Loading...
Loading...
HOUSTON, TX --(Marketwired - May 09, 2016) - Sanchez Energy Corporation SN ("Sanchez Energy" or the "Company"), today announced operating and financial results for the first quarter 2016. Highlights include:
-- Total production of 5.1 million barrels of oil equivalent ("MMBoe")
during the first quarter 2016, up approximately 26% over the first
quarter 2015
-- Average production of approximately 56,500 barrels of oil equivalent per
day ("Boe/d"), which exceeded the high end of the Company's guidance of
48,000 to 52,000 Boe/d for the first quarter 2016 by over 8.5%
-- Revenues of $79.8 million (approximately $133 million inclusive of hedge
settlements) and Adjusted EBITDA (a non-GAAP financial measure) of $64.6
million
-- Total liquidity of approximately $662 million as of March 31, 2016,
which consisted of $362 million in cash and cash equivalents and an
undrawn bank credit facility with an elected commitment amount of $300
million
-- Average drilling and completion costs during the first quarter 2016 of
$3.3 million per well at Catarina and $3.4 million per well at Cotulla,
with the Company's best wells coming in at approximately $3.0 million
per well in both areas
-- South-Central Catarina wells continue to exceed expectations, with
average 30-day rates of greater than 1,300 Boe/d from all South-Central
wells the Company has brought on-line to date
-- The Company has met its 50 well annual drilling commitment at Catarina
for the period July 2015 through June 2016 and has banked 13 wells
toward the 50 well annual drilling commitment for the period July 2016
through June 2017
-- The Carnero Pipeline, constructed by Sanchez Energy's joint venture with
a subsidiary of Targa Resources Corp. TRGP ("Targa"), went in-
service in March 2016 and now transports the majority of Catarina gas
volumes
MANAGEMENT COMMENTS
"We are off to a strong start in 2016," said Tony Sanchez, III, Chief Executive Officer of Sanchez Energy. "As previously reported, we achieved excellent production results in the first quarter 2016, exceeding the high end of our guidance by over 8.5%. Process improvements and efficiency gains continue to drive our performance, with several wells coming in at a cost of approximately $3.0 million. This combination of lower costs and strong production has allowed us to achieve positive returns on our capital program, even in today's challenging commodity price environment, which provides us with a key competitive advantage in responding to current industry conditions."
"During the first quarter 2016, our development focus remained on Catarina and further delineation of the South-Central region of the lease. Development results in this area continue to meet or exceed our expectations, with 11 additional wells brought on-line in South-Central Catarina during the quarter. The 15 total wells brought on-line as of March 31, 2016 in South-Central Catarina have averaged 30-day production rates of greater than 1,300 Boe/d. Since March 31, 2016, we have also brought the E15 pad on-line, which is a 5-well pad that appraises the area between Western and South-Central Catarina. Initial production and pressure results from the E15 pad exceeded expectations and are in line with recent results in South-Central Catarina. The extension of the fairway between our two most productive regions of Catarina expands an already significant growth of inventory in South-Central Catarina."
"As a result of design and process improvements, we are currently averaging 8 days spud to total depth at Catarina and 6 days at Cotulla. As a testament to the continued optimization, one of our most recent wells was drilled with a spud to total depth time of 4.35 days at a cost of $66 per foot including production casing. In addition to having already met our drilling commitments at Catarina for the period July 2015 through June 2016, as of March 31, 2016, we have banked 13 wells toward our 50 well annual drilling commitment for the period July 2016 through June 2017. We anticipate that our two rig drilling program at Catarina will drop to one rig by mid-year 2016, at which time we anticipate a bank of approximately 20 wells toward our next annual drilling commitment, which runs from July 2016 through June 2017. This provides us with considerable financial flexibility as we execute our 2016 program and plan for future development and other opportunities that may emerge as a result of distress in the industry."
"With respect to our midstream strategy, the Carnero Pipeline, constructed by the Targa joint venture, went in-service in March 2016 and now transports the majority of our Catarina gas volumes. The joint venture continues construction of a new cryogenic natural gas processing plant in La Salle County, Texas. Once complete, the project is expected to provide a path to improved yields, lower processing fees, and significant marketing benefits to Sanchez Energy."
