COTERRA ENERGY INC. HOUSTON, July 27, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the second quarter of 2017.
Second Quarter 2017 Highlights
-- Equivalent daily production growth of 14 percent relative to the
prior-year comparable quarter
-- Net income of $21.5 million compared to a net loss of $62.9 million in
the prior-year comparable quarter
-- Net income excluding selected items of $64.0 million compared to a net
loss of $30.2 million in the prior-year comparable quarter
-- Cash flow from operating activities of $260.6 million, an increase of
206 percent relative to the prior-year comparable quarter
-- EBITDAX of $274.4 million, an increase of 115 percent relative to the
prior-year comparable quarter
-- Generated positive free cash flow (cash flow from operating activities
less capital expenditures) for the fifth consecutive quarter
-- Natural gas price realizations improved by 46 percent relative to the
prior-year comparable quarter
-- Operating expenses per unit improved by nine percent relative to the
prior-year comparable quarter
-- Previously announced a 150 percent increase in the quarterly dividend,
effective during the second quarter
-- Repurchased 3.0 million shares during the second quarter at a
weighted-average share price of $22.41
"Our second quarter results demonstrate what our high-quality asset base can continue to deliver, highlighted by double-digit year-over-year production growth while generating positive free cash flow for the fifth consecutive quarter," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "We continue to focus our capital allocation efforts not only on driving returns-focused growth from our deep inventory base, but also on increasing our return of capital to shareholders as evidenced by our dividend increase and share repurchases during the quarter. Year-to-date we have returned over $100 million of our free cash flow to shareholders."
Second Quarter 2017 Financial Results
Equivalent production for the second quarter of 2017 was 173.1 billion cubic feet equivalent (Bcfe), consisting of 166.2 billion cubic feet (Bcf) of natural gas, 1,014.0 thousand barrels (Mbbls) of crude oil and condensate, and 132.4 Mbbls of natural gas liquids (NGLs).
Net income for the second quarter of 2017 was $21.5 million, or $0.05 per share, compared to a net loss of $62.9 million, or $0.14 per share, for the second quarter of 2016. Net income for the second quarter of 2017 included the impact of a non-cash, after-tax impairment charge of $43.2 million primarily associated with non-core oil and gas properties and related pipeline assets in West Virginia, Virginia and Ohio that were classified as held for sale as of June 30, 2017. Excluding the effect of this impairment and other selected items (detailed in the supplemental table below), net income was $64.0 million, or $0.14 per share, compared to a net loss of $30.2 million, or $0.07 per share, for the second quarter of 2016. Cash flow from operating activities for the second quarter of 2017 was $260.6 million, compared to $85.2 million for the second quarter of 2016. Discretionary cash flow for the second quarter of 2017 was $255.7 million, compared to $97.6 million for the second quarter of 2016. EBITDAX for the second quarter of 2017 was $274.4 million, compared to $127.6 million for the second quarter of 2016. See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including discretionary cash flow, net income (loss) excluding selected items, EBITDAX and net debt to adjusted capitalization ratio.
Natural gas price realizations, including the impact of derivatives, were $2.38 per thousand cubic feet (Mcf) for the second quarter of 2017, a 46 percent improvement compared to second quarter of 2016. The Company's natural gas price realizations for the quarter represented an $0.80 discount to NYMEX settlement prices. Oil price realizations, including the impact of derivatives, were $44.96 per barrel (Bbl), an increase of 12 percent compared to the second quarter of 2016. NGL price realizations were $16.59 per Bbl, an increase of 33 percent compared to the second quarter of 2016.
Operating expenses (including financing) decreased to $2.02 per thousand cubic feet equivalent (Mcfe) in the second quarter of 2017, a nine percent improvement compared to $2.22 per Mcfe in the second quarter of 2016. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.12 per Mcfe in the second quarter of 2017, a six percent improvement over the second quarter of 2016.
