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 JUNE 30, 2004. | |
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 0-30321
QUESTAR MARKET RESOURCES, INC. |
(Exact name of registrant as specified in its charter) |
State of Utah | 87-0287750 | |
| ||
P.O. Box 45601 | 84145-0601 |
(801) 324-2600
(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 [ ] | ||
Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act). | |||
Yes [ ] | No [X] | ||
Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date. |
Class | Outstanding as of July 31, 2004 | |
Common Stock, $1.00 par value | 4,309,427 shares |
Registrant meets the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and is filing this Form 10-Q with the reduced disclosure format. |
Questar Market Resources, Inc.
Form 10-Q for the Quarterly Period Ended June 30, 2004
TABLE OF CONTENTS
Page
PART I.
FINANCIAL INFORMATION
Item 1.
Financial Statements
Consolidated Statements of Income
Condensed Consolidated Balance Sheets
Condensed Consolidated Statements of Cash Flows
Notes Accompanying Consolidated Financial Statements
Item 2.
Management’s Discussion and Analysis of
Financial Condition and Results of Operations
Item 3.
Quantitative and Qualitative Disclosures about Market Risk
Item 4.
PART II.
OTHER INFORMATION
Item 1.
Item 5.
Item 6.
Exhibits and Reports on Form 8-K
Signatures
Glossary of Commonly Used Terms
bbl
Barrel, which is equal to 42 United States gallons and is a common unit of measurement of crude oil.
basis
The difference between a reference or benchmark commodity price and the corresponding selling prices at various regional sales points.
bcf
One billion cubic feet, a common unit of measurement of natural gas.
bcfe
One billion cubic feet of natural gas equivalent. Oil volume is converted to natural gas equivalent using the ratio of one barrel of crude oil to 6,000 cubic feet of natural gas.
Btu
One British Thermal Unit – a measure of the amount of energy required to raise the temperature of one pound of water one degree Fahrenheit.
cash flow hedge
A derivative instrument that complies with Statement of Financial Accounting Standards (“SFAS”) 133, as amended, and is used to reduce the exposure to variability in cash flows from the forecasted physical sale of gas and oil production whereby the gains (losses) on the derivative transaction are anticipated to offset the losses (gains) on the forecasted physical sale.
development well
A well drilled into a known producing formation in a previously discovered field.
dew point
A specific temperature and pressure at which hydrocarbons condense to form a liquid.
dry hole
A well drilled and found to be incapable of producing hydrocarbons in sufficient quantities such that proceeds from the sale of such production exceed production expenses and taxes.
dth
Decatherms or ten therms. One dth equals one million Btu or approximately one Mcf.
exploratory well
A well drilled into a previously untested geologic structure to determine the presence of gas or oil.
futures contract
An exchange-traded legal contract to buy or sell a standard quantity and quality of a commodity at a specified future date and price.
gross
“Gross” natural gas and oil wells or “gross” acres equals the total number of wells or acres in which the Company has an interest.
hedging
The use of derivative commodity and interest rate instruments to reduce financial exposure to commodity price and interest rate volatility.
Mbbl
One thousand barrels.
Mcf
One thousand cubic feet.
Mcfe
One thousand cubic feet of natural gas equivalents.
Mdth
One thousand decatherms.
Mdthe
One thousand decatherm equivalents.
MMbbl
One million barrels.
MMBtu
One million British Thermal Units.
MMcf
One million cubic feet.
MMcfe
One million cubic feet of natural gas equivalents
MMdth
One million decatherms.
natural gas liquids
Liquid hydrocarbons that are extracted and separated from the natural gas stream NGL
(NGL)
stream. NGL products include ethane, propane, butane, natural gasoline and heavier hydrocarbons.
net
“Net” gas and oil wells or “net” acres are determined by multiplying gross wells or acres by the Company’s working interest in those wells or acres.
proved reserves
“Proved reserves” means those quantities of natural gas and crude oil, condensate, and natural gas liquids on a net revenue interest basis, which geological and engineering data demonstrate with reasonable certainty to be recoverable under existing economic and operating conditions. “Proved developed reserves” include proved developed producing reserves and proved developed behind-pipe reserves. “Proved developed producing reserves” include only those reserves expected to be recovered from existing completion intervals in existing wells. “Proved undeveloped reserves” include those reserves expected to be recovered from new wells on proved undrilled acreage or from existing wells where a relatively major expenditure is required for recompletion.
reservoir
A porous and permeable underground formation containing a natural accumulation of producible natural gas and/or oil that is confined by impermeable rock or water barriers and is separate from other reservoirs.
wet gas
Unprocessed natural gas that contains a mixture of heavier hydrocarbons including ethane, propane, butane, and natural gasoline.
working interest
An interest that gives the owner the right to drill, produce, and conduct operating activities on a property and receive a share of any production.
FORWARD-LOOKING STATEMENTS
This report includes “forward-looking statements” within the meaning of Section 27(a) of the Securities Act of 1933, as amended, and Section 21(e) of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical facts included or incorporated by reference in this report, including, without limitation, statements regarding the company’s future financial position, business strategy, budgets, projected costs and plans and objectives of management for future operations, are forward-looking statements. In addition forward-looking statements generally can be identified by the use of forward-looking terminology such as “may,” “will,” “could,” “expect,” “intend,” “project,” “estimate,” “anticipate,” “believe,” “forecast,” or “continue” or th e negative thereof or variations thereon or similar terminology. Although these statements are made in good faith and are reasonable representations of Questar Market Resources, Inc. (“Market Resources” or the “Company”) expected performance at the time, actual results may vary from management’s stated expectations and projections due to a variety of factors.