"Based on the strong showing in the first quarter 2016, we reiterate our 2016 upstream capital spending guidance of $200 million to $250 million. Our 2016 capital budget is expected to maintain production consistent with 2015 levels, with approximately 70% of the capital expected to be incurred in the first half of the year."
OPERATIONS UPDATE
The Company's Eagle Ford development plan remains primarily focused on Catarina, where the Company is currently running two rigs and expects to reduce activity to one rig by the end of the second quarter 2016. First quarter 2016 development activity was primarily focused in South-Central Catarina, where the Company has realized some of the best production results on the lease. South-Central Catarina well results continue to trend above expectations and are currently tracking estimated ultimate recoveries ("EURs") of approximately 1,100 thousand barrels of oil equivalent ("MBoe"). The Company has met its 50 well annual drilling commitment at Catarina for the period July 2015 through June 2016 and, as of March 31, 2016, has banked 13 wells towards the 50 well annual drilling commitment for the period July 2016 through June 2017.
Drilling and completion costs in the first quarter 2016 averaged approximately $3.3 million per well at Catarina and $3.4 million per well at Cotulla, with the Company's best wells coming in at approximately $3.0 million per well in both areas. Nearly all of the Company's recent well cost reductions are attributable to process and design improvements, which have resulted in reductions in drill time. The Company's well cost reductions are expected to be sustainable, even in a rising commodity price environment.
As of March 31, 2016, the Company had 640 gross (522 net) producing wells with 17 gross (15.5 net) wells in various stages of completion, as detailed in the following table:
Gross
Wells Waiting/
Gross Undergoing
Project Area Producing Wells Completion
----------------- --------------- --------------------
Catarina 298 11
Marquis 103 --
Cotulla / Wycross 149 3
Palmetto 76 3
TMS / Other 14 --
--------------- --------------------
Total 640 17
PRODUCTION VOLUMES, AVERAGE SALES PRICES, AND OPERATING COSTS PER BOE
The Company's production mix during the first quarter 2016 consisted of approximately 32% oil, 33% natural gas liquids ("NGLs"), and 35% natural gas. By asset area, Catarina, Marquis, Cotulla, and Palmetto/Other comprised approximately 81%, 6%, 10%, and 3%, respectively, of the Company's total first quarter 2016 production volumes.
Revenue, inclusive of realized hedge gains, for the three months ended March 31, 2016 totaled approximately $133 million, a decrease of just 5% when compared to the same period a year ago. The effect of the decrease in commodity prices was partially offset by higher production due to better well performance and efficiency gains across the portfolio.
Production, average sales prices, and operating costs and expenses per Boe for the first quarter 2016 are summarized in the tables that follow:
Three Months Ended
March 31,
------------------
2016 2015
-------- --------
Net Production:
Oil (MBbl) 1,639 1,784
Natural gas liquids (MBbl) 1,689 1,121
Natural gas (MMcf) 10,895 6,992
Total oil equivalent (MBoe) 5,144 4,070
Average Sales Price Excluding Derivatives(1):
Oil ($ per Bbl) $ 26.04 $ 42.35
Natural gas liquids ($ per Bbl) 8.91 12.36
Natural gas ($ per Mcf) 2.03 3.03
Oil equivalent ($ per Boe) $ 15.52 $ 27.18
Average Sales Price Including Derivatives(2):
Oil ($ per Bbl) $ 52.71 $ 57.33
Natural gas liquids ($ per Bbl) 8.91 12.36
Natural gas ($ per Mcf) 2.89 3.41
Oil equivalent ($ per Boe) $ 25.85 $ 34.39
Average unit costs per Boe:
Oil and natural gas production expenses $ 8.69 $ 8.39
Production and ad valorem taxes $ 0.77 $ 2.13
General and administrative (3) $ 3.14 $ 3.39
Depreciation, depletion, amortization and accretion $ 9.13 $ 25.22
Impairment of oil and natural gas properties $ 4.29 $ 108.46
(1) Excludes the impact of derivative instrument settlements.
(2) Includes the impact of derivative instrument settlements.
(3) Excludes stock based compensation.
2016 GUIDANCE
The Company reiterated its 2016 upstream capital spending guidance of $200 million to $250 million, with approximately 70% of the capital expected to be incurred in the first half of the year. At this level of capital spending, the Company anticipates it will be able to maintain production consistent with 2015 levels. Additional detail concerning the Company's capital program can be found in the investor presentation available in the Investors section of the Company's website, provided below.
