SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
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FORM 10-Q
(Mark One)
[x] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 1996
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OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
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Commission file number 1-720
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PHILLIPS PETROLEUM COMPANY
(Exact name of registrant as specified in its charter)
Delaware 73-0400345
- ------------------------------- ------------------
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
Phillips Building, Bartlesville, Oklahoma 74004
(Address of principal executive offices) (Zip Code)
918-661-6600
(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 registrant had 263,182,947 shares of common stock, $1.25 par value,
outstanding at October 31, 1996.
<PAGE>
PART I. FINANCIAL INFORMATION
- ---------------------------------------------------------------------
Consolidated Statement of Income Phillips Petroleum Company
Millions of Dollars
---------------------------------
Three Months Nine Months
Ended Ended
September 30 September 30
---------------------------------
1996 1995 1996 1995
---------------------------------
Revenues
Sales and other operating revenues $3,852 3,369 11,384 10,047
Equity in earnings of affiliated
companies 22 38 42 106
Other revenues 23 8 48 22
- ---------------------------------------------------------------------
Total Revenues 3,897 3,415 11,474 10,175
- ---------------------------------------------------------------------
Costs and Expenses
Purchased crude oil and products 2,429 2,083 7,171 6,149
Production and operating expenses 514 527 1,526 1,589
Exploration expenses 46 49 159 138
Selling, general and
administrative expenses 132 142 393 363
Depreciation, depletion and
amortization 205 190 633 682
Taxes other than income taxes 69 62 201 201
Interest expense 53 63 171 199
Preferred dividend requirements
of subsidiary and capital trust 14 8 32 24
- ---------------------------------------------------------------------
Total Costs and Expenses 3,462 3,124 10,286 9,345
- ---------------------------------------------------------------------
Income before income taxes and
interest effects of tax
settlement 435 291 1,188 830
Interest effects of Kenai LNG tax
settlement - - 571 -
- ---------------------------------------------------------------------
Income before income taxes 435 291 1,759 830
Provision for income taxes 248 155 656 470
- ---------------------------------------------------------------------
Net Income $ 187 136 1,103 360
=====================================================================
Per Share of Common Stock
Net Income $ .71 .52 4.20 1.37
Dividends Paid $ .32 .305 .93 .89
- ---------------------------------------------------------------------
Average Common Shares Outstanding
(in thousands) 263,180 262,154 262,814 261,954
- ---------------------------------------------------------------------
See Notes to Financial Statements.
1
<PAGE>
- ------------------------------------------------------------------
Consolidated Balance Sheet Phillips Petroleum Company
Millions of Dollars
-------------------------
September 30 December 31
1996 1995
-------------------------
Assets
Cash and cash equivalents $ 346 67
Accounts and notes receivable (less
allowances: 1996--$20; 1995--$15) 1,701 1,522
Inventories 504 505
Deferred income taxes 133 229
Prepaid expenses and other current assets 80 86
- ------------------------------------------------------------------
Total Current Assets 2,764 2,409
Investments and long-term receivables 1,087 841
Properties, plants and equipment (net) 8,849 8,493
Deferred income taxes 88 121
Deferred charges 141 114
- ------------------------------------------------------------------
Total $12,929 11,978
==================================================================
Liabilities
Accounts payable $ 1,481 1,494
Long-term debt due within one year 30 19
Accrued income and other taxes 629 922
Other accruals 359 380
- ------------------------------------------------------------------
Total Current Liabilities 2,499 2,815
Long-term debt 2,855 3,097
Accrued dismantlement, removal and
environmental costs 697 657
Deferred income taxes 1,014 948
Employee benefit obligations 398 400
Other liabilities and deferred credits 714 522
- ------------------------------------------------------------------
Total Liabilities 8,177 8,439
- ------------------------------------------------------------------
Preferred Stock of Subsidiary and Other
Minority Interests 350 351
- ------------------------------------------------------------------
Company-Obligated Mandatorily
Redeemable Preferred Securities
of Phillips Capital Trust 300 -
- ------------------------------------------------------------------
Common Stockholders' Equity
Common stock--500,000,000 shares
authorized at $1.25 par value
Issued (306,380,511 shares)
Par value 383 383
Capital in excess of par 1,993 1,966
Treasury stock (at cost:
1996--13,917,501 shares;
1995--15,047,246 shares) (761) (827)
Compensation and Benefits Trust (CBT)
(at cost: 29,200,000 shares) (989) (989)
Foreign currency translation adjustments 31 39
Unearned employee compensation--Long-
Term Stock Savings Plan (LTSSP) (387) (414)
Retained earnings 3,832 3,030
- ------------------------------------------------------------------
Total Stockholders' Equity 4,102 3,188
- ------------------------------------------------------------------
Total $12,929 11,978
==================================================================
See Notes to Financial Statements.
2
<PAGE>
- -----------------------------------------------------------------
Consolidated Statement of Phillips Petroleum Company
Cash Flows
Millions of Dollars
-------------------
Nine Months Ended
September 30
-------------------
1996 1995
-------------------
Cash Flows from Operating Activities
Net income $1,103 360
Adjustments to reconcile net income to net
cash provided by operating activities
Non-working capital adjustments
Depreciation, depletion and
amortization 633 682
Dry hole costs and leasehold
impairment 63 44
Deferred taxes 138 (10)
Tax settlement receivable (176) -
Other (30) (66)
Working capital adjustments
Increase (decrease) in aggregate
balance of accounts receivable sold (200) 115
Decrease (increase) in other accounts
and notes receivable 11 (51)
Increase in inventories (2) (55)
Decrease in prepaid expenses and
other current assets 7 27
Decrease in accounts payable (6) (53)
Increase (decrease) in taxes and
other accruals (114) 286
- -----------------------------------------------------------------
Net Cash Provided by Operating Activities 1,427 1,279
- -----------------------------------------------------------------
Cash Flows from Investing Activities
Capital expenditures and investments,
including dry hole costs (1,060) (880)
Proceeds from asset dispositions 84 45
Long-term advances to affiliates and
other investments (58) (6)
- -----------------------------------------------------------------
Net Cash Used for Investing Activities (1,034) (841)
- -----------------------------------------------------------------
Cash Flows from Financing Activities
Issuance of debt 465 327
Repayment of debt (704) (547)
Issuance of company stock 21 7
Issuance of company-obligated mandatorily
redeemable preferred securities 300 -
Dividends paid (244) (233)
Other 48 (42)
- -----------------------------------------------------------------
Net Cash Used for Financing Activities (114) (488)
- -----------------------------------------------------------------
Increase (Decrease) in Cash and Cash
Equivalents 279 (50)
Balance at beginning of period 67 193
- -----------------------------------------------------------------
Cash and Cash Equivalents at End of Period $ 346 143
=================================================================
See Notes to Financial Statements.
3
<PAGE>
- -----------------------------------------------------------------
Notes to Financial Statements Phillips Petroleum Company
Note 1--Interim Financial Information
The financial information for the interim periods presented in
the financial statements included in this report is unaudited and
includes all known accruals and adjustments which Phillips
Petroleum Company (hereinafter referred to as "Phillips" or "the
company") considers necessary for a fair presentation of the
consolidated financial position of the company and its results of
operations and cash flows for such periods. All such adjustments
are of a normal and recurring nature. Certain amounts in the
1995 financial statements have been reclassified to conform with
the 1996 presentation.
Note 2--Accounting Change
Effective January 1, 1996, the company made certain changes in
the estimated useful lives of its major domestic downstream
facilities. This change increased third quarter and the first
nine months of 1996 net income by $5 million, $.02 per share, and
$15 million, $.06 per share, respectively. Also, effective
January 1, 1996, the company changed its method of accounting for
the depreciation of its Gas Gathering, Processing and Marketing
segment's natural gas plants and systems from the unit-of-
production method to the straight-line method, using an estimated
life of 20 years for most of these assets. This change was made
to better reflect how the assets are expected to be used over
time, to provide a better matching of revenues and expenses, and
to be consistent with prevalent industry practice. As a result
of the change, net income for the three- and nine-month periods
ended September 30, 1996, was $5 million and $13 million higher,
or $.02 and $.05 per share, respectively. The estimated
cumulative effect of the change was not material. The effect of
these changes was substantially offset by increased depreciation
expense as a result of asset acquisitions and capital additions.