Important assumptions and other significant factors that could cause actual results to differ materially from those expressed or implied in forward-looking statements include:
Changes in estimated quantities of gas and oil reserves. Gas and oil reserve estimates are subject to numerous uncertainties inherent in the estimation of quantities of proved reserves, the projection of future rates of production and the timing of development expenditures. The accuracy of these estimates is a function of the quality of available data and of engineering and geological interpretation and judgment. Reserve estimates are imprecise and should be expected to change as additional information becomes available. Estimates of economically recoverable reserves and of future net cash flows prepared by different engineers or by the same engineers at different times may vary significantly. Results of subsequent drilling, testing and production may cause either upward or downward revisions of previous estimates. In addition the estimates of future net revenu es from proved reserves and the present value of those reserves are based upon certain assumptions about production levels, prices and costs, which may not be correct. The volumes considered to be commercially recoverable fluctuate with changes in prices and operating costs. The meaningfulness of such estimates is highly dependent upon the accuracy of the assumptions upon which they were based. Actual results may differ materially from the results estimated. Questar Exploration and Production’s (“Questar E&P”) reserves are prepared on an annual basis by independent reservoir engineers.
Presence of wildlife and potential endangered species could limit access to public lands. Various wildlife species occupy portions of Market Resources leasehold at Pinedale and in other areas. Current federal regulations restrict activities during certain times of the year on portions of Market Resources’ leasehold due to wildlife activity and/or habitat. Some species that are known to be present, such as the sage grouse, may in the future be listed under federal law as endangered or threatened species. Such listing could have a material impact on access to Market Resources’ leasehold in certain areas or during periods when the particular species is found to be present.
Changes in gas and oil prices. The sale of gas and oil production is a commodity-based business subject to pricing influenced by regional factors. Market Resources has established policies and procedures for managing commodity-price risks through the use of derivatives. Market Resources hedges commodity prices to support credit ratings, returns on invested capital, cash-flow targets, and protect earnings from downward movements in commodity prices. However these arrangements usually limit future gains from favorable price movements.
Other important assumptions: changes in general economic conditions; regulation of the Wexpro Agreement; availability and economic viability of gas and oil properties for sale or exploration; creditworthiness of counterparties; rate of inflation and interest rates; assumptions used in business combinations; weather and natural disasters; effects of environmental and other regulation; changes in customers' credit ratings; competition from other forms of energy; effects of accounting policies issued periodically by accounting standard-setting bodies; terrorist attacks or acts of war; changes in the business or financial condition of the Company; and changes in credit ratings for Market Resources.
QUESTAR MARKET RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
June 30, 2004
(Unaudited)
Note 1 – Basis of Presentation of Interim Financial Statements
Market Resources’ interim consolidated financial statements, with the exception of the condensed consolidated balance sheet at December 31, 2003, have not been audited by independent public accountants. The interim financial statements reflect all normal, recurring adjustments that are, in the opinion of management, necessary for a fair presentation of the results of operations for the interim periods presented. The preparation of financial statements in conformity with accounting principles generally accepted (“GAAP”) in the United States requires management to make estimates and assumptions that affect the amounts of assets and liabilities and disclosure of contingent liabilities reported in the financial statements and accompanying notes. Actual results could differ from estimates. All significant intercompany accounts and transactions were eliminated in consolidation.
The results of operations for the three- and six-month periods ended June 30, 2004, are not necessarily indicative of the results that may be expected for the year ending December 31, 2004. Interim financial statements do not include all of the information and notes required by GAAP for audited annual financial statements. For further information please refer to the consolidated financial statements and notes included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2003.
Note 2 – Asset-Retirement Obligations (“ARO”)
On January 1, 2003, Market Resources adopted SFAS 143 “Accounting for Asset Retirement Obligations.” SFAS 143 addresses the financial accounting and reporting of the fair value of legal obligations associated with the retirement of tangible long-lived assets. The fair value of abandonment costs are estimated and depreciated over the life of the related assets. ARO is adjusted to present value each period through an accretion calculation using a credit-adjusted risk-free interest rate. Both the accretion expense associated with the liability and the depreciation associated with the capitalized abandonment costs are non-cash expenses until the time the asset is retired.
Changes in asset-retirement obligations were as follows.
2004 | 2003 | |
(in thousands) | ||
Balance at January 1, | $60,493 | $55,674 |
Accretion | 900 | 1,654 |
Additions | 869 | 606 |
Revisions | 695 | |
Retirements | (262) | (578) |
Balance at June 30, | $62,695 | $57,356 |
During the second quarter of 2004, Wexpro finalized a guideline letter with the Utah Division of Public Utilities and the staff of the Wyoming Public Service Commission agreeing to the accounting treatment of reclamation activity associated with ARO for properties administered under the Wexpro Agreement. Pursuant to the stipulation, Wexpro will collect and deposit in trust certain funds related to the estimated ARO costs. The funds will be used to satisfy reclamation obligations as the properties are reclaimed over time.
Note 3 – Investment in Unconsolidated Affiliates
Market Resources uses the equity method to account for investments in unconsolidated affiliates where the Company does not have control. These entities are engaged in gathering and compressing natural gas, and have no debt obligations with third-party lenders. The principal affiliates and Market Resources’ ownership percentage as of June 30, 2004, were: Rendezvous Gas Services, LLC (“Rendezvous”), a limited liability corporation, (50%) and Canyon Creek Compression Co., a general partnership (15%).