First quarter 2016 results and second quarter and full year 2016 guidance are summarized in the table that follows:
Actuals Guidance
---------- -----------------------------------
1Q 2016 2Q 2016 FY 2016
---------- ----------------- ----------------
Production Volumes:
----------------------------
Oil (Bbls/d) 18,011 16,667 - 17,333 16,000 - 17,333
NGLs (Bbls/d) 18,560 16,667 - 17,333 16,000 - 17,333
Natural Gas (Mcf/d) 119,725 100,000 - 104,000 96,000 - 104,000
----------------------------------------------------------------------------
Barrel of Oil Equivalent
(Boe/d) 56,526 50,000 - 52,000 48,000 - 52,000
============================================================================
Operating Costs & Expenses :
----------------------------
Cash Production Expense
($/Boe)(1) $9.41 $8.75 - $9.75 $8.75 - $9.75
Non-Cash Production
Expense ($/Boe) $0.72 $0.80 - $0.90 $0.80 - $0.90
Production & Ad Valorem
Taxes (% of O&G Revenue) 5% 5% - 6% 5% - 6%
Cash G&A ($/Boe)(2) $3.14 $2.75 - $3.25 $2.75 - $3.25
DD&A Expense ($/Boe) $9.13
Interest Expense ($MM) $31.6 $30 $120
Preferred Dividend ($MM) $4.0 $4 $16
(1) Cash Production Expense
guidance only relates to
production expenses
reported on the cash flow
statement and does not
include the effect from the
deferred gain related to
the Western Catarina
Midstream Divestiture.
(2) Excludes stock based
compensation.
CAPITAL EXPENDITURES
Capital expenditures incurred during the first quarter 2016 related to upstream activities, including accruals, totaled approximately $91.4 million. With respect to midstream activities, the Company incurred approximately $5.2 million of capital expenditures in the first quarter 2016 related to the Targa joint venture. The Company expects capital expenditures totaling approximately $60 million during the remainder of 2016 related to the Targa joint venture.
FINANCIAL RESULTS
The Company reported Adjusted EBITDA of $64.6 million and Adjusted Net Income (Loss) of ($17.6) million for the first quarter 2016, which compares to Adjusted Net Income (Loss) of $(55.2) million reported in the first quarter 2015. Adjusted EBITDA and Adjusted Net Income (Loss) are non-GAAP financial measures defined in the tables included with today's news release.
On a GAAP basis, the Company reported a net loss attributable to common stockholders of $(69.8) million for the first quarter 2016, which includes a non-cash after tax impairment charge of $22.1 million and a non-cash mark-to-market loss on the value of the Company's hedge portfolio of $30.4 million.
HEDGING UPDATE
In April 2016, the Company entered into swaps to hedge 1,000 Bbl/d of oil in 2017 at a fixed price of $50.00/Bbl and 10,000 MMBtu/d of natural gas in 2018 at a fixed price of $3.00/MMBtu. The Company's counterparty on the swaps has the right, under certain circumstances, to expand the hedges to cover an additional 1,000 Bbl/d of oil in 2017 and an additional 10,000 MMBtu/d of natural gas in 2018 at the same fixed prices. In May 2016, the Company entered into an additional swap to hedge 10,000 MMBtu/d of natural gas in 2018 at a fixed price of $3.00/MMBtu. This brings the Company's current total hedged position to 18,000 Bbls/d of oil and 99,154 MMbtu/d of natural gas in 2016, 1,000 to 2,000 Bbls/d of oil and 76,562 MMbtu/d of natural gas in 2017, and 20,000 to 30,000 MMbtu/d of natural gas in 2018.
LIQUIDITY AND CREDIT FACILITY
The Company had liquidity of approximately $662 million as of March 31, 2016, which consisted of $362 million in cash and cash equivalents and an undrawn bank credit facility with an elected commitment amount of $300 million and a borrowing base of $350 million. The Company's elected commitment amount on the bank credit facility is expected to remain at $300 million until the next semi-annual redetermination of the borrowing base by the lenders, which is anticipated in the fourth quarter 2016.
