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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 SEPTEMBER 30, 1997
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
FOR THE TRANSITION PERIOD FROM ___________ TO ___________
COMMISSION FILE NUMBER 1-11566
MARKWEST HYDROCARBON, INC.
(EXACT NAME OF REGISTRANT AS SPECIFIED IN ITS CHARTER)
DELAWARE 84-1352233
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
155 INVERNESS DRIVE WEST, SUITE 200, ENGLEWOOD, CO 80112-5004
(Address of principal executive offices)
REGISTRANT'S TELEPHONE NUMBER, INCLUDING AREA CODE: 303-290-8700
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 8,479,101 shares of common stock, $.01 per share par value,
outstanding as of November 10, 1997.
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PART I - FINANCIAL INFORMATION Page
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Item 1. Consolidated Financial Statements
Consolidated Balance Sheet at September 30, 1997 and
December 31, 1996............................................. 1
Consolidated Statement of Operations for the Three and
Nine Months Ended September 30, 1997 and 1996................. 2
Consolidated Statement of Cash Flows for the Three and Nine
Months Ended September 30, 1997 and 1996...................... 3
Notes to the Consolidated Financial Statements................. 4
Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations.......................................... 6
PART II - OTHER INFORMATION
Item 1. Legal Proceedings................................................. 13
Item 6. Exhibits and Reports on Form 8-K.................................. 13
SIGNATURES................................................................. 14
PART I - FINANCIAL INFORMATION
Item 1. Consolidated Financial Statements
MARKWEST HYDROCARBON, INC.
CONSOLIDATED BALANCE SHEET
(000S, EXCEPT SHARE DATA)
September 30,
1997 December 31,
ASSETS (Unaudited) 1996
--------------------------------
Current assets:
Cash and cash equivalents.............................................. $ -- $ 4,401
Receivables............................................................ 8,749 9,755
Inventories............................................................ 7,419 5,632
Prepaid feedstock...................................................... 3,098 1,831
Other assets........................................................... 498 458
----------- ----------
Total current assets................................................ 19,764 22,077
Property and equipment:
Gas processing, gathering, storage and marketing equipment............. 48,027 46,416
Oil and gas properties and equipment................................... 7,205 3,731
Land, buildings and other equipment.................................... 9,250 4,478
Construction in progress............................................... 13,044 5,831
----------- ----------
77,526 60,456
Less: accumulated depreciation, depletion and amortization............. (14,619) (12,316)
----------- ----------
Total property and equipment, net................................... 62,907 48,140
Intangible assets, net of accumulated amortization of $276
and $315 respectively.................................................. 500 380
Note receivable and other assets........................................... 9,938 7,657
----------- ----------
Total assets............................................................... $ 93,109 $ 78,254
=========== ==========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Trade accounts payable................................................. $ 1,937 $ 5,382
Accrued liabilities.................................................... 4,625 4,643
Current portion of long-term debt...................................... 156 156
----------- ----------
Total current liabilities........................................... 6,718 10,181
Long-term debt............................................................. 22,969 11,257
Deferred income taxes...................................................... 5,175 3,977
Minority interest.......................................................... 9,113 9,175
Stockholders' equity:
Preferred stock, par value $0.01, 5,000,000 shares authorized, 0
shares issued and outstanding......................................... -- --
Common stock, par value $0.01, 20,000,000 shares authorized, 8,510,173
shares issued, 8,485,268 shares outstanding........................... 85 85
Additional paid-in capital............................................. 42,582 42,237
Retained earnings...................................................... 6,792 1,342
Treasury stock......................................................... (325) --
----------- ----------
Total stockholders' equity.................................. 49,134 43,664
----------- ----------
Total liabilities and stockholders' equity................................. $ 93,109 $ 78,254
=========== ==========
The accompanying notes are an integral part of these financial statements.
1
MARKWEST HYDROCARBON, INC.