4
<PAGE>
Note 3--Inventories
Inventories consisted of the following:
Millions of Dollars
-------------------------
September 30 December 31
1996 1995
-------------------------
Crude oil and petroleum products $ 195 173
Chemical products 231 245
Materials, supplies and other 78 87
- -----------------------------------------------------------------
$ 504 505
=================================================================
Note 4--Properties, Plants and Equipment
Properties, plants and equipment (net) included the following:
Millions of Dollars
-------------------------
September 30 December 31
1996 1995
-------------------------
Properties, plants and equipment
(at cost) $19,847 19,088
Less accumulated depreciation,
depletion and amortization 10,998 10,595
- -----------------------------------------------------------------
$ 8,849 8,493
=================================================================
Note 5--Impairments
Point Arguello Field - Due to declining production and an updated
production forecast for the Point Arguello field offshore
California, an impairment of $45 million after-tax was taken in
the first quarter of 1996, reducing the net book value to the
estimated fair market value. The fair market value of this
Exploration and Production (E&P) asset was determined using the
present value of expected future cash flows, resulting in a
before-tax charge of $51 million to depreciation, depletion and
amortization expense, and a $19 million reduction in equity in
earnings of affiliated companies.
Certain Canadian Properties - Due to a weaker gas price outlook
in Canada and disappointing drilling and production results on
certain Canadian properties, the company initiated and completed
a review of future cash flows from its Canadian properties during
third quarter 1996, resulting in an impairment charge of
$25 million to reduce the net book value of certain properties to
estimated fair market value. The fair market value of these E&P
assets was determined using the present value of expected future
5
<PAGE>
cash flows which resulted in a charge of $25 million to
depreciation, depletion and amortization expense. There was no
tax impact due to available Canadian net operating loss
carryforwards that are not expected to be fully utilized.
Note 6--Debt
The company has a $1.1 billion revolving bank credit facility,
and a $250 million commercial paper program that is supported by
a portion of the company's revolving credit line equal to
100 percent of the commercial paper outstanding. No amounts were
outstanding under the revolving bank credit facility or the
commercial paper program at September 30, 1996.
Effective November 1, 1996, the company's wholly owned
subsidiary, Phillips Petroleum Company Norway, reduced its
revolving credit facility from $500 million to $300 million. No
amounts were outstanding under this facility at September 30,
1996.
Note 7--Kenai LNG Tax Settlement
On February 26, 1996, the U.S. Tax Court's previous decisions
related to the company's sales of liquefied natural gas (LNG)
from its Kenai, Alaska, facility to Japan, became final. The Tax
Court's decisions supported the company's position that more than
50 percent of the income for years 1975 through 1978 was from a
foreign source. The favorable resolution of this issue increased
net income for the nine-month period ended September 30, 1996, by
$565 million.
Note 8--Income Taxes
The company's effective tax rates for the three- and nine-month
periods ended September 30, 1996, were 57 and 37 percent,
respectively, compared with 53 and 57 percent for each of the
same periods a year ago. The increase for the three-month period
was due mainly to the mix of income in the various taxing
jurisdictions. The decrease in the rate for the nine-month
period was due mainly to the favorable resolution of the Kenai
LNG tax case, discussed in Note 7. Excluding the Kenai
settlement, the effective tax rate for the nine-month period
ended September 30, 1996, would have been 55 percent. The
remaining decrease is due mainly to the utilization of foreign
tax credits against current period Kenai LNG earnings.
6
<PAGE>
Note 9--Contingencies
In the case of all known contingencies, the company accrues an
undiscounted liability when the loss is probable and the amount
is reasonably estimable. These liabilities are not reduced for
potential insurance recoveries. If applicable, undiscounted
receivables are accrued for probable insurance recoveries. Based
on currently available information, the company believes that it
is remote that future costs related to known contingent liability
exposures will exceed current accruals by an amount that would
have a material adverse impact on the company's financial
statements.
As facts concerning contingencies become known to the company,
the company reassesses its position both with respect to accrued
liabilities and other potential exposures. Estimates that are
particularly sensitive to future change include contingent
liabilities recorded for environmental remediation, tax and legal
matters. Estimated future environmental remediation costs are
subject to change due to such factors as the unknown magnitude of
cleanup costs, the unknown time and extent of such remedial
actions that may be required, and the determination of the
company's liability in proportion to other responsible parties.
Estimated future costs related to tax and legal matters are
subject to change as events evolve and as additional information
becomes available during the administrative and litigation
process.
Environmental--The company is subject to federal, state and local
environmental laws and regulations. These may result in
obligations to remove or mitigate the effects on the environment
of the placement, storage, disposal or release of certain
chemical, mineral and petroleum substances at various sites. The
company is currently participating in environmental assessments
and cleanup under these laws at federal Superfund and comparable
state sites. In the future, the company may be involved in
additional environmental assessments, cleanups and proceedings.
Tax Contingencies--The company has a number of issues outstanding
with the IRS related to tax years 1979 through 1992 that can
proceed toward final settlement as a result of resolving the
Kenai LNG tax case. Although it is too early to determine the
final financial effects of resolving these years, a favorable
outcome would have a positive effect on net income and cash flow
while an unfavorable one would not impact the company's net
income or cash position. While total resolution may require a
number of years, the earliest years are expected to be resolved
in the near term.
7
<PAGE>
Other Legal Proceedings--The company is a party to a number of
other legal proceedings pending in various courts or agencies for
which, in some instances, no provision has been made.
Other Contingencies--The company has contingent liabilities
resulting from throughput agreements with pipeline and processing
companies in which it holds stock interests. Under these
agreements, Phillips may be required to provide any such company
with additional funds through advances against future charges for
the shipping or processing of petroleum liquids, natural gas and
refined products.
Note 10--Company-Obligated Mandatorily Redeemable Preferred
Securities of Phillips Capital Trust
During February 1996, the company formed a new statutory business
trust, Phillips 66 Capital I (Trust), of which the company owns
all of the common stock. The Trust exists for the sole purpose
of issuing trust securities and investing the proceeds thereof in
an equivalent amount of subordinated debt securities of Phillips
Petroleum Company.
On May 29, 1996, the Trust completed a $300 million underwritten
public offering of 12,000,000 shares of 8.24% Trust Originated
Preferred Securities (Preferred Securities). The sole asset of
the Trust is $309 million of Phillips' 8.24% Junior Subordinated
Deferrable Interest Securities due 2036 (Subordinated Debt
Securities), purchased by the Trust on May 29, 1996. The
Subordinated Debt Securities are unsecured obligations of
Phillips and subordinate and junior in right of payment to all
present and future senior indebtedness of Phillips. The
Subordinated Debt Securities and related income statement effects
are eliminated in the company's consolidated financial
statements. The Subordinated Debt Securities are due May 29,
2036, and are redeemable in whole, or in part, at the option of
Phillips, on or after May 29, 2001, at a redemption price of
$25 per share, plus accrued and unpaid interest. When the
company redeems the Subordinated Debt Securities, the Trust is
required to apply all redemption proceeds to the immediate
redemption of the Trust's Preferred Securities.
Phillips fully and unconditionally guarantees the Trust's
obligations under the Preferred Securities.
8
<PAGE>
Note 11--Cash Flow Information
Cash payments and non-cash investing and financing activities for
the nine-month periods ended September 30 were as follows:
Millions of Dollars
-------------------
1996 1995
-------------------
Cash payments
Interest
Debt $173 164
Taxes and other 26 16
- -----------------------------------------------------------------
$199 180
=================================================================
Income taxes $482 293
- -----------------------------------------------------------------
Non-Cash Financing Activities
Common stock awards issued under
incentive compensation plans $ 4 6
Issuance of promissory note to purchase
service stations 7 -
- -----------------------------------------------------------------
9
<PAGE>
- -----------------------------------------------------------------
Management's Discussion and Analysis Phillips Petroleum Company
RESULTS OF OPERATIONS
Unless otherwise noted, discussion of results for the three- and
nine-month periods ending September 30, 1996, are based on a
comparison with the corresponding periods in 1995.