SHARE COUNT
As of March 31, 2016, the Company had 64.3 million total common shares outstanding. Assuming all Series A Convertible Perpetual Preferred Stock and Series B Convertible Perpetual Preferred Stock were converted, total outstanding common shares as of March 31, 2016 would have been 76.8 million. For the three months ended March 31, 2016, the weighted average number of unrestricted common shares used to calculate net loss attributable to common stockholders and adjusted net income (loss) per common share, basic and diluted, which are determined in accordance with GAAP, was 58.1 million.
CONFERENCE CALL
Sanchez Energy will host a conference call for investors on Monday, May 9, 2016, at 1:00 p.m. Central Time (2:00 p.m. Eastern Time). Interested investors can listen to the call by visiting our website at www.sanchezenergycorp.com or via webcast, both live and rebroadcast, over the internet at: http://edge.media-server.com/m/p/dwmsgbao/lan/en.
UPDATED INVESTOR PRESENTATION
An updated investor presentation has been uploaded to the Investors section of the Company's website, provided below.
ABOUT SANCHEZ ENERGY CORPORATION
Sanchez Energy Corporation is an independent exploration and production company focused on the acquisition and development of unconventional oil and natural gas resources in the onshore U.S. Gulf Coast, with a current focus on the Eagle Ford Shale in South Texas where we have assembled approximately 200,000 net acres, and the Tuscaloosa Marine Shale. For more information about Sanchez Energy Corporation, please visit our website: www.sanchezenergycorp.com.
FORWARD LOOKING STATEMENTS
This press release contains, and our officers and representatives may from time to time make, 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. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that Sanchez Energy expects, believes or anticipates will or may occur in the future are forward-looking statements, including statements relating to estimates of our future production, revenues, well cost reductions, operational and commercial benefits of the Targa joint venture, capital expenditures regarding the Targa joint venture, our strategy and plans, our view of the market, our well drilling plans, and our capital plans for the remainder of 2016 and beyond. These statements are based on certain assumptions made by the Company based on management's experience, perception of historical trends and technical analyses, current conditions, anticipated future developments and other factors believed to be appropriate and reasonable by management. When used in this press release, the words "will," "potential," "believe," "estimate," "intend," "expect," "may," "should," "anticipate," "could," "plan," "predict," "project," "profile," "model," "strategy," "future," or their negatives, other similar expressions or the statements that include those words, are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words.
Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of Sanchez Energy, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements, including, but not limited to failure of acquired assets to produce as anticipated, failure or delays on the part of our joint venture partners, failure to continue to produce oil and gas at historical rates, costs of operations, delays, and any other difficulties related to producing oil or gas, the price of oil or gas, marketing and sales of produced oil and gas, estimates made in evaluating reserves, competition, general economic conditions and the ability to manage our growth, our expectations regarding our future liquidity, our expectations regarding the results of our efforts to improve the efficiency of our operations to reduce our costs and other factors described in Sanchez Energy's most recent Annual Report on Form 10-K and any updates to those risk factors set forth in Sanchez Energy's Quarterly Reports on Form 10-Q. Further information on such assumptions, risks and uncertainties is available in Sanchez Energy's filings with the U.S. Securities and Exchange Commission (the "SEC"). Sanchez Energy's filings with the SEC are available on our website at www.sanchezenergycorp.com and on the SEC's website at www.sec.gov. In light of these risks, uncertainties and assumptions, the events anticipated by Sanchez Energy's forward-looking statements may not occur, and, if any of such events do occur, Sanchez Energy may not have correctly anticipated the timing of their occurrence or the extent of their impact on its actual results. Accordingly, you should not place any undue reliance on any of Sanchez Energy's forward-looking statements. Any forward-looking statement speaks only as of the date on which such statement is made and Sanchez Energy undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law.
