PITTSBURGH--(BUSINESS WIRE)--EQT Corporation (NYSE: EQT) today announced third quarter 2013 earnings
of $88.3 million, or $0.58 per diluted share; 177% higher than the third
quarter 2012 earnings of $31.9 million, or $0.21 per diluted share.
Operating cash flow was $232.8 million, 36% higher; and adjusted cash
flow per share was $1.92, 68% higher. EQT’s third quarter 2013 operating
income was $170.5 million, 98% higher. The non-GAAP financial measures
are detailed and reconciled in the Non-GAAP Disclosures section below.
Third Quarter Highlights 2013 vs. 2012:
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Production sales volume was 42% higher
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Marcellus production sales volume was 74% higher
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Production LOE per Mcfe was 17% lower
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Production SG&A per Mcfe was 34% lower
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Midstream gathered volume was 43% higher
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Midstream gathering and compression expense per unit was 29% lower
Earnings per share, adjusted cash flow per share, and operating income
were higher due to increased production sales volume, higher commodity
prices, increased gathered volume, and increased firm transmission
capacity sales and throughput. Net operating revenues increased 42% to
$469.3 million; while net operating expenses only increased 23%, to
$298.8 million, in support of the Company’s growth.
RESULTS BY BUSINESS
EQT Production
For the third quarter 2013, EQT Production had sales volume of 96.9
Bcfe, an average of 1.0 Bcfe per day, which was a 42% increase over the
third quarter 2012. This increase was driven by production from the
Marcellus, which averaged 787 MMcfe per day, 74% higher than last year.
Natural gas liquids (NGL) volume totaled 1,150 Mbbls, a 35% increase
over the same period last year. The Company’s fourth quarter and
full-year 2013 sales volume guidance is 97 Bcfe and 366 Bcfe,
respectively, which is approximately 42% higher than 2012; and its
fourth quarter and full-year 2013 NGL volume guidance is 1,300 Mbbls and
4,875 Mbbls, respectively.
Operating income for the Production business in the third quarter 2013
was $97.6 million, 153% higher than the third quarter 2012; while total
operating revenues were $304.2 million, 56% higher. The revenue growth
was due to a 42% increase in sales volume and a higher average effective
sales price. The average effective sales price to EQT was 4.0% higher at
$4.20 per Mcfe, with $3.13 per Mcfe allocated to EQT Production; and
$1.07 per Mcfe allocated to EQT Midstream.
Operating expenses for EQT Production for the third quarter 2013 were
$206.6 million, $49.9 million, or 32% higher than the same quarter last
year. Depreciation, depletion and amortization expenses (DD&A) were
$42.4 million higher; lease operating expenses (LOE), excluding
production taxes, were $2.5 million higher; and production taxes were
$2.3 million higher; all related to sales volume growth. Per unit LOE
decreased 17% to $0.15 per Mcfe, as volume growth dramatically outpaced
higher costs. Exploration expense was $4.1 million higher.
EQT spud 32 gross wells in the Marcellus during the quarter, with an
average length-of-pay of 4,880 feet; eight Upper Devonian wells, with an
average length-of-pay of 4,800 feet; and two Utica wells, with an
average length-of-pay of 4,890 feet.
Utica Well Results
The Company completed three Utica wells in the oil window in the third
quarter 2013 – with 30-day initial production rates of 286, 268, and 241
bbls/d of oil, respectively. If processing were available, the wells
would have produced 41, 58, and 42 bbls/d of NGLs, plus, approximately
755, 1,082, and 771 MMcf/d of natural gas, respectively. Regional
pricing was realized for the natural gas; while the realized oil price
was approximately $101 per bbl. The Company is on track to spud eight
Utica wells in 2013.
EQT Midstream
EQT Midstream’s third quarter 2013 operating income was $78.5 million;
54% higher than the third quarter of 2012. Net gathering revenues
increased 19% to $91.8 million, primarily due to a 43% increase in
gathered volume, partly offset by lower average gathering rates. Net
transmission revenues totaled $40.0 million, a 50% increase, primarily
due to sales of new capacity, as well as higher throughput. Net storage,
marketing and other revenues were $2.8 million higher. Operating
expenses for the quarter were $61.4 million, 6% higher, and consistent
with the growth of the business. Per unit gathering and compression
expense decreased by 29%.
OTHER BUSINESS
Sunrise Sale
On July 22, 2013, EQT sold its Sunrise Pipeline to EQT Midstream
Partners for $507.5 million plus 479,184 common units and 267,942
general partner units in EQT Midstream Partners. EQT recognized a
federal income tax gain of approximately $475 million, resulting in cash
taxes of approximately $57 million.
EQT Midstream Partners, LP
As of September 30, 2013, EQT had a 42.6% limited partner interest and a
2% general partner interest in EQT Midstream Partners, whose results are
consolidated in EQT’s results. For the third quarter 2013, EQT
Corporation recorded $14.4 million, or $0.09 of earnings per diluted
share, attributable to non-controlling interests. EQT Midstream
Partners’ results were released today and are available at www.eqtmidstreampartners.com.
On October 22, 2013, EQT Midstream Partners announced a cash
distribution to its unitholders of $0.43 per unit for the third quarter
of 2013. EQT will receive $8.9 million on its limited partner units,
plus a corresponding $0.4 million related to its 2% general partner
interest, and $0.2 million related to its incentive distribution rights;
as EQT is entitled to 15% of the amount by which the quarterly
distribution exceeds $0.4025 per unit.
Utility Sale
On December 20, 2012, the Company announced that it entered into a
definitive agreement for the transfer of its natural gas distribution
business, Equitable Gas Company, to Peoples Natural Gas, subject to
receipt of regulatory approvals. The Company incurred a $0.4 million of
unallocated expense in the third quarter of 2013 related to the
transaction.
