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Section 1: 8-K (8-K)

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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 8-K

CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Date of Report (or Date of Earliest Event Reported): February 27, 2019

SilverBow Resources, Inc.
(Exact name of Registrant as specified in its charter)

Delaware
001-8754
20-3940661
(State or other jurisdiction
of incorporation)
(Commission File Number)
(IRS Employer
Identification No.)

575 North Dairy Ashford, Suite 1200
Houston, Texas 77079
(Address of principal executive offices)

(281) 874-2700
(Registrant’s telephone number)

N/A
(Former Name or former address, if changed since last report)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):

o
Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
o
Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
o
Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
o
Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).

Emerging growth company o


1



If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

2




Item 2.02.    Results of Operations and Financial Condition
In a news release after the market closed on February 27, 2019, SilverBow Resources, Inc. (“SilverBow Resources” or the “Company”) announced fourth quarter and full year 2018 financial and operational results, and reported that a conference call for investors, discussing the Company’s financial and operational results, would be held at 8 a.m. (CST) on February 28, 2019. In the release, the Company also announced that the conference call would be webcast live and archived on its website at www.sbow.com. The press release is attached to this report as Exhibit 99.1. SilverBow Resources does not intend for this Item 2.02 or Exhibit 99.1 to be incorporated by reference into its filings under the Securities Exchange Act of 1934.

Item 9.01.    Financial Statements and Exhibits
(d) Exhibit
Exhibit
Number
 
Description
 
 
 
99.1
 
 
 
 

3



SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
Date: February 27, 2019

 
 
 
SilverBow Resources, Inc.
 
 
 
 
By:
/s/ Christopher M. Abundis
 
 
 
 
 
Christopher M. Abundis
Senior Vice President, General Counsel and Secretary

 


4
(Back To Top)

Section 2: EX-99.1 (EXHIBIT 99.1)

Exhibit



396905469_silverbowlogoblacka03.jpg    

COMPANY CONTACT:
Jeff Magids
Senior Manager, Finance & Investor Relations
(281) 874-2700, (800) 777-2412
FOR IMMEDIATE RELEASE

SilverBow Resources Announces Fourth Quarter and Full Year 2018 Results;
2019 Capital Program and Guidance
Houston, TX - February 27, 2019 - SilverBow Resources, Inc. (NYSE: SBOW) (“SilverBow” or the “Company”) today announced operating and financial results for the fourth quarter and full year 2018.
Highlights for the fourth quarter include:
Net production averaged approximately 227 million cubic feet of natural gas equivalent per day (“MMcfe/d”), an 18% increase over third quarter
Revenues of $88.2 million, up 36% from third quarter on crude oil and natural gas realizations of 104% and 105% of WTI and Henry Hub, respectively, excluding hedging
Net Income of $56.8 million
Adjusted EBITDA (a non-GAAP measure) of $56.5 million, a 27% increase quarter over quarter
SilverBow's McMullen Oil area delivers a 30-day average initial production ("IP") rate of 147 barrels of oil equivalent per day ("Boe/d") per 1,000' of lateral (94% liquids) per well from latest two-well pad
Highlights for the full year 2018 include:
Net production averaged approximately 185 MMcfe/d, a 20% increase year over year
Lease operating expenses of $0.26/Mcfe down from $0.39/Mcfe, a 33% decrease from prior year
Net Income of $74.6 million
Adjusted EBITDA (a non-GAAP measure) of $168.4 million, a 38% increase year over year
Year-end 2018 estimated proved reserves of 1.3 Tcfe (41% proved developed), up 31% from prior year with a Standardized Measure of $994 million and a PV-10 (a non-GAAP measure) of $1.1 billion at SEC pricing
Maintained reserve life index in excess of 16 years
2019 Capital Program and Guidance:
Full-year capital program of $250-$260 million, a 17% decrease from prior year