A summary of the company's net income, by business segment and
consolidated, follows:
Millions of Dollars
-------------------------------------
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995 1996 1995
------------------ -----------------
Exploration and Production
(E&P) 141 79 378 254
Gas Gathering, Processing
and Marketing (GPM) 31 2* 88 10*
Refining, Marketing and
Transportation (RM&T) 38 31 94 38
Chemicals 56 118 209 326
Corporate and Other (79) (94)* 334 (268)*
- -----------------------------------------------------------------
Net Income $187 136 1,103 360
=================================================================
*Preferred stock dividend requirements of subsidiary was
reclassified from GPM to Corporate and Other for segment
reporting.
Consolidated Results
Earnings included the following special items on an after-tax
basis:
Millions of Dollars
-------------------------------------
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995 1996 1995
------------------ -----------------
Property impairments $(25) (1) (70) (50)
Kenai LNG tax settlement - - 565 -
Net gains on asset sales 9 - 14 -
Work force reduction
charges 1 (5) - (18)
Foreign currency gains
(losses) 2 (2) 2 (1)
Pending claims and
settlements (13) (11) (42) (11)
Other items 5 4 (5) (10)
- -----------------------------------------------------------------
Total special items $(21) (15) 464 (90)
=================================================================
10
<PAGE>
Excluding the special items above, net operating income was
$208 million for the three-month period ended September 30, 1996,
compared with $151 million for the corresponding period in 1995.
For the nine-month period ended September 30, 1996, net operating
income was $639 million, compared with $450 million for the
corresponding nine-month period a year ago. The 38 percent
improvement in the results for the third quarter is attributable
to substantially improved operating income from E&P and GPM. The
strong results from these businesses were driven by higher crude
oil, natural gas and natural gas liquids sales prices. Lower
motor fuel margins contributed to lower earnings in the RM&T
segment in the quarter, while lower ethylene and paraxylene
margins resulted in substantially lower earnings in the chemicals
segment, compared with last year's strong results.
For the year-to-date period, net operating income increased
42 percent. Results by segment generally tracked the third
quarter, with the exception of RM&T, where higher distillates
margins in the nine-month period led to net operating income
levels of more than double that of a year ago.
11
<PAGE>
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
Phillips at a Glance 1996 1995 1996 1995
------------------ -----------------
U.S. crude oil
production (MBD) 68 77 70 80
Worldwide crude oil
production (MBD) 213 214 218 220
U.S. natural gas
production (MMCFD) 1,129 1,068 1,132 1,076
Worldwide natural gas
production (MMCFD) 1,471 1,413 1,538 1,489
Worldwide natural gas
liquids production (MBD) 166 164 162 161
Liquefied natural gas
sales (MMCFD) 144 146 130 125
Refinery utilization
rate (%) 100 99 94 96
U.S. automotive gasoline
sales (MBD) 349 352 339 332
U.S. distillates
sales (MBD) 135 125 135 131
Worldwide petroleum
products sales (MBD) 685 688 688 692
Natural gas liquids
processed (MBD) 202 202 202 202
Ethylene production
(MMlbs)* 549 630 1,862 1,889
Polyethylene
production (MMlbs)* 529 450 1,546 1,364
Polypropylene production
(MMlbs)* 90 109 232 328
Paraxylene production
(MMlbs) 129 140 455 398
- -----------------------------------------------------------------
*Includes equity in affiliates.
Income Statement Analysis
Sales and other operating revenues increased 14 percent and
13 percent for the third quarter and nine-month period,
respectively, as a result of higher crude oil, petroleum products
and natural gas prices. These same factors also contributed to
17 percent higher purchase costs in both periods.
Equity earnings of affiliated companies declined 42 percent and
60 percent in the third quarter and first nine months,
respectively. Lower earnings from the company's equity interest
in Sweeny Olefins Limited Partnership, due to lower ethylene
margins, reduced both periods. In addition, equity earnings for
12
<PAGE>
the nine-month period were lower due to a first-quarter 1996
impairment on certain equity companies related to the Point
Arguello field, offshore California. Higher net gains from
assets sales and higher interest income resulted in increased
other revenues for both the third quarter and nine-month period.
Controllable costs, composed primarily of production and
operating expenses and selling, general and administrative
expenses, both adjusted for special items, were about the same as
a year ago in both the quarter and year-to-date period. Lower
costs from the company's Norway E&P operations and the GPM
segment were offset by higher fuel costs and costs associated
with company growth-related projects.
Exploration expenses decreased 6 percent in the third quarter and
increased 15 percent in the nine-month period. Higher dry hole
charges in the first quarter of 1996, mainly due to the
Alexandrite subsalt exploratory well in the Gulf of Mexico and an
exploratory well in Algeria, contributed to the higher nine-month
period expenses.
Depreciation, depletion and amortization (DD&A) was 5 percent
lower in both the third quarter and nine-month period, after
adjusting for property impairments. Primarily responsible for
the decrease were lower DD&A from RM&T and Chemicals, due to new
depreciation rates, and from GPM, due to an accounting method
change, both of which became effective January 1, 1996. Also,
Norway E&P DD&A was lower, mainly due to upward revisions to
recoverable reserves at year-end 1995. The effect of these
changes was partially offset by asset acquisitions and capital
additions.
Taxes other than income taxes were 11 percent higher in the third
quarter, primarily as a result of a Nigerian education tax
assessment.
Interest expense was 16 percent and 14 percent lower in the
quarter and nine-month period, respectively, mainly as a result
of lower interest expense on tax contingencies, due to the
favorable resolution of the Kenai LNG tax case.
13
<PAGE>
Segment Results
E&P Millions of Dollars
-------------------------------------
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995 1996 1995
------------------ -----------------
Reported net income $141 79 378 254
Less special items (21) (3) (85) (59)
- -----------------------------------------------------------------
Net operating income $162 82 463 313
=================================================================
Average Sales Prices
Crude oil (per barrel)
United States $19.21 14.50 18.12 15.13
Foreign 21.13 16.24 19.93 17.21
Worldwide 20.54 15.64 19.36 16.48
Natural gas--lease (per
thousand cubic feet)
United States 1.91 1.28 1.88 1.32
Foreign 2.54 2.53 2.49 2.48
Worldwide 2.10 1.70 2.08 1.75
- -----------------------------------------------------------------
Worldwide Exploration
Expenses
Geological and geophysical $32 32 90 90
Leasehold impairment 6 8 20 24
Dry holes 6 7 43 20
Lease rentals 2 2 6 4
- -----------------------------------------------------------------
$46 49 159 138
=================================================================
Thousands of Barrels Daily
-------------------------------------
Operating Statistics
Crude Oil Produced
United States 68 77 70 80
Norway 96 99 98 98
United Kingdom 5 4 6 4
Nigeria 25 23 25 23
China 14 6 14 10
Canada 5 5 5 5
- -----------------------------------------------------------------
213 214 218 220
=================================================================
Natural Gas Liquids Produced
United States 4 6 4 5
Norway 7 8 8 9
Other areas 3 3 3 2
- -----------------------------------------------------------------
14 17 15 16
=================================================================
14
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Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995 1996 1995
------------------ -----------------
Millions of Cubic Feet Daily
-------------------------------------
Natural Gas Produced
United States (less gas
equivalent of liquids
shown above) 1,129 1,068 1,132 1,076
Norway* 242 283 284 303
United Kingdom* 48 7 69 52
Canada 52 55 53 58
- -----------------------------------------------------------------
1,471 1,413 1,538 1,489
=================================================================
*Dry basis.