Operating results are listed below. | ||||
6 Months Ended | ||||
June 30, | ||||
2004 | 2003 | |||
(in thousands) | ||||
Revenues | $ 8,420 | $ 7,908 | ||
Operating income | 5,296 | 4,787 | ||
Income before income taxes | 5,306 | 4,806 | ||
Note 4 - Operations By Line of Business | ||||
3 Months Ended | 6 Months Ended | |||
June 30, | June 30, | |||
2004 | 2003 | 2004 | 2003 | |
(in thousands) | ||||
REVENUES FROM UNAFFILIATED CUSTOMERS | ||||
Exploration and production | $108,113 | $ 79,856 | $215,067 | $166,594 |
Cost of service | 3,748 | 1,656 | 8,201 | 6,658 |
Gathering, processing and marketing | 132,499 | 74,468 | 255,146 | 195,921 |
$244,360 | $155,980 | $478,414 | $369,173 | |
REVENUES FROM AFFILIATED COMPANIES | ||||
Cost of service | $ 31,010 | $ 26,790 | $ 59,414 | $ 50,536 |
Gathering, processing and marketing | 3,080 | 3,167 | 9,033 | 5,870 |
$ 34,090 | $ 29,957 | $ 68,447 | $ 56,406 | |
OPERATING INCOME | ||||
Exploration and production | $ 45,802 | $ 32,386 | $ 91,326 | $ 70,080 |
Cost of service | 14,033 | 12,930 | 28,565 | 26,326 |
Gathering, processing and marketing | 6,077 | 2,896 | 15,344 | 11,363 |
$ 65,912 | $ 48,212 | $135,235 | $107,769 | |
INCOME BEFORE CUMULATIVE EFFECT OF ACCOUNTING CHANGE | ||||
Exploration and production | $ 25,432 | $ 17,413 | $ 50,623 | $ 37,958 |
Cost of service | 8,793 | 8,466 | 17,815 | 16,652 |
Gathering, processing and marketing | 3,938 | 1,897 | 9,980 | 7,215 |
$ 38,163 | $ 27,776 | $ 78,418 | $ 61,825 | |
NET INCOME | ||||
Exploration and production | $ 25,432 | $ 17,413 | $ 50,623 | $ 33,408 |
Cost of service | 8,793 | 8,466 | 17,815 | 16,089 |
Gathering, processing and marketing | 3,938 | 1,897 | 9,980 | 7,215 |
| $ 38,163 | $ 27,776 | $ 78,418 | $ 56,712 |
Note 5 – Financing
On March 19, 2004, Market Resources completed a $200 million credit facility with a consortium of banks that replaced an existing facility that expired in April 2004. The facility allows for floating-rate interest and revolving loans of various maturities until March 2009. Key financial covenants place limits on minimum levels of cash flow compared to interest expense and maximum amounts of debt as a percentage of total capital. The interest rate credit spread on borrowings varies with changes in Market Resources’ credit rating, but a reduction in or loss of credit ratings does not trigger an event of default under the facility.
Note 6 – Comprehensive Income
Comprehensive income is the sum of net income as reported in the Consolidated Statements of Income and other comprehensive income or loss reported in Common Shareholder’s Equity. Other comprehensive income or loss includes changes in the market value of gas or oil-price derivatives and are not reported in current income or loss. Income or loss is realized when the physical gas or oil underlying the derivative instrument is sold. A summary of comprehensive income is shown below.
3 Months Ended | 6 Months Ended | |||
June 30, | June 30, | |||
2004 | 2003 | 2004 | 2003 | |
(in thousands) | ||||
Net income | $ 38,163 | $ 27,776 | $ 78,418 | $ 56,712 |
Other comprehensive income (loss) | ||||
Unrealized loss on hedging transactions | (40,829) | (16,740) | (64,589) | (39,928) |
Income taxes | 15,266 | 6,260 | 24,201 | 14,929 |
Other comprehensive loss | (25,563) | (10,480) | (40,388) | (24,999) |
Comprehensive income | $ 12,600 | $ 17,296 | $ 38,030 | $ 31,713 |
Note 7 – Reclassifications
Certain reclassifications were made to the 2003 financial statements to conform with the 2004 presentation.
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
June 30, 2004
(Unaudited)
Results of Operations
Market Resources is a wholly-owned subsidiary of Questar Corporation (“Questar”). Market Resources conducts its operations through several subsidiaries. Questar E&P acquires, explores for, develops and produces gas and oil. Wexpro Company (“Wexpro”) manages, develops and produces cost-of-service reserves for affiliated company, Questar Gas Company. Questar Gas Management Company (“Gas Management”) provides gas gathering and processing services for affiliates and third parties. Questar Energy Trading Company (“Energy Trading”) markets equity and third-party gas and oil, provides risk-management services, and through its wholly-owned subsidiary Clear Creek Storage Company, LLC (“Clear Creek”) owns and operates an underground gas-storage reservoir. Following is a summary of Market Resources’ financial results and operating information.
