-
Increased crude oil production by 55% over the first quarter 2013 to
37 Mbod driven by
Williston Basin oil production growth of nearly 100%. - Grew crude oil production to 27% of total production from 16% in the first quarter 2013.
- Delivered significant year-over-year increases in Net Income, Adjusted Net Income and Adjusted EBITDA.
-
Acquired Permian Basin assets (the "Permian Basin Acquisition") for approximately$945 million with early drilling and production results surpassing initial expectations. -
Entered into definitive agreements to sell multiple non-core E&P
assets for an aggregate price of
$807 million , subject to customary adjustments. -
Entered into a definitive agreement to sell a 40% equity interest in
QEP's affiliate
Green River Processing, LLC toQEP Midstream Partners, LP (“QEPM”) for an aggregate price of$230 million .
Net income or loss includes non-cash gains and losses associated with
the change in the fair value of derivative instruments, gains and losses
from asset sales, and impairment charges. Excluding these items, the
Company’s Adjusted Net Income (a non-GAAP measure) was
Adjusted EBITDA (a non-GAAP measure) for the first quarter 2014 was
“During the first quarter we made substantial progress on positioning
QEP to have a more focused asset portfolio with significant positions in
high-return, high-margin crude oil and liquids-rich gas plays,”
commented
"The announced sales of non-core E&P assets, totaling approximately
"As we continue to make progress on the previously-announced separation of our midstream business, the underlying performance of the business remains strong. In the quarter, we initiated multiple expansion projects and delivered a processing margin that was at the highest level in two years."
"We continue to maintain our relentless focus on shareholder value
creation through growing crude oil production from our
Slides for the first quarter 2014 with maps and other supporting materials referred to in this release are posted on the Company’s website at www.qepres.com.
QEP Financial Results Summary
Adjusted EBITDA by Subsidiary(1) | |||||||||||||||||||||
Three Months Ended | |||||||||||||||||||||
March 31, | |||||||||||||||||||||
2014 | 2013 | Change | |||||||||||||||||||
(in millions) | |||||||||||||||||||||
QEP Energy | $ | 331.8 | $ | 323.7 | 3 | % | |||||||||||||||
QEP Field Services | 53.2 | 53.2 | — | % | |||||||||||||||||
QEP Marketing and Resources | 1.3 | (1.9 | ) | 168 | % | ||||||||||||||||
Adjusted EBITDA | $ | 386.3 | $ | 375.0 | 3 | % | |||||||||||||||
|
(1) | See attached financial tables of this release for a reconciliation of Adjusted EBITDA to net income attributable to QEP. | |
QEP Energy
-
Net natural gas equivalent production decreased by 6% to 73.7 Bcfe in
the first quarter 2014 compared to 78.0 Bcfe in the first quarter
2013, due primarily to decreased gas production in the Haynesville,
Midcontinent and Pinedale areas offset by increased crude oil and NGL
production in the
Williston Basin and the addition ofPermian Basin Acquisition production during the month of March. Crude oil and NGL production increased 55% and 41%, respectively, while natural gas production decreased 24%, in the first quarter 2014, compared to 2013. - Adjusted EBITDA increased 3% compared to the first quarter 2013, driven by increases in crude oil and NGL production volumes and a 10% increase in the net realized price for natural gas. This increase was partially offset by an 11% and 12% decrease in the net realized prices of crude oil and NGLs, respectively.
- Crude oil and NGL revenues increased 44% compared to the first quarter 2013, and represented approximately 61% of field-level production revenues.
-
QEP Energy's capital investment (on an accrual basis) for the first
three months of 2014, excluding the
$945.0 million related to the Permian Basin Acquisition, was$318.2 million .
QEP Field Services
-
QEP Field Services’ Adjusted EBITDA during the first quarter 2014 was
equal to the prior-year period. The first quarter 2014 Adjusted EBITDA
was driven primarily by an increase in processing margin of
$16.5 million , offset by a 13% decrease in natural gas gathering volumes as a result of declining dry gas production volumes on the Haynesville gathering system. -
QEP Field Services' capital investment (on an accrual basis) for the
first quarter of 2014 totaled
$21.5 million .