Liquefied Natural Gas
Sales 144 146 130 125
- -----------------------------------------------------------------
E&P's net operating income in the third quarter of 1996 almost
doubled over the third quarter of last year. For the first nine
months of 1996, net operating income was 48 percent higher than
the corresponding period a year ago. Both 1996 periods benefited
from higher worldwide crude oil and U.S. natural gas sales
prices.
Phillips' average worldwide crude oil sales price rose throughout
the third quarter, and averaged $22.07 per barrel in September,
its highest level since January 1991. The third quarter average
price of $20.54 per barrel was 31 percent higher than the third
quarter of 1995, and resulted in marked improvement in E&P's
crude oil revenues. Political uncertainties, primarily tension
in the Middle East and lowered expectations for a resumption of
Iraqi crude oil exports, have resulted in increasing industry
crude oil prices over the last several months. Low industry
heating oil inventories have increased demand for crude oil as a
refinery feedstock, also helping to support the higher crude oil
prices.
15
<PAGE>
U.S. E&P Millions of Dollars
- -------- -------------------------------------
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995 1996 1995
------------------ ----------------
Reported net income $113 64 256 166
Less special items 2 - (62) (37)
- -----------------------------------------------------------------
Net operating income $111 64 318 203
=================================================================
Net operating income increased 73 percent in the company's U.S.
E&P operations for the third quarter of 1996, and 57 percent for
the first nine months. Higher U.S. natural gas sales
prices--49 percent higher for the quarter and 42 percent higher
for the year-to-date period--were primarily responsible for the
improved results. Natural gas prices benefited from an increase
in industry demand and a reduction in natural gas storage levels
caused by a cold winter in North America in 1995-1996. Higher
summer cooling demand and the replenishment of industry natural
gas storage sustained the improved prices in the third quarter,
although prices weakened markedly in September. U.S. crude oil
lease revenues were higher in the third quarter, as 32 percent
higher average sales prices more than offset lower production
volumes.
U.S. crude oil production continued to trend downward in the
third quarter of 1996, ending with a quarterly average production
rate of 68,000 barrels of oil per day, compared with
77,000 barrels per day in the third quarter of 1995. Continuing
production declines from the Point Arguello field, offshore
California, field declines in the Gulf of Mexico and Prudhoe Bay,
and the effect of non-strategic property dispositions have
resulted in the production declines.
U.S. natural gas production was 6 percent higher in the third
quarter and 5 percent higher in the first nine months of 1996,
compared with the corresponding periods last year. For both
periods, the increase is attributable to new production from the
Seastar (Garden Banks Blocks 70/71) field in the Gulf of Mexico,
which came online in mid-year 1995; increases from property
acquisitions in south Louisiana; higher production from the San
Juan Basin; new wells onshore Gulf Coast; partially offset by
lower production from the South Marsh Island Blocks 146/147
field, Gulf of Mexico.
Special items in the third quarter included asset sale gains of
$4 million after-tax, partially offset by contingency accruals.
In addition, the first nine months of 1996 included an after-tax
charge of $45 million for the impairment of the Point Arguello
field and associated facilities. During the third quarter
16
<PAGE>
of 1995, a decline in production was experienced from the Point
Arguello field, related to increasing water production from the
reservoir and the deferral of certain projects. Subsequent well
workovers and other measures improved production during the
fourth quarter of 1995, but volumes again declined during the
first quarter of 1996, as increasing water encroachment continued
to adversely affect production. Based upon new production data,
experience gained from well workover activity, and technical
reviews with the operator, a new production forecast was made.
As a result, an impairment was taken in the first quarter of
1996, reducing the net book value to the estimated fair market
value. Also included in special items in the first nine months
of 1996 were various contingency accruals, the most significant
of which relates to an unfavorable court judgment regarding
producing properties in Alabama. Special items in the nine-month
period of 1995 represented property impairments on an after-tax
basis of $33 million, as a result of the adoption of Financial
Accounting Standards Board Statement No. 121, "Accounting for the
Impairment of Long-Lived Assets and for Long-Lived Assets to Be
Disposed Of," as well as work force reduction charges.
Foreign E&P Millions of Dollars
- ----------- -------------------------------------
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995 1996 1995
------------------ -----------------
Reported net income $ 28 15 122 88
Less special items (23) (3) (23) (22)
- -----------------------------------------------------------------
Net operating income $ 51 18 145 110
=================================================================
Net operating income from the company's foreign E&P operations
increased $33 million in the third quarter of 1996, compared with
the third quarter of 1995, primarily due to higher crude oil
sales prices and volumes. For the nine-month period, net
operating income increased 32 percent, again, primarily on the
strength of higher crude oil sales prices and volumes.
Foreign crude oil production was up 6 percent in the third
quarter and nine-month period. For the quarter and year-to-date
periods, the increases are primarily attributable to offshore
China, as a result of new production from the Xijiang 30-2 field,
which began producing in October 1995, and the impact of
operating disruptions in the third quarter of 1995 on the Xijiang
24-3 field, which caused production to be shut-in for two months.
Foreign natural gas production declined slightly for both the
quarter and first nine months, as lower demand in Norway was
mostly offset by new production and increased demand in the U.K.
sector of the North Sea.
17
<PAGE>
Special items in the third quarter and nine-month period of 1996
primarily represented an impairment of certain Canadian proved
properties on an after-tax basis of $25 million. Special items
in the third quarter of 1995 consisted of a contract settlement.
The nine-month period of 1995 also included work force reduction
charges, property impairments and a tax contingency accrual.
GPM Millions of Dollars
-------------------------------------
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995 1996 1995
------------------ ----------------
Reported net income $31 2* 88 10*
Less special items 1 (2) 3 (2)
- -----------------------------------------------------------------
Net operating income $30 4 85 12
=================================================================
*Preferred stock dividend requirements of subsidiary was
reclassified from GPM to Corporate and Other for segment
reporting.
Average Sales Prices
U.S. residue gas (per
thousand cubic feet) $ 2.04 1.34 2.05 1.41
U.S. natural gas liquids
(per barrel--
unfractionated) 14.05 9.66 12.93 9.98
- -----------------------------------------------------------------
Millions of Cubic Feet Daily
-------------------------------------
Operating Statistics
Natural Gas Purchases
Outside Phillips 1,391 1,261 1,369 1,246
Phillips 179 194 179 196
- -----------------------------------------------------------------
1,570 1,455 1,548 1,442
=================================================================
Raw Gas Throughput 1,930 1,650 1,920 1,619
- -----------------------------------------------------------------
Residue Gas Sales
Outside Phillips 1,001 812 998 836
Phillips 72 206 80 181
- -----------------------------------------------------------------
1,073 1,018 1,078 1,017
=================================================================
Thousands of Barrels Daily
-------------------------------------
Natural Gas Liquids Net
Production
From Phillips E&P
leasehold gas 18 19 17 19
From gas purchased
outside Phillips 134 128 130 126
- -----------------------------------------------------------------
152 147 147 145
=================================================================
18
<PAGE>
GPM's net operating income increased $26 million and $73 million
for the third quarter and first nine months of 1996,
respectively, compared with the same periods in 1995. The
improvements were mainly the result of improved margins, due to
higher natural gas liquids (NGL) and residue gas sales prices,
and higher raw gas throughput volumes. Earnings also benefited
from significantly lower operating expenses.
NGL prices have increased primarily as a result of low industry
inventories and increased demand for NGL as a petrochemical
feedstock. NGL production volumes increased 3 percent in the
third quarter, mainly due to higher NGL extractions and operating
consistency at the Linam Ranch plant, New Mexico, and
acquisitions completed at the end of 1995.
Residue gas sales prices benefited from a cold winter in North
America, compared with a mild winter in 1994-1995, impacting both
demand for gas and storage levels in the first quarter of 1996.
The effect of lower storage levels and higher summer cooling
demand resulted in a continuation of the strong residue gas
prices through the third quarter of 1996, although prices began
to soften in September. The increase in residue gas sales
volumes was primarily the result of acquisitions completed at the
end of 1995.
