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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
[ X ] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 1995
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Commission file number 1-1402
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SOUTHERN CALIFORNIA GAS COMPANY
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(Exact name of registrant as specified in its charter)
California 95-1240705
- --------------------------------------------- -------------------
(State or other jurisdiction of incorporation (I.R.S. Employer
or organization) Identification No.)
555 West Fifth Street, Los Angeles, California 90013-1011
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(Address of principal executive offices)
(Zip Code)
(213) 244-1200
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(Registrant's telephone number, including area code)
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15 (d) of the Securities Exchange Act
of 1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to
such filing requirements for the past 90 days.
Yes X No
---
The number of shares of common stock outstanding on April 28, 1995 was
91,300,000.
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS.
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SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARY
CONDENSED STATEMENT OF CONSOLIDATED INCOME
(Thousands of Dollars)
Three Months Ended
March 31
--------------------
1995 1994
-------- --------
(Unaudited)
Operating Revenues $604,690 $689,154
-------- --------
Operating Expenses:
Cost of gas distributed 231,690 354,087
Operation and maintenance 169,541 146,062
Depreciation 58,978 57,640
Income taxes 40,935 32,798
Other taxes and franchise
payments 30,274 30,969
-------- --------
Total 531,418 621,556
-------- --------
Net Operating Revenue 73,272 67,598
-------- --------
Other Income and (Deductions):
Interest income 1,597 278
Regulatory interest 1,637 1,064
Allowance for equity funds used
during construction 635 713
Income taxes on non-operating
income 184 247
Other - net (1,734) (1,461)
-------- --------
Total 2,319 841
-------- --------
Interest Charges and (Credits):
Interest on long-term debt 22,256 22,257
Other interest 2,653 2,639
Allowance for borrowed funds
used during construction (367) (406)
-------- --------
Total 24,542 24,490
-------- --------
Net Income 51,049 43,949
Dividends on Preferred Stock 2,928 2,440
-------- --------
Net Income Applicable to
Common Stock $ 48,121 $ 41,509
======== ========
See Notes to Condensed Consolidated Financial Statements.
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SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEET
ASSETS
(Thousands of Dollars)
March 31 December 31
1995 1994
---------- -----------
(Unaudited)
Utility Plant $5,645,643 $5,613,013
Less accumulated depreciation 2,451,732 2,400,601
---------- ----------
Utility plant - net 3,193,911 3,212,412
---------- ----------
Current Assets:
Cash and cash equivalents 186,402 57,531
Accounts and notes receivable - net 402,402 523,975
Regulatory accounts receivable 125,015 360,479
Gas in storage 8,203 63,470
Materials and supplies 25,505 25,792
Prepaid expenses 25,910 34,129
---------- ----------
Total current assets 773,437 1,065,376
---------- ----------
Regulatory Assets 480,708 497,975
---------- ----------
Total $4,448,056 $4,775,763
========== ==========
See Notes to Condensed Consolidated Financial Statements.
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SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEET
CAPITALIZATION AND LIABILITIES
(Thousands of Dollars)
March 31 December 31
1995 1994
---------- -----------
(Unaudited)
Capitalization:
Common equity:
Common stock $ 834,889 $ 834,889
Retained earnings 660,119 643,040
---------- ----------
Total common equity 1,495,008 1,447,929
Preferred stock 196,551 196,551
Long-term debt 1,386,046 1,396,931
---------- ----------
Total capitalization 3,077,605 3,071,411
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Current Liabilities:
Short-term debt 83,817 278,201
Accounts payable 311,018 409,462
Accounts payable-affiliates 13,932 35,013
Accrued taxes and franchise payments 108,916 117,576
Deferred income taxes 36,161 40,792
Long-term debt due within one year 86,000 86,000
Accrued interest 37,619 40,057
Other accrued liabilities 104,796 109,150
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Total current liabilities 782,259 1,116,251
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Deferred Credits:
Customer advances for construction 43,203 44,269
Deferred income taxes 343,012 341,149
Deferred investment tax credits 69,222 69,969
Other deferred credits 132,755 132,714
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Total deferred credits 588,192 588,101
---------- ----------
Total $4,448,056 $4,775,763
========== ==========
See Notes to Condensed Consolidated Financial Statements.