Full year estimated production guidance of 225-239 MMcfe/d, implying a 25% increase year over year based on the mid-point, with a 17% increase in gas and 69% increase in liquids
Capital program balances investment between SilverBow's gas and liquids opportunities
2019 focus on becoming cash flow positive while still generating meaningful annual production growth
Adjusted EBITDA and PV-10 are non-GAAP measures and are reconciled at the end of this press release.
MANAGEMENT COMMENTS
Sean Woolverton, SilverBow’s Chief Executive Officer, commented, "2018 proved to be another great year for SilverBow. We pursued a more active drilling program specifically designed to delineate our asset base. We completed more wells than originally planned and selectively moved toward high intensity slickwater fracs resulting in better well results. Our fourth quarter numbers were bolstered by successful liquids drilling, furthering the Company's move toward a more a balanced production mix. By leveraging our competitive lifting costs and taking advantage of our proximity to key downstream markets and favorable basis differentials, we continue to create sustainable value for our shareholders."
Woolverton commented further, “By focusing on repeatable results and continual per-unit cost reductions, we achieved our goal of expanding our full year Adjusted EBITDA margin to 65% of oil and gas sales. Our full year 2018 production increased 20%, and our lease operating expenses declined 33% on a per unit basis compared to full year 2017. Our growth profile is further supported by a deep inventory of high quality drilling locations providing over 15 years of development at a two-rig pace. As of year-end 2018, our proved reserves were 1.3 Tcfe with a PV-10 of $1.1 billion, an increase of 31% and 40%, respectively, from 2017. With a strong balance sheet and ongoing cost initiatives, our 2019 capital program should allow us to reach cash flow positive in the second half of 2019 while still generating meaningful annual production growth."
OPERATIONS HIGHLIGHTS
During the fourth quarter 2018, the Company brought 12 net wells online. For the full year, the Company drilled 33 net wells and completed 32 net wells. The number of wells completed is above the Company's prior guidance of 25-27 net wells. The Company drilled in all areas of its portfolio during 2018 and more recently has increased its investment in liquids opportunities.
In the Webb County Gas area, which includes Fasken, the Company brought 13 net wells online in 2018. The Company focused on developing its high return Lower Eagle Ford wells and strategically appraising and delineating its Upper Eagle Ford locations. The Fasken development demonstrates the Company’s shift to selectively employing high intensity slickwater fracs across its portfolio. For the second half of 2018, the Company averaged a completion intensity of approximately 2,700 pounds of proppant





per lateral foot and 59 barrels of fluid per lateral foot, an increase of 71% and 161%, respectively, from the first half of the year. The Company continues to value Fasken's consistent performance, low operating expense and upside potential.
In the La Salle Condensate area, which includes Artesia, the Company brought five net wells online in 2018. Due to operational improvements and service price reductions, the Company realized an 18% reduction in total well cost per foot from a two-well pad that was brought online in the third quarter and a three-well pad that was brought online in the fourth quarter. All five wells were completed similarly and averaged approximately 2,400 pounds of proppant per foot and 64 barrels of slickwater fluid per foot. Based on these results, the Company plans to accelerate the development of the La Salle Condensate area in 2019, which it believes will increase its oil and natural gas liquids production.
In the Southern Eagle Ford Gas fairway, which includes Oro Grande, Uno Mas and south AWP, the Company carried forward its successful delineation and appraisal across its 60,000 gross acre position. The Company continues to realize operational efficiencies with its NMC 6H well costing 30% less and being drilled 35% faster than the average of its NMC 1H through NMC 5H wells. In addition, the Company continued to add to its position through leasing and acreage trades. The Company swapped 2,300 net isolated acres for 4,300 net acres contiguous to its Southern Eagle Ford Gas area. In total, this acreage trade added 35 gross drilling locations. Additionally, the acreage the Company traded away was stranded and would have required a significant amount of midstream capital investment in order to develop.
In the McMullen Oil area, which includes north AWP and where the Company had not been active for several years, the team set a Company record by drilling an 11,400 foot lateral in the fourth quarter with a second well on this pad also exceeding 11,000 feet. During 2018, the Company decreased its drilling cost per lateral foot on a recent three-well pad by 27% compared to a three-well pad drilled in 2014. These developments have affected both the cost and the speed of drilling, with the team setting a spud to total depth Company record of 6.8 days on the SMR 21H, a 31% reduction from the prior Company record.
In 2018, the Company conducted numerous initiatives to reduce capital expenditures, including moving to offline production cementing, using significant amounts of regional sand and the more widespread utilization of simultaneous-operations. Offline production cementing, which allows drilling rigs to reduce walking time in-between wells, saved roughly one-half day per well on multi-well pads. In 2018, the Company pumped over 200 million pounds of regional sand, over 30% of the total sand pumped for the year, and aims to increase this percentage in 2019 due to its compelling value proposition. The Company's use of simultaneous-operations, including flowback and drill out activities, helped decrease the time to bring a well online by two days on average. These shortened cycle times, combined with our artificial intelligence guided rate-transient analysis, allow the Company to turn wells online faster and manage them better during the critical initial flowback period.