Controllable costs were 14 percent and 22 percent lower for the
third quarter and first nine months, respectively, reflecting
continuous cost improvement efforts, such as technology
enhancements, plant modernizations, plant consolidations and
reengineering efforts completed in 1995.
Special items in the third quarter represented a favorable
adjustment to previously accrued work force reduction charges.
The nine-month period also included a gain on the sale of an NGL
plant and gathering system. The special items in 1995
represented work force reduction charges.
19
<PAGE>
RM&T Millions of Dollars
-------------------------------------
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995 1996 1995
------------------ ----------------
Reported net income $38 31 94 38
Less special items 5 (5) 4 (6)
- -----------------------------------------------------------------
Net operating income $33 36 90 44
=================================================================
Average Sales Prices
(per gallon)
Automotive gasoline--
wholesale $.67 .58 .65 .59
Automotive gasoline--retail .82 .74 .81 .75
Distillates .63 .52 .61 .51
Propane .45 .37 .45 .36
- -----------------------------------------------------------------
Thousands of Barrels Daily
-------------------------------------
Operating Statistics
U.S. Refinery Crude Oil
Capacity 345 345 345 345
Refined 345 340 325 331
Capacity utilization
(percent) 100% 99 94 96
- -----------------------------------------------------------------
Petroleum Products Outside
Sales
United States
Automotive gasoline--
wholesale 296 299 290 288
Automotive gasoline--
retail 37 36 37 35
Aviation fuels 26 29 25 30
Distillates 135 125 135 131
Propane 20 16 24 21
Other products 14 18 15 19
- -----------------------------------------------------------------
528 523 526 524
Foreign 44 32 46 44
- -----------------------------------------------------------------
572 555 572 568
=================================================================
RM&T had net operating income of $33 million in the third quarter
of 1996, 8 percent lower than $36 million in last year's third
quarter. For the first nine months, net operating income was
$90 million, up significantly from $44 million reported in the
first nine months of 1995. The much improved year-to-date
results are attributable primarily to higher distillates margins,
20
<PAGE>
and, to a lesser extent, higher motor fuel margins. For the
quarter, higher distillates margins and sales volumes were more
than offset by lower motor fuel and other product margins and
volumes, and higher refinery fuel costs and costs associated with
the retail marketing expansion program.
Distillates prices remained about 10 cents per gallon higher than
a year ago in the third quarter. Low industry-wide inventories
have created a tight supply situation, compared with last year,
supporting improved distillates prices. However, crude oil and
NGL feedstock costs were higher in both the 1996 third quarter
and nine-month period, partially offsetting the benefit of higher
average distillates and motor fuel sales prices.
The company's U.S. refineries ran at capacity in the third
quarter, averaging 345,000 barrels of crude oil runs daily. For
the nine-month period, crude runs were slightly lower than a year
ago, due to turnarounds at the Borger and Sweeny, Texas,
refineries during the first half of 1996.
Special items in the third quarter of 1996 represented a gain on
the sale of the company's retail propane business. Special items
in both 1995 periods related to a charge associated with
withdrawing from an industry association, as well as work force
reduction charges.
Chemicals Millions of Dollars
-------------------------------------
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995 1996 1995
------------------ -----------------
Reported net income $ 56 118 209 326
Less special items - 4 (7) (4)
- -----------------------------------------------------------------
Net operating income $ 56 114 216 330
=================================================================
Millions of Pounds,
Except as Indicated
-------------------------------------
Operating Statistics
Production*
Ethylene 549 630 1,862 1,889
Polyethylene 529 450 1,546 1,364
Propylene 81 105 294 324
Polypropylene 90 109 232 328
Paraxylene 129 140 455 398
Cyclohexane (millions
of gallons) 41 42 126 89
- -----------------------------------------------------------------
*Includes equity in affiliates.
21
<PAGE>
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995 1996 1995
------------------ -----------------
Thousands of Barrels Daily
-------------------------------------
U.S. Petroleum Products
Outside Sales
Automotive gasoline 16 17 12 9
Liquefied petroleum gas 63 79 73 77
Other products 34 37 31 38
- -----------------------------------------------------------------
113 133 116 124
=================================================================
Natural Gas Liquids
Processing capacity 250 227 250 227
Liquids processed 202 202 202 202
- -----------------------------------------------------------------
Chemicals net operating income declined substantially in the
third quarter and nine-month period from the strong results
experienced during 1995, when industry conditions were much more
favorable. For the quarter, earnings were down due to lower
margins for ethylene and paraxylene, partially offset by higher
ethylene and polyethylene sales volumes. For the first nine
months, lower margins for ethylene and polyethylene were
partially offset by higher sales volumes for these same products.
While ethylene margins were much lower than a year ago, generally
tight industry supply kept this market steady through the second
and third quarters of 1996, but rising NGL feedstock costs,
particularly late in the third quarter, began to cause pressure
on margins. Ethylene and propylene production volumes were
13 percent and 23 percent lower in the quarter, respectively, due
to debottlenecking work and a major scheduled maintenance
turnaround of the olefins unit at Sweeny Olefins Limited
Partnership, in which the company owns a 50-percent equity
interest. Paraxylene margins continued the decline began in the
second quarter of 1996, due to surplus industry capacity and weak
demand. Weather-related downtime at the company's Puerto Rico
Core facilities resulted in lower paraxylene production, compared
with the third quarter of 1995.
Polyethylene industry conditions remained steady through the
third quarter, resulting in feedstock margins higher than the
second quarter of 1996, but slightly lower than the third quarter
last year. The company's facilities operating performance was
strong during the third quarter, with 18 percent higher
polyethylene production rates than a year ago.
Special items in the first nine months of 1996 represented a tax
item related to the Puerto Rico Core operations. Special items
in the third quarter of 1995 included a favorable income tax
22
<PAGE>
adjustment, partially offset by a contingency accrual. In
addition, the nine-month period of 1995 included property
impairments.
Corporate and Other Millions of Dollars
-------------------------------------
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
1996 1995* 1996 1995*
------------------ -----------------
Reported Corporate and
Other $(79) (94) 334 (268)
Less special items (6) (9) 549 (19)
- -----------------------------------------------------------------
Adjusted Corporate and
Other $(73) (85) (215) (249)
=================================================================
Adjusted Corporate and Other includes:
Corporate general and
administrative expenses $(31) (35) (91) (94)
Net interest (32) (43) (104) (130)
Preferred dividend
requirements (12) (8) (30) (24)
Other 2 1 10 (1)
- -----------------------------------------------------------------
Adjusted Corporate and
Other $(73) (85) (215) (249)
=================================================================
*Preferred stock dividend requirements of subsidiary was
reclassified from GPM to Corporate and Other for segment
reporting.
Corporate general and administrative expenses were $4 million and
$3 million lower in the third quarter and first nine months of
1996, respectively, compared with the corresponding periods in
1995. Both 1996 periods were lower relative to 1995 due to a
lump-sum merit salary increase program in the third quarter of
1995.
Net interest represents interest income and expense, net of
capitalized interest. Net interest was lower in both the third
quarter and first nine months of 1996 due to lower interest
expense on tax contingencies resulting from the favorable
resolution of the Kenai LNG tax case.
Preferred dividend requirements includes dividends on the
Phillips Gas Company preferred stock and on the preferred
securities of the Phillips 66 Capital I trust, which were issued
in May 1996.
23
<PAGE>
Other consists primarily of the company's insurance operations,
along with income tax and other items that are not directly
associated with the operating segments on a stand-alone basis.
Other benefited from improved results from the company's
captive insurance subsidiary, along with lower tax accruals not
directly associated with the operating segments.
Special items in the third quarter of 1996 primarily included tax
related adjustments and settlements. In addition, the nine-month
period of 1996 included an after-tax gain of $565 million related
to the favorable settlement of the Kenai LNG tax case. Special
items in the third quarter of 1995 included work force reduction
charges and a $7 million after-tax contingency accrual. In
addition, the first nine months of 1995 also included property
impairments.