SANCHEZ ENERGY CORPORATION
CONSOLIDATED STATEMENT OF OPERATIONS DATA
(unaudited)
Three Months Ended
March 31,
--------------------
2016 2015
--------- ---------
REVENUES:
Oil sales $ 42,682 $ 75,524
Natural gas liquid sales 15,045 13,853
Natural gas sales 22,089 21,216
--------- ---------
Total revenues 79,816 110,593
--------- ---------
OPERATING COSTS AND EXPENSES:
Oil and natural gas production expenses 44,693 34,163
Production and ad valorem taxes 3,943 8,670
Depreciation, depletion, amortization and accretion 46,965 102,657
Impairment of oil and natural gas properties 22,084 441,450
General and administrative (inclusive of stock-based
compensation expense of $3,344 and $7,694,
respectively, for the three months ended March 31,
2016 and 2015) 19,480 21,477
--------- ---------
Total operating costs and expenses 137,165 608,417
--------- ---------
Operating loss (57,349) (497,824)
Other income (expense):
Interest income and other expense (88) (1,824)
Interest expense (31,606) (31,558)
Earnings from equity investments 512 --
Net gains on commodity derivatives 22,757 41,303
--------- ---------
Total other income (expense) (8,425) 7,921
--------- ---------
Income (loss) before income taxes (65,774) (489,903)
Income tax expense -- 7,442
--------- ---------
Net loss (65,774) (497,345)
Less:
Preferred stock dividends (3,987) (3,991)
Net income allocable to participating securities -- --
Net income allocable to participating securities -- --
--------- ---------
Net loss attributable to common stockholders $ (69,761) $(501,336)
========= =========
Net loss per common share - basic and diluted $ (1.20) $ (8.83)
========= =========
Weighted average number of shares used to calculate
net loss attributable to common stockholders - basic
and diluted 58,099 56,805
========= =========
SANCHEZ ENERGY CORPORATION
CONSOLIDATED BALANCE SHEET
(unaudited)
March 31, December 31,
----------- -------------
2016 2015
----------- -------------
ASSETS
Current assets:
Cash and cash equivalents $ 362,221 $ 435,048
Oil and natural gas receivables 33,596 30,668
Joint interest billings receivables 547 1,259
Accounts receivable - related entities 3,636 3,697
Fair value of derivative instruments 136,479 172,494
Deferred tax asset -- --
Other current assets 22,043 23,452
----------- -------------
Total current assets 558,522 666,618
----------- -------------
Oil and natural gas properties, at cost, using
the full cost method:
Unproved oil and natural gas properties 281,106 253,529
Proved oil and natural gas properties 2,978,732 2,914,867
----------- -------------
Total oil and natural gas properties 3,259,838 3,168,396
Less: Accumulated depreciation, depletion,
amortization and impairment (2,480,381) (2,412,293)
----------- -------------
Total oil and natural gas properties, net 779,457 756,103
----------- -------------
Other assets:
Debt issuance costs, net 125 --
Fair value of derivative instruments 5,299 5,789
Deferred tax asset -- --
Investments 55,721 49,985
Other assets 22,079 22,809
----------- -------------
Total assets $ 1,421,203 $ 1,501,304
=========== =============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable $ 1,600 $ 4,184
Accounts payable - related entities -- --
Other payables 1,599 2,004
Accrued liabilities:
Capital expenditures 57,580 51,983
Other 60,570 69,974
Deferred premium liability 20,523 24,548
Fair value of derivative instruments -- --
Deferred tax liability -- --
Other current liabilities 14,921 14,813
----------- -------------
Total current liabilities 156,793 167,506
Long term debt
Long term debt, net of premium, discount and
debt issuance costs 1,706,367 1,705,927
Asset retirement obligations 26,467 25,907
Deferred tax liability -- --
Deferred premium liability -- --
Fair value of derivative instruments -- --
Other liabilities 54,699 58,133
----------- -------------
Total liabilities 1,944,326 1,957,473
----------- -------------
Commitments and contingencies (Note 16)
Stockholders' equity:
Preferred stock ($0.01 par value, 15,000,000
shares authorized; 1,838,985 shares issued
and outstanding as of March 31, 2016 and
December 31, 2015 of 4.875% Convertible
Perpetual Preferred Stock, Series A; 53 53
3,527,830 shares issued and outstanding as
of March 31, 2016 and December 31, 2015 of
6.500% Convertible Perpetual Preferred
Stock, Series B)
Common stock ($0.01 par value, 150,000,000
shares authorized; 64,296,945 and
61,928,089 shares issued and outstanding as 646 619
of March 31, 2016 and December 31, 2015,
respectively)
Additional paid-in capital 1,082,293 1,079,513
Accumulated deficit (1,606,115) (1,536,354)
----------- -------------
Total stockholders' deficit (523,123) (456,169)
----------- -------------
Total liabilities and stockholders' deficit $ 1,421,203 $ 1,501,304
=========== =============
SANCHEZ ENERGY CORPORATION
Non-GAAP Reconciliation - Adjusted EBITDA
Three Months Ended March 31,
----------------------------
2016 2015
------------- -------------
Net income (loss) $ (65,774) $ (497,345)
Plus:
Interest expense 31,606 31,558
Net gains on commodity derivative contracts (22,757) (41,303)
Net settlements received on commodity
derivative contracts (1) 53,159 29,355
Depreciation, depletion, amortization and
accretion 46,965 102,657
Impairment of oil and natural gas properties 22,084 441,450
Stock-based compensation expense 3,344 7,694
Write off of joint venture receivable, non-
recurring -- 2,251
Income tax expense -- 7,442
Less:
Amortization of deferred gain on Western
Catarina Midstream Divestiture (3,703) --
Interest income (326) (93)
------------- -------------
Adjusted EBITDA $ 64,598 $ 83,666
============= =============
(1) This amount includes premiums accrued but
not paid as of the end of the period.