CONSOLIDATED STATEMENT OF OPERATIONS
(UNAUDITED)
(000S, EXCEPT PER SHARE DATA)
For the three months ended For the nine months ended
September 30, September 30,
1997 1996 1997 1996
--------------- ---------------- ---------------- --------------
Revenues:
Appalachia plant revenue...................... $ 9,560 $10,543 $39,847 $28,876
Terminal and marketing revenue................ 2,650 3,976 10,930 13,798
Michigan transportation and treating revenue.. 2,103 -- 3,344 --
Oil and gas revenue........................... 425 74 695 237
Interest income............................... 65 26 406 69
Other income.................................. 210 342 508 643
--------------- ---------------- ---------------- --------------
Total revenue........................... 15,013 14,961 55,730 43,623
--------------- ---------------- ---------------- --------------
Costs and expenses:
Appalachia feedstock purchases................ 4,664 5,882 19,225 14,420
Terminal and marketing purchases.............. 2,393 3,372 10,879 12,055
Michigan feedstock purchases.................. 1,036 -- 1,036 --
Operating expenses............................ 2,849 1,365 7,605 4,216
General and administrative expenses........... 1,636 1,238 5,467 3,507
Depreciation, depletion and amortization...... 825 783 2,408 2,111
Interest expense, net of capitalized interest. 395 378 726 887
--------------- ---------------- ---------------- --------------
Total costs and expenses................ 13,798 13,018 47,346 37,196
--------------- ---------------- ---------------- --------------
Income before minority interest and income taxes.. 1,215 1,943 8,384 6,427
Minority interest in net loss of subsidiary....... 30 -- 252 --
--------------- ---------------- ---------------- --------------
Income before income taxes........................ 1,245 1,943 8,636 6,427
Provision for income taxes:
Current....................................... (544) -- 2,001 --
Deferred...................................... 922 -- 1,185 --
--------------- ---------------- ---------------- --------------
378 -- 3,186 --
--------------- ---------------- ---------------- --------------
Net income........................................ $ 867 $ 1,943 $ 5,450 $ 6,427
=============== ================ ================ ==============
Earnings per share of common stock (A)............ $0.10 $0.15 $0.64 $0.50
=============== ================ ================ ==============
Weighted average number of outstanding shares of
common stock (A)................................. 8,485 7,908 8,485 7,908
=============== ================ ================ ==============
Pro forma net income (Note 4)
Historical income before income taxes......... N/A $ 1,943 N/A $ 6,427
Provision for income taxes.................... N/A 738 N/A 2,442
--------------- --------------
Net income.................................... N/A $ 1,205 N/A $ 3,985
================ ==============
(A) Pro forma for 1996 (see Note 4).
The accompanying notes are an integral part of these financial statements.
2
MARKWEST HYDROCARBON, INC.
CONSOLIDATED STATEMENT OF CASH FLOWS
(UNAUDITED)
(000S)
For the three months For the nine months
ended September 30, ended September 30,
1997 1996 1997 1996
-------------- -------------- -------------- -----------
Reconciliation of net income to net cash provided by
operating activities:
Net income............................................ $ 867 $ 1,943 $ 5,450 $ 6,427
Add income items that do not affect working capital:
Depreciation, depletion and amortization........... 825 783 2,408 2,111
Deferred income taxes.............................. 922 -- 1,185 --
Gain on sale of assets............................. -- -- (75) --
-------------- -------------- -------------- ---------
2,614 2,726 8,968 8,538
-------------- -------------- -------------- ---------
Adjustments to working capital:
(Increase) decrease in accounts receivable........ (187) (1,432) 1,006 3,686
(Increase) in inventories......................... (4,499) (3,443) (1,787) (4,174)
(Increase) in prepaid feedstock and other assets.. (1,447) (1,323) (1,307) (1,735)
(Decrease) increase in accounts payable and
accrued liabilities.............................. (958) 205 (4,523) 1,128
-------------- -------------- -------------- ---------
(7,091) (5,993) (6,611) (1,095)
-------------- -------------- -------------- ---------
Net cash (used in) provided by operating
activities.................................... (4,477) (3,267) 2,357 7,443
Cash flows from investing activities:
Capital expenditures.............................. (8,450) (960) (16,170) (2,902)
Increase in intangible assets, note receivable
and other assets................................. (513) (1,748) (2,401) (2,336)
Other............................................. 206 -- 62 --
-------------- -------------- -------------- ---------
Net cash used in investing activities......... (8,757) (2,708) (18,509) (5,238)
Cash flows from financing activities:
Proceeds from long-term debt...................... 13,000 8,790 22,920 13,640
Repayment of long-term debt....................... (57) -- (11,207) (10,000)
Partners' distributions........................... -- (973) -- (4,192)
Other............................................. 105 (158) 38 (158)
-------------- -------------- -------------- ---------
Net cash provided by (used in) financing
activities................................... 13,048 7,659 11,751 (710)
-------------- -------------- -------------- ---------
Net (decrease) increase in cash and cash equivalents....... (186) 1,684 (4,401) 1,495
Cash and cash equivalents at beginning of period........... 186 572 4,401 761
-------------- -------------- -------------- ---------
Cash and cash equivalents at end of period................. $ -- $ 2,256 $ -- $ 2,256
============== ============== ============== =========
The accompanying notes are an integral part of these financial statements.
3
NOTE 1. GENERAL
The consolidated financial statements include the accounts of MarkWest
Hydrocarbon, Inc. ("MarkWest" or the "Company") and its wholly-owned
subsidiaries, MarkWest Resources, Inc. ("Resources") and MarkWest Michigan, Inc.
("Michigan"). All significant intercompany accounts and transactions have been
eliminated in consolidation.
The unaudited financial statements presented herein have been prepared in
accordance with the instructions to Form 10-Q and do not include all the
information and note disclosures required by generally accepted accounting
principles for complete financial statements. The interim consolidated financial
statements should be read in conjunction with the Consolidated Financial
Statements and Notes thereto for the year ended December 31, 1996 included in
the Company's Form 10-K, as filed with the Securities and Exchange Commission.
In the opinion of management, all adjustments necessary for a fair statement of
the results for the unaudited interim periods have been made. These adjustments
consist only of normal recurring adjustments.
The effective corporate tax rate for interim periods is based on the estimated
annual effective corporate tax rate, excluding certain nonrecurring or unusual
events. The effective tax rate varies from statutory rates due primarily to tax
credits and intangible development costs.
