbution Revenue Requirement (M$)$1,768

Annual EG/COG Volumes (Mdth)272.101

Distribution Rate Component (S/dtherm) s 0.0065

PAGE 17

**..

PAGE 18 OF APPENDIX A INTENTIONALLY LEFT BLANK