3 Months Ended | 6 Months Ended | |||
June 30, | June 30, | |||
2004 | 2003 | 2004 | 2003 | |
FINANCIAL RESULTS - (in thousands) | ||||
Revenues | ||||
From unaffiliated customers | $244,360 | $155,980 | $478,414 | $369,173 |
From affiliates | 34,090 | 29,957 | 68,447 | 56,406 |
Total revenues | $278,450 | $185,937 | $546,861 | $425,579 |
Operating income | $ 65,912 | $ 48,212 | $135,235 | $107,769 |
Income before cumulative effect | $ 38,163 | $ 27,776 | $ 78,418 | $ 61,825 |
Cumulative effect of accounting change | (5,113) | |||
Net income | $ 38,163 | $ 27,776 | $ 78,418 | $ 56,712 |
OPERATING STATISTICS | ||||
Nonregulated production volumes | ||||
Natural gas (MMcf) | 21,827 | 17,957 | 43,715 | 38,061 |
Oil and natural gas liquids (Mbbl) | 559 | 568 | 1,146 | 1,140 |
Total production (bcfe) | 25.2 | 21.4 | 50.6 | 44.9 |
Average daily production (MMcfe) | 277 | 235 | 278 | 248 |
Average commodity prices, net to the well | ||||
Average realized price (including hedges) | ||||
Natural gas (per Mcf) | $4.17 | $3.66 | $4.11 | $3.59 |
Oil and natural gas liquids (per bbl) | 29.55 | 22.45 | 29.50 | 23.59 |
Average sales price (excluding hedges) | ||||
Natural gas (per Mcf) | $5.03 | $4.34 | $4.87 | $4.27 |
Oil and natural gas liquids (per bbl) | 35.38 | 26.62 | 33.57 | 28.89 |
Wexpro investment base at June 30, net of | ||||
depreciation and deferred income taxes (millions) | $165.3 | $160.3 | ||
Natural gas and oil marketing volumes (Mdthe) | 20,725 | 16,900 | 42,580 | 38,211 |
Natural gas gathering volumes (Mdth) | ||||
For unaffiliated customers | 32,164 | 28,031 | 66,458 | 56,357 |
For Questar Gas | 9,149 | 9,515 | 18,906 | 21,099 |
For other affiliated customers | 13,336 | 8,936 | 27,894 | 21,027 |
Total gathering | 54,649 | 46,482 | 113,258 | 98,483 |
Gathering revenue (per dth) | $0.21 | $0.20 | $0.21 | $0.20 |
Market Resources
Market Resources net income for the second quarter of 2004 totaled $38.2 million compared with $27.8 million for the year earlier period, a 37% increase. Net income for the first half of 2004 was $78.4 million, a 38% increase over the $56.7 million earned in the first half of 2003 as revenue growth continued to outpace increases in expenses. Operating income increased $17.7 million, or 37%, in the quarter-to-quarter comparison and $27.5 million, or 25%, in the first half comparison, due primarily to increased production and higher prices at Questar E&P and improved margins at Gas Management. Total revenues increased $92.5 million, or 50%, in the second quarter of 2004, and $121.3 million, or 28%, in the first half of 2004. Revenue growth was driven by increased nonregulated production volumes (nonregulated volumes exclude Wexpro “cost-of-service” production), hi gher realized commodity prices at Questar E&P, and increased throughput and higher fees at Gas Management. Expenses increased in the 2004 periods due to increased abandonment expense, production taxes, lease operating expense, and depreciation, depletion and amortization
Questar E&P
For the second quarter of 2004, Questar E&P earned $25.4 million compared with $17.4 million for the same period in 2003. Net income for the first half of 2004 was $50.6 million, a 52% increase over the $33.4 million earned in 2003. Higher profits were driven by increased nonregulated production and higher realized natural gas, oil and NGL prices.
Questar E&P’s nonregulated production for the first half of 2004 was 50.6 bcfe compared to 44.9 bcfe for the 2003 period, a 13% increase. Production growth was driven by the accelerated pace of development drilling on the Pinedale Anticline in western Wyoming and significant year-over-year volume increases from Midcontinent properties. Natural gas remains the primary focus of Questar E&P’s exploration and production strategy. On an energy-equivalent ratio, natural gas comprised approximately 85% of nonregulated production for the second quarter and first half of 2004. The three- and six-month comparisons of energy-equivalent production by region are shown in the following table.
3 Months Ending | 6 Months Ending | |||
June 30, | June 30, | |||
2004 | 2003 | 2004 | 2003 | |
(in bcfe) | ||||
Rocky Mountains | ||||
Pinedale Anticline | 4.9 | 2.5 | 11.0 | 5.4 |
Uinta Basin | 6.1 | 7.0 | 12.4 | 15.5 |
Rockies Legacy | 4.7 | 3.9 | 9.1 | 8.4 |
Subtotal – Rocky Mountains | 15.7 | 13.4 | 32.5 | 29.3 |
Midcontinent | 9.5 | 8.0 | 18.1 | 15.6 |
Total nonregulated production | 25.2 | 21.4 | 50.6 | 44.9 |
At June 30, 2004, Market Resources had 76 producing wells on the Pinedale Anticline compared to 51 at the beginning of 2003. Current quarter nonregulated production from Pinedale decreased 1.2 bcfe from first quarter 2004 volumes. Production at Pinedale typically declines during the second and third quarters due to a suspension of drilling and completion activities caused by access restrictions from mid-November to early May. (See the discussion of Pinedale Anticline Drilling Activity later in this Item.) Continued good performance from Questar E&P’s Hartshorne coal bed methane (“CBM”) project in the Arkoma Basin of eastern Oklahoma and ongoing development drilling on the Elm Grove properties in northwest Louisiana drove Midcontinent results. Current quarter Midcontinent production was up 0.9 bcfe, or 10%, versus the first quarter of 2004. Prod uction volumes from the Uinta Basin of eastern Utah decreased 13% in the current quarter compared to the year earlier period and 20% in the first half comparison. The production decline in the Uinta Basin has flattened significantly from a year ago. Uinta Basin current quarter volumes were down only 0.2 bcfe compared to the first quarter of 2004. Second quarter 2004 volumes were negatively impacted by gathering and compression constraints that reduced Uinta Basin net production volumes approximately 0.3 bcfe. The constraint should be alleviated with installation of additional compression in early August, 2004. Production from Rockies “Legacy” properties in the first half of 2004 was 9.1 bcfe compared to 8.4 bcfe in 2003, a 9% increase. Legacy properties include all of Questar E&P’s Rocky Mountain producing properties exclusive of Pinedale and the Uinta Basin.
Questar E&P benefited from higher realized prices for natural gas, oil and NGL in the second quarter and first half of 2004. For the current quarter the weighted average realized gas price for Questar E&P (including the effects of hedging) was $4.17 per Mcf compared to $3.66 per Mcf for the same period in 2003, a 14% increase. For the 2004 quarter, realized oil and NGL prices averaged $29.55 per bbl, compared with $22.45 per bbl in the second quarter of 2003, a 32% increase. A comparison of average realized prices by region, including hedges, is shown in the following table.