Certain prior year amounts have been reclassified to conform to the 1997
presentation.
NOTE 2. REORGANIZATION
The Company was incorporated in June 1996 to act as the successor to MarkWest
Hydrocarbon Partners, Ltd. (the "Partnership"). Effective October 7, 1996, the
Partnership reorganized (the "Reorganization") and the existing general and
limited partners exchanged 100% of their interests in the Partnership for
5,725,000 common shares of the Company. An additional 2,400,000 shares of
common stock were offered for public sale, totaling 8,125,000 shares outstanding
as of October 15, 1996. The over-allotment of 360,000 shares was also exercised
during October, resulting in a total of 8,485,000 shares outstanding at October
31, 1996. This transaction was a reorganization of entities under common
control, and accordingly, it was accounted for at historical cost.
NOTE 3. SIGNIFICANT BUSINESS ACQUISITIONS
Prior to July 1, 1996, the Partnership owned 49% of MarkWest Coalseam
Development Company LLC (formerly MarkWest Coalseam Joint Venture) ("Coalseam"),
a natural gas development venture, and MW Gathering LLC ("Gathering"), a natural
gas gathering venture. Effective July 1, 1996, Gathering was merged into
Coalseam. Simultaneously, the Partnership formed MarkWest Resources Inc.
("Resources"), and Coalseam distributed 49% of its assets to Resources and 51%
to MAK-J Energy Partners, Ltd. (formerly MarkWest Energy Partners, Ltd.), a
partnership whose general partner is a corporation owned and controlled by the
President of the Company. The consolidated financial statements reflect
Resources' 49% proportionate share of the underlying oil and gas assets,
liabilities, revenues and expenses.
Effective May 6, 1996, the Partnership acquired the right to earn up to a 60%
interest for $16.8 million in a newly formed venture, West Shore Processing, LLC
("West Shore"). The most significant asset of West Shore is Basin Pipeline LLC,
which was contributed by the Partnership's venture partner, Michigan Energy
Company, LLC. The West Shore agreement is structured so that the Company's
ownership interest increases as capital expenditures for the benefit of West
Shore are made by the Company. The Company completed its earn-in of a 60%
interest in the venture in the second quarter of 1997, through the funding of
capital expenditures totaling approximately $16.8 million.
NOTE 4. PRO FORMA INFORMATION
Prior to the Reorganization, the Company was organized as a partnership and
consequently, was not subject to income tax. A pro forma provision for income
taxes and pro forma net income for the three and nine months ended
4
September 30, 1996 have been presented for purposes of comparability as if the
Company had been a taxable entity. In addition, the Company's historical capital
structure is not indicative of its current structure and, accordingly,
historical net income per common share has not been presented. Pro forma net
income per common share for the three and nine months ended September 30, 1996
has been computed using the weighted average number of common and common
equivalent shares outstanding for the fourth quarter of 1996 following the
Company's initial public offering.
NOTE 5. LONG TERM DEBT
Effective June 20, 1997, the Company replaced its existing financing agreements
with a new credit facility (the "credit facility") with the Bank of Montreal, as
agent, NationsBank and Colorado National Bank. The credit facility allows the
Company to borrow up to $55 million pursuant to a revolving loan commitment.
The revolving loan commitment converts to a reducing loan commitment on May 31,
1999. The reducing loan commitment reduces ratably on a quarterly basis to zero
by May 31, 2003.
Interest rates are based on either the agent bank's prime rate plus 1% or the
London Interbank Offered Rate (LIBOR), plus an applicable margin of between 50
and 150 basis points, based upon the Company's debt to capitalization ratio. As
of September 30, 1997, approximately $22.9 million was outstanding. Of the
total debt outstanding, $18.9 million bears interest at 6.125% and $4.0 million
bears interest at 6.185%.
The debt is secured by a first mortgage on the Company's major assets. The loan
agreement restricts certain activities and requires the maintenance of certain
financial ratios and other conditions.
As a direct result of entering into a new credit facility, the Company wrote off
previously deferred financing costs associated with the previous credit facility
of approximately $235,000 in the second quarter of 1997.
NOTE 6. RECENT ACCOUNTING PRONOUNCEMENTS
In February 1997, the Financial Accounting Standards Board issued Statement No.
128 ("SFAS 128"), "Earnings Per Share". This Statement is effective for
financial statements issued for periods ending after December 15, 1997. Earlier
adoption is not permitted. SFAS 128 requires dual presentation of basic and
diluted EPS for entities with complex capital structures. The impact of
adopting SFAS 128 will not have a material effect on the Company's earnings per
share calculation.
5
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
Management's Discussion and Analysis of Financial Condition and Results of
Operations includes forward-looking statements (within the meaning of Section
21E of the Securities Exchange Act of 1934) reflecting the expectations, plans
and objectives of management for operations of the Company. Such statements are
based on current expectations that involve numerous risks and uncertainties.