Cabot incurred a total of $195.1 million of capital expenditures during the second quarter of 2017 including $168.3 million of drilling and facilities capital associated with drilling 27 gross (21.1 net) wells and completing 26 gross (24.0 net) wells; $23.6 million of leasehold acquisition capital primarily associated with the Company's grassroots leasing efforts in two new exploratory operating areas; and $3.2 million of other capital. Additionally, the Company contributed $5.9 million to its equity pipeline investments in the Atlantic Sunrise and Constitution projects during the second quarter of 2017.
See the supplemental table at the end of this press release reconciling the capital expenditures for the quarter.
Year-To-Date 2017 Financial Results
Equivalent production for the six-month period ended June 30, 2017 was 343.1 Bcfe, consisting of 330.0 Bcf of natural gas, 1,934.6 Mbbls of crude oil and condensate, and 255.9 Mbbls of NGLs.
For the six-month period ended June 30, 2017, net income was $127.2 million, or $0.27 per share, compared to a net loss of $114.1 million, or $0.25 per share, for the six-month period ended June 30, 2016. Excluding the effect of selected items (detailed in the supplemental table below), net income was $153.1 million, or $0.33 per share, compared to a net loss of $85.6 million, or $0.19 per share, for the six-month period ended June 30, 2016. For the six-month period ended June 30, 2017, cash flow from operations was $529.9 million, compared to $152.3 million for the six-month period ended June 30, 2016. Discretionary cash flow was $528.7 million for the six-month period ended June 30, 2017, compared to $168.8 million for the six-month period ended June 30, 2016. EBITDAX for the six-month period ended June 30, 2017 was $580.7 million, compared to $229.1 million for the six-month period ended June 30, 2016.
Natural gas price realizations, including the impact of derivatives, were $2.51 per Mcf for the six-month period ended June 30, 2017, a 62 percent improvement compared to the six-month period ended June 30, 2016. Oil price realizations, including the impact of derivatives, were $45.80 per Bbl, an increase of 34 percent compared to the six-month period ended June 30, 2016. NGL price realizations were $18.58 per Bbl, an increase of 84 percent compared to the six-month period ended June 30, 2016.
Operating expenses (including financing) decreased to $2.01 per Mcfe for the six-month period ended June 30, 2017, a 10 percent improvement compared to $2.24 per Mcfe for the six-month period ended June 30, 2016. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.13 per Mcfe for the six-month period ended June 30, 2017, a four percent improvement compared to the six-month period ended June 30, 2016.
Cabot incurred a total of $407.3 million of capital expenditures during the six-month period ended June 30, 2017 including $310.3 million of drilling and facilities capital associated with drilling 48 gross (42.1 net) wells and completing 51 gross (48.0 net) wells; $91.5 million of leasehold acquisition capital primarily associated with the Company's grassroots leasing efforts in two new exploratory operating areas; and $5.5 million of other capital. Additionally, the Company contributed $13.6 million to its equity pipeline investments in the Atlantic Sunrise and Constitution projects during the six-month period ended June 30, 2017.
Second Quarter 2017 Operational Highlights
Marcellus Shale
During the second quarter of 2017, Cabot averaged 1,771 million cubic feet (Mmcf) per day of net Marcellus production (2,079 gross operated Mmcf per day). During the second quarter, the Company drilled 13.7 net wells, completed 8.0 net wells and placed 6.0 net wells on production. "The average cumulative production for the 26 fourth generation wells that we placed on production during the first half of 2017 continues to outperform our 4.4 Bcf per 1,000 lateral feet type curve," noted Dinges.
Cabot is currently operating two rigs and utilizing one 24-hour completion crew in the Marcellus Shale and plans to remain at this level for the remainder of the year.
Eagle Ford Shale
Cabot's net production in the Eagle Ford Shale during the second quarter of 2017 was 13,146 barrels of oil equivalent (Boe) per day (84% oil), an increase of nine percent sequentially compared to the first quarter of 2017. During the second quarter, the Company drilled 7.4 net wells and completed and placed on production 16.0 net wells. "Despite lower oil production volumes than originally anticipated for the quarter primarily due to operational delays and an extended clean up period for our longer lateral wells, we are confident that we will generate double-digit oil production growth for the year," commented Dinges.