The waiting period under the Hart-Scott-Rodino Antitrust Improvements
Act for the pending transaction expired on April 22, 2013, without a
request for additional information. This expiration indicates that the
Federal Trade Commission did not object to the transaction and that the
parties may proceed. As part of the regulatory approval process, EQT has
also submitted filings with the Pennsylvania Public Utility Commission,
the West Virginia Public Service Commission, and the Federal Energy
Regulatory Commission. The Kentucky Public Service Commission concluded
that they did not need to approve the transaction. The Company expects
to complete the regulatory review process by year-end.
Hedging
The Company recently added to its hedge position for 2014 and 2015. The
Company’s total natural gas hedge positions for October 2013 through
December 2015 production are:
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2013**
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2014
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2015
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Fixed Price
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Total Volume (Bcf)
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51
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163
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70
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Average Price per Mcf (NYMEX)*
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$
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4.56
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$
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4.43
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$
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4.57
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Collars
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Total Volume (Bcf)
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6
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24
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23
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Average Floor Price per Mcf (NYMEX)*
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$
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4.95
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$
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5.05
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$
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5.03
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Average Cap Price per Mcf (NYMEX)*
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$
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9.09
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$
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8.85
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$
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8.97
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* The average price is based on a conversion rate of 1.05 MMBtu/Mcf
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** October through December
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Operating Income
The Company reports operating income by segment in this news release.
Interest, income taxes, other income, and unallocated income/(expense)
are controlled on a consolidated, corporate-wide basis and are not
allocated to the segments. The Company’s management reviews and reports
segment results for operating revenues and purchased gas costs, net of
third-party transportation costs.
The following table reconciles operating income by segment to the
consolidated operating income reported in the Company’s financial
statements:
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Three Months Ended
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Nine Months Ended
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September 30,
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September 30,
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2013
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2012
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2013
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2012
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Operating income (thousands):
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EQT Production
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$
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97,600
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$
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38,528
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$
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276,753
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$
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115,270
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EQT Midstream
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78,533
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51,021
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224,993
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166,907
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Distribution
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(87
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)
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685
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58,359
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43,831
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Unallocated expenses
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(5,498
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)
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(4,286
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)
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(19,627
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)
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(6,470
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Operating income
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$
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170,548
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$
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85,948
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$
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540,478
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$
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319,538
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For the third quarter 2013, unallocated expense is primarily due to
higher non-cash incentive compensation expense.
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Marcellus Horizontal Well Status (cumulative since inception)
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As of
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As of
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As of
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As of
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As of
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9/30/13
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6/30/13
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3/31/13
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12/31/12
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9/30/12
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Wells spud
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477
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445
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404
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371
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344
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Wells online
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337
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321
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276
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258
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229
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Wells complete, not online
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20
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11
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30
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17
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27
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Frac stages (spud wells)*
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10,613
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9,754
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8,327
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7,230
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6,331
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Frac stages online
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6,596
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6,297
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4,788
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4,366
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3,545
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Frac stages complete, not online
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553
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224
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925
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462
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622
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*Includes planned stages for spud wells that have not yet been
hydraulically fractured.
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NON-GAAP DISCLOSURES
Operating Cash Flow
Operating cash flow is a non-GAAP financial measure that is presented as
an accepted indicator of an oil and gas exploration and production
company's ability to internally fund exploration and development
activities and to service or incur additional debt. EQT has also
included this information because management believes that changes in
operating assets and liabilities relate to the timing of cash receipts
and disbursements, which the Company may not control, and therefore, may
not relate to the period in which the operating activities occurred.
Operating cash flow should not be considered in isolation or as a
substitute for the most comparable GAAP financial measure of net cash
provided by operating activities. The table below reconciles operating
cash flow with net cash provided by operating activities, as derived
from the statement of cash flows to be included in EQT’s quarterly
report on Form 10-Q for the three and nine months ended September 30,
2013, and 2012.
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Three Months Ended
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Nine Months Ended
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September 30,
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September 30,
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(thousands)
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2013
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2012
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2013
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2012
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Net Income
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$
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102,610
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$
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36,704
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$
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306,009
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$
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140,185
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(Deduct) / add back:
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Deferred income taxes
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(48,383
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(7,584
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14,869
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45,473
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Depreciation, depletion, and amortization
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175,648
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131,611
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493,341
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354,817
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Non-cash incentive compensation
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9,628
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11,517
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37,108
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28,752
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Non-cash financial instrument put premium
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--
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--
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--
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8,227
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Other items
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(6,732
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(1,264
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3,962
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(12,729
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Operating cash flow
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$
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232,771
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$
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170,984
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$
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855,289
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$
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564,725
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(Deduct) / add back:
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Changes in other assets and liabilities
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165,503
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80,547
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151,811
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105,245
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Net cash provided by operating activities
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$
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398,274
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$
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251,531
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$
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1,007,100
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$
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669,970
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Adjusted Cash Flow Per Share
Adjusted cash flow per share is a non-GAAP financial measure that is
presented because it is a capital efficiency metric used by investors
and analysts to evaluate oil and gas companies. Adjusted cash flow per
share should not be considered in isolation or as a substitute for the
most comparable GAAP financial measure of net cash provided by operating
activities or net income per share or as a measure of liquidity.
The table below provides the calculation for adjusted cash flow per
share, as derived from the financial statements to be included in EQT’s
Form 10-Q for the three and nine months ended September 30, 2013, and
2012.