Assumptions relating to these expectations involve judgments with respect to,
among other things, future drilling success in the vicinity of the company's
Michigan operations and future economic, competitive and market conditions,
including the price of propane, other natural gas liquids and natural gas, all
of which are difficult or impossible to predict accurately and many of which are
beyond the control of the Company. Accordingly, there can be no assurance that
the forward-looking statements included in the Form 10-Q will prove to be
accurate. Inclusion of such information should not be regarded as a
representation by the Company or any other person that the expectations, plans
and objectives of the Company will be realized.
GENERAL
MarkWest Hydrocarbon, Inc. ("MarkWest" or the "Company") provides compression,
gathering, treatment, processing and natural gas liquids ("NGL") extraction
services to natural gas producers and pipeline companies and fractionates NGLs
into marketable products for sale to third parties. The Company also purchases,
stores and markets natural gas and NGLs. Historically, the majority of the
Company's operating income has been derived from gas processing, NGL
fractionation and NGL sales in its Appalachia core area. In the near future, an
increasing portion of the Company's revenues is expected to be derived from
transportation and treating revenues from the Company's Michigan operations, as
production volumes and throughput in Michigan are expected to grow significantly
beginning in the second half of 1998 (see further discussion below under
"Michigan"). In its Appalachia core area, NGL prices and the volume of liquids
extracted, fractionated, and sold are the primary determinants of revenues.
Prices of NGLs typically do not vary directly with natural gas prices, but more
closely follow the prices of crude oil. In addition to sales of NGLs processed
by the Company, the Company generates income from the purchase and resale of
NGLs as part of its terminal and marketing activities, and provides marketing
activities in support of its company-owned facilities and production. The
Company also currently operates two propane terminals.
A significant portion of the Company's revenues are derived from the sale of
natural gas liquids, particularly propane. The strongest demand for propane and
the highest propane sales margins generally occur during the winter heating
season. As a result, the Company realizes the greatest proportion of its annual
income during the first and fourth quarters of the year.
APPALACHIA
As previously announced, in April 1997, the Federal Energy Regulatory Commission
approved Columbia Gas Transmission Corporation's rate case. As part of this
rate case, MarkWest and Columbia signed a letter agreement ("the Agreement")
which will allow the Company to acquire and operate two additional facilities
from Columbia, the Boldman and Cobb NGL Extraction plants. Boldman is currently
owned by MarkWest and leased to and operated by Columbia. Cobb will be acquired
and operated by MarkWest. Implementation of the Agreement began during the
second quarter. Definitive agreements are in progress, and MarkWest began
contracting for processing services directly with producers in June 1997.
Upon completion, the financial impact of this transaction for MarkWest will be
that the term of NGLs committed to Siloam from these facilities will be extended
from 2003 to 2009, and the arrangement will provide the opportunity to target
potential NGL production increases at these facilities. Studies have begun to
evaluate either upgrading or replacing the Cobb facility.
NGL production at MarkWest's Siloam Plant in Kentucky remained about constant at
26.4 million gallons for the third quarter, compared to the same quarter in
1996. Sales volumes of NGLs for the third quarter decreased 12 percent to
20.9 million gallons, compared to the same period in 1996. In 1996, a cold
winter started early in the
6
heating season, increasing demand and prices for propane. Several other factors
influenced third quarter 1997 results. Lower sales volumes were offset by
increased processing fee revenue. The impact of lower propane prices was more
than offset by favorably priced advanced purchases of natural gas. Third quarter
results also reflect lower terminal sales volumes.
MICHIGAN
Gas volumes through MarkWest's 60-percent-owned sour gas pipeline and plant in
western Michigan more than tripled to 12.8 million cubic feet per day (mmcfd) in
the third quarter. This volume, increased through another company's gas well
completed late in the second quarter of 1997, is up from the 3.9 mmcfd reported
in 1996. A third company announced two new discoveries in the third quarter of
1997, with a combined flow rate of 15 mmcfd, and announced plans to drill four
more prospects in 1998. These well results, combined with a pending application
with the Michigan Public Service Commission to extend the pipeline, are causing
increased drilling activity and acreage acquisitions in the area. The Company's
new natural gas liquids plant is expected to start up operations in the fourth
quarter of 1997, and will allow the Company to sell propane and other liquids
directly into higher-priced markets.
In addition, two 3-D seismic programs were completed this year with drilling
expected to begin in the fourth quarter. MarkWest has a 17.5 percent working
interest in the first program, which covers 27 square miles. The second program
covers 50 square miles. Drilling success resulting from these programs could
add significantly to pipeline and NGL throughput in 1998.
MarkWest plans to extend the pipeline and connect it to these wells, other shut-
in wells and future wells to be drilled in 1998. Pipeline route selection and
permitting activities for this extension are underway. As a result of these
developments, the Company commenced detailed studies to expand the capacity in
the pipeline and NGL plant to 50 mmcfd from 35 mmcfd.
OUTLOOK
It is expected that the results from the fourth quarter of 1997 and the first
quarter of 1998 will reflect more normal price levels when compared to the near
record-high price levels experienced in the fourth quarter of 1996 and the first
quarter of 1997. Propane prices rose dramatically in the fourth quarter of 1996
due to an early cold start to the winter and a Mexican plant explosion, which
had a detrimental impact on imported propane volumes into the United States.