QEP 2014 Guidance
Guidance and Assumptions | |||||||||||||
2014 | 2014 | ||||||||||||
Previous Forecast | Asset sale Impact |
Forecast Revision(1) |
Current Forecast | ||||||||||
QEP Energy oil production (MMBbl) | 14.0 - 15.0 | (0.3) | 0.5 | 14.2 - 15.2 | |||||||||
QEP Energy NGL production (MMBbl) | 4.0 - 4.5 | (0.7) | 0.5 | 3.8 - 4.3 | |||||||||
QEP Energy natural gas production (Bcf) | 175 - 190 | (9) | 0 | 166 - 181 | |||||||||
QEP Energy total equivalent production (Bcfe) | 283 - 307 | 274 - 298 | |||||||||||
Lease operating and transportation expense (per Mcfe) | $1.50 - $1.65 | $1.50 - $1.65 | |||||||||||
QEP Energy Depletion, Depreciation and Amortization (per Mcfe) | $3.50 - $3.80 | ($0.20) | $3.30 - $3.60 | ||||||||||
Production and property taxes, % of field-level revenue | 9% - 10% | 9% - 10% | |||||||||||
(figures below in millions) |
|||||||||||||
QEP Resources General and Administrative Expense | $190 - $210 | $190 - $210 | |||||||||||
QEP Energy capital investment(2) |
$1,650 - $1,750 | ($50) | $1,600 - $1,700 | ||||||||||
QEP Field Services capital investment | $80 | $80 | |||||||||||
Corporate and other capital investment | $25 | $25 | |||||||||||
Total QEP Resources capital investment | $1,755 - $1,855 | $1,705 - $1,805 |
(1) |
Revision of forecast for retained assets |
|
(2) |
Excludes acquisitions |
|
Operations Summary
QEP Energy
At the end of the first quarter, QEP Energy had eight operated rigs
running in the
Slides 6-8 depict QEP Energy's acreage and activity in the Bakken/Three Forks play.
QEP Energy closed the previously-announced
At end of first quarter, QEP Energy had three operated rigs in the
Slide 9 depicts QEP Energy's acreage and activity in the northern
Pinedale Anticline:
During the first quarter 2014, QEP Energy's Pinedale net production
averaged 232 MMcfed (24% liquids). QEP Energy began recovering ethane
from Pinedale production on
The Company completed and turned to sales 22 gross Pinedale wells during the first quarter 2014, including one well for which QEP Energy was the operator but owns only a small overriding royalty interest. In 2014, Pinedale completions will focus on those areas of the field where QEP Energy has a majority working interest. QEP Energy suspends Pinedale completion operations during the coldest months of the winter, generally from December to mid-February. At the end of the first quarter, the Company had 55 gross Pinedale wells with QEP working interests drilled, cased and waiting on completion (average working interest 83%).
Drilling and completion efficiencies have allowed QEP Energy to maintain industry-leading average well costs at Pinedale. In the first quarter, drill times from spud to total depth averaged 11.3 days, compared to an average of 12.0 days in 2013. At the end of the first quarter, QEP Energy had four rigs operating at Pinedale. The Company currently expects to complete a total of approximately 110 - 115 gross wells during 2014, including approximately ten wells for which QEP Energy is the designated operator but owns only a small overriding royalty interest.
Please refer to slides 10-11 for additional details on the Company's Pinedale operations.
During the first quarter 2014,
At the end of the first quarter, the Company had one operated drilling rig working in the Lower Mesaverde play, 81 producing wells in the play, and one well waiting on completion (working interest 100%). QEP Energy has over 3,200 potential remaining locations in this liquids-rich gas resource play. At the end of the first quarter, the Company was drilling its third Lower Mesaverde well with a fundamentally different design that could considerably alter the well economics and lead to an accelerated development approach.
Slide 12 depicts QEP Energy's acreage and additional details of the Lower Mesaverde play.
QEP Field Services
During the first quarter 2014 QEP Field Services' processing margin
(total processing plant revenues less shrink, transportation,
fractionation, and operating expenses) was
Gathering margin declined 10% in the first quarter of 2014 compared to the first quarter of 2013, due to a 13% decrease in gathering system throughput. Gathering system throughput volumes decreased primarily as a result of a 42% decline at QEP Field Services' Northwest Louisiana Hub primarily due to lower QEP Energy production resulting from the ongoing suspension of drilling in the Haynesville, as well as lower gathering volumes on the Uinta gathering system and QEPM's Vermillion gathering system. Approximately 69% and 83% of QEP Field Services' total margin was derived from fee-based gathering and processing agreements in the first quarter 2014 and 2013, respectively.
As a result of the initial public offering of QEPM, QEP Field Services
saw an increase in net income attributable to noncontrolling interest.
For the first quarter 2014, this change resulted in negative impacts on
QEP's net income and Adjusted EBITDA of
First Quarter 2014 Results Conference Call
QEP Resources’ management will discuss first quarter 2014 results in a
conference call on
About
Forward-Looking Statements
This release 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.