3 Months Ending | 6 Months Ending | |||
June 30, | June 30, | |||
2004 | 2003 | 2004 | 2003 | |
Natural gas (per Mcf) | ||||
Rocky Mountains | $3.83 | $3.27 | $3.89 | $3.13 |
Midcontinent | 4.71 | 4.27 | 4.50 | 4.40 |
Volume weighted average | $4.17 | $3.66 | $4.11 | $3.59 |
Oil and NGL (per bbl) | ||||
Rocky Mountains | $28.41 | $20.74 | $28.62 | $22.04 |
Midcontinent | 32.14 | 26.68 | 31.51 | 27.55 |
Volume weighted average | $29.55 | $22.45 | $29.50 | $23.59 |
Realized natural gas prices in Questar E&P’s core Rockies areas increased significantly in the second quarter and first half of 2004 compared to the 2003 periods. Approximately 60% of Questar E&P’s 2004 natural gas production came from properties located in the Rockies. Rockies basis, the regional difference between Rockies prices and the reference Henry Hub price, averaged $0.95 per MMBtu for the second quarter of 2004, compared to approximately $1.25 per MMBtu for the same period in 2003. For the first half of 2004 Rockies basis averaged $0.85, compared to $2.04 in the first half of 2003. The May 2003 completion of a major interstate pipeline expansion that delivers Rockies gas to California markets alleviated the transportation bottleneck that adversely affected prices in the 2003 periods.
Approximately 80% of Market Resources’ nonregulated gas production in the first half of 2004 was hedged or pre-sold at an average price of $4.05 per Mcf net to the well (which reflects adjustments for regional basis, gathering and processing costs, and gas quality) resulting in a $33.3 million reduction in revenue for the six months compared to results if the entire volume had not been hedged and instead was sold at prevailing market prices. Market Resources also hedged or pre-sold approximately 56% of its oil production for the first half of 2004 at an average net to the well price of $30.98 per bbl, which resulted in a $4.7 million reduction in revenues for the period versus sales at then-prevailing market prices. Market Resources may hedge up to 100 percent of its forecasted nonregulated production from proved developed reserves to lock in acceptable returns on invested capital a nd to protect cash flows and earnings from a decline in commodity prices.
Market Resources has continued to take advantage of higher natural gas and oil prices to add to its hedge positions in 2005 and 2006. Natural gas and oil hedges as of June 30, 2004, are summarized in Item 3 of this report.
Questar E&P’s cost structure is summarized in the following table.
3 Months Ending | 6 Months Ending | |||
June 30, | June 30, | |||
2004 | 2003 | 2004 | 2003 | |
(per Mcfe) | ||||
Lease-operating expense | $0.52 | $0.52 | $0.50 | $0.48 |
Production taxes | 0.42 | 0.33 | 0.42 | 0.32 |
Lifting costs | 0.94 | 0.85 | 0.92 | 0.80 |
Depreciation, depletion and amortization | 1.01 | 0.94 | 1.00 | 0.94 |
General and administrative expense | 0.33 | 0.30 | 0.30 | 0.28 |
Allocated-interest expense | 0.21 | 0.24 | 0.21 | 0.24 |
Total | $2.49 | $2.33 | $2.43 | $2.26 |
Lifting costs per Mcfe were higher in the 2004 periods primarily due to increased production taxes related to higher gas, oil and NGL sales prices. Most production taxes are based on a fixed percentage of commodity sales prices. Depreciation, depletion and amortization expense increased in the 2004 periods primarily due to higher reserve replacement costs. Increased industry activity in core operating areas has increased drilling and completion costs. General and administrative expenses per Mcfe increased $0.03 and $0.02, or 10% and 7%, in the second quarter and first half of 2004 when compared to the same periods of 2003. The increase in both periods of 2004 was primarily due to higher legal, insurance, and employee benefit costs and higher allocated corporate overhead (primarily employee benefits and compliance costs). For the second quarter and first half of 2004 all ocated interest decreased to $0.21 per Mcfe compared to $0.24 per Mcfe for the same periods in 2003 due mostly to increased production.
Pinedale Anticline Drilling Activity
During the second quarter of 2004, Market Resources continued limited winter drilling for a second year on the Pinedale Anticline. Market Resources drilled three wells from a single pad over the winter of 2003/2004 and will continue drilling activity from the pad through the remainder of 2004. Sage grouse stipulations imposed by the Bureau of Land Management (“BLM”) delayed startup of drilling activities at some locations on Market Resources’ Pinedale acreage during May and June, including the 19,500 foot deep Stewart Point 15-29 well. Drilling began on the Stewart Point well in mid July. Questar E&P has a 71.25% working interest in the deeper zones. Market Resources currently has 14 rigs actively drilling on its Pinedale acreage. In spite of early-season delays, Market Resources still expects to drill and complete approximately 30 Lance/Mesaverde Formation development wells in 2004.
Questar E&P and Wexpro have a combined 62% average Lance/Mesaverde working interest in 14,800 acres at Pinedale.
Pinedale Anticline Year-Round Drilling Proposal
On April 15, 2004, Market Resources submitted a proposal to the BLM seeking a long-term exception to the winter drilling restrictions on its Pinedale acreage from November 15 through May 1. If approved, Market Resources will be allowed to drill from three active pads with two drilling rigs per pad, starting in the winter of 2004/2005. The BLM has initiated an Environmental Assessment and is soliciting public comments on Market Resources’ proposal.
Market Resources believes that year-round drilling from pads is the most efficient and environmentally responsible approach for developing its Pinedale acreage. Market Resources’ proposal would shorten the anticipated development drilling period from 18 years to about 9 years. Under the proposal Market Resources would drill multiple directional wells from single surface pads. If approved Market Resources estimates that only nine additional surface disturbances will be required to fully develop its current Pinedale acreage on 20-acre spacing. With Market Resources’ proposal, surface disturbance will be reduced initially from almost 1,500 acres currently allowed to less than 540 acres. Surface disturbance would be further reduced to about 260 acres with post-drilling reclamation.