The Company was able to extend the benefit from these high price levels by
entering into various hedge contracts which positively affected the Company's
results in the first quarter of 1997.
As of the end of the third quarter of 1997, the Company has entered into various
hedge contracts for the upcoming fourth quarter which lock in natural gas prices
in Appalachia on 65% of the Company's expected purchases. These hedge contracts
are expected to limit the Company's risk of price fluctuations for its natural
gas purchases throughout the fourth quarter of 1997. However, a significant
portion of the Company's revenues, and as a result, its gross margins, remain
dependent upon the sales price of propane, which fluctuates with the winter
weather conditions and other supply and demand determinants. Currently,
MarkWest has an annual sensitivity to NGL prices equal to $1.0 million in pretax
income for every $0.01/gallon change in NGL prices and an annual sensitivity to
natural gas prices equal to $1.0 million in pretax income for every $0.10/mmbtu
change in natural gas prices. As of the end of the third quarter, the Company
has not entered into significant hedge contracts for its expected natural gas
purchases in the first quarter of 1998 and beyond. As a result, the Company
will be subject to price risk on both natural gas and propane prices in the
first quarter of 1998 and beyond.
The Company's future results are expected to be positively affected by volumes
through MarkWest's 60-percent-owned sour gas pipeline and plant in Western
Michigan which more than tripled to 12.8 mmcfd in the third quarter of 1997.
This increase in volumes due to significant drilling success in the area,
together with the start up of the Company's new natural gas liquids plant
expected in the fourth quarter of 1997, is expected to add substantial
production volumes and related revenues as described above.
7
THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30, SEPTEMBER 30,
OPERATING STATISTICS 1997 1996 % CHANGE 1997 1996 % CHANGE
----------------------------------------------------------------------
Fee gas processed (mmbtu) 13,667,349 8,663,134 58% 41,039,676 22,485,510 83%
NGL production - Siloam plant (gallons) 26,440,651 26,265,662 1% 76,318,338 69,359,365 10%
NGLs marketed - Siloam plant (gallons) 20,851,267 23,648,355 (12%) 70,721,011 64,250,073 10%
Terminal throughput (gallons) 5,842,224 6,257,409 (6%) 19,127,090 24,694,593 (22%)
Michigan pipeline throughput (mcf) 1,175,060 359,343 227% 2,018,408 780,841 158%
Gas production (mcf) 133,253 26,950 394% 309,887 77,376 300%
THREE MONTHS ENDED SEPTEMBER 30, 1997 COMPARED TO THE THREE MONTHS ENDED
SEPTEMBER 30, 1996
The Company reported net income of $867,000 or $0.10 per share on revenues of
$15.0 million for the third quarter of 1997. This compares to pro forma net
income of $1.2 million or $0.15 per share on revenues of $15.0 million for the
same period in 1996. Net income for the three months ended September 30, 1997
decreased primarily due to reduced gross margins from the Company's Appalachia
terminals, as a result of warmer weather during the third quarter of 1997
compared to the third quarter of 1996, reducing volumes sold.
GROSS MARGIN ANALYSIS (IN MILLIONS)
APPALACHIA PLANTS 1997 1996 Variance Volume Price
-----------------------------------------------------------------------------
Plant revenue $ 9.6 $10.5 $(0.9) $(0.6) $(0.3)
Feedstock costs 4.7 5.9 1.2 0.7 0.5
-----------------------------------------------------------------------------
Gross margin $ 4.9 $ 4.6 $ 0.3 $ 0.1 $ 0.2
=============================================================================
The Company's third quarter 1997 Appalachia plant revenues decreased from the
third quarter of 1996, primarily due to a 12% decrease in sales volumes during
the quarter. The decrease in volumes can be attributed to the Company's
efforts to build the necessary inventory levels for the upcoming winter
heating season. The remaining decrease is due to more normal propane price
levels in 1997 compared to above average price levels in the previous year.
Appalachia plant feedstock costs decreased in the third quarter of 1997 as
compared to the third quarter of 1996, primarily due to lower NGL sales
volumes. The remaining variance was due to a decrease in unit prices in the
third quarter of 1997 from the same quarter in 1996, primarily as a result of
favorably priced advance purchases of natural gas in 1997.
APPALACHIA TERMINALS 1997 1996 Variance Volume Price
-----------------------------------------------------------------------------
Terminal and marketing revenue $ 2.7 $ 4.0 $(1.3) $(1.2) $(0.1)
Terminal and marketing purchases 2.4 3.4 1.0 1.0 --
-----------------------------------------------------------------------------
Gross margin $ 0.3 $ 0.6 $(0.3) $(0.2) $(0.1)
=============================================================================
Terminal and marketing revenue for the third quarter of 1997 decreased
primarily as a result of a 6% volume decrease caused by the warm weather
experienced in the third quarter of 1997, compared to the cold early start to
winter experienced in the same quarter in 1996, and due to the lack of non-
terminal sales in 1997.
The Company's third quarter 1997 terminal and marketing purchases decreased
from the same quarter in 1996 as a result of the volume decrease.