Cabot is currently operating one rig and utilizing one 24-hour completion crew in the Eagle Ford Shale. The Company plans to maintain one rig for the remainder of the year and cease its completion activity for the year in October.
Share Repurchase Program Update
During the second quarter of 2017, Cabot repurchased 3.0 million shares at a weighted-average share price of $22.41. The Company has approximately 7.1 million shares remaining under its share repurchase program. "We will remain opportunistic with our share repurchase program as we continue to become more confident in the timing of infrastructure additions and the resulting increased level of positive free cash flow that we are anticipating in the coming years," stated Dinges.
Non-Core Asset Sale
During the second quarter of 2017, the Company entered into a purchase and sale agreement to sell certain legacy conventional oil and gas properties located in West Virginia, Virginia and Ohio for $41.3 million, subject to customary purchase price adjustments. Year-to-date 2017 production from these properties was 38.8 million cubic feet equivalent (Mmcfe) per day (99% gas). This transaction is expected to close by the end of the third quarter of 2017. Cabot will retain the deep rights across this approximately 780,000 net acre position. "Since we first began leasing in the Marcellus Shale in 2006, we have made efforts to high-grade our portfolio by opportunistically monetizing non-core assets and focusing our drilling activity in our lower-cost assets," said Dinges. "We have not allocated drilling capital to this legacy asset position since 2009 and had no plans to allocate capital to these assets in the future given our substantial drilling inventory in the Marcellus and Eagle Ford and our increased focus on returning capital to shareholders."
Financial Position and Liquidity
As of June 30, 2017, Cabot had total debt of $1.5 billion and cash on hand of $516.5 million. The Company's net debt to adjusted capitalization ratio and net debt to trailing twelve months EBITDAX ratio were 27.6 percent and 1.1x, respectively, compared to 28.5 percent and 1.8x as of December 31, 2016.
Total commitments under the Company's credit facility remain unchanged at $1.8 billion, with approximately $1.7 billion currently available to Cabot. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.2 billion of liquidity.
Third Quarter and Full-Year 2017 Guidance Update
Cabot has provided third quarter 2017 net production guidance of 1,750 to 1,800 Mmcf per day for natural gas; 13,000 to 13,750 Bbls per day for crude oil and condensate; and 1,350 to 1,450 Bbls per day for NGLs. "The mid-point of our natural gas production guidance for the third quarter implies a three percent sequential decline relative to the second quarter primarily due to mechanical issues at a third-party compressor station that began in late June and are expected to continue until late August; however, we anticipate sequential growth of natural gas volumes in the fourth quarter," noted Dinges.
The Company has reaffirmed its 2017 production growth guidance range of 8 - 12 percent (including 10 - 15 percent oil production growth) and its total 2017 program spending of $845 million, which is comprised of $775 million of exploration and production (E&P) spending and $70 million of contributions to its equity pipeline investments.