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SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARY
CONDENSED STATEMENT OF CONSOLIDATED CASH FLOWS
(Thousands of Dollars)
Three Months Ended
March 31
--------------------------
1995 1994
-------- --------
(Unaudited)
Cash Flows From Operating Activities:
Net income $ 51,049 $ 43,949
Items not requiring cash 65,019 48,756
Net change in other working capital
components 278,733 111,066
-------- --------
Net cash provided by operating
activities 394,801 203,771
-------- --------
Cash Flows from Investing Activities:
Expenditures for utility plant (39,765) (39,601)
(Increase)decrease in other assets 13,456 (24,952)
-------- --------
Net cash used in investing activities (26,309) (64,553)
-------- --------
Cash Flows from Financing Activities:
Dividends (33,970) (30,809)
Issuance of long-term debt (11,267)
Decrease in short-term debt (194,384) (89,221)
-------- --------
Net cash used in financing activities (239,621) (120,030)
-------- --------
Increase in Cash and Cash Equivalents 128,871 19,188
Cash and Cash Equivalents - January 1 57,531 14,533
-------- --------
Cash and Cash Equivalents - March 31 $186,402 $ 33,721
======== ========
Supplemental Disclosure of Cash Flow Information:
Cash paid during the period for:
Interest (net of amount capitalized) $ 26,381 $ 20,820
======== ========
Income taxes $ 56,243
======== ========
See Notes to Condensed Consolidated Financial Statements.
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SOUTHERN CALIFORNIA GAS COMPANY AND SUBSIDIARY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
1. SUMMARY OF ACCOUNTING POLICIES
The accompanying condensed consolidated financial statements have been
prepared in accordance with the interim period reporting requirements of Form
10-Q. Reference is made to the Form 10-K for the year ended December 31,
1994 for additional information.
Results of operations for interim periods are not necessarily indicative of
results for the entire year. In order to match revenues and costs for
interim reporting purposes, the Company defers revenue related to costs which
are expected to be incurred later in the year. In the opinion of management,
the accompanying statements reflect all adjustments which are necessary for a
fair presentation. These adjustments are of a normal recurring nature.
Certain changes in account classification have been made in the prior years'
consolidated financial statements to conform to the 1995 financial statement
presentation.
2. ENVIRONMENTAL OBLIGATIONS
The Company has identified and reported to California environmental
authorities 42 former manufactured gas plant sites for which it (together
with other utilities as to 21 of these sites) may have environmental
obligations under environmental laws. As of March 31, 1995, eight of these
sites have been remediated, of which five have received certification from
the California Environmental Protection Agency. Preliminary investigations,
at a minimum, have been completed on 39 of the gas plant sites, including
those sites at which the remediations described above have been completed.
In addition, the Company has been named as a potentially responsible party of
one landfill site and three industrial waste disposal sites.
On May 4, 1994, the CPUC approved a collaborative settlement between the
Company and other California energy utilities and the Division of Ratepayer
Advocates that provides for rate recovery of 90 percent of environmental
investigation and remediation costs without reasonableness review. In
addition, the utilities have the opportunity to retain a percentage of any
insurance recoveries to offset the 10 percent of costs not recovered in
rates.
At March 31, 1995, the Company's estimated remaining investigation and
remediation liability was approximately $65 million which it is authorized to
recover through the mechanism discussed above. The estimated liability is
subject to future adjustment pending further investigation. The Company
believes that any costs not ultimately recovered through rates, insurance or
other means, upon giving effect to previously established liabilities, will
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not have a material adverse effect on the Company's financial statements.
Item 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
Southern California Gas Company (the Company) is a subsidiary of Pacific
Enterprises (Parent). The Company, a public utility, provides natural gas
distribution, transmission and storage in a 23,000 square mile service area
in southern California and parts of central California. SoCalGas markets are
separated into core customers and noncore customers. Core customers consist
of approximately 4.7 million customers (4.5 million residential and 200,000
smaller commercial and industrial customers). The noncore market consists of
approximately 1,200 customers which primarily include utility electric
generation, wholesale and large commercial and industrial customers. Many
noncore customers are sensitive to the price relationship between natural gas
and alternate fuels, and are capable of readily switching from one fuel to
another, subject to air quality regulations. The Company is regulated by the
California Public Utilities Commission (CPUC). It is the responsibility of
the CPUC to determine that utilities operate in the best interest of the
ratepayers with the opportunity to earn a reasonable return on investment.