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Three Months Ended
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Nine Months Ended
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September 30,
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September 30,
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(thousands)
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2013
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2012
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2013
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2012
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Operating cash flow (a non-GAAP measure reconciled above)
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$
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232,771
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$
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170,984
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$
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855,289
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$
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564,725
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(Deduct) / add back:
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Exploration expense (cash)
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1,257
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1,099
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2,992
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3,719
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Cash taxes for Sunrise sale
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56,764
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--
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56,764
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--
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Adjusted operating cash flow
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$
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290,792
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$
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172,083
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$
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915,045
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$
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568,444
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Diluted weighted average common shares outstanding
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151,663
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150,388
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151,365
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150,270
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Adjusted cash flow per share
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$
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1.92
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$
|
1.14
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$
|
6.05
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$
|
3.78
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Net Operating Revenues and Net Operating Expenses
Net operating revenues and net operating expenses are non-GAAP financial
measures that exclude purchased gas costs, but are presented because
they are important analytical measures used by management to evaluate
period-to-period comparisons of revenue and operating expenses.
Purchased gas cost is typically excluded by management in such analysis
because, although subject to commodity price volatility, purchased gas
cost is mostly passed on to customers and does not have a significant
impact on EQT’s earnings. Net operating revenues and net operating
expenses should not be considered in isolation or as a substitute for
the most comparable GAAP financial measures of operating revenues or
total operating expenses. The table below reconciles net operating
revenues to operating revenues and net operating expenses to total
operating expenses for the three and nine months ended September 30,
2013, and 2012:
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Three Months Ended
|
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Nine Months Ended
|
|
|
|
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September 30,
|
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September 30,
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(thousands)
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2013
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2012
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2013
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2012
|
|
Net operating revenues
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$
|
469,333
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$
|
329,663
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$
|
1,397,151
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$
|
993,694
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Plus: purchased gas cost
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|
37,265
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|
|
34,394
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|
|
188,199
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|
|
158,127
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Operating revenues
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|
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|
$
|
506,598
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|
$
|
364,057
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|
$
|
1,585,350
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|
$
|
1,151,821
|
|
|
|
|
|
|
|
|
|
|
|
|
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Net operating expenses
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|
$
|
298,785
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|
$
|
243,715
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$
|
856,673
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$
|
674,156
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|
Plus: purchased gas cost
|
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|
37,265
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|
34,394
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|
|
188,199
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|
|
158,127
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Total operating expenses
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$
|
336,050
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$
|
278,109
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$
|
1,044,872
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$
|
832,283
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Q3 2013 Earnings Webcast Information
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The Company's conference call with securities analysts begins at
10:30 a.m. ET today. The call will be broadcast live via the
Company's website at www.eqt.com,
and on the investor information page of the Company’s website at http://ir.eqt.com,
with a replay available for seven days following the call.
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EQT Midstream Partners, LP, for which EQT Corporation is the
general partner and a significant equity owner, will host a
conference call with security analysts today, beginning at 11:30
a.m. ET. The call will be broadcast live via www.eqtmidstreampartners.com,
with a replay available for seven days following the call.
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About EQT Corporation:
EQT Corporation is an integrated energy company with emphasis on
Appalachian area natural gas production, gathering, transmission, and
distribution. EQT is the general partner and significant equity owner of
EQT Midstream Partners, LP. With more than 120 years of experience, EQT
continues to be a leader in the use of advanced horizontal drilling
technology – designed to minimize the potential impact of
drilling-related activities and reduce the overall environmental
footprint. Through safe and responsible operations, the Company is
committed to meeting the country’s growing demand for clean-burning
energy, while continuing to provide a rewarding workplace and enrich the
communities where its employees live and work. Company shares are traded
on the New York Stock Exchange as EQT.
Visit EQT Corporation at www.EQT.com.
Cautionary Statements
The United States Securities and Exchange Commission (SEC) permits oil
and gas companies, in their filings with the SEC, to disclose only
proved, probable and possible reserves that a company anticipates as of
a given date to be economically and legally producible and deliverable
by application of development projects to known accumulations. We use
certain terms, such as “EUR” (estimated ultimate recovery) and “3P”
(proved, probable and possible), that the SEC’s guidelines prohibit us
from including in filings with the SEC. These measures are by their
nature more speculative than estimates of reserves prepared in
accordance with SEC definitions and guidelines and accordingly are less
certain.
Total sales volume per day (or daily production) is an operational
estimate of the daily production or sales volume on a typical day
(excluding curtailments).
EBITDA is defined as earnings before interest, taxes, depreciation, and
amortization and is not a financial measure calculated in accordance
with generally accepted accounting principles (GAAP). EBITDA is a
non-GAAP supplemental financial measure that EQT management and external
users of EQT’s financial statements, such as industry analysts,
investors, lenders and rating agencies, may use to assess: (i) EQT’s
performance versus prior periods; (ii) EQT’s operating performance as
compared to other companies in its industry; (iii) the ability of EQT’s
assets to generate sufficient cash flow to make distributions to its
investors; (iv) EQT’s ability to incur and service debt and fund capital
expenditures; and (v) the viability of acquisitions and other capital
expenditure projects and the returns on investment of various investment
opportunities.
EQT is unable to provide a reconciliation of projected EBITDA to
projected net income, the most comparable financial measure calculated
in accordance with GAAP, because of uncertainties associated with
projecting future net income.
Similarly, EQT is unable to provide a reconciliation of its projected
operating cash flow to projected net cash provided by operating
activities, the most comparable financial measure calculated in
accordance with GAAP, because of uncertainties associated with
projecting future net income and changes in assets and liabilities.