For further disclosure on Cabot's natural gas pricing exposure by index and cost guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
Conference Call Webcast
A conference call is scheduled for Friday, July 28, 2017, at 9:30 a.m. Eastern Time to discuss second quarter 2017 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward?looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "target", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
OPERATING DATA
Quarter Ended Six Months Ended
June 30, June 30,
2017 2016 2017 2016
---- ---- ---- ----
PRODUCTION VOLUMES
Natural gas (Bcf) 166.2 144.3 330.0 297.4
Crude oil and
condensate (Mbbl) 1,014.0 1,139.3 1,934.6 2,248.9
Natural gas liquids
(NGLs) (Mbbl) 132.4 112.9 255.9 205.0
Equivalent production
(Bcfe) 173.1 151.8 343.1 312.1
AVERAGE SALES PRICE
Natural gas, including
hedges ($/Mcf) $2.38 $1.63 $2.51 $1.55
Natural gas, excluding
hedges ($/Mcf) $2.38 $1.55 $2.51 $1.52
Crude oil and
condensate, including
hedges ($/Bbl) $44.96 $40.30 $45.80 $34.06
Crude oil and
condensate, excluding
hedges ($/Bbl) $44.03 $40.51 $45.29 $34.16
NGL ($/Bbl) $16.59 $12.43 $18.58 $10.09
AVERAGE UNIT COSTS
($/Mcfe)
Direct operations $0.16 $0.17 $0.15 $0.17
Transportation and
gathering 0.70 0.71 0.71 0.70
Taxes other than
income 0.05 0.06 0.05 0.05
Exploration 0.02 0.02 0.03 0.03
Depreciation,
depletion and
amortization 0.83 0.97 0.81 0.99
General and
administrative
(excluding stock-
based compensation) 0.08 0.09 0.09 0.10
Stock-based
compensation 0.06 0.05 0.05 0.06
Interest expense 0.12 0.14 0.12 0.15
---- ---- ---- ----
$2.02 $2.22 $2.01 $2.24
===== ===== ===== =====
WELLS DRILLED (1)
Gross 27 7 48 17
Net 21.1 7.0 42.1 17.0
WELLS COMPLETED (1)
Gross 26 13 51 28
Net 24.0 13.0 48.0 28.0
(1) Wells drilled represents
wells drilled to total
depth during the period.
Wells completed includes
wells completed during the
period, regardless of when
they were drilled.
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited)
Quarter Ended Six Months Ended
June 30, June 30,
--------
(In thousands, except per
share amounts) 2017 2016 2017 2016
------------------------- ---- ---- ---- ----
OPERATING REVENUES
Natural gas $395,328 $223,232 $828,770 $450,811
Crude oil and condensate 44,625 46,156 87,616 76,833
Gain (loss) on derivative
instruments 13,805 (27,184) 47,190 (8,190)
Brokered natural gas 4,037 2,596 8,732 5,776
Other 2,662 2,016 5,994 3,527
----- ----- ----- -----
460,457 246,816 978,302 528,757
OPERATING EXPENSES
Direct operations 27,262 26,477 51,903 52,513
Transportation and
gathering 120,544 107,560 244,018 217,213
Brokered natural gas 3,419 2,021 7,465 4,587
Taxes other than income 8,310 8,973 17,368 14,967
Exploration 3,959 3,738 10,157 10,121
Depreciation, depletion
and amortization 144,322 147,533 279,422 309,420
Impairment of oil and gas
properties 68,555 - 68,555 -
General and administrative
(excluding stock-based
compensation) 13,882 12,644 29,331 29,911
Stock-based
compensation(1) 10,075 7,301 18,328 17,906
------ ----- ------ ------
400,328 316,247 726,547 656,638
Earnings (loss) on equity
method investments (1,286) (73) (2,569) 1,935
Gain (loss) on sale of
assets (1,403) (878) (1,626) 477
------ ---- ------ ---
INCOME (LOSS) FROM
OPERATIONS 57,440 (70,382) 247,560 (125,469)
Interest expense 20,619 21,963 41,390 46,338
Loss on debt
extinguishment - 4,709 - 4,709
Other (income) expense (315) 302 109 804
--- ---
Income (loss) before
income taxes 37,136 (97,356) 206,061 (177,320)
Income tax expense
(benefit) 15,609 (34,446) 78,814 (63,216)
------ ------- ------ -------
NET INCOME (LOSS) $21,527 $(62,910) $127,247 $(114,104)
======= ======== ======== =========
Earnings (loss) per share
-Basic $0.05 $(0.14) $0.27 $(0.25)
Weighted-average common
shares outstanding 464,768 465,068 465,057 448,455
(1) Includes the impact of the
Company's performance share
awards, restricted stock and
expense associated with the
Supplemental Employee Incentive
Plan.
