San Diego Gas & Electric Company s1

SAN DIEGO GAS & ELECTRIC COMPANY

SOUTHERN CALIFORNIA GAS COMPANY

APPLICATION UPDATING FIRM ACCESS RIGHTS SERVICE AND RATES

(A.10-03-028)

4th DATA REQUEST FROM SOCAL GENERATION COALITION (SCGC-04)

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QUESTION 4.1:

4.1. With respect to SoCalGas’ response to SCGC Data Request Question No. 2.1, please provide the following information:

4.1.1. Define PCC-C

4.1.2. For each of the OFO days listed in the response, indicate the aggregate volumes of any voluntary reductions in individual customer nominations that SoCalGas experienced for that day.

4.1.3. For each of the OFO days listed in the response, state the percentage reduction in overall FAR rights that was imposed in Cycle 3 under Rule 30, Section F.3.

4.1.4. For each of the OFO days that have a “Y” in column D of the spreadsheet table provided in the response, state the additional percentage reduction in FAR rights that was imposed in Cycle 4 under Rule 30, Section F.3.

4.1.5. For each of the OFO days listed in the response, state the maximum percentage reduction in FAR rights using firm primary receipt point rights that was imposed in Cycles 3 or 4 under Rule 30, Section F.3.

4.1.6. For each of the OFO days listed in the response, did any volumes flow under rights other than FAR rights using firm primary receipt point rights?

4.1.6.1. Please identify by date and service location, the volumes in MDth that flowed under FAR rights using firm alternate receipt point rights.

4.1.6.2. Please state the maximum percentage reduction in FAR rights using firm alternate receipt point rights that was imposed in Cycles 3 or 4 under Rule 30, Section F.3.

4.1.6.3. Please identify by date and service location, the volumes in MDth that flowed under interruptible rights.

4.1.7. Please describe SoCalGas’ policy for treating nominations under FAR rights using firm alternate receipt point rights versus nominations under FAR rights using firm primary receipt point rights once SoCalGas has declared an OFO. Please specify the nomination cycles in your response.

RESPONSE 4.1.1:

PCC-C: Pipeline Capacity Constraint (System Capacity) - This reduction occurs when there is a constraint on the whole transmission system. The reduction is applied to the Receipt Point Access contract when balancing the system.

RESPONSE 4.1.2:

For each of the OFO days listed in response to SCGC Data Request Question 2.1, the aggregate volumes for voluntary reductions in individual customer’s nominations can be found on the attached spreadsheet.

RESPONSE 4.1.3:

For each of the OFO days listed in Response to SCGC Data Request question 2.1, the over all reduction to nominated firm rights can be found on the attached spreadsheet.

RESPONSE 4.1.4:

For each of the OFO days that have a “Y’ in column D of the spreadsheet table provided in response to SCGC Data Request Question 2.1, the additional reductions in FAR rights that were imposed in Cycle 4, under Rule 30, Section F.3 can be found on the spreadsheet attached to Response 4.1.3. The cases where there were additional cuts to the nominated firm rights are highlighted in Red. For all other cases, the cycle 4 cuts were due to an increase and or an addition of new nominations.

RESPONSE 4.1.5:

See Response 4.1.3.

RESPONSE 4.1.6:

For each of the OFO days listed in the response to SCGC Data Request No. 2.1, the volumes that flowed under rights other than FAR using firm primary receipt point rights are available in Envoy: www.socalgasenvoy.com by first selecting “Receipt Point Capacity” in the left hand column; clicking on “Available Capacity vs. Scheduled”; “Archive” and then selecting the year and month.

RESPONSE 4.1.6.1:

The volumes that flowed under FAR rights using firm alternate receipt point rights by date and service location are available in Envoy: www.socalgasenvoy.com by first selecting “Receipt Point Capacity” in the left hand column; clicking on “Available Capacity vs. Scheduled”; “Archive” and then selecting the year and month.

RESPONSE 4.1.6.2:

See Response 4.1.3.

RESPONSE 4.1.6.3:

The volumes that flowed under interruptible rights by date and service location are available in Envoy: www.socalgasenvoy.com by first selecting “Receipt Point Capacity” in the left hand column; clicking on “Available Capacity vs. Scheduled”; “Archive” and then selecting the year and month.

RESPONSE 4.1.7:

Please see SoCalGas’ Rule No. 30, Section D.3.

QUESTION 4.2:

4.2. Aggregating all core volumes across all receipt points, please provide on a daily basis the following information for the months October 2008 through April 2010:

4.2.1. The difference between core nominations and core receipts.

4.2.2. The difference between core scheduled volumes and core receipts.

RESPONSE 4.2.1:

SoCalGas objects to this question on the grounds of relevance and that itseeksconfidential and proprietary trade secret information, disclosure of which would harmSoCalGas and its core customers. SoCalGas also objects to this request because production of this information would violate section IV(A) of the Commission's affiliate transaction rules, which precludes a utility from releasing confidential customer information without prior written customer consent.

RESPONSE 4.2.2:

QUESTION 4.3:

4.3. Please provide a spreadsheet table that shows by month, for the months October 2008 through April 2010, the difference between the core’s actual burn plus the core’s actual injection into storage for the month and the sum of the core’s daily forecast quantity plus the core’s average daily injection rights for all of the days during the month.

RESPONSE 4.3:

QUESTION 4.4:

4.4. Regarding SoCalGas’ response to SCGC Data Request Question No. 2.7.4, which states:

If the proposed change is approved, SDG&E/SoCalGas would, when cuts are needed in later cycles, first confirm prior cycle firm scheduled quantities and then cut the remaining nominations based on the priorities.

4.4.1. Would SoCalGas propose to distinguish between FAR rights using firm primary receipt point rights and FAR rights using firm alternative receipt point rights?

4.4.2. Would SoCalGas propose to allow nominations made in Cycle 2 using firm primary receipt point rights to bump nominations made in Cycle 1 using firm alternative receipt point rights?

4.4.3. Would SoCalGas propose to allow nominations made in Cycle 3 using firm primary receipt point rights to bump nominations made in Cycle 1 or Cycle 2 using firm alternative receipt point rights?

RESPONSE 4.4.1:

SoCalGas is not proposing any other changes to how it cuts nominations and would continue to follow SoCalGas’ Rule No. 30, Section D.3 as needed.

RESPONSE 4.4.2:

See Response 4.4.1

RESPONSE 4.4.3:

See Response 4.4.1

QUESTION 4.5:

4.5. Please provide spreadsheet example of how SoCalGas arrives at Envoy “forecasted send out” parameter included in Envoy under Informational Postings, Operations, OFO calculations. The “forecasted send out” parameter for 5/26/10, from Envoy’s PDF capture feature, is attached below.

RESPONSE 4.5:

There is no specific formula used by the Gas Control department in determining the system demand forecast. The Gas Control department uses temperature and weather forecasts, historical data, both public and private market data, and operating experience with the SoCalGas/SDG&E gas transmission system to determine the system demand forecast.