8
MICHIGAN 1997 1996 Variance
---------------------------------------------
Transportation and treatment revenue $2.1 $ -- $2.1
Feedstock purchases 1.0 -- 1.0
---------------------------------------------
Gross margin $1.1 $ -- $1.1
=============================================
At September 30, 1996, the Company had earned an 11.3% interest in the Michigan
project, which was accounted for under the equity method of accounting.
Accordingly, the Company's respective share of income in the Michigan project,
which was approximately $169,000 for the third quarter of 1996, was reflected in
other income during 1996. Michigan transportation and treatment revenue and
feedstock purchases increased for the third quarter of 1997, reflecting higher
1997 volumes as described above. The Company incurs operating expenses, general
and administrative costs and interest expense on debt funding the capital
program, all as described below.
OIL AND GAS REVENUE
Oil and gas revenue increased to $425,000 for the third quarter of 1997 as
compared to $74,000 for the third quarter of 1996, an increase of $351,000. Gas
production from all of the Company's properties during the three months ended
September 30, 1997 increased 400% from the three months ended September 30,
1996, reflecting new production from the Company's capital program.
COSTS AND EXPENSES
Operating expenses increased $1.4 million to $2.8 million for the third quarter
of 1997, as compared to the third quarter of 1996. The increase was principally
driven by the Company's new operations in Michigan, which commenced in May 1996.
General and administrative expenses increased $400,000 to $1.6 million for the
third quarter of 1997 from $1.2 million for the third quarter of 1996. The
increase was attributable to administrative support activities related to the
new operations in Michigan and to costs incurred in connection with being a
public company in 1997.
NINE MONTHS ENDED SEPTEMBER 30, 1997 COMPARED TO THE NINE MONTHS ENDED SEPTEMBER
30, 1996
The Company reported net income of $5.5 million or $0.64 per share on revenues
of $55.7 million for the nine months ended September 30, 1997. This compares to
pro forma net income of $4.0 million or $0.50 per share on revenues of $43.6
million for the same period in 1996. Net income for the nine months ended
September 30, 1997 increased primarily due to increased sales margins and
volumes at the Company's Siloam plant during the first two quarters of 1997.
This was partially offset by a decrease in sales margins and volumes at the
Company's Appalachia terminals for the nine months ended September 30, 1997, as
compared to the nine months ended September 30, 1996.
GROSS MARGIN ANALYSIS (IN MILLIONS)
APPALACHIA PLANTS 1997 1996 Variance Volume Price
-----------------------------------------------------------------------------
Plant revenue $39.8 $28.9 $10.9 $ 3.1 $ 7.8
Feedstock costs 19.2 14.4 (4.8) (1.4) (3.4)
-----------------------------------------------------------------------------
Gross margin $20.6 $14.5 $ 6.1 $ 1.7 $ 4.4
=============================================================================
The Company's Appalachia plant revenues for the nine months ended September 30,
1997 increased primarily as a result of higher sales prices for NGLs compared
with the same period in 1996, as a result of the factors described in "Outlook"
above. The remaining increase was caused by a 10% increase in NGL sales
volumes during the first nine months of 1997 compared to the first nine months
of 1996.
9
Appalachia plant feedstock costs increased for the nine months ended September
30, 1997, compared to plant feedstock for the same period in 1996 primarily as a
result of higher natural gas prices during the first nine months of
1997. The remaining increase in feedstock costs was related to higher NGL
production and sales volumes in the first nine months of 1997, compared to the
first nine months of 1996.
APPALACHIA TERMINALS 1997 1996 Variance Volume Price
-----------------------------------------------------------------------------
Terminal and marketing revenue $10.9 $13.8 $(2.9) $(2.7) $(0.2)
Terminal and marketing purchases 10.9 12.1 1.2 2.3 (1.1)
-----------------------------------------------------------------------------
Gross margin $ -- $ 1.7 $(1.7) $(0.4) $(1.3)
=============================================================================
Terminal results in 1997 have been adversely affected by two factors. First,
beginning in the fourth quarter of 1996, there was a significant appreciation in
propane prices as described above in "Outlook". As a result, the Company
entered 1997 with higher-than-normally priced propane inventories. The first
quarter of 1997 saw sales prices decline rapidly as the supply and demand
characteristics returned to normal levels. Second, weather has been warmer in
1997, resulting lower sales volumes during the nine months ended September 30,
1997.
MICHIGAN 1997 1996 Variance
----------------------------------------------
Transportation and treatment revenue $ 3.3 $ -- $3.3
Feedstock purchases 1.0 -- 1.0
----------------------------------------------
Gross margin $ 2.3 $ -- $2.3
==============================================
At September 30, 1996, the Company had earned an 11.3% interest in the Michigan
project, which was accounted for under the equity method of accounting.
Accordingly, the Company's respective share of income in the Michigan project,
which was approximately $169,000 for the nine months ended September 30, 1996,
was reflected in other income during 1996. Michigan transportation and treating
revenue and feedstock purchases increased for the nine months ended September
30, 1997, reflecting higher 1997 volumes as described above. The Company
incurs operating expenses, general and administrative costs and interest expense
on debt funding the capital program, all as described below.