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited)
(In
thousands) June 30, December 31,
2017 2016
--- ---- ----
ASSETS
Current
assets $735,824 $715,881
Properties
and
equipment,
net
(Successful
efforts
method) 4,202,985 4,250,125
Other
assets 280,650 156,563
$5,219,459 $5,122,569
========== ==========
LIABILITIES
AND
STOCKHOLDERS'
EQUITY
Current
liabilities $234,422 $257,812
Long-term
debt, net 1,521,211 1,520,530
Deferred
income
taxes 617,332 579,447
Other
liabilities 204,463 197,113
Stockholders'
equity 2,642,031 2,567,667
--------- ---------
$5,219,459 $5,122,569
========== ==========
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited)
Quarter Ended Six Months Ended
June 30, June 30,
(In thousands) 2017 2016 2017 2016
------------- ---- ---- ---- ----
CASH FLOWS FROM
OPERATING
ACTIVITIES
Net income (loss) $21,527 $(62,910) $127,247 $(114,104)
Deferred income
tax expense
(benefit) 20,104 (35,322) 73,394 (64,294)
Impairment of oil
and gas
properties 68,555 - 68,555 -
(Gain) loss on
sale of assets 1,403 878 1,626 (477)
Exploratory dry
hole cost - 18 2,842 18
(Gain) loss on
derivative
instruments (13,805) 27,184 (47,190) 8,190
Net cash received
(paid) in
settlement of
derivative
instruments 1,204 11,305 (319) 11,305
Income charges not
requiring cash 156,719 156,465 302,573 328,140
Changes in assets
and liabilities 4,861 (12,440) 1,218 (16,488)
----- ------- ----- -------
Net cash provided
by operating
activities 260,568 85,178 529,946 152,290
------- ------ ------- -------
CASH FLOWS FROM
INVESTING
ACTIVITIES
Capital
expenditures (184,949) (67,162) (393,333) (159,399)
Proceeds from sale
of assets 1,101 - 1,475 49,828
Investment in
equity method
investments (5,884) (6,519) (13,626) (18,171)
------ ------ ------- -------
Net cash used in
investing
activities (189,732) (73,681) (405,484) (127,742)
-------- ------- -------- --------
CASH FLOWS FROM
FINANCING
ACTIVITIES
Net borrowings
(repayments) of
debt - (64,000) - (477,000)
Treasury stock
repurchases (68,255) - (68,255) -
Sale of common
stock, net - 1 - 995,279
Dividends paid (23,276) (9,300) (32,582) (17,582)
Tax withholdings
on stock award
vestings (258) (24) (5,672) (5,046)
Capitalized debt
issuance costs - - - (3,223)
Other 2 - 39 -
--- --- --- ---
Net cash provided
by (used in)
financing
activities (91,787) (73,323) (106,470) 492,428
------- ------- -------- -------
Net increase in
cash and cash
equivalents $(20,951) $(61,826) $17,992 $516,976
======== ======== ======= ========
Selected Item Review and Reconciliation of Net Income and Earnings Per Share
Quarter Ended Six Months Ended
June 30, June 30,
(In thousands, except per
share amounts) 2017 2016 2017 2016
------------------------- ---- ---- ---- ----
As reported -net income
(loss) $21,527 $(62,910) $127,247 $(114,104)
Reversal of selected
items:
Impairment of oil and gas
properties 68,555 - 68,555 -
(Gain) loss on sale of
assets 1,403 878 1,626 (477)
(Gain) loss on derivative
instruments(1) (12,601) 38,489 (47,509) 19,495
Loss on debt
extinguishment - 4,709 - 4,709
Drilling rig termination
fees - - - 3,188
Stock-based compensation
expense 10,075 7,301 18,328 17,906
Tax effect on selected
items (24,916) (18,647) (15,150) (16,268)
------- ------- ------- -------
Net income (loss)
excluding selected items $64,043 $(30,180) $153,097 $(85,551)
======= ======== ======== ========
As reported -earnings
(loss) per share $0.05 $(0.14) $0.27 $(0.25)
Per share impact of
selected items 0.09 0.07 0.06 0.06
---- ---- ---- ----
Earnings (loss) per share
excluding selected items $0.14 $(0.07) $0.33 $(0.19)
====== ===== ======
Weighted-average common
shares outstanding 464,768 465,068 465,057 448,455
(1) This amount represents the
non-cash mark-to-market
changes of our commodity
derivative instruments recorded
in gain (loss) on derivative
instruments in the Condensed
Consolidated Statement of
Operations.