Forward-looking statements can be identified by words such as
“anticipates,” “believes,” “forecasts,” “plans,” “estimates,” “expects,”
“should,” “will” or other similar expressions. Such statements are based
on management’s current expectations, estimates and projections, which
are subject to a wide range of uncertainties and business risks. These
forward-looking statements include statements regarding: forecasted
production, lease operating and transportation expense, DD&A expense,
general and administrative expense, property taxes and capital
investment for 2014 and related assumptions for such guidance; plans to
drill and complete wells; cost reductions in the
Disclosures regarding Estimated Ultimate Recovery (EUR)
QEP RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) |
|||||||||||||
Three Months Ended | |||||||||||||
March 31, | |||||||||||||
2014 | 2013 | ||||||||||||
REVENUES | (in millions except per share data) | ||||||||||||
Gas sales | $ | 222.5 | $ | 197.6 | |||||||||
Oil sales | 288.7 | 194.2 | |||||||||||
NGL sales | 101.1 | 68.4 | |||||||||||
Gathering, processing and other | 44.4 | 45.6 | |||||||||||
Purchased gas, oil and NGL sales | 227.2 | 190.7 | |||||||||||
Total Revenues | 883.9 | 696.5 | |||||||||||
OPERATING EXPENSES | |||||||||||||
Purchased gas, oil and NGL expense | 224.3 | 196.8 | |||||||||||
Lease operating expense | 55.3 | 40.1 | |||||||||||
Gas, oil and NGL transportation and other handling costs | 43.4 | 32.8 | |||||||||||
Gathering, processing and other | 25.8 | 20.6 | |||||||||||
General and administrative | 56.6 | 46.0 | |||||||||||
Production and property taxes | 49.3 | 35.9 | |||||||||||
Depreciation, depletion and amortization | 240.2 | 254.2 | |||||||||||
Exploration expenses | 2.2 | 5.1 | |||||||||||
Impairment | 2.0 | — | |||||||||||
Total Operating Expenses | 699.1 | 631.5 | |||||||||||
Net gain (loss) from asset sales | 2.4 | (0.2 | ) | ||||||||||
OPERATING INCOME | 187.2 | 64.8 | |||||||||||
Realized and unrealized losses on derivative contracts | (80.9 | ) | (34.6 | ) | |||||||||
Interest and other income | 2.9 | 2.0 | |||||||||||
Income from unconsolidated affiliates | 2.2 | 1.3 | |||||||||||
Interest expense | (42.5 | ) | (39.4 | ) | |||||||||
INCOME (LOSS) BEFORE INCOME TAXES | 68.9 | (5.9 | ) | ||||||||||
Income tax (provision) benefit | (23.4 | ) | 2.2 | ||||||||||
NET INCOME (LOSS) | 45.5 | (3.7 | ) | ||||||||||
Net income attributable to noncontrolling interest | (5.8 | ) | (0.6 | ) | |||||||||
NET INCOME (LOSS) ATTRIBUTABLE TO QEP | $ | 39.7 | $ | (4.3 | ) | ||||||||
Earnings Per Common Share Attributable to QEP | |||||||||||||
Basic total | $ | 0.22 | $ | (0.02 | ) | ||||||||
Diluted total | $ | 0.22 | $ | (0.02 | ) | ||||||||
Weighted-average common shares outstanding | |||||||||||||
Used in basic calculation | 179.7 | 177.0 | |||||||||||
Used in diluted calculation | 180.0 | 177.0 | |||||||||||
Dividends per common share | $ | 0.02 | $ | 0.02 | |||||||||
QEP RESOURCES, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) |
||||||||||||||
March 31, |
December 31, |
|||||||||||||
ASSETS | (in millions) | |||||||||||||