CAPITAL RESOURCES AND LIQUIDITY
Financial Indicators
Millions of Dollars
---------------------------------------
At At At
September 30 December 31 September 30
1996 1995 1995
---------------------------------------
Current ratio 1.1 .9 .9
Long-term debt $2,855 3,097 2,876
Preferred stock of
subsidiary $ 345 345 345
Company-obligated
mandatorily redeemable
preferred securities $ 300 - -
Common stockholders'
equity $4,102 3,188 3,154
Percent of long-term
debt to capital* 38% 47 45
Percent of floating-rate
debt to total debt 16% 22 17
- -----------------------------------------------------------------
*Capital includes long-term debt, preferred stock of subsidiary,
company-obligated mandatorily redeemable preferred securities
and common stockholders' equity.
Cash from operations increased $148 million, a 12 percent
increase for the nine-month period ended September 30, 1996,
compared with the same period in 1995. A net operating income
increase of $189 million, coupled with a cash refund from the
Internal Revenue Service (IRS) of $209 million as a result of the
favorable resolution of the Kenai LNG tax case, was mostly offset
by a $315 million decrease in the aggregate balance of accounts
receivable sold. Improved operating results and the Kenai LNG
24
<PAGE>
settlement have strengthened the company's equity base, dropping
the percentage of long-term debt to capital to its lowest level
since 1984.
During the third quarter of 1996, Moody's Investors Service
upgraded the rating of Phillips' senior, unsecured debt from Baa1
to A3. This follows a recent Standard and Poor's upgrade of
Phillips' long-term public debt from BBB to A-, an increase of
two levels. These ratings are the highest since 1985.
During the first quarter, the company filed with the Securities
and Exchange Commission a shelf registration for $750 million of
trust preferred securities and subordinated debt securities.
This shelf registration became effective in May 1996. In a
related transaction, the company formed four new statutory
business trusts, for the sole purpose of issuing trust securities
and investing the proceeds thereof in an equivalent amount of
Phillips subordinated debt securities. Phillips owns all of the
common stock of the trusts.
During the second quarter, Phillips 66 Capital I (Trust)
completed a $300 million underwritten public offering of 8.24%
Trust Originated Preferred Securities (Preferred Securities).
The sole asset of the Trust is $309 million of the company's
8.24% Junior Subordinated Deferrable Interest Securities due
2036, purchased from Phillips by the Trust. Phillips fully and
unconditionally guarantees the Trust's obligations under the
Preferred Securities.
During the second quarter of 1996, the company received
$115 million from institutional investors in exchange for a
variable interest in the net proceeds from production of certain
coal-seam gas properties.
The company recently negotiated a master leasing arrangement
under which it will lease and supervise the construction of
service stations throughout the Midwest, Southwest, West and
Southeast. An initial $50 million of service stations is
expected to be financed under the arrangement over the next year,
after which the company may expand the arrangement to
$300 million. The term of the lease payments is seven years with
a fair market value purchase option at the end of that period,
and includes certain guaranteed residual values if the company
does not exercise the purchase option. Individual leases under
the arrangement are expected to qualify for operating lease
accounting treatment.
Effective November 1, 1996, Phillips Petroleum Company Norway, a
wholly owned subsidiary, reduced its revolving credit facility
from $500 million to $300 million, lowering commitment fees for
25
<PAGE>
having the line of credit available. The company reduced the
line of credit, primarily due to lower estimated Ekofisk II
redevelopment costs. The total cost of the project was
originally estimated at about $3 billion, with Phillips'
35 percent share of the cost being approximately $1 billion. The
total cost estimate has been reduced to about $2.5 billion, with
Phillips' share now estimated to be $840 million.
Capital Expenditures and Investments
Millions of Dollars
----------------------------------------------------
Three Months Ended Nine Months Ended
September 30 September 30
------------------ -----------------
Estimated 1996 1996 1995 1996 1995
-------------- ------------------ -----------------
E&P $1,029 226 223 702 546
GPM 80 18 43 47 115
RM&T 204 43 35 134 93
Chemicals 240 48 31 136 107
Corporate
and Other 67 18 (1) 41 19
- ------------------------------------------------------------------
$1,620 353 331 1,060 880
==================================================================
United States $ 839 188 189 532 532
Foreign 781 165 142 528 348
- ------------------------------------------------------------------
$1,620 353 331 1,060 880
==================================================================
The company's improved operating results and the Kenai LNG tax
settlement have enhanced Phillips' financial flexibility. As a
result, in April the company announced a 16 percent increase in
its 1996 capital budget, from $1.4 billion to $1.62 billion. The
boost in spending plans is 11 percent above actual 1995
expenditures, and reaches its highest level since the mid-1980s.
The E&P capital spending program received the largest increase--
from $855 million to $1.029 billion. The increase supports the
company's worldwide exploration program, development drilling in
North America, and the purchase of a subsidiary of Parker and
Parsley Petroleum Company, which held a 22.5 percent interest in
permit 91-13 that contains part of the Bayu-Undan field, offshore
Australia and Indonesia in the Timor Sea.
Capital spending plans for RM&T increased to $204 million from
$175 million, with 58 percent and 42 percent allocated to
refining and marketing, respectively. Marketing's capital
spending plans are over three times that of its actual 1995
expenditures. While capital spending for refining modernization
projects continues, the increase accelerates plans to expand the
26
<PAGE>
number of company-operated retail outlets in the United States
from 300 to 500 over the next several years. The company is
utilizing a master leasing program to partially support this
planned retail marketing expansion.
The company began its planned expansion of retail marketing
during the first quarter of 1996. During the first nine months
of 1996, the company purchased 24 retail outlets, the majority of
which are in Albuquerque, New Mexico, and the Salt Lake City,
Utah, region. In the third quarter, construction began on 12 new
stations and five that will be razed and rebuilt using the
company's new larger Kicks service station-convenience store
design. In the fourth quarter, construction is scheduled to
begin on 11 new outlets, and seven existing stations will be
razed and rebuilt. Phillips is currently conducting an asset
study to evaluate the profitability of certain of its retail
outlets to determine, on an individual basis, whether the company
will continue to operate, close or sell the outlets.
Spending plans for Chemicals and GPM are unchanged at
$240 million and $80 million, respectively.
Phillips owns a 50 percent interest in Sweeny Olefins Limited
Partnership (SOLP), which owns and operates an ethylene plant
located adjacent to the company's Sweeny, Texas, refinery. Late
in 1995, First Olefins Limited Partnership (FOLP), a general
partner of SOLP, filed suit in Delaware against the company and
its subsidiary, American Olefins, Inc., the managing general
partner of SOLP, seeking an injunction to halt construction on a
debottlenecking project at SOLP. The trial court denied FOLP's
application by opinion dated March 1, 1996. On April 2, 1996,
the Delaware Supreme Court denied FOLP's application for
interlocutory appeal, thus effectively foreclosing the effort to
halt construction. Construction has been substantially completed
and the facility returned to operation during the third quarter.
The lawsuit remains on file and may result in a trial of the
issues at some future date. It is believed that the ultimate
resolution of this litigation will not affect the operations of
SOLP. The debottlenecking project will raise the nameplate
capacity of the unit from 1.5 billion pounds per year to
2 billion pounds per year.
Funds for the 1996 capital budget will be provided by cash
generated from continuing operations, and from financing.
27
<PAGE>
J-Block Update
The gas reserves in blocks 30/7a and 30/12a (J-Block) offshore
the United Kingdom are dedicated to a single gas purchaser, Enron
Europe Limited (EEL). EEL has advised that its present estimate
of future total daily nominations for delivery is zero through
September 1999.
The J-Block owners are currently installing gas injection
facilities, which will allow for the production of liquids while
the natural gas production is reinjected for later delivery. The
U.K. government has approved these plans and reinjection is
planned to commence in April 1997.