OIL AND GAS REVENUE
Oil and gas revenue increased to $695,000 for the nine months ended September
30, 1997 compared to $237,000 for the nine months ended September 30, 1996, an
increase of $458,000. Gas production from all of the Company's properties
during the nine months ended September 30, 1997 increased 300% from the previous
year, reflecting new production from the Company's capital program.
INTEREST INCOME
Interest income increased $337,000, to $406,000 for the nine months ended
September 30, 1997, compared to interest income of $69,000 for the nine months
ended September 30, 1996. This increase resulted primarily from interest income
earned in the first six months of 1997 on the long-term note receivable, which
earned interest at a rate of 5.98%.
COSTS AND EXPENSES
Operating expenses increased $3.4 million, or 81%, to $7.6 million for the nine
months ended September 30, 1997 as compared to operating expenses of $4.2
million for the nine months ended September 30, 1996. The increase was
principally driven by the Company's operations in Michigan, which commenced in
May 1996.
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General and administrative expenses increased $2.0 million to $5.5 million for
the nine months ended September 30, 1997, compared to general and administrative
expenses of $3.5 million for the nine months ended September 30, 1996. This
increase was attributable to administrative support activities related to the
new operations in Michigan and to costs incurred in connection with being a
public company in 1997.
Depreciation and amortization increased approximately $300,000, or 14%, to $2.4
million for the nine months ended September 30, 1997, compared to depreciation
and amortization expense of $2.1 million for the same period in 1996. This
increase was principally due to increased depreciation attributable to the
Company's new Michigan operations.
INTEREST EXPENSE
Interest expense decreased $161,000 to $726,000 for the nine months ended
September 30, 1997, compared to interest expense of $887,000 for the same period
in 1996, primarily as a result of the lower cost of the Company's new credit
facility (see further discussion below under "Liquidity and Capital Resources").
LIQUIDITY AND CAPITAL RESOURCES
The Company's sources of liquidity and capital resources historically have been
net cash provided by operating activities; proceeds from issuance of long-term
debt; and in 1996, an initial public offering of equity. The Company's
principal uses of cash have been to fund operations, capital expenditures and
acquisitions.
For the nine months ended September 30, 1997, net cash flow provided from
operations, before adjustments for working capital, increased to $9.0 million
from $8.5 million for the nine months ended September 30, 1996. The Company
invested $6.6 million in working capital in the nine months ended September 30,
1997, compared to $1.1 million invested in the nine months ended September 30,
1996. This was primarily caused by a higher accounts receivable balance at
September 30, 1997 related to the Company's Michigan operations and a decrease
in 1997 in accounts payable and accrued liabilities, primarily related to tax
payments made in 1997, offset by a smaller build in inventories for the nine
months ended September 30, 1997 when compared to the same time period in 1996.
Cash used in investing activities increased $13.3 million for the nine months
ended September 30, 1997 to $18.5 million, as compared to cash used in
investing activities of $5.2 million for the nine months ended September 30,
1996, mainly due to $16.2 million of capital expenditures funded by the Company
during the first three quarters of 1997. The Company's 1997 capital program
is discussed further below.
Financing activities during the third quarter of both 1997 and 1996 principally
consisted of borrowings and repayments on long-term debt.
Financing Facilities
New Credit Facility Effective June 20, 1997, the Company replaced its existing
financing agreement with a new credit facility (the "credit facility") with the
Bank of Montreal, as agent, NationsBank and Colorado National Bank. The credit
facility allows the Company to borrow up to $55 million, subject to borrowing
base calculations, pursuant to a revolving loan commitment. The revolving loan
commitment converts to a reducing loan commitment on May 31, 1999. The reducing
loan commitment reduces ratably on a quarterly basis to zero by May 21, 2003.
Interest rates are based on either the agent bank's prime rate plus 1% or the
London Interbank Offered Rate (LIBOR), plus an applicable margin of between 50
and 150 basis points, based upon the Company's debt to capitalization ratio. As
of September 30, 1997, approximately $22.9 million was outstanding. Of the total
debt outstanding, $18.9 million bears interest at 6.125% and $4.0 million bears
interest at 6.185%.
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The loan agreement contains affirmative and negative covenants customary in
commercial lending transactions, including maintenance of a specified tangible
net worth, ratio of total funded debt to capitalization, total funded debt to
trailing twelve month EBITDA and current ratio.
Resources Revolver Loan The Company had a revolving facility with Colorado
National Bank with a maximum borrowing base of $5.8 million as of March 31,
1997. This facility was canceled by the Company, effective April 25, 1997.
At September 30, 1997, the Company had $32.1 million of available credit and
working capital of $13.0 million. The Company believes that cash flows
generated by its operations and existing credit facilities will be sufficient to
meet its anticipated cash needs for working capital and capital expenditures,
other than acquisitions, if any, for the next 12 months.