PRODUCTION VOLUMES, OPERATING COSTS, AND REALIZED PRICES
The Company's total net production for the fourth quarter averaged approximately 227 MMcfe/d, which was above the midpoint of guidance. Production mix for the fourth quarter consisted of approximately 6% crude oil, 84% natural gas, and 10% NGLs.
Lease operating expenses of $0.23/Mcfe were lower than the $0.34/Mcfe reported in the fourth quarter 2017, a decrease of 33%. Lease operating expenses for the fourth quarter and full year 2018 were within the Company’s guidance range, primarily driven by continued cost reduction initiatives.
After deducting $1.7 million of non-cash compensation expense, cash general and administrative costs of $4.0 million were significantly lower than the $5.0 million reported in the fourth quarter 2017. Cash general and administrative costs compared favorably to guidance due to ongoing efforts to reduce administrative costs.
Fourth quarter transportation and processing expenses came in at $0.35/Mcfe, while production and ad valorem taxes were 3.7% of oil and gas revenue. Production and ad valorem taxes came in below the low end of the Company's guidance range.
The Company’s average realized natural gas price, excluding the effect of hedging, was $3.84/Mcf in the fourth quarter compared to $2.97/Mcf in the third quarter. The average realized crude oil selling price, excluding the effect of hedging, was $61.19/Bbl in the fourth quarter, down from $71.68/Bbl in the third quarter. The average realized NGL selling price in the fourth quarter was $22.81/Bbl, compared to $30.59/Bbl in the third quarter. The Company continues to benefit from strong basis pricing in the Eagle Ford. Crude oil and natural gas realizations in the fourth quarter were 104% and 105% of WTI and Henry Hub, respectively, excluding hedging.
YEAR-END 2018 RESERVES
The Company reported year-end estimated proved reserves of 1.35 trillion cubic feet equivalent (Tcfe), an increase of 31% over year-end 2017. Specific highlights from the Company’s year-end reserve report include:
Finding and development costs of $0.74/Mcfe
All-sources reserve replacement of 617%
Standardized Measure of $994 million
PV-10 value (non-GAAP measure) of $1.1 billion, an increase of 40% over prior year






The table below reconciles 2017 reserves to 2018 reserves:
 
Total (MMcfe)
Proved reserves as of December 31, 2017
1,024,421

Extensions, discoveries and other additions
450,354

Revisions of previous estimates
(34,443
)
Purchases of minerals in place
427

Sales of minerals in place
(27,867
)
Production
(67,530
)
Proved reserves as of December 31, 2018
1,345,362

The Company's total estimated proved reserves at December 31, 2018, were approximately 6% crude oil, 81% natural gas, and 13% NGLs, while 41% of its total proved reserves were developed. All of the Company's proved reserves are located in Texas. Total capital costs incurred during 2018 were $308.3 million, which included approximately $284.5 million for development costs, $22.7 million for leasehold acquisition and prospect costs, and $1.1 million for property acquisitions.
The SEC prices used for reporting the Company's year-end 2018 estimated proved reserves, which have been adjusted for basis and quality differentials, were $3.04 per Mcf for natural gas, $26.63 per Bbl for natural gas liquids and $66.96 per Bbl for crude oil compared to $2.95 per Mcf, $20.32 per Bbl, and $50.38 per Bbl in 2017. Using the SEC prices, the pre-tax present value of future net cash flows discounted at 10% (“PV-10”) of the year-end 2018 proved reserves was $1.1 billion with a Standardized Measure of $994 million.
FINANCIAL RESULTS
The Company reported total oil and gas revenues of $88.2 million for the fourth quarter, up 36% over the third quarter. On a GAAP basis, the Company reported net income of $56.8 million for the fourth quarter, which includes a net gain on the value of the Company's hedge portfolio of $20.9 million.
The Company reported Adjusted EBITDA of $56.5 million for the fourth quarter, up 27% over the third quarter. Adjusted EBITDA is a non-GAAP financial measure. Please see the tables included with today's news release for a reconciliation of net income to Adjusted EBITDA.
Capital expenditures incurred during the fourth quarter totaled approximately $95 million.