Current Assets | ||||||||||||||
Cash and cash equivalents | $ | 3.9 | $ | 11.9 | ||||||||||
Accounts receivable, net | 586.5 | 408.5 | ||||||||||||
Fair value of derivative contracts | — | 0.2 | ||||||||||||
Gas, oil and NGL inventories, at lower of average cost or market | 7.8 | 13.4 | ||||||||||||
Deferred income taxes - current | 50.4 | 30.6 | ||||||||||||
Prepaid expenses and other | 61.8 | 54.4 | ||||||||||||
Total Current Assets | 710.4 | 519.0 | ||||||||||||
Property, Plant and Equipment (successful efforts method for gas and oil properties) | ||||||||||||||
Proved properties | 12,401.4 | 11,571.4 | ||||||||||||
Unproved properties | 1,102.5 | 665.1 | ||||||||||||
Midstream field services | 1,719.2 | 1,698.1 | ||||||||||||
Marketing and resources | 89.4 | 85.5 | ||||||||||||
Material and supplies | 64.8 | 59.0 | ||||||||||||
Total Property, Plant and Equipment | 15,377.3 | 14,079.1 | ||||||||||||
Less Accumulated Depreciation, Depletion and Amortization | ||||||||||||||
Exploration and production | 5,146.5 | 4,930.9 | ||||||||||||
Midstream field services | 425.0 | 409.7 | ||||||||||||
Marketing and resources | 24.2 | 22.1 | ||||||||||||
Total Accumulated Depreciation, Depletion and Amortization | 5,595.7 | 5,362.7 | ||||||||||||
Net Property, Plant and Equipment | 9,781.6 | 8,716.4 | ||||||||||||
Investment in unconsolidated affiliates | 38.5 | 39.0 | ||||||||||||
Fair value of derivative contracts | 3.9 | 1.0 | ||||||||||||
Restricted Cash | — | 50.0 | ||||||||||||
Other noncurrent assets | 45.2 | 51.4 | ||||||||||||
TOTAL ASSETS | $ | 10,579.6 | $ | 9,376.8 | ||||||||||
LIABILITIES AND EQUITY | ||||||||||||||
Current Liabilities | ||||||||||||||
Checks outstanding in excess of cash balances | $ | 78.4 | $ | 90.9 | ||||||||||
Accounts payable and accrued expenses | 581.0 | 434.9 | ||||||||||||
Production and property taxes | 62.3 | 51.8 | ||||||||||||
Interest payable | 34.2 | 37.2 | ||||||||||||
Fair value of derivative contracts | 71.8 | 26.7 | ||||||||||||
Total Current Liabilities | 827.7 | 641.5 | ||||||||||||
Long-term debt | 3,919.2 | 2,997.5 | ||||||||||||
Deferred income taxes | 1,601.7 | 1,560.6 | ||||||||||||
Asset retirement obligations | 204.3 | 191.8 | ||||||||||||
Fair value of derivative contracts | 2.9 | — | ||||||||||||
Other long-term liabilities | 108.1 | 108.6 | ||||||||||||
Commitments and contingencies (see Note 11) | ||||||||||||||
EQUITY | ||||||||||||||
Common stock - par value $0.01 per share; 500.0 million shares
authorized; 180.7 million and 179.7 million shares issued, respectively |
1.8 | 1.8 | ||||||||||||
Treasury stock - 0.6 million and 0.4 million shares, respectively | (20.9 | ) | (14.9 | ) | ||||||||||
Additional paid-in capital | 508.1 | 498.4 | ||||||||||||
Retained earnings | 2,953.8 | 2,917.8 | ||||||||||||
Accumulated other comprehensive loss | (25.5 | ) | (26.5 | ) | ||||||||||
Total Common Shareholders' Equity | 3,417.3 | 3,376.6 | ||||||||||||
Noncontrolling interest | 498.4 | 500.2 | ||||||||||||
Total Equity | 3,915.7 | 3,876.8 | ||||||||||||
TOTAL LIABILITIES AND EQUITY | $ | 10,579.6 | $ | 9,376.8 | ||||||||||
QEP RESOURCES, INC.