The J-Block owners also own the rights to the reserves in a block
(block 30/6b) immediately adjacent to J-Block, which are in
communication with J-Block reserves but not dedicated under the
above contracts. The J-Block owners are continuing to
investigate transportation, processing and sales of natural gas
from the adjoining block. In order to maximize the value of its
J-Block infrastructure, the company has also initiated and is
continuing an active drilling program to explore and appraise the
reserves in blocks 30/2c and 30/13.
On March 29, 1996, the J-Block owners filed legal proceedings in
the English High Court in London seeking a declaration that EEL
as buyer under the J-Block gas sales agreements cannot refuse to
agree to a commissioning date for the J-Block facilities on the
basis of a decline in natural gas prices in the United Kingdom,
and cannot thereby delay commencement of its take-or-pay
obligations under the sales agreements. On May 8, 1996, the
English High Court ruled in favor of the J-Block owners, finding
that EEL could not refuse by virtue of the decline in natural gas
prices to agree to commissioning of the J-Block facilities.
Enron appealed that judgment. On October 10, 1996, the English
Court of Appeal reversed the May 8 decision, concluding that the
date for commissioning the J-Block facilities could be delayed by
EEL until the contract fall-back date of September 25, 1996. The
J-Block owners have requested the House of Lords to hear an
appeal of that decision.
EEL has continued to refuse to take delivery of J-Block
commissioning gas on and after the contract fall-back date of
September 25, 1996. The J-Block owners have, therefore, amended
their claims in the English High Court to enforce EEL's
obligation to accept J-Block commissioning gas on and after
September 25, as well as to seek damages resulting from EEL's
breach. Trial of this amended claim by the J-Block owners began
in the English High Court on October 28, 1996, together with the
related claim filed in 1995 by the owners of the Central Area
28
<PAGE>
Transmission System (CATS), but was immediately recessed for a
two-week period. The CATS claim against EEL's wholly owned
subsidiary Teesside Gas Transportation Limited (TGTL) is for
breach of TGTL's obligation to pay the capacity reservation fee
under the Capacity Reservation and Transportation Agreement
(CRTA) related to the transportation of J-Block gas to EEL's
onshore processing facilities.
Soon after the J-Block owners filed their commissioning-date
lawsuit in London, on March 29, 1996, Enron Corp. (Enron), EEL,
and TGTL filed a lawsuit in district court in Harris County,
Texas. Enron asserted that the CRTA between TGTL and the owners
of CATS had terminated as a result of breaches of the agreement
by the CATS owners. It further asserted that the J-Block
transportation agreements between TGTL and the J-Block owners,
and the J-Block gas sales agreements had likewise terminated, and
that Enron was discharged from its guarantee obligations under
those agreements. On June 26, 1996, the English High Court
granted Phillips and the other J-Block owners injunctions
prohibiting the Enron companies from proceeding with their Texas
lawsuit. The Court concluded that Enron's lawsuit in Texas
raised issues that should have properly been raised in the
English Court or were essentially the same as issues already in
litigation in the English Court. Enron has appealed this
judgment. However, the U.S. District Court sitting in Houston
has recognized the English High Court injunction and
administratively closed Enron's Texas case. Enron, EEL and TGTL
continue to assert that the CRTA, J-Block transportation
agreements, J-Block gas sales agreements and parent company
guarantees are terminated.
Further developments in this litigation are anticipated, and the
course of events and range of possible outcomes cannot be
predicted at this time. The company intends to vigorously assert
its interests in each of the pending matters.
The J-Block production, processing and transportation facilities,
located in block 30/7a of the U.K. North Sea, were completed on
schedule and below budget in mid-February and are available for
production and delivery of gas. The J-Block and block 30/6b are
operated by Phillips Petroleum Company United Kingdom Limited,
which has 36.5 percent interest. The company owns 32.5 percent
and 35 percent interests in blocks 30/2c and 30/13, respectively.
29
<PAGE>
Contingencies
Legal and Tax Matters
The company has a number of issues outstanding with the IRS
related to tax years 1979 through 1992 that can proceed toward
final settlement as a result of resolving the Kenai LNG tax case.
Although it is too early to determine the final financial effects
of resolving these years, a favorable outcome would have a
positive effect on net income and cash flow while an unfavorable
one would not impact the company's net income or cash position.
While total resolution may require a number of years, the
earliest years are expected to be resolved in the near term.
Phillips accrues for contingencies when a loss is probable and
the amounts can be reasonably estimated. Based on currently
available information, the company believes that it is remote
that future costs related to known contingent liability exposures
will exceed current accruals by an amount that would have a
material adverse impact on the company's financial statements.
Environmental
Most aspects of the businesses in which the company engages are
subject to various federal, state, local and foreign
environmental laws and regulations. Similar to other companies
in the petroleum and chemical industries, the company incurs
costs for preventive and corrective actions at facilities and
waste disposal sites.
Phillips may be obligated to take remedial action as the result
of the enactment of laws, such as the federal Superfund law, the
issuance of new regulations, or as a result of leaks and spills.
In addition, an obligation may arise when a facility is closed or
sold. Most of the expenditures to fulfill these obligations
relate to facilities and sites where past operations followed
practices and procedures that were considered appropriate under
regulations, if any, existing at the time, but may now require
investigatory or remedial work to adequately protect the
environment or address new regulatory requirements.
At year-end 1995, Phillips reported 48 sites where it had
information indicating that it might have been identified as a
Potentially Responsible Party (PRP). Since then, seven of these
sites have been resolved through consent decrees, deposit into
trust funds or otherwise. Six sites were added during the nine-
month period. Of the 47 sites remaining at September 30, 1996,
the company believes it has a legal defense or its records
indicate no involvement for 16 sites. At seven other sites,
30
<PAGE>
present information indicates that it is probable that the
company's exposure is less than $100,000 per site. At nine
sites, Phillips has had no communication or activity with
government agencies or other PRPs in more than two years. Of the
15 remaining sites, the company has provided for any probable
costs that can be reasonably estimated.
Phillips does not consider the number of sites at which it has
been designated potentially responsible by state or federal
agencies as a relevant measure of liability. Some companies may
be involved in few sites but have much larger liabilities than
companies involved in many more sites. Although liability of
those potentially responsible is generally joint and several for
federal sites and frequently so for state sites, the company is
usually but one of many companies cited at a particular site. It
has, to date, been successful in sharing cleanup costs with other
financially sound companies. Many of the sites at which the
company is potentially responsible are still under investigation
by the Environmental Protection Agency (EPA) or the state
agencies concerned. Prior to actual cleanup, those potentially
responsible normally assess site conditions, apportion
responsibility and determine the appropriate remediation. In
some instances, Phillips may have no liability or attain a
settlement of liability. Actual cleanup costs generally occur
after the parties obtain EPA or equivalent state agency approval.
At September 30, 1996, accruals of $9 million had been made for
the company's unresolved PRP sites. In addition, the company has
accrued $89 million for other planned remediation activities,
including resolved state, PRP, and other federal sites, as well
as sites where no claims have been asserted, and $6 million for
other environmental contingent liabilities, for total
environmental accruals of $104 million. No one site represents
more than 10 percent of the total.
After an assessment of environmental exposures for cleanup and
other costs, the company makes accruals on an undiscounted basis
for planned investigation and remediation activities for sites
where it is probable that future costs will be incurred and these
costs can be reasonably estimated. These accruals have not been
reduced for possible insurance recoveries. However, where
applicable, probable insurance recoveries and state
reimbursements have been accrued as receivables. Based on
currently available information, the company believes that it is
remote that future costs related to known contingent liability
exposures will exceed current accruals by an amount that would
have a material adverse impact on the company's financial
statements.
31
<PAGE>
OUTLOOK
During the third quarter, crude oil prices strengthened to their
highest level since the Gulf War and natural gas prices remained
strong, compared with the same period in 1995. With an unstable
Middle East situation, and lower industry inventory levels, crude
prices during the fourth quarter of 1996 are expected to remain
well above prices experienced during the same period in 1995.
Natural gas prices are also expected to remain higher than last
year due to seasonal demand, and lower industry underground
storage levels.