In addition to reduced surface disturbance and a shortened development drilling period, other benefits of Market Resources’ year-round proposal include a substantial reduction in emissions, noise, dust and traffic compared to the current situation in which activities are compressed into the summer months. Year-round drilling also creates year-round jobs and thus a more stable, better trained, more productive and safer workforce in the drilling and completion service industries. If the proposal is approved, Market Resources has committed to build pipelines to transport condensate and water production off the Mesa (that portion of the Pinedale Anticline where Market Resources’ acreage is located). The pipelines will eliminate the need for storage tanks at each location and up to 25,500 tanker-truck trips per year at peak production. Market Resources anticipates that the BLM will make a decision on its proposal in time for the 2004/2005 winter drilling season. Certain groups have sued the BLM over granting Market Resources prior winter-long exceptions to winter stipulations at Pinedale and the case is still pending.
Pinedale Anticline 20-Acre Spacing Approved
On July 13, 2004, the Wyoming Oil and Gas Conservation Commission unanimously approved 20-acre density drilling of Lance Pool (Lance and Mesaverde Formation) wells on Market Resources Pinedale Anticline acreage. The commission’s written order is expected by mid-September. Market Resources currently has 76 proved-developed producing wells at Pinedale and another 96 booked proved-undeveloped locations based on 40-acre spacing. With approval of 20-acre spacing, Market Resources expects to book incremental proved reserves on 124 additional proved-undeveloped locations, for a total of 220 locations. As a result Questar E&P expects its Pinedale reserves to increase by 250-300 bcfe by year end. There are approximately 134 additional locations that cannot be booked as proved at this time because they do not directly offset currently producing wells. Pursuant to Securities an d Exchange Commission reserve-booking guidelines, only locations that directly offset currently producing wells can be booked as proved. Market Resources believes that no further approvals will be necessary to begin 20-acre development on its leasehold. Market Resources estimates that each 20-acre-spaced well drilled and completed in the Lance and Mesaverde Formations will recover between 3.8 and 8.8 bcfe of gross incremental proved reserves.
New Pinedale Lease
Questar E&P was the high bidder on a 1,425-acre lease at the June 8, 2004, Competitive Oil and Gas Lease Sale held by the BLM. The lease includes Sections 30 and 31, T32N, R109W and adjoins the southwest side of Market Resources current 14,800 acre leasehold. The Governor of Wyoming and various environmental groups filed protests against the BLM auction of this lease and eleven other leases in the Pinedale Resource Area. The BLM has stated that it will consider the protests but believes it acted properly.
Wexpro
For the second quarter of 2004 Wexpro earned $8.8 million, compared with $8.5 million for the same period in 2003. Net income for the first half of 2004 was $17.8 million, an 11% increase over the $16.1 million earned in 2003. Wexpro manages, develops and produces gas reserves on behalf of Questar Gas. Wexpro activities are governed by a long-standing agreement (Wexpro Agreement) with the States of Utah and Wyoming. Pursuant to the Wexpro Agreement, Wexpro recovers its costs and receives an after-tax return of approximately 19% on its net investment in commercial wells and related facilities – known as the investment base – adjusted for working capital, deferred taxes, and depreciation. Wexpro’s net investment base increased to $165.3 million at June 30, 2004, up $5.0 million over the year earlier period.
Gas Gathering and Processing; Gas and Oil Marketing
Net income from gas gathering, processing and marketing operations increased 108% to $4.0 million in the second quarter of 2004 from $1.9 million in the 2003 period. Net income for the first half of 2004 was $10.0 million versus $7.2 million for the same period in 2003, an increase of 38%. Gathering volumes increased 15% to 113.3 MMdth for the first half of 2004 due primarily to increased production from the Pinedale field in western Wyoming. Pre-tax earnings from Gas Management’s 50% interest in Rendezvous increased from $2.3 million for the six months ended June 30, 2003, to $2.6 million for the comparable 2004 period. Rendezvous provides gas gathering services for the Pinedale and Jonah producing areas.
Gas Management continues to invest in additional gas gathering and processing and liquids-handling facilities to serve growing equity and third-party production in its core areas. These core areas are the Pinedale and Jonah fields in western Wyoming and the Uinta Basin in eastern Utah.
Energy Trading’s gross margins (gross revenues less the costs to purchase gas and oil, commitments to gas transportation contracts on interstate pipelines, and gas storage costs), increased to $4.1 million in the second quarter of 2004 versus $1.9 million for the year earlier period, a 110% increase. The increase was due primarily to 70% higher unit margins and a 23% increase in volumes over the same period last year.
In June 2004 Energy Trading purchased the remaining 25% interest in Clear Creek that it did not already own from Montana Power Ventures, Inc., a subsidiary of EnCana Corp., for total consideration of $1.0 million. Energy Trading is now the sole owner of Clear Creek and owns and operates the Clear Creek natural gas storage facility in southwestern Wyoming. Clear Creek has working gas storage capacity of approximately 3.0 bcf and is connected to four interstate pipelines – Kern River Gas Transmission, Northwest Pipeline, Questar Pipeline and Overthrust Pipeline.
Accounting change
On January 1, 2003, the Company adopted a new accounting standard, SFAS 143, “Accounting for Asset Retirement Obligations,” and recorded a cumulative effect that reduced net income by $5.1 million.
Liquidity and Capital Resources
Market Resources’ primary source of liquidity has historically been net cash provided by operating activities. This source has been supplemented as needed by accessing credit lines and commercial paper markets and issuing long-term debt securities.
Operating Activities
Net cash provided from operating activities increased 44% in the first half of 2004 compared with 2003 due to increased income and changes in operating assets and liabilities.