CONSOLIDATED CASH FLOWS (Unaudited) |
||||||||||||||
Three Months Ended | ||||||||||||||
March 31, | ||||||||||||||
2014 | 2013 | |||||||||||||
(in millions) | ||||||||||||||
OPERATING ACTIVITIES | ||||||||||||||
Net income (loss) | $ | 45.5 | $ | (3.7 | ) | |||||||||
Adjustments to reconcile net income to net cash provided by operating activities: | ||||||||||||||
Depreciation, depletion and amortization | 240.2 | 254.2 | ||||||||||||
Deferred income taxes | 20.7 | (9.3 | ) | |||||||||||
Impairment | 2.0 | — | ||||||||||||
Equity-based compensation | 6.8 | 6.1 | ||||||||||||
Amortization of debt issuance costs and discounts | 1.7 | 1.5 | ||||||||||||
Net (gain) loss from asset sales | (2.4 | ) | 0.2 | |||||||||||
Income from unconsolidated affiliates | (2.2 | ) | (1.3 | ) | ||||||||||
Distributions from unconsolidated affiliates and other | 2.7 | 1.5 | ||||||||||||
Unrealized loss on derivative contracts | 45.5 | 85.3 | ||||||||||||
Changes in operating assets and liabilities | (38.1 | ) | (162.4 | ) | ||||||||||
Net Cash Provided by Operating Activities | 322.4 | 172.1 | ||||||||||||
INVESTING ACTIVITIES | ||||||||||||||
Property acquisitions | (946.6 | ) | (23.6 | ) | ||||||||||
Property, plant and equipment, including dry exploratory well expense | (330.2 | ) | (361.0 | ) | ||||||||||
Proceeds from disposition of assets | 2.9 | 1.5 | ||||||||||||
Acquisition deposit held in escrow | 50.0 | — | ||||||||||||
Net Cash Used in Investing Activities | (1,223.9 | ) | (383.1 | ) | ||||||||||
FINANCING ACTIVITIES | ||||||||||||||
Checks outstanding in excess of cash balances | (12.5 | ) | 60.0 | |||||||||||
Long-term debt issued | 300.0 | — | ||||||||||||
Long-term debt issuance costs paid | (1.1 | ) | — | |||||||||||
Proceeds from credit facility | 1,643.0 | 1,027.0 | ||||||||||||
Repayments of credit facility | (1,021.5 | ) | (866.5 | ) | ||||||||||
Treasury stock repurchases | (5.5 | ) | (7.5 | ) | ||||||||||
Other capital contributions | 2.9 | 2.1 | ||||||||||||
Dividends paid | (3.6 | ) | (3.6 | ) | ||||||||||
Excess tax benefit on equity-based compensation | (0.6 | ) | 1.0 | |||||||||||
Distribution to noncontrolling interest | (7.6 | ) | (1.5 | ) | ||||||||||
Net Cash Provided by Financing Activities | 893.5 | 211.0 | ||||||||||||
Change in cash and cash equivalents | (8.0 | ) | — | |||||||||||
Beginning cash and cash equivalents | 11.9 | — | ||||||||||||
Ending cash and cash equivalents | $ | 3.9 | $ | — | ||||||||||
QEP RESOURCES, INC. OPERATIONS BY LINE OF BUSINESS (Unaudited) |
||||||||||||||||||||||||||
QEP Energy - Production by Region |
||||||||||||||||||||||||||
Three Months Ended | ||||||||||||||||||||||||||
March 31, | ||||||||||||||||||||||||||
(in Bcfe) | ||||||||||||||||||||||||||
2014 | 2013 | Change | ||||||||||||||||||||||||
Northern Region |
||||||||||||||||||||||||||
Pinedale | 20.9 | 21.7 | (4 | )% | ||||||||||||||||||||||
Williston Basin | 16.8 | 9.0 | 87 | % | ||||||||||||||||||||||
Uinta Basin | 6.2 | 5.8 | 7 | % | ||||||||||||||||||||||
Other Northern | 2.5 | 3.5 | (29 | )% | ||||||||||||||||||||||
Total Northern Region | 46.4 | 40.0 | 16 | % | ||||||||||||||||||||||
Southern Region |
||||||||||||||||||||||||||
Haynesville/Cotton Valley | 14.4 | 22.3 | (35 | )% | ||||||||||||||||||||||
Permian Basin | 1.2 | — | — | % | ||||||||||||||||||||||
Midcontinent | 11.7 | 15.7 | (25 | )% | ||||||||||||||||||||||
Total Southern Region | 27.3 | 38.0 | (28 | )% | ||||||||||||||||||||||
Total production | 73.7 | 78.0 | (6 | )% | ||||||||||||||||||||||
QEP Energy - Total Production | ||||||||||||||||||
Three Months Ended | ||||||||||||||||||
March 31, | ||||||||||||||||||
2014 | 2013 | Change | ||||||||||||||||
QEP Energy Production Volumes | ||||||||||||||||||
Gas (Bcf) | 44.5 | 58.5 | (24 | )% | ||||||||||||||
Oil (Mbbl) | 3,312.0 | 2,138.9 | 55 | % | ||||||||||||||