Disclosures in this press release contain certain forward-looking
statements. Statements that do not relate strictly to historical or
current facts are forward-looking. Without limiting the generality of
the foregoing, forward-looking statements contained in this press
release specifically include the expectations of plans, strategies,
objectives and growth and anticipated financial and operational
performance of EQT and its subsidiaries, including guidance regarding
EQT’s strategy to develop its Marcellus and other reserves; drilling
plans and programs (including the number, type, feet of pay and location
of wells to be drilled, the conversion of drilling rigs to utilize
natural gas and the availability of capital to complete these plans and
programs); projected natural gas prices and basis; total resource
potential, reserves, EUR, expected decline curve, reserve replacement
ratio and production sales volume and growth rates (including liquids
sales volume and growth); F&D costs, operating costs, unit costs, well
costs and gathering and transmission revenue deductions to EQT
Midstream; gathering and transmission volume and growth rates;
processing capacity; infrastructure programs (including the timing, cost
and capacity of the transmission and gathering expansion projects);
technology (including drilling techniques); projected midstream EBITDA;
monetization transactions, including midstream asset sales (dropdowns)
to EQT Midstream Partners, LP (the Partnership) and other asset sales
and joint ventures or other transactions involving EQT’s assets
(including the timing of receipt, if at all, of any additional
consideration from the Partnership for new transportation agreements
entered into by the Partnership on the Sunrise Pipeline); the cash flows
resulting from, and the value of, EQT’s general partner and limited
partner interests and incentive distribution rights in the Partnership;
the proposed transfer of Equitable Gas Company to Peoples Natural Gas;
the timing of receipt of required approvals for the proposed Equitable
Gas Company transaction; the expected form and amount of midstream
assets to be exchanged in the Equitable Gas Company transaction; the
expected EBITDA to be generated from the midstream assets and commercial
arrangements transferred by or entered into with Peoples Natural Gas or
its affiliates; uses of capital provided by the Sunrise Pipeline and
Equitable Gas Company transactions; internal rate of return (IRR);
projected capital expenditures; liquidity and financing requirements,
including funding sources and availability; projected operating revenues
and cash flows; hedging strategy; the effects of government regulation
and litigation; the annual dividend rate; and tax position and projected
tax rates (including EQT’s ability to complete like-kind exchanges).
These forward-looking statements involve risks and uncertainties that
could cause actual results to differ materially from projected results.
Accordingly, investors should not place undue reliance on
forward-looking statements as a prediction of actual results. EQT has
based these forward-looking statements on current expectations and
assumptions about future events. While EQT considers these expectations
and assumptions to be reasonable, they are inherently subject to
significant business, economic, competitive, regulatory and other risks
and uncertainties, most of which are difficult to predict and many of
which are beyond EQT’s control. With respect to the proposed Equitable
Gas Company transaction, these risks and uncertainties include, among
others, the ability to obtain regulatory approvals for the transaction
on the proposed terms and schedule; disruption to EQT’s business,
including customer, employee and supplier relationships resulting from
the transaction; and risks that the conditions to closing may not be
satisfied. The risks and uncertainties that may affect the operations,
performance and results of EQT’s business and forward-looking statements
include, but are not limited to, those set forth under Item 1A, “Risk
Factors” of EQT’s Form 10-K for the year ended December 31, 2012, as
updated by any subsequent Form 10-Qs.
Any forward-looking statement speaks only as of the date on which such
statement is made and EQT does not intend to correct or update any