Phillips is continuing discussions with its co-venturer to obtain
the co-venturer's working interest in the Sunfish prospect in the
South Cook Inlet of Alaska. The company is unable to predict the
results of these discussions, but, in the event discussions are
successful, the next appraisal well is now planned for spring of
1997, after ice breakup in the South Cook Inlet.
Oil production from the Point Arguello field, offshore
California, continued to decline during the third quarter due to
increasing water production and maintenance related downtime.
Third quarter production was approximately 6,800 net barrels per
day, which was lower than previous forecasts, compared with
approximately 7,900 during the second quarter. Phillips and its
co-venturers continue to pursue with the Minerals Management
Service the unitization of the field, which, if approved, will
result in a reduction in operating expenses. Work will begin in
1997 on developing an overall plan of abandonment for the field.
During the fourth quarter of 1996, the company will be working
with the operator reviewing Point Arguello reservoir performance
to determine if an additional charge for impairment may be
necessary.
The company and its co-venturers recently announced the results
of the Monazite #1 discovery well in the Gulf of Mexico subsalt
trend. Although all test intervals flowed oil, data obtained
were largely inconclusive due to various mechanical problems
encountered during testing. The well was plugged and abandoned
due to wellbore conditions. Phillips and the co-venturers plan
to obtain new seismic data and utilize information obtained from
the well for possible future appraisal drilling which is required
to determine the commerciality of the prospect.
The company is expanding its Ryton production with a
debottlenecking project under way at the company's Ryton facility
in Borger, Texas. Ryton is an engineering plastic known for its
heat- and chemical- resistance, with applications including
electronic components, under-the-hood automotive parts, and fiber
applications. The project is expected to increase Ryton capacity
32
<PAGE>
by 40 percent, from 7,000 to 9,800 metric tons (15.4 million to
21.6 million pounds) per year, and is scheduled for completion by
year-end 1997.
In addition to the Ryton debottlenecking project, the company
plans to construct a Ryton compounding facility near Antwerp,
Belgium, with scheduled completion by second quarter 1997. This
plant will compound Ryton production from the company's Borger
facility. Compounding is the combining of Ryton with glass
fibers or mineral fillers to tailor the engineering plastic to
customer needs. Initial capacity at the Antwerp facility is
expected to be about 8.4 million pounds a year, with expansion
capability up to approximately 30 million pounds a year.
Previously idled assets are being upgraded at the company's
Sweeny, Texas, facility to increase ethylene production by
400 million pounds per year. The assets are now expected to be
restarted and producing in the second quarter of 1997.
Phillips has recently agreed to license its proprietary loop
reactor technology, used in the manufacture of polyethylene, to a
project in North America. This is the first time in 20 years the
company has agreed to license its polyethylene technology in the
United States, marking a major shift in Phillips' U.S. licensing
strategy. The change in strategy will enable Phillips to
increase licensing income by leveraging its technology in the
growing U.S. polyethylene market. Currently, the Phillips
process accounts for approximately 50 percent of the total U.S.
polyethylene production, and 35 percent of worldwide production.
High-density polyethylene, a widely used plastic, is found in a
variety of products including trash bags, milk jugs, and toys.
In an effort to reduce operating costs and increase the
reliability of steam and electrical supplies, Phillips is
pursuing four power co-generation projects at its Borger, Sweeny,
HCC and Puerto Rico Core facilities. Co-generation is the
simultaneous production of electricity and steam from a single
process, which requires less fuel than separate production
processes. Construction began in September on a co-generation
facility at Sweeny with completion expected in early 1998. Also
during September, Phillips entered into definitive agreements
with a third party developer to construct a co-generation
facility adjacent to the company's HCC facility. Construction at
HCC is expected to begin by year-end, with completion targeted
for third quarter of 1998. Phillips does not have an equity
interest in either of the co-generation facilities.
33
<PAGE>
PART II. OTHER INFORMATION
Item 6. EXHIBITS AND REPORTS ON FORM 8-K
Exhibits
- --------
12 Computation of Ratio of Earnings to Fixed Charges
27 Financial Data Schedule
Reports on Form 8-K
- -------------------
During the three months ended September 30, 1996, the company did
not file any reports on Form 8-K.
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.
PHILLIPS PETROLEUM COMPANY
/s/ L. F. Francis
--------------------------
L. F. Francis
Controller
(Chief Accounting and Duly
Authorized Officer)
November 13, 1996
34
<PAGE>
Exhibit 12
PHILLIPS PETROLEUM COMPANY AND CONSOLIDATED SUBSIDIARIES
TOTAL ENTERPRISE
Computation of Ratio of Earnings to Fixed Charges
Millions of Dollars
------------------------
Nine Months Ended
September 30
------------------------
1996 1995
------------------------
(Unaudited)
Earnings Available for Fixed Charges
Income before income taxes $1,759 830
Distributions less than equity in earnings
of less-than-fifty-percent-owned companies 19 1
Fixed charges, excluding capitalized
interest and the portion of the
preferred dividend requirements of a
subsidiary not previously deducted
from income* 253 270
- ----------------------------------------------------------------------------
$2,031 1,101
============================================================================
Fixed Charges
Interest and expense on indebtedness,
excluding capitalized interest $ 186 214
Capitalized interest 25 21
Preferred dividend requirements of
a subsidiary and a capital trust 47 56
One-third of rental expense, net of
subleasing income, for operating leases 27 24
- ----------------------------------------------------------------------------
$ 285 315
============================================================================
Ratio of Earnings to Fixed Charges 7.1 3.5
- ----------------------------------------------------------------------------
*Includes amortization of capitalized interest totaling approximately
$7 million and $8 million in 1996 and 1995, respectively.
Earnings available for fixed charges include, if any, the company's equity
in losses of companies owned less than fifty percent and having debt for
which the company is contingently liable. Fixed charges include the
company's proportionate share, if any, of interest relating to the
contingent debt.
In 1990 and 1988, respectively, the company guaranteed a $400 million bank
loan and $250 million of notes payable for the Long-Term Stock Savings Plan
(LTSSP), an employee benefit plan. In 1994, the notes payable were
refinanced with a $131 million term loan, and the $400 million loan was
amended in 1994, and again in 1995. Consolidated interest expense included
a minimal amount of interest related to LTSSP borrowings for the first nine
months of 1996 and 1995.
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
This schedule contains summary financial information extracted from the
consolidated balance sheet of Phillips Petroleum Company as of September 30,
1996, and the related consolidated statement of income for the nine-month
period ended September 30, 1996, and is qualified in its entirety by
reference to such financial statements.
</LEGEND>
<MULTIPLIER> 1,000,000
<S> <C>
<PERIOD-TYPE> 9-MOS
<FISCAL-YEAR-END> DEC-31-1996
<PERIOD-END> SEP-30-1996
<CASH> 346
<SECURITIES> 0
<RECEIVABLES> 1,721
<ALLOWANCES> 20
<INVENTORY> 504
<CURRENT-ASSETS> 2,764
<PP&E> 19,847
<DEPRECIATION> 10,998
<TOTAL-ASSETS> 12,929
<CURRENT-LIABILITIES> 2,499
<BONDS> 2,855
300
0
<COMMON> 626
<OTHER-SE> 3,476
<TOTAL-LIABILITY-AND-EQUITY> 12,929
<SALES> 11,384
<TOTAL-REVENUES> 11,474
<CGS> 9,489<F1>
<TOTAL-COSTS> 9,690<F2>
<OTHER-EXPENSES> 32<F3>
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 171
<INCOME-PRETAX> 1,759
<INCOME-TAX> 656
<INCOME-CONTINUING> 1,103
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 1,103
<EPS-PRIMARY> 4.20
<EPS-DILUTED> 4.20
<FN>
<F1> Purchased crude oil and products + Production and operating expenses +
Exploration expenses + Depreciation, depletion and amortization.
<F2> CGS + Taxes other than income taxes.
<F3> Preferred dividend requirements of subsidiary and capital trust.
</FN>
</TABLE>