NGL (Mbbl) | 1,568.3 | 1,108.5 | 41 | % | ||||||||||||||
Total production (Bcfe) | 73.7 | 78.0 | (6 | )% | ||||||||||||||
Average daily production (MMcfe) | 819.3 | 866.4 | (5 | )% | ||||||||||||||
QEP Energy - Prices | ||||||||||||||||||||||||||
Three Months Ended | ||||||||||||||||||||||||||
March 31, | ||||||||||||||||||||||||||
2014 | 2013 | Change | ||||||||||||||||||||||||
Gas (per Mcf) | ||||||||||||||||||||||||||
Average field-level price | $ | 5.00 | $ | 3.38 | ||||||||||||||||||||||
Commodity derivative impact | (0.46 | ) | 0.76 | |||||||||||||||||||||||
Net realized price | $ | 4.54 | $ | 4.14 | 10 | % | ||||||||||||||||||||
Oil (per bbl) | ||||||||||||||||||||||||||
Average field-level price | $ | 87.16 | $ | 90.81 | ||||||||||||||||||||||
Commodity derivative impact | (3.91 | ) | 2.43 | |||||||||||||||||||||||
Net realized price | $ | 83.25 | $ | 93.24 | (11 | )% | ||||||||||||||||||||
NGL (per bbl) | ||||||||||||||||||||||||||
Average field-level price | $ | 40.26 | $ | 45.64 | ||||||||||||||||||||||
Commodity derivative impact | — | — | ||||||||||||||||||||||||
Net realized price | $ | 40.26 | $ | 45.64 | (12 | )% | ||||||||||||||||||||
Average net equivalent price (per Mcfe) | ||||||||||||||||||||||||||
Average field-level price | $ | 7.79 | $ | 5.67 | ||||||||||||||||||||||
Commodity derivative impact | (0.45 | ) | 0.64 | |||||||||||||||||||||||
Net realized price | $ | 7.34 | $ | 6.31 | 16 | % | ||||||||||||||||||||
QEP Energy - Operating Expenses | |||||||||||||||||||||||||
Three Months Ended | |||||||||||||||||||||||||
March 31, | |||||||||||||||||||||||||
2014 | 2013 | Change | |||||||||||||||||||||||
(per Mcfe) | |||||||||||||||||||||||||
Depreciation, depletion and amortization | $ | 3.03 | $ | 3.05 | (1 | )% | |||||||||||||||||||
Lease operating expense | 0.76 | 0.53 | 43 | % | |||||||||||||||||||||
Gas, oil and NGL transport & other handling costs | 0.88 | 0.72 | 22 | % | |||||||||||||||||||||
Production taxes | 0.65 | 0.44 | 48 | % | |||||||||||||||||||||
Total Operating Expenses | $ | 5.32 | $ | 4.74 | 12 | % | |||||||||||||||||||
Three Months Ended | ||||||||||||||||||
March 31, | ||||||||||||||||||
2014 | 2013 | Change | ||||||||||||||||
QEP Field Services Gathering Operating Statistics | ||||||||||||||||||
Gas gathering volumes (millions of MMBtu) | 97.3 | 111.3 | (13 | )% | ||||||||||||||
Gathering revenue (per MMBtu) | $ | 0.34 | $ | 0.34 | — | % | ||||||||||||
QEP Field Services Gathering Margin (in millions) | ||||||||||||||||||
Gathering revenue | $ | 32.6 | $ | 37.6 | (13 | )% | ||||||||||||
Other Gathering revenue | 11.1 | 10.2 | 9 | % | ||||||||||||||
Gathering expense | (10.0 | ) | (10.3 | ) | (3 | )% | ||||||||||||
Gathering margin | $ | 33.7 | $ | 37.5 | (10 | )% | ||||||||||||
QEP Field Services Processing Margin (in millions) | ||||||||||||||||||
NGL sales | $ | 38.0 | $ | 17.8 | 113 | % | ||||||||||||
Processing (fee-based) revenues | 16.0 | 16.4 | (2 | )% | ||||||||||||||
Other processing revenues | 8.1 | 4.9 | 65 | % | ||||||||||||||
Processing expense | (4.4 | ) | (4.1 | ) | 7 | % | ||||||||||||
Processing plant fuel and shrink expense | (11.3 | ) | (5.9 | ) | 92 | % | ||||||||||||
Gas, oil and NGL transport & other handling costs | (3.6 | ) | (2.8 | ) | 29 | % | ||||||||||||
Processing margin | $ | 42.8 | $ | 26.3 | 63 | % | ||||||||||||
Keep-whole margin(1) | $ | 23.1 | $ | 9.1 | 154 | % | ||||||||||||
QEP Field Services Processing Operating Statistics | ||||||||||||||||||
NGL sales (MBbls) | 669.2 | 341.1 | 96 | % | ||||||||||||||
Average net realized NGL sales price (per Bbl)(2) | $ | 56.78 | $ | 52.32 | 9 | % | ||||||||||||
Total fee-based processing volumes (in millions of MMBtu) | 54.7 | 53.7 | 2 | % | ||||||||||||||
Average fee-based processing revenue (per MMBtu) | $ | 0.29 | $ | 0.31 | (6 | )% |