Management's Discussion and Analysis of Financial Condition and Results of
Operations should be read in conjunction with the Condensed Consolidated
Financial Statements and the Company's Annual Report on
Form 10-K.
RESULTS OF OPERATIONS
Net income for the three months ended March 31, 1995 increased by $7 million
compared to 1994. The increase in net income was due primarily to the
increase in the authorized rate of return on common equity from 11.0 percent
in 1994 to 12.0 percent in 1995 and lower operating expenses and capital
expenditures in 1995 from the amounts authorized in the most recent general
rate case decision as adjusted for 1995 attrition allowances.
Operating revenues and cost of gas distributed for the three months ended
March 31, 1995 decreased $84 million and $122 million, respectively compared
to the same period in 1994. The decreases reflect lower volumes of gas sold
to core customers in 1995 and a decrease in the average unit cost of gas.
Core volumes decreased as a result of warmer weather in 1995 compared to
1994. The average unit cost of gas declined as a result of lower market
prices. Under the current regulatory framework, changes in revenue resulting
from changes in volumes in the core market and cost of gas do not affect net
income.
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RECENT CPUC REGULATORY ACTIVITY
General rate applications are filed every three years. In a general rate
case, the CPUC establishes a margin, which is the amount of revenue
authorized to be collected from customers to recover authorized operating
expenses (other than the cost of gas), depreciation, interest, taxes and
return on rate base. Rate adjustments from the Company's next general rate
case proceeding would normally be scheduled to go into effect in 1997,
however, the Company filed a petition for modification with the CPUC in 1994
to delay the proceeding and is exploring a new approach for setting rates to
its customers. Known as "Performance Based Ratemaking"(PBR), this new method
would link financial performance with productivity improvements and generally
would allow for rates to increase by the rate of inflation, less an agreed-
upon percentage for productivity improvements. On April 26, 1995, the CPUC
approved the Company's petition for modification subject to certain
conditions including a PBR application being filed with the CPUC no later
than June 30, 1995. If approved by the CPUC, PBR would be implemented in
1997 at the earliest.
On March 16, 1994, the CPUC approved a new process for evaluating the
Company's gas purchases, substantially replacing the previous process of
reasonableness reviews. The new Gas Cost Incentive Mechanism (GCIM) is a
three-year pilot program that began on April 1, 1994. The GCIM essentially
compares the Company's cost of gas with a benchmark level, which is the
average market price of 30-day firm spot supplies delivered to the Company's
service areas.
All savings from gas purchased below the benchmark are shared equally between
ratepayers and shareholders. The Company can recover all costs in excess of
the benchmark that are within a tolerance band. If the Company's cost of gas
exceeds the tolerance band, then the excess costs are shared equally between
ratepayers and shareholders. For the first year of the program, the GCIM
provides a 4.5 percent tolerance band above the benchmark. For the second
and third years of the program, the tolerance band decreases to 4 percent.
For the first full year ended March 31, 1995, the Company's gas costs,
including gains and losses from gas futures contracts discussed below, were
within the tolerance band.
The Company enters into gas futures contracts in the open market on a limited
basis to help reduce gas costs within the GCIM tolerance band. The Company's
policy is to use gas futures contracts to mitigate risk and better manage gas
costs. The CPUC has approved the use of gas futures for managing risk
associated with the GCIM.
FACTORS INFLUENCING FUTURE PERFORMANCE. Under current ratemaking policies,
future Company earnings and cash flow will be determined primarily by the
allowed rate of return on common equity, the growth in rate base, noncore
pricing and the variance in gas volumes delivered to noncore customers versus
CPUC-adopted forecast deliveries and the ability of management to control
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expenses and investment in line with the amounts authorized by the CPUC to be
collected in rates.
The impact of any future regulatory restructuring, such as Performance Based
Ratemaking, increased competitiveness in the industry, including the
continuing threat of customers bypassing the Company's system and obtaining
service directly from interstate pipelines, and electric industry
restructuring could also affect the Company's future performance. The
Company's ability to report as earnings the results from revenues in excess
of its authorized return from noncore customers due to volume increases has
been substantially eliminated for the five years beginning August 1, 1994 as
a consequence of the restructuring of high-cost gas contracts that was
approved by the CPUC last July (the Comprehensive Settlement). This is
because certain forecasted levels of gas deliveries in excess of the 1991
throughput levels used to establish noncore rates were contemplated in
estimating the costs of the Comprehensive Settlement in prior years.