Discretionary Cash Flow Calculation and Reconciliation
Quarter Ended Six Months Ended
June 30, June 30,
(In thousands) 2017 2016 2017 2016
------------- ---- ---- ---- ----
Net income (loss) $21,527 $(62,910) $127,247 $(114,104)
Plus (less):
Deferred income tax
expense (benefit) 20,104 (35,322) 73,394 (64,294)
Impairment of oil
and gas properties 68,555 - 68,555 -
(Gain) loss on sale
of assets 1,403 878 1,626 (477)
Exploratory dry hole
cost - 18 2,842 18
(Gain) loss on
derivative
instruments (13,805) 27,184 (47,190) 8,190
Net cash received
(paid) in
settlement of
derivative
instruments 1,204 11,305 (319) 11,305
Income charges not
requiring cash 156,719 156,465 302,573 328,140
------- ------- ------- -------
Discretionary cash
flow 255,707 97,618 528,728 168,778
Changes in assets
and liabilities 4,861 (12,440) 1,218 (16,488)
----- ------- ----- -------
Net cash provided by
operating
activities $260,568 $85,178 $529,946 $152,290
======== ======= ======== ========
EBITDAX Calculation and Reconciliation
Quarter Ended Six Months Ended
June 30, June 30,
(In thousands) 2017 2016 2017 2016
------------- ---- ---- ---- ----
Net income (loss) $21,527 $(62,910) $127,247 $(114,104)
Plus (less):
Loss on debt
extinguishment - 4,709 - 4,709
Interest expense 20,619 21,963 41,390 46,338
Other (income) expense (315) 302 109 804
Income tax expense
(benefit) 15,609 (34,446) 78,814 (63,216)
Depreciation, depletion
and amortization 144,322 147,533 279,422 309,420
Impairment of oil and gas
properties 68,555 - 68,555 -
Exploration 3,959 3,738 10,157 10,121
(Gain) loss on sale of
assets 1,403 878 1,626 (477)
Non-cash (gain) loss on
derivative instruments (12,601) 38,489 (47,509) 19,495
(Earnings) loss on equity
method investments 1,286 73 2,569 (1,935)
Stock-based compensation 10,075 7,301 18,328 17,906
------ ----- ------ ------
EBITDAX $274,439 $127,630 $580,708 $229,061
======== ======== ======== ========
Net Debt Reconciliation
(In
thousands) June 30, December 31,
2017 2016
--- ---- ----
Total
debt $1,521,211 $1,520,530
Stockholders'
equity 2,642,031 2,567,667
--------- ---------
Total
capitalization $4,163,242 $4,088,197
Total
debt $1,521,211 $1,520,530
Less:
Cash and
cash
equivalents (516,534) (498,542)
-------- --------
Net debt $1,004,677 $1,021,988
Net debt $1,004,677 $1,021,988
Stockholders'
equity 2,642,031 2,567,667
--------- ---------
Total
adjusted
capitalization $3,646,708 $3,589,655
Total
debt to
total
capitalization
ratio 36.5% 37.2%
Less:
Impact
of cash
and cash
equivalents 8.9% 8.7%
--- ---
Net debt
to
adjusted
capitalization
ratio 27.6% 28.5%
Capital Expenditures
Quarter Ended Six Months Ended
June 30, June 30,
(In thousands) 2017 2016 2017 2016
------------- ---- ---- ---- ----
Cash paid for
capital
expenditures $184,949 $67,162 $393,333 $159,399
Change in accrued
capital costs 10,103 3,716 16,798 3,167
Exploratory dry
hole cost - (18) (2,842) (18)
--- --- ------ ---
Capital
expenditures $195,052 $70,860 $407,289 $162,548
======== ======= ======== ========
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SOURCE Cabot Oil & Gas Corporation