(1) | Keep-whole margin is calculated as NGL sales less processing plant fuel and shrink, natural gas, oil and NGL transportation & other handling costs. | |
(2) | Average net realized NGL sales price per barrel is calculated as NGL sales including realized gains from commodity derivative contracts settlements divided by NGL sales volumes. | |
QEP RESOURCES, INC. |
NON-GAAP MEASURES |
(Unaudited) |
This release contains references to the non-GAAP measure of Adjusted EBITDA. Management believes Adjusted EBITDA is an important measure of the Company’s cash flow, liquidity, and ability to incur and service debt, fund capital expenditures and make distributions to shareholders. The use of this measure allows investors to understand how management evaluates financial performance to make operating decisions and allocates resources. It is also an important measure for comparing the Company’s financial performance to other gas and oil producing companies. Management defines Adjusted EBITDA as earnings before interest, income taxes, depreciation, depletion and amortization (EBITDA) adjusted to exclude changes in fair value of derivative contracts, exploration expenses, gains and losses from asset sales, impairment, and certain other non-cash and/or non-recurring items. The following tables reconcile QEP Resources’ and its subsidiaries’ net income attributable to QEP to Adjusted EBITDA:
QEP Energy |
QEP Field |
QEP Marketing |
QEP Resources | |||||||||||||||||
Three Months Ended March 31, 2014 | (in millions) | |||||||||||||||||||
Net income attributable to QEP | 9.5 | 25.4 | 4.8 | 39.7 | ||||||||||||||||
Unrealized losses on derivative contracts | 45.2 | — | 0.3 | 45.5 | ||||||||||||||||
Net gain from asset sales | (2.4 | ) | — | — | (2.4 | ) | ||||||||||||||
Interest and other income | (2.9 | ) | — | — | (2.9 | ) | ||||||||||||||
Income tax provision | 5.9 | 14.6 | 2.9 | 23.4 | ||||||||||||||||
Interest expense (income) (1) | 48.9 | 0.4 | (7.0 | ) | 42.3 | |||||||||||||||
Depreciation, depletion and amortization (2) | 223.4 | 12.8 | 0.3 | 236.5 | ||||||||||||||||
Impairment | 2.0 | — | — | 2.0 | ||||||||||||||||
Exploration expenses | 2.2 | — | — | 2.2 | ||||||||||||||||
Adjusted EBITDA | 331.8 | 53.2 | 1.3 | 386.3 | ||||||||||||||||
Three Months Ended March 31, 2013 | ||||||||||||||||||||
Net (loss) income attributable to QEP | (29.8 | ) | 21.6 | 3.9 | (4.3 | ) | ||||||||||||||
Unrealized losses on derivative contracts | 84.0 | — | 1.3 | 85.3 | ||||||||||||||||
Net (gain) loss from asset sales | (0.1 | ) | 0.3 | — | 0.2 | |||||||||||||||
Interest and other income | (1.7 | ) | (0.3 | ) | — | (2.0 | ) | |||||||||||||
Income tax (benefit) provision | (17.2 | ) | 12.5 | 2.5 | (2.2 | ) | ||||||||||||||
Interest expense | 45.3 | 4.0 | (9.9 | ) | 39.4 | |||||||||||||||
Depreciation, depletion and amortization (2) | 238.1 | 15.1 | 0.3 | 253.5 | ||||||||||||||||
Exploration expenses | 5.1 | — | — | 5.1 | ||||||||||||||||
Adjusted EBITDA | 323.7 | 53.2 | (1.9 | ) | 375.0 | |||||||||||||||
|
(1) | Excludes noncontrolling interest's share, of $0.2 million during the three months ended March 31, 2014, of interest expense attributable to QEP Midstream. | |
(2) | Excludes noncontrolling interests' share of $3.7 and $0.7 million during the three months ended March 31, 2014 and 2013, respectively. | |
This release also contains references to the non-GAAP measure of Adjusted Net Income. Management defines Adjusted Net Income as earnings excluding gains and losses from asset sales, unrealized gains and losses on derivative contracts, accrued litigation loss contingency, costs from early extinguishment of debt and asset impairments. Management believes Adjusted Net Income is an important measure of the Company’s operational performance relative to other gas and oil producing companies.