forward-looking statement, whether as a result of new information,
future events or otherwise.
EQT’s management speaks to investors from time to time. Slides for these
discussions, which are updated periodically, will be available online
via EQT’s investor relations website at http://ir.eqt.com.
|
EQT CORPORATION AND SUBSIDIARIES
|
|
STATEMENTS OF CONSOLIDATED INCOME (UNAUDITED)
|
|
(Thousands, except per share amounts)
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 30,
|
|
September 30,
|
|
|
2013
|
|
2012
|
|
2013
|
|
2012
|
|
|
(Thousands, except per share amounts)
|
|
Operating revenues
|
$
|
506,598
|
|
$
|
364,057
|
|
$
|
1,585,350
|
|
$
|
1,151,821
|
|
|
|
|
|
|
|
|
|
|
Operating expenses:
|
|
|
|
|
|
|
|
|
Purchased gas costs
|
|
37,265
|
|
|
34,394
|
|
|
188,199
|
|
|
158,127
|
|
Operation and maintenance
|
|
36,861
|
|
|
36,259
|
|
|
105,124
|
|
|
105,464
|
|
Production
|
|
28,076
|
|
|
23,201
|
|
|
80,712
|
|
|
72,796
|
|
Exploration
|
|
5,256
|
|
|
1,163
|
|
|
15,124
|
|
|
4,878
|
|
Selling, general and administrative
|
|
52,944
|
|
|
51,481
|
|
|
162,372
|
|
|
136,201
|
|
Depreciation, depletion and amortization
|
|
175,648
|
|
|
131,611
|
|
|
493,341
|
|
|
354,817
|
|
Total operating expenses
|
|
336,050
|
|
|
278,109
|
|
|
1,044,872
|
|
|
832,283
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
170,548
|
|
|
85,948
|
|
|
540,478
|
|
|
319,538
|
|
Other income
|
|
2,405
|
|
|
2,801
|
|
|
6,846
|
|
|
13,841
|
|
Interest expense
|
|
35,554
|
|
|
40,460
|
|
|
110,690
|
|
|
122,341
|
|
Income before income taxes
|
|
137,399
|
|
|
48,289
|
|
|
436,634
|
|
|
211,038
|
|
Income taxes
|
|
34,789
|
|
|
11,585
|
|
|
130,625
|
|
|
70,853
|
|
Net income
|
|
102,610
|
|
|
36,704
|
|
|
306,009
|
|
|
140,185
|
|
Less: Net income attributable to noncontrolling
Interests
|
|
14,354
|
|
|
4,831
|
|
|
30,642
|
|
|
4,831
|
|
Net income attributable to EQT Corporation
|
$
|
88,256
|
|
$
|
31,873
|
|
$
|
275,367
|
|
$
|
135,354
|
|
|
|
|
|
|
|
|
|
|
Earnings per share of common stock attributable
to EQT Corporation:
|
|
|
|
|
|
|
|
|
Basic:
|
|
|
|
|
|
|
|
|
Weighted average common shares outstanding
|
|
150,679
|
|
|
149,604
|
|
|
150,509
|
|
|
149,555
|
|
Net income
|
$
|
0.59
|
|
$
|
0.21
|
|
$
|
1.83
|
|
$
|
0.91
|
|
Diluted:
|
|
|
|
|
|
|
|
|
Weighted average common shares outstanding
|
|
151,663
|
|
|
150,388
|
|
|
151,365
|
|
|
150,270
|
|
Net income
|
$
|
0.58
|
|
$
|
0.21
|
|
$
|
1.82
|
|
$
|
0.90
|
|
Dividends declared per common share
|
$
|
0.03
|
|
$
|
0.22
|
|
$
|
0.09
|
|
$
|
0.66
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EQT Corporation
|
|
Price Reconciliation
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
September 30,
|
|
|
|
2013
|
|
2012
|
|
2013
|
|
2012
|
|
in thousands, unless noted
|
|
|
|
|
|
|
|
|
|
Liquids
|
|
|
|
|
|
|
|
|
|
NGLs:
|
|
|
|
|
|
|
|
|
|
Sales Volume (MMcfe) (a)
|
|
|
4,391
|
|
|
|
3,190
|
|
|
|
13,623
|
|
|
|
9,364
|
|
|
Sales Volume (Mbbls)
|
|
|
1,150
|
|
|
|
853
|
|
|
|
3,578
|
|
|
|
2,490
|
|
|
Gross Price ($/Bbl)
|
|
$
|
38.06
|
|
|
$
|
39.33
|
|
|
$
|
40.38
|
|
|
$
|
45.30
|
|
|
Gross NGL Revenue
|
|
$
|
43,786
|
|
|
$
|
33,545
|
|
|
$
|
144,469
|
|
|
$
|
112,807
|
|
|
BTU Premium (Ethane sold as natural gas):
|
|
|
|
|
|
|
|
|
|
Sales Volume (MMbtu)
|
|
|
8,244
|
|
|
|
5,889
|
|
|
|
21,364
|
|
|
|
15,602
|
|
|
Price ($/MMbtu)
|
|
$
|
3.58
|
|
|
$
|
2.81
|
|
|
$
|
3.69
|
|
|
$
|
2.59
|
|
|
BTU Premium Revenue
|
|
$
|
29,494
|
|
|
$
|
16,524
|
|
|
$
|
78,741
|
|
|
$
|
40,477
|
|
|
Oil:
|
|
|
|
|
|
|
|
|
|
Sales Volume (MMcfe) (a)
|
|
|
473
|
|
|
|
384
|
|
|
|
1,169
|
|
|
|
1,152
|
|
|
Sales Volume (Mbbls)
|
|
|
79
|
|
|
|
64
|
|
|
|
195
|
|
|
|
192
|
|
|
Net Price ($/Bbl)
|
|
$
|
94.78
|
|
|
$
|
80.25
|
|
|
$
|
87.43
|
|
|
$
|
83.43
|
|
|
Net Oil Revenue
|
|
$
|
7,488
|
|
|
$
|
5,136
|
|
|
$
|
17,049
|
|
|
$
|
16,020
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Liquids Revenue
|
|
$
|
80,768
|
|
|
$
|
55,205
|
|
|
$
|
240,259
|
|
|
$
|
169,304
|
|
|
GAS
|
|
|
|
|
|
|
|
|
|
Sales Volume (MMcf)
|
|
|
92,076
|
|
|
|
64,639
|
|
|
|
253,956
|
|
|
|
171,764
|
|
|
NYMEX Price ($/Mcf) (b)
|
|
$
|
3.58
|
|
|
$
|
2.81
|
|
|
$
|
3.69
|
|
|
$
|
2.59
|
|
|
Gas Revenue
|
|
$
|
329,416
|
|
|
$
|
181,377
|
|
|
$
|
936,013
|
|
|
$
|
445,322
|
|
|
Basis
|
|
|
(25,117
|
)
|
|
|