Capital Investment Program
On July 1, 1997, the Company closed on the purchase of a 44,000 square-foot
office building in Englewood, Colorado, with the objective of reducing the
Company's effective office costs. The four year old building will serve as
MarkWest's corporate headquarters. MarkWest will occupy approximately half of
the building and lease out the remainder. The cost of the building and tenant
improvements will total approximately $5.6 million, to be financed initially
from the Company's line of credit, and to be converted to long-term financing
later in 1997. Of the total cost, $4.6 million has been expended in the nine
months ended September 30, 1997.
In addition, the Company expects to spend approximately $17.0 million during
1997, including approximately $10.0 million in the Michigan Core Area in order
to complete construction of a pipeline and a new liquids facility, with the
balance being allocated for projects in the Appalachian Core Area and
exploration projects. For the nine months ended September 30, 1997, the Company
made capital expenditures totaling approximately $11.6 million.
RISK MANAGEMENT ACTIVITIES
The Company's primary hedging objectives are to meet or exceed budgeted gross
margins by locking in budgeted or above-budgeted prices in the financial
derivatives markets and to protect margins from precipitous declines. The
Company maintains a three-person committee of senior management that oversees
all hedging activity.
MarkWest employs three general risk management strategies. First, the Company
contracts for future purchases of natural gas at a predetermined BTU
differential based upon a basket of Gulf Coast NGL prices (or a substitute for
propane such as crude oil). Second, MarkWest protects margins by purchasing
natural gas contracts while simultaneously selling propane contracts of
approximately the same BTU value. Third, the Company purchases propane futures
contracts to hedge future sales of propane at the Company's terminals or gas
plants.
MarkWest enters into futures transactions in two ways: (1) on the New York
Mercantile Exchange ("NYMEX"); and (2) future gas purchases are negotiated with
natural gas suppliers and are structured to provide similar risk protections as
NYMEX futures.
Gains and loss related to qualifying hedges, as defined by Statement of
Financial Accounting Standards No. 80, "Accounting for Futures Contracts", of
firm commitments or anticipated transactions are recognized in plant revenue and
feedstock purchases upon execution of the hedged physical transaction. Under
internal guidelines, speculative transactions are prohibited.
In addition to these risk management tools, MarkWest is able to use its liquids
storage facilities to inventory product during lower-priced periods for resale
during higher-priced periods. Also, MarkWest has contractual arrangements to
purchase certain quantities of its natural gas feedstock in advance of physical
needs.
During the three and nine months ended September 30, 1997, a $0 and $1.0 million
gain, respectively, were recognized in operating income on the settlement of
propane and natural gas futures, compared to gains of $36,000
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and $107,000 recognized during the three and nine months ended September 30,
1996, respectively. Financial instrument gains and losses on hedging activities
were generally offset by amounts realized from the sale of the underlying
products in the physical market.
RECENT ACCOUNTING PRONOUNCEMENTS
In February 1997, the Financial Accounting Standards Board issued Statement No.
128 ("SFAS 128"), "Earnings Per Share". This Statement is effective for
financial statements issued for periods ending after December 15, 1997. Earlier
adoption is not permitted. SFAS 128 requires dual presentation of basic and
diluted EPS for entities with
complex capital structures. The impact of adopting SFAS 128 will not have a
material effect on the Company's earnings per share calculation.
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
In April 1997, Domain Energy Corporation and EnCap Investments, L.C. informed
the Company that they had purported to transfer their interests in Michigan
Energy Company, LLC ("MEC") and Michigan Production Company to Energy
Acquisition Corp. MEC holds a minority interest in West Shore. In April 1997,
the Company commenced arbitration proceedings pursuant to the Participation,
Ownership and Operating Agreement for West Shore, to challenge the transfer of
the interest in MEC.
The arbitration demand also asserted claims involving certain West Shore
operating issues generated by MEC's actions subsequent to the challenged
transfer. Domain Energy Corporation, EnCap Investments, L.C. and other entities
participating in the transfer transaction, named as Respondents in the
arbitration, subsequently filed an action in Harris County, Texas seeking a
declaration that the transfer transaction was proper and challenging the
arbitrability of the Company's claims concerning the transfer. The Texas State
Court action also sought an issuance of an injunction against the arbitration
proceeding during the pendency of the declaratory judgment action.
To facilitate prompt resolution of the West Shore operating issue claims
initially asserted in the arbitration and additional issues which have arisen
since April, the Company amended the arbitration demand in July 1997 to
withdraw, without prejudice, its challenge to the transfer transaction. The
Company believes the transfer issue will be resolved by alternative means.
On October 16, 1997, the Harris County Texas Court entered a notice of intent to
dismiss the Domain action, discussed above, for want of prosecution.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
10.1 MarkWest Hydrocarbon, Inc. 1997 Severance Plan
27 - Financial Data Schedule
(b) Reports on Form 8-K
No reports on Form 8-K were filed during the quarter ended September
30, 1997.
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SIGNATURES
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.
MarkWest Hydrocarbon, Inc.
(Registrant)
Date: November 12, 1997 By: /s/ Gerald A. Tywoniuk
--------------------------------
Gerald A. Tywoniuk
Chief Financial Officer and Vice
President of Finance
(On Behalf of the Registrant and
as Principal Financial and
Accounting Officer)
14