2019 CAPITAL PROGRAM
The Company provided its 2019 capital budget range of $250-$260 million, which provides for 26-27 net operated wells drilled compared to 33 net operated wells in 2018. Approximately 85% of the 2019 capital budget is allocated toward drilling and completion, driven primarily by 18-19 net wells in the La Salle Condensate area, two net wells in the McMullen Oil area, five net wells in the Southern Eagle Ford gas fairway and one net well in the Webb County gas area.
For 2019, the Company will be moving to a one-rig program in the second quarter. It will be retaining its super-spec rig which has walking capabilities. The Company will be utilizing this rig primarily on development drilling, but will continue drilling some delineation and appraisal wells in support of the Company's strategic goal of moving into development mode for all of its areas. The Company is already seeing pricing across drilling and completions services reminiscent of 2015 and is selectively locking in long-term contracts with limited to no commitment of activity levels for volume of sales.
2019 GUIDANCE
For the first quarter, the Company is guiding for estimated production of 210-217 MMcfe/d. For the full year, the Company is guiding for estimated production of 225-239 MMcfe/d, implying a 25% increase year over year based on the mid-point of the guidance range. Additional detail concerning the Company's first quarter and full year 2019 financial and operational guidance can be found in the table included with today’s news release and the Corporate Presentation uploaded to the Investor Relations section of the Company’s website.
HEDGING UPDATE
Hedging continues to be an important element of SilverBow’s strategy. The Company maintains an active hedging program to provide predictable cash flows while still allowing for flexibility in capturing price increases. As of December 31, 2018, the Company had approximately 65% of total estimated production volumes hedged for full year 2019, using the mid-point of production guidance. The Company continues to layer on additional hedges when prices are favorable, including both oil and gas basis. Please see the Company's Form 10-K filing, which the Company expects to file on Thursday, February 28, 2019, for a detailed summary of derivative contracts.
CAPITAL STRUCTURE AND LIQUIDITY
The Company's liquidity as of December 31, 2018, was $217.5 million, primarily consisting of $2.5 million of cash and $215.0 million of availability under the Company’s credit facility. The Company believes it has sufficient liquidity to meet its obligations





for at least the next twelve months and execute its long-term development plans. As of January 31, 2019, the Company had 11.7 million total common shares outstanding.
CONFERENCE CALL & UPDATED INVESTOR PRESENTATION
The Company will host a conference call for investors on Thursday, February 28, 2019, at 8:00 a.m. Central Time (9:00 a.m. Eastern Time). Interested investors can listen to the call by dialing 1-877-420-2751 (U.S.) or 1-442-275-1680 (International) and requesting "Fourth Quarter and Full Year 2018 Earnings Conference Call" or by visiting the SilverBow website.
A simultaneous webcast of the call may be accessed over the internet by visiting our website at www.sbow.com, clicking on “Investor Relations” and “Events and Presentations” and then clicking on the “Fourth Quarter and Full Year 2018 Earnings Conference Call” link. The webcast will be archived for replay on the SilverBow website for 14 days. Additionally, an updated Corporate Presentation will be uploaded to the Investor Relations section of the Company's website before the conference call.
ABOUT SILVERBOW RESOURCES, INC.
SilverBow Resources, Inc. (NYSE: SBOW) is a Houston-based energy company actively engaged in the exploration, development, and production of oil and gas in the Eagle Ford Shale in South Texas. With almost 30 years of history operating in South Texas, the Company possesses a significant understanding of regional reservoirs which we leverage to assemble high-quality drilling inventory while continuously enhancing our operations to maximize returns on capital invested.
For more information, please visit www.sbow.com.
FORWARD-LOOKING STATEMENTS
This 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. These forward-looking statements represent management's expectations or beliefs concerning future events, and it is possible that the results described in this release will not be achieved. These forward-looking statements are subject to a number of risks and uncertainties, many of which are beyond our control, which could cause actual results to differ materially from the results discussed in the forward-looking statements, including among other things: oil and natural gas price levels and volatility, our ability to satisfy our short- or long-term liquidity needs; our ability to execute our business strategy, including the success of our drilling and development efforts; timing, cost and amount of future production of oil and natural gas; and other factors discussed in the Company’s reports filed with the SEC, including its Annual Report on Form 10-K for the year ended December 31, 2018. All statements, other than statements of historical fact included in this press release, regarding our strategy, future operations, financial position, future cash flows, estimated production levels,