(1,952
|
)
|
|
|
(26,250
|
)
|
|
|
(1,705
|
)
|
|
Gross Gas Revenue (unhedged)
|
|
$
|
304,299
|
|
|
$
|
179,425
|
|
|
$
|
909,763
|
|
|
$
|
443,617
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Gross Gas & Liquids Revenue (unhedged)
|
|
$
|
385,067
|
|
|
$
|
234,630
|
|
|
$
|
1,150,022
|
|
|
$
|
612,921
|
|
|
Hedge impact (c)
|
|
|
53,424
|
|
|
|
75,074
|
|
|
|
106,650
|
|
|
|
237,218
|
|
|
Total Gross Gas & Liquids Revenue
|
|
$
|
438,491
|
|
|
$
|
309,704
|
|
|
$
|
1,256,672
|
|
|
$
|
850,139
|
|
|
Total Sales Volume (MMcfe)
|
|
|
96,940
|
|
|
|
68,213
|
|
|
|
268,748
|
|
|
|
182,280
|
|
|
Average hedge adjusted price ($/Mcfe)
|
|
$
|
4.52
|
|
|
$
|
4.54
|
|
|
$
|
4.68
|
|
|
$
|
4.66
|
|
|
|
|
|
|
|
|
|
|
|
|
Midstream Revenue Deductions ($ / Mcfe)
|
|
|
|
|
|
|
|
|
|
Gathering to EQT Midstream
|
|
$
|
(0.84
|
)
|
|
$
|
(1.00
|
)
|
|
$
|
(0.85
|
)
|
|
$
|
(1.04
|
)
|
|
Transmission to EQT Midstream
|
|
|
(0.23
|
)
|
|
|
(0.19
|
)
|
|
|
(0.24
|
)
|
|
|
(0.18
|
)
|
|
Third-party gathering and transmission (d)
|
|
|
(0.22
|
)
|
|
|
(0.40
|
)
|
|
|
(0.29
|
)
|
|
|
(0.35
|
)
|
|
Third-party processing
|
|
|
(0.10
|
)
|
|
|
(0.10
|
)
|
|
|
(0.11
|
)
|
|
|
(0.10
|
)
|
|
Total midstream revenue deductions
|
|
|
(1.39
|
)
|
|
|
(1.69
|
)
|
|
|
(1.49
|
)
|
|
|
(1.67
|
)
|
|
Average effective sales price to EQT Production
|
|
$
|
3.13
|
|
|
$
|
2.85
|
|
|
$
|
3.19
|
|
|
$
|
2.99
|
|
|
|
|
|
|
|
|
|
|
|
|
EQT Revenue ($ / Mcfe)
|
|
|
|
|
|
|
|
|
|
Revenues to EQT Midstream
|
|
$
|
1.07
|
|
|
$
|
1.19
|
|
|
$
|
1.09
|
|
|
$
|
1.22
|
|
|
Revenues to EQT Production
|
|
|
3.13
|
|
|
|
2.85
|
|
|
|
3.19
|
|
|
|
2.99
|
|
|
Average effective sales price to EQT Corporation
|
|
$
|
4.20
|
|
|
$
|
4.04
|
|
|
$
|
4.28
|
|
|
$
|
4.21
|
|
|
(a)
|
|
NGLs were converted to Mcfe at the rates of 3.82 Mcfe per barrel and
3.74 Mcfe per barrel based on the liquids content for the three
months ended September 30, 2013, and 2012, respectively, and 3.81
Mcfe per barrel and 3.76 Mcfe per barrel based on the liquids
content for the nine months ended September 30, 2013, and 2012,
respectively. Crude oil was converted to Mcfe at the rate of six
Mcfe per barrel for all periods.
|
|
|
|
|
|
(b)
|
|
The Company’s volume weighted NYMEX natural gas price (actual
average NYMEX natural gas price ($/Mcf) was $3.58 and $2.81 for the
three months ended September 30, 2013, and 2012, respectively, and
$3.67 and $2.59 for the nine months ended September 30, 2013, and
2012, respectively.)
|
|
|
|
|
|
(c)
|
|
Includes gains of $6.4 million, $0.07 per Mcfe, and $6.4 million,
$0.02 per Mcfe, for the three and nine months ended September 30,
2013, respectively, related to the sale of fixed price natural gas.
|
|
|
|
|
|
(d)
|
|
Due to the sale of unused capacity on the El Paso 300 line that was
not under long-term resale agreements at prices below the capacity
charge, third-party gathering and transmission rates increased by
$0.05 per Mcfe and $0.06 per Mcfe for the three and nine months
ended September 30, 2013, respectively. The unused capacity on the
El Paso 300 line not under long-term resale agreements was sold at
prices below the capacity charge, increasing third-party gathering
and transmission rates by $0.07 per Mcfe and $0.03 per Mcfe for the
three and nine months ended September 30, 2012, respectively.
|
|
|
|
|
|
UNIT COSTS
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
|
|
|
|
September 30,
|
|
September 30,
|
|
|
|
|
|
|
2013
|
|
2012
|
|
2013
|
|
2012
|
|
Production segment costs: ($ / Mcfe)
|
|
|
|
|
|
|
|
|
|
|
|
|
LOE
|
|
|
|
|
$
|
0.15
|
|
$
|
0.18
|
|
$
|
0.16
|
|
$
|
0.19
|
|
Production taxes*
|
|
|
|
|
|
0.14
|
|
|
0.16
|
|
|
0.14
|
|
|
0.17
|
|
SG&A
|
|
|
|
|
|
0.23
|
|
|
0.35
|
|
|
0.26
|
|
|
0.37
|
|
|
|
|
|
|
$
|
0.52
|
|
$
|
0.69
|
|
$
|
0.56
|
|
$
|
0.73
|
|
Midstream segment costs: ($ / Mcfe)
|
|
|
|
|
|
|
|
|
|
|
|
|
Gathering and transmission
|
|
|
|
|
$
|
0.24
|
|
$
|
0.32
|
|
$
|
0.24
|
|
$
|
0.34
|
|
SG&A
|
|
|
|
|
|
0.15
|
|
|
0.17
|
|
|
0.15
|
|
|
0.18
|
|
|
|
|
|
|
$
|
0.39
|
|
$
|
0.49
|
|
$
|
0.39
|
|
$
|
0.52
|
|
Total ($ / Mcfe)
|
|
|
|
|
$
|
0.91
|
|
$
|
1.18
|
|
$
|
0.95
|
|
$
|
1.25
|
|
*
|
Excludes the retroactive Pennsylvania Impact Fee of $0.04 per Mcfe
for the nine months ended September 30, 2012, for Marcellus wells
spud prior to 2012.