SANCHEZ ENERGY CORPORATION
Non-GAAP Reconciliation - Adjusted Net Income
Three Months Ended March 31,
----------------------------
2016 2015
------------- -------------
Net loss $ (65,774) $ (497,345)
Less: Preferred stock dividends (3,987) (3,991)
------------- -------------
Net loss attributable to common shares and
participating securities (69,761) (501,336)
Plus:
Non-cash preferred stock dividends associated
with conversion -- --
Non-cash write off of joint venture
receivables -- 2,251
Net gains on commodity derivatives contracts (22,757) (41,303)
Net settlements received (paid) on commodity
derivative contracts (1) 53,159 29,355
Premiums on commodity derivative contracts
(1) -- --
Impairment of oil and natural gas properties 22,084 441,450
Stock-based compensation expense 3,344 7,694
Acquisition and divestiture costs included in
general and administrative -- --
Amortization of deferred gain on Western
Catarina Midstream Divestiture (3,703) --
Tax impact of adjustments to net income (loss)
(2) -- 6,642
------------- -------------
Adjusted net income (loss) (17,634) (55,247)
Adjusted net income allocable to participating
securities (3) -- --
------------- -------------
Adjusted net income (loss) attributable to
common stockholders $ (17,634) $ (55,247)
============= =============
Adjusted net income (loss) per common share -
basic and diluted (4)(5) $ (0.30) $ (0.97)
============= =============
Weighted average number of unrestricted
outstanding common shares to calculate
adjusted net income (loss) per common share -
basic and diluted 58,099 56,805
============= =============
(1) This amount includes premiums accrued but not paid as of the end of the
period.
(2) The tax impact is computed by utilizing the Company's effective tax
rate on the adjustments to reconcile net income (loss) to adjusted net
income (loss).
(3) The Company's restricted shares of common stock are participating
securities.
(4) The three months ended March 31, 2016 excludes 685,597 shares of
weighted average restricted stock and 12,520,179 shares of common stock
resulting from an assumed conversion of the Company's Series A Convertible
Stock and Series B Convertible Perpetual Preferred Stock from the
calculation of the denominator for diluted earnings per common share as
these shares were anti-dilutive.
(5) The three months ended March 31, 2015 excludes 1,556,115 shares of
weighted average restricted stock and 12,530,695 shares of common stock
resulting from an assumed conversion of the Company's Series A Convertible
Stock and Series B Convertible Perpetual Preferred Stock from the
calculation of the denominator for diluted earnings per common share as
these shares were anti-dilutive.
FOR FURTHER INFORMATION PLEASE CONTACT:
COMPANY CONTACT:
Garrick (Rick) Hill
Interim Chief Financial Officer
(877) 847-0009
General Inquiries:
(713) 783-8000
www.sanchezenergycorp.com
Loading...
Loading...
© 2024 Benzinga.com. Benzinga does not provide investment advice. All rights reserved.
Posted In: Press Releases
Benzinga simplifies the market for smarter investing
Trade confidently with insights and alerts from analyst ratings, free reports and breaking news that affects the stocks you care about.
Join Now: Free!
Already a member?Sign in