The following table reconciles net income attributable to QEP Resources’ to Adjusted Net Income:
Three Months Ended | ||||||||||||||
March 31, | ||||||||||||||
2014 | 2013 | |||||||||||||
(in millions, except per earnings per share) | ||||||||||||||
Net income (loss) attributable to QEP | $ | 39.7 | $ | (4.3 | ) | |||||||||
Adjustments to net income (loss) | ||||||||||||||
Net (gain) loss from asset sales | (2.4 | ) | 0.2 | |||||||||||
Income tax provision (benefit) from asset sales | 0.9 | (0.1 | ) | |||||||||||
Unrealized loss on derivative contracts | 45.5 | 85.3 | ||||||||||||
Income tax (benefit) on unrealized loss on derivative contracts | (16.9 | ) | (31.7 | ) | ||||||||||
Impairment Charges | 2.0 | — | ||||||||||||
Income tax (benefit) on non-cash price-related impairment charge | (0.7 | ) | — | |||||||||||
Total after-tax adjustments to net income | 28.4 | 53.7 | ||||||||||||
Adjusted net income attributable to QEP Resources | $ | 68.1 | $ | 49.4 | ||||||||||
Earnings per Common Share attributable to QEP | ||||||||||||||
Diluted earnings per share | $ | 0.22 | $ | (0.02 | ) | |||||||||
Diluted after-tax adjustments to net income per share | 0.16 | 0.30 | ||||||||||||
Diluted Adjusted Net Income per share | $ | 0.38 | $ | 0.28 | ||||||||||
Weighted-average common shares outstanding | ||||||||||||||
Diluted(1) |
180.0 | 177.3 | ||||||||||||
Weighted-average common shares outstanding diluted Non-GAAP reconciliation(1) | ||||||||||||||
Weighted-average common shares outstanding used in GAAP diluted calculation | 177.0 | |||||||||||||
Potential number of shares issuable upon exercise of in-the-money stock options under the long-term stock incentive plan | 0.3 | |||||||||||||
Weighted-average common shares outstanding used in Non- GAAP diluted calculation | 177.3 |
(1) | The three months ended March 31, 2013, diluted common shares outstanding for purposes of calculating Diluted Adjusted Net Income per share include potential increases in shares that could result from the exercise of in-the-money stock options. These potential shares are excluded for the three months ended March 31, 2013, in calculating earnings-per-share for GAAP purposes, because the effect is antidilutive due to the Company's net loss for GAAP purposes. | |
The following table presents open 2014 derivative positions as of
Year | Type of Contract | Index |
Total |
Average |
||||||||||||||
(in millions) | ||||||||||||||||||
Gas sales | (MMBtu) | |||||||||||||||||
2014 | SWAP | NYMEX | 19.6 | $ | 4.22 | |||||||||||||
2014 | SWAP | IFNPCR | 53.9 | $ | 4.08 | |||||||||||||
2015 | SWAP | NYMEX | 25.6 | $ | 4.14 | |||||||||||||
2015 | SWAP | IFNPCR | 7.3 | $ | 3.97 | |||||||||||||
Oil Sales | (Bbls) | |||||||||||||||||
2014 | SWAP | NYMEX WTI | 7.2 | $ | 92.59 | |||||||||||||
2015 | SWAP | NYMEX WTI | 4.7 | $ | 88.17 | |||||||||||||
The following table sets forth QEP Energy's oil basis swaps as of
Year | Index | Index Less Differential |
Total |
Weighted |
||||||||||||
Oil basis swaps | (in millions) | |||||||||||||||
(Bbls) | ||||||||||||||||
2014 | NYMEX WTI | ICE Brent | 0.5 | $ | 13.78 | |||||||||||
2014 | NYMEX WTI | LLS | 0.5 | $ | 4.00 | |||||||||||
2015 | NYMEX WTI | LLS | 0.1 | $ | 4.00 | |||||||||||
The following table sets forth QEP Marketing’s volumes and swap prices
for its commodity derivative contracts as of
Year | Type of Contract | Index |
Total Volumes |
Average |
|||||||||||||||
(in millions) | |||||||||||||||||||
Gas sales | (MMBtu) | ||||||||||||||||||
2014 | SWAP | IFNPCR | 2.6 | $ | 3.77 | ||||||||||||||
Gas purchases | (MMBtu) | ||||||||||||||||||
2014 | SWAP | IFNPCR | 0.8 | $ | 3.82 |
Source:
QEP Resources, Inc.
Investors:
Greg Bensen
Director,
Investor Relations
303-405-6665
or
Media:
Brent
Rockwood
Director, Communications
303-672-6999