The Company's earnings for 1995 will be affected by the increase in the
authorized rate of return on common equity, reflecting the overall increase
in cost of capital. For 1995, the Company is authorized to earn a rate of
return on rate base of 9.67 percent and a rate of return on common equity of
12.00 percent compared to 9.22 percent and 11.00 percent, respectively, in
1994. Rate base is expected to remain at the same level as 1994.
The Company's earnings for the third and fourth quarters of 1995 and all of
1996 will be favorably impacted by the completion of a realignment of the
Company into two business units in July 1995. A significant amount of the
after-tax savings will not be realized until 1996, the first full year
following the realignment. The anticipated savings are partially offset by
the 2 percent and 3 percent productivity adjustments for 1995 and 1996,
respectively, authorized by the CPUC, under the terms of the 1994
Comprehensive Settlement.
Existing interstate pipeline capacity into California exceeds current demand
by over 1 billion cubic feet per day. Up to 2 billion cubic feet per day of
capacity on the El Paso and Transwestern interstate pipeline systems
representing over $175 million and $55 million, respectively, of reservation
charges annually, may be relinquished within the next few years based on
existing contract reduction options and contract expirations. Some of this
capacity may not be resubscribed. Current FERC regulation could permit the
cost of unsubscribed capacity to be allocated to remaining firm service
customers, including the Company. Under existing regulation in California,
the Company would have the opportunity to include its portion of any such
reallocated costs in its rates. If competitive conditions did not support
higher rates resulting from these reallocated costs, then the Company would
be at risk for lost revenues in the noncore market.
The Company, as a part of a coalition of customers who hold 90 percent of the
firm transportation capacity rights on the El Paso and Transwestern systems,
has offered a proposal for negotiated rates with balanced incentives to El
PAGE 10
Paso and Transwestern to resolve the issue of unsubscribed capacity. In
March 1995, a Principles of Agreement consistent with the coalition's
proposal was finalized with Transwestern. The agreement is subject to the
signatories (which includes the Company) and Transwestern finalizing a
definitive settlement to be submitted to the FERC during the second quarter
of 1995, with approval expected by the end of 1995. A similar proposal was
offered to and rejected by El Paso. The Coalition (including the Company) is
currently evaluating other alternatives available to it for resolving the
issue of unsubscribed capacity with El Paso.
The Company's operations and those of its customers are affected by a growing
number of environmental laws and regulations. These laws and regulations
affect current operations as well as future expansion. Historically,
environmental laws favorably impacted the use of natural gas in the Company's
service territory, particularly by utility electric generation and large
industrial customers. However, increasingly complex administrative
requirements may discourage natural gas use by commercial and industrial
customers. Environmental laws also require clean up of facilities no longer
in use. Because of current and expected rate recovery, the Company believes
that compliance with these laws will not have a significant impact on its
financial statements. For further discussion of regulatory and environmental
matters, see Note 2 of Notes to Condensed Consolidated Financial Statements.
CAPITAL EXPENDITURES. For the three months ended March 31, 1995, capital
expenditures were $40 million. Capital expenditures for utility plant are
expected to be $250 million in 1995 and will be financed primarily by
internally-generated funds.
LIQUIDITY
Regulatory accounts receivable decreased $235 million reflecting the recovery
through increased operating revenues above amounts authorized in current
rates of prior undercollections under the regulatory account procedures. As
a result, the cash flows generated were available for additional cash
requirements, which were primarily utilized for the repayment of short-term
debt of approximately $194 million. The decrease in gas in storage
inventories of $55 million was primarily due to the seasonal withdrawals
required to meet the Company's winter demand.
PART II. OTHER INFORMATION
Item 6. EXHIBITS AND REPORTS ON FORM 8-K
(b) There were no reports of Form 8-K filed during the quarter ended March
31, 1995 were as follows:
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SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
SOUTHERN CALIFORNIA GAS COMPANY
- -------------------------------
(Registrant)
Ralph Todaro
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Ralph Todaro
Vice President-Finance and Controller
(Principal Accounting Officer and duly
authorized signatory)
Date: May 12, 1995