Investing Activities
Capital expenditures amounted to $96.2 million in the first half of 2004, up 68% over the 2003 period due primarily to increased well-drilling activity. Market Resources expects to spend $343.8 million in 2004 primarily focused on development drilling within Questar E&P and Wexpro, but including expenditures for gathering and processing facilities and other capital projects.
Financing Activities
Net cash flow provided from operating activities was more than sufficient to fund capital expenditures and pay dividends in the first half of 2004. The excess cash flow was used to repay debt. Total debt was 35% of total capital at June 30, 2004. Market Resources expects to finance 2004 capital expenditures with cash flow from operations.
Item 3. Quantitative and Qualitative Disclosures about Market Risk
Questar’s primary market risk exposures arise from commodity-price changes for natural gas, oil and NGL, estimation of gas and oil reserves and volatility in interest rates. Energy Trading has long-term contracts for pipeline capacity and is obligated for transportation services with no guarantee that it will be able to recover the full cost of these transportation commitments.
Commodity-Price-Risk Management
Market Resources bears the risk associated with commodity-price changes and uses gas- and oil-price hedging arrangements in the normal course of business to limit the risk of adverse price movements. However these same arrangements typically limit future gains from favorable price movements. The hedging contracts exist for a significant share of Market Resources-owned gas and oil production and for a portion of gas- and oil-marketing transactions.
Market Resources has established policies and procedures for managing commodity-price risks through the use of derivatives. Natural gas- and-oil-price hedging support Market Resources’ rate of return and cash flow targets and protect earnings from downward movements in commodity prices. The volume of hedged production and the mix of derivative instruments are regularly evaluated and adjusted by management in response to changing market conditions and reviewed periodically by Market Resources’ Board of Directors. Market Resources may hedge up to 100% of forecast nonregulated production from proved-developed reserves when prices meet earnings and cash flow objectives. Proved-developed production represents production from existing wells. Market Resources does not enter into derivative arrangements for speculative purposes and does not hedge undeveloped reserves or equity NGL.
Hedges are matched to equity gas and oil production, thus qualifying as cash-flow hedges under the accounting provisions of SFAS 133 as amended and interpreted. Gas hedges are structured as fixed-price swaps into regional pipelines, locking in basis and hedge effectiveness. The portion of hedges no longer deemed effective is immediately recognized in the income statement. The ineffective portion of hedges was not significant in 2004 and 2003.
As of June 30, 2004, approximately 67.9 bcf of forecast full-year 2004 gas production is hedged at an average price of $4.02 per Mcf, net to the well. Hedges are more heavily weighted to the Rockies to reduce basis risk and to protect returns on capital.
Market Resources enters into commodity-price hedging arrangements with several banks and energy-trading firms. Generally the contracts allow some amount of credit before Market Resources is required to deposit collateral for out-of-the-money hedges. In some contracts the amount of credit varies depending on the credit rating assigned to Market Resources’ debt. Market Resources’ current ratings support counterparty credit ranges from $5 million to $20 million. If Market Resources’ credit ratings fall below investment grade (BBB- by Standard & Poor’s or Baa3 by Moody’s), counterparty credit generally falls to zero. Questar maintains lines of credit to cover potential collateral calls. Collateral required at June 30, 2004, was $35.3 million.
A summary of Market Resources’ hedging positions for equity production as of June 30, 2004, is shown below. Prices are net to the well. Currently all hedges are fixed-price swaps with creditworthy counterparties, which allows Market Resources to achieve a known price for a specific volume of production delivered into a regional sales point, i.e., incorporating a known basis. The swap price is then reduced by gathering costs and adjusted for product quality to determine the net-to-the-well price.
Rocky | Rocky | ||||||
Time periods | Mountains | Midcontinent | Total | Mountains | Midcontinent | Total | |
| Gas (in bcf) | Average price per Mcf, net to the well | |||||
Second half of 2004 | 21.0 | 12.1 | 33.1 | $ 3.69 | $ 4.53 | $ 4.00 | |
First half of 2005 | 16.5 | 7.7 | 24.2 | $ 4.07 | $ 4.44 | $ 4.19 | |
Second half of 2005 | 16.7 | 7.8 | 24.5 | 4.07 | 4.44 | 4.19 | |
12 months of 2005 | 33.2 | 15.5 | 48.7 | 4.07 | 4.44 | 4.19 | |
First half of 2006 | 5.5 | 1.6 | 7.1 | $ 4.53 | $ 4.81 | $ 4.59 | |
Second half of 2006 | 5.5 | 1.7 | 7.2 | 4.53 | 4.81 | 4.59 | |
12 months of 2006 | 11.0 | 3.3 | 14.3 | 4.53 | 4.81 | 4.59 | |
Oil (in Mbbl) | Average price per bbl, net to the well | ||||||
Second half of 2004 | 552 | 184 | 736 | $30.91 | $31.22 | $30.99 | |
First half of 2005 | 272 | 90 | 362 | $31.71 | $30.20 | $31.33 | |
Second half of 2005 | 276 | 92 | 368 | 31.71 | 30.20 | 31.33 | |
12 months of 2005 | 548 | 182 | 730 | 31.71 | 30.20 | 31.33 | |
Market Resources held gas-price hedging contracts covering the price exposure for about 139.1 MMdth of gas and 1.5 MMbbl of oil as of June 30, 2004. A year earlier Market Resources’ hedging contracts covered 127.3 MMdth of natural gas and 552,000 bbl of oil.
The following table summarizes changes in the fair value of hedging contracts from December 31, 2003, to June 30, 2004.
A table of the net fair value of gas-hedging contracts as of June 30, 2004, is shown below. About 60% of the volumes and 76% of the fair value of all contracts will settle and be reclassified from other comprehensive income in the next 12 months.
The following table shows sensitivity of the mark-to-market valuation of gas and oil price-hedging contracts to changes in the market price of gas and oil.