|
|
|
|
|
EQT PRODUCTION
|
|
RESULTS OF OPERATIONS
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
|
|
September 30,
|
|
September 30,
|
|
OPERATIONAL DATA
|
|
|
2013
|
|
2012
|
|
2013
|
|
2012
|
|
|
|
|
|
|
|
|
|
|
|
|
Sales volume detail (MMcfe):
|
|
|
|
|
|
|
|
|
|
|
Horizontal Marcellus Play (a)
|
|
|
|
72,361
|
|
|
41,486
|
|
|
194,928
|
|
|
100,551
|
|
Horizontal Huron Play
|
|
|
|
7,293
|
|
|
8,934
|
|
|
22,824
|
|
|
28,452
|
|
CBM Play
|
|
|
|
3,108
|
|
|
3,282
|
|
|
9,340
|
|
|
9,868
|
|
Other
|
|
|
|
14,178
|
|
|
14,511
|
|
|
41,656
|
|
|
43,409
|
|
Total production sales volumes
|
|
|
|
96,940
|
|
|
68,213
|
|
|
268,748
|
|
|
182,280
|
|
|
|
|
|
|
|
|
|
|
|
|
Average daily sales volumes (MMcfe/d)
|
|
|
|
1,054
|
|
|
741
|
|
|
984
|
|
|
665
|
|
|
|
|
|
|
|
|
|
|
|
|
Average effective sales price to EQT
Production ($/Mcfe)
|
|
|
$
|
3.13
|
|
$
|
2.85
|
|
$
|
3.19
|
|
$
|
2.99
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating expenses (LOE), excluding
production taxes ($/Mcfe)
|
|
|
$
|
0.15
|
|
$
|
0.18
|
|
$
|
0.16
|
|
$
|
0.19
|
|
Production taxes ($/Mcfe) (b)
|
|
|
$
|
0.14
|
|
$
|
0.16
|
|
$
|
0.14
|
|
$
|
0.17
|
|
Production depletion ($/Mcfe)
|
|
|
$
|
1.53
|
|
$
|
1.56
|
|
$
|
1.53
|
|
$
|
1.55
|
|
|
|
|
|
|
|
|
|
|
|
|
DD&A (thousands):
|
|
|
|
|
|
|
|
|
|
|
Production depletion
|
|
|
$
|
148,362
|
|
$
|
106,196
|
|
$
|
412,514
|
|
$
|
283,152
|
|
Other DD&A
|
|
|
|
2,275
|
|
|
2,008
|
|
|
7,105
|
|
|
6,024
|
|
Total DD&A (thousands)
|
|
|
$
|
150,637
|
|
$
|
108,204
|
|
$
|
419,619
|
|
$
|
289,176
|
|
|
|
|
|
|
|
|
|
|
|
|
Capital expenditures (thousands) (c)
|
|
|
$
|
332,370
|
|
$
|
255,223
|
|
$
|
977,394
|
|
$
|
703,834
|
|
|
|
|
|
|
|
|
|
|
|
|
FINANCIAL DATA (thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total net operating revenues
|
|
|
$
|
304,231
|
|
$
|
195,289
|
|
$
|
860,874
|
|
$
|
549,334
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating expenses:
|
|
|
|
|
|
|
|
|
|
|
LOE, excluding production taxes
|
|
|
|
14,801
|
|
|
12,257
|
|
|
42,452
|
|
|
34,991
|
|
Production taxes (b)
|
|
|
|
13,275
|
|
|
10,944
|
|
|
38,260
|
|
|
37,805
|
|
Exploration expense
|
|
|
|
5,256
|
|
|
1,163
|
|
|
15,124
|
|
|
4,878
|
|
SG&A
|
|
|
|
22,662
|
|
|
24,193
|
|
|
68,666
|
|
|
67,214
|
|
DD&A
|
|
|
|
150,637
|
|
|
108,204
|
|
|
419,619
|
|
|
289,176
|
|
Total operating expenses
|
|
|
|
206,631
|
|
|
156,761
|
|
|
584,121
|
|
|
434,064
|
|
Operating income
|
|
|
$
|
97,600
|
|
$
|
38,528
|
|
|
276,753
|
|
$
|
115,270
|
|
(a)
|
|
Includes Upper Devonian wells.
|
|
|
|
|
|
(b)
|
|
Production taxes include severance and production-related ad valorem
and other property taxes and the Pennsylvania impact fee. The
Pennsylvania impact fee for the nine months ended September 30,
2013, totaled $8.8 million. The Pennsylvania impact fee for the nine
months ended September 30, 2012, totaled $13.2 million, of which
$6.7 million represented the retroactive fee for pre-2012 Marcellus
wells. The production taxes unit rate for the nine months ended
September 30, 2012, excludes the impact of the accrual for pre-2012
Marcellus wells.
|
|
|
|
|
|
(c)
|
|
Includes $2.1 million and $114.6 million of capital expenditures for
the purchase of acreage and Marcellus wells from Chesapeake Energy
Corporation and its partners during the three and nine months ended
September 30, 2013, respectively.