At June 30, | ||
2004 | 2003 | |
(in millions) | ||
|
| |
Mark-to-market valuation – asset (liability) | ($115.4) | ($62.2) |
Value if market prices of gas and oil decline by 10% | (55.6) | (24.6) |
Value if market prices of gas and oil increase by 10% | (175.1) | (99.7) |
Interest-Rate Risk Management
As of June 30, 2004, Market Resources had $350 million of fixed-rate long-term debt and no variable-rate long-term debt.
Item 4. Controls and Procedures
a. Evaluation of Disclosure Controls and Procedures. The Company’s Chief Executive Officer and Chief Financial Officer have evaluated the effectiveness of the Company’s disclosure controls and procedures (as such term is defined in Rules 13a-14(c) and 15d-14(c) under the Securities Exchange Act of 1934, as amended (the "Exchange Act")) as of a date within 90 days prior to the filing date of this quarterly report (the "Evaluation Date"). Based on such evaluation, such officers have concluded that, as of the Evaluation Date, the Company’s disclosure controls and procedures are effective in alerting them on a timely basis to material information relating to the Company, including its consolidated subsidiaries, required to be included in the Company’s reports filed or submitted under the Exchange Act.
b. Changes in Internal Controls. Since the Evaluation Date, there have not been any significant changes in the Company’s internal controls or in other factors that could significantly affect such controls.
Part II
OTHER INFORMATION
During the second quarter of 2004, the Environmental Protection Agency ("EPA") issued two separate compliance orders alleging that Questar Gas Management Company, a direct subsidiary of the Company, failed to comply with regulatory requirements adopted to enforce the federal Clean Air Act. Both orders involve facilities in the Uinta Basin of eastern Utah that were owned by Shenandoah Energy, Inc., before its purchase by the Company in mid-2001. Questar Gas Management is currently operating the facilities and filing necessary reports in compliance with regulatory requirements. It is discussing the allegations with the EPA and expects to be required to pay a civil penalty in excess of $100,000 in conjunction with each order.
Martin H. Craven, age 52, was elected to serve as the Company's Treasurer effective May 18, 2004. He replaces S. E. Parks who will continue to serve as the Company's Chief Financial Officer. Mr. Craven also serves as Treasurer of Questar Corporation and all affiliates.
Item 6. Exhibits and Reports on Form 8-K
a.
The following exhibits are filed as part of this report.
Exhibit No.
Exhibit
31.1.
Certification signed by Charles B. Stanley, the Company's Chief Executive Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2.
Certification signed by S. E. Parks, the Company's Chief Financial Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
b.
The Company did not file any Current Reports on Form 8-K during the second quarter of 2004.
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.
QUESTAR MARKET RESOURCES, INC.
(Registrant)
August 12, 2004
/s/C. B. Stanley
Date
C. B. Stanley
President and Chief Executive Officer
August 12, 2004
/s/S. E. Parks
Date
S. E. Parks
Vice President and Chief Financial Officer
Exhibits List
Exhibit No.
Exhibit
31.1.
Certification signed by C. B. Stanley, the Company's Chief Executive Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2.
Certification signed by S. E. Parks, the Company's Chief Financial Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
Exhibit No. 31.1.
CERTIFICATION
I, Charles B. Stanley, certify that:
1.
I have reviewed this quarterly report on Form 10-Q of Questar Market Resources, Inc.
2.
Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this quarterly report.
3.
Based on my knowledge, the financial statements, and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this quarterly report.
4.
The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:
a)
designed such disclosure controls and procedures to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this quarterly report is being prepared;
b)
evaluated the effectiveness of the registrant's disclosure controls and procedures as of a date within 90 days prior to the filing date of this quarterly report (the "Evaluation Date"); and
c)
presented in this quarterly report our conclusions about the effectiveness of the disclosure controls and procedures based on our evaluation as of the Evaluation Date;
5.
The registrant's other certifying officer and I have disclosed, based on our most recent evaluation, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent function);
a)
all significant deficiencies in the design or operation of internal controls that could adversely affect the registrant's ability to record, process, summarize and report financial data and have identified for the registrant's auditors any material weaknesses in internal controls; and
b)
any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal controls;
6.
The registrant's other certifying officer and I have indicated in this quarterly report whether or not there were significant changes in internal controls or in other factors that could significantly affect internal controls subsequent to the date of our most recent evaluation, including any corrective actions with regard to significant deficiencies and material weaknesses.
August 12, 2004
/s/C. B. Stanley___________________________
Date
C. B. Stanley
President and Chief Executive Officer
Exhibit No. 31.2.
CERTIFICATION
I, S. E. Parks, certify that:
1.
I have reviewed this quarterly report on Form 10-Q of Questar Market Resources, Inc.
2.
Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this quarterly report.
3.
Based on my knowledge, the financial statements, and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this quarterly report.
4.
The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:
a)
designed such disclosure controls and procedures to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this quarterly report is being prepared;
b)
evaluated the effectiveness of the registrant's disclosure controls and procedures as of a date within 90 days prior to the filing date of this quarterly report (the "Evaluation Date"); and
c)
presented in this quarterly report our conclusions about the effectiveness of the disclosure controls and procedures based on our evaluation as of the Evaluation Date;
5.
The registrant's other certifying officer and I have disclosed, based on our most recent evaluation, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent function);
a)
all significant deficiencies in the design or operation of internal controls that could adversely affect the registrant's ability to record, process, summarize and report financial data and have identified for the registrant's auditors any material weaknesses in internal controls; and
b)
any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal controls;
6.
The registrant's other certifying officer and I have indicated in this quarterly report whether or not there were significant changes in internal controls or in other factors that could significantly affect internal controls subsequent to the date of our most recent evaluation, including any corrective actions with regard to significant deficiencies and material weaknesses.
August 12, 2004
/s/ S. E. Parks_______________________________________
Date
S. E. Parks
Vice President and Chief Financial Officer
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