|
|
|
|
|
|
EQT MIDSTREAM
|
|
RESULTS OF OPERATIONS
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 30,
|
|
September 30,
|
|
|
2013
|
|
2012
|
|
2013
|
|
2012
|
|
OPERATIONAL DATA
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gathered volumes (BBtu)
|
|
125,139
|
|
|
87,318
|
|
|
|
342,502
|
|
|
235,877
|
|
|
Average gathering fee ($/MMBtu)
|
$
|
0.73
|
|
$
|
0.88
|
|
|
$
|
0.76
|
|
$
|
0.93
|
|
|
Gathering and compression expense ($/MMBtu)
|
$
|
0.17
|
|
$
|
0.24
|
|
|
$
|
0.18
|
|
$
|
0.26
|
|
|
Transmission pipeline throughput (BBtu)
|
|
111,309
|
|
|
59,746
|
|
|
|
297,126
|
|
|
148,870
|
|
|
|
|
|
|
|
|
|
|
|
Net operating revenues (thousands):
|
|
|
|
|
|
|
|
|
Gathering
|
$
|
91,825
|
|
$
|
77,034
|
|
|
$
|
260,631
|
|
$
|
218,411
|
|
|
Transmission
|
|
39,962
|
|
|
26,563
|
|
|
|
116,105
|
|
|
71,018
|
|
|
Storage, marketing and other
|
|
8,165
|
|
|
5,362
|
|
|
|
23,426
|
|
|
34,956
|
|
|
Total net operating revenues
|
$
|
139,952
|
|
$
|
108,959
|
|
|
$
|
400,162
|
|
$
|
324,385
|
|
|
|
|
|
|
|
|
|
|
|
Unrealized gains (losses) on derivatives
and inventory (thousands) (a)
|
$
|
3,449
|
|
$
|
(3,018
|
)
|
|
$
|
6,411
|
|
$
|
(4,946
|
)
|
|
|
|
|
|
|
|
|
|
|
Capital expenditures (thousands)
|
$
|
111,593
|
|
$
|
97,135
|
|
|
$
|
254,205
|
|
$
|
296,698
|
|
|
|
|
|
|
|
|
|
|
|
FINANCIAL DATA (thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating revenues
|
$
|
155,677
|
|
$
|
120,484
|
|
|
$ 452,731
|
|
$
|
362,630
|
|
|
Purchased gas costs
|
|
15,725
|
|
|
11,525
|
|
|
52,569
|
|
|
38,245
|
|
|
Total net operating revenues
|
|
139,952
|
|
|
108,959
|
|
|
400,162
|
|
|
324,385
|
|
|
|
|
|
|
|
|
|
|
|
Operating expenses:
|
|
|
|
|
|
|
|
|
Operating and maintenance (O&M)
|
|
25,720
|
|
|
25,441
|
|
|
72,329
|
|
|
73,245
|
|
|
SG&A
|
|
16,769
|
|
|
15,325
|
|
|
47,239
|
|
|
37,369
|
|
|
DD&A
|
|
18,930
|
|
|
17,172
|
|
|
55,601
|
|
|
46,864
|
|
|
Total operating expenses
|
|
61,419
|
|
|
57,938
|
|
|
175,169
|
|
|
157,478
|
|
|
Operating income
|
$
|
78,533
|
|
$
|
51,021
|
|
|
$ 224,993
|
|
$
|
166,907
|
|
|
(a)
|
|
Included within storage, marketing and other net operating revenues.
|
|
|
|
|
|
DISTRIBUTION
|
|
RESULTS OF OPERATIONS
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 30,
|
|
September 30,
|
|
|
2013
|
|
2012
|
|
2013
|
|
2012
|
|
OPERATIONAL DATA
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Heating degree days (30 year average: QTD – 114; YTD – 3,649)
|
|
98
|
|
|
|
115
|
|
|
3,507
|
|
|
2,836
|
|
|
|
|
|
|
|
|
|
|
Residential sales and transportation volumes (MMcf)
|
|
1,363
|
|
|
|
1,266
|
|
|
15,907
|
|
|
12,726
|
|
Commercial and industrial volumes (MMcf)
|
|
4,648
|
|
|
|
4,939
|
|
|
19,879
|
|
|
20,051
|
|
Total throughput (MMcf)
|
|
6,011
|
|
|
|
6,205
|
|
|
35,786
|
|
|
32,777
|
|
|
|
|
|
|
|
|
|
|
Net operating revenues (thousands):
|
|
|
|
|
|
|
|
|
Residential
|
$
|
14,687
|
|
|
$
|
14,221
|
|
$
|
88,614
|
|
$
|
72,855
|
|
Commercial and industrial
|
|
6,179
|
|
|
|
6,499
|
|
|
33,823
|
|
|
32,182
|
|
Off-system and energy services
|
|
4,295
|
|
|
|
4,706
|
|
|
13,707
|
|
|
14,968
|
|
Total net operating revenues
|
$
|
25,161
|
|
|
$
|
25,426
|
|
$
|
136,144
|
|
$
|
120,005
|
|
|
|
|
|
|
|
|
|
|
Capital expenditures (thousands)
|
$
|
9,710
|
|
|
$
|
8,164
|
|
$
|
24,873
|
|
$
|
21,066
|
|
|
|
|
|
|
|
|
|
|
FINANCIAL DATA (thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating revenues
|
$
|
36,118
|
|
|
$
|
35,649
|
|
$
|
246,281
|
|
$
|
219,343
|
|
Purchased gas costs
|
|
10,957
|
|
|
|
10,223
|
|
|
110,137
|
|
|
99,338
|
|
Net operating revenues
|
|
25,161
|
|
|
|
25,426
|
|
|
136,144
|
|
|
120,005
|
|
|
|
|
|
|
|
|
|
|
Operating expenses:
|
|
|
|
|
|
|
|
|
O&M
|
|
11,034
|
|
|
|
10,549
|
|
|
32,087
|
|
|
31,010
|
|
SG&A
|
|
8,118
|
|
|
|
7,955
|
|
|
27,482
|
|
|
26,397
|
|
DD&A
|
|
6,096
|
|
|
|
6,237
|
|
|
18,216
|
|
|
18,767
|
|
Total operating expenses
|
|
25,248
|
|
|
|
24,741
|
|
|
77,785
|
|
|
76,174
|
|
Operating (loss) income
|
$
|
(87
|
)
|
|
$
|
685
|
|
$
|
58,359
|
|
$
|
43,831
|