expected oil and natural gas pricing, estimated oil and natural gas reserves or the present value thereof, reserve increases, capital expenditures, budget, projected costs, prospects, plans and objectives of management are forward-looking statements.
All forward-looking statements speak only as of the date this news release. You should not place undue reliance on these forward-looking statements. Although we believe that our plans, intentions and expectations reflected in or suggested by the forward-looking statements we make in this release are reasonable, we can give no assurance that these plans, intentions or expectations will be achieved. The risk factors and other factors noted herein and in the Company's SEC filings could cause its actual results to differ materially from those contained in any forward-looking statement. These cautionary statements qualify all forward-looking statements attributable to us or persons acting on our behalf.
All subsequent written and oral forward-looking statements attributable to us or to persons acting on our behalf are expressly qualified in their entirety by the foregoing. We undertake no obligation to publicly release the results of any revisions to any such forward-looking statements that may be made to reflect events or circumstances after the date of this release or to reflect the occurrence of unanticipated events. New factors emerge from time to time, and it is not possible for us to predict all such factors.
(Financial Highlights to Follow)







Consolidated Balance Sheets
SilverBow Resources, Inc. and Subsidiaries (in thousands, except share amounts)
 
December 31, 2018
 
December 31, 2017
ASSETS
 
 
 
Current Assets:
 
 
 
Cash and cash equivalents
$
2,465

 
$
7,806

Accounts receivable, net
46,472

 
27,263

Fair value of commodity derivatives
15,261

 
5,148

Other current assets
2,126

 
2,352

Total Current Assets
66,324

 
42,569

Property and Equipment:
 

 
 

Property and Equipment, Full Cost Method, including $56,715 and $50,377 of unproved property costs not being amortized
986,100

 
712,166

Less – Accumulated depreciation, depletion, amortization and impairment
(284,804
)
 
(216,769
)
Property and Equipment, Net
701,296

 
495,397

Fair Value of long-term commodity derivatives
4,333

 
2,553

Other Long-Term Assets
5,567

 
10,751

Total Assets
$
777,520

 
$
551,270

LIABILITIES AND STOCKHOLDERS’ EQUITY
 

 
 

Current Liabilities:
 

 
 

Accounts payable and accrued liabilities
$
48,921

 
$
44,437

Fair value of commodity derivatives
2,824

 
5,075

Accrued capital costs
38,073

 
10,883

Accrued interest
1,513

 
2,106

Undistributed oil and gas revenues
14,681

 
12,996

Total Current Liabilities
106,012

 
75,497

 
 
 
 
Long-term debt
387,988

 
265,325

Deferred tax liabilities, net
1,014

 

Asset retirement obligations
3,956

 
8,678

Fair value of long-term commodity derivatives
3,723

 
2,758

Other long-term liabilities

 
5,554

Commitments and Contingencies


 


Stockholders' Equity:
 

 
 

Preferred stock, $.01 par value, 10,000,000 shares authorized, none issued

 

Common stock, $.01 par value, 40,000,000 shares authorized, 11,757,972 and 11,621,385 shares issued and 11,692,101 and 11,570,621 shares outstanding
118

 
116

Additional paid-in capital
286,281

 
279,111

Treasury stock held, at cost, 65,871 and 50,764 shares
(1,870
)
 
(1,452
)
Retained earnings (Accumulated deficit)
(9,702
)
 
(84,317
)
Total Stockholders’ Equity
274,827

 
193,458

Total Liabilities and Stockholders’ Equity
$
777,520

 
$
551,270

See accompanying Notes to Consolidated Financial Statements.







Consolidated Statements of Operations
SilverBow Resources, Inc. and Subsidiaries (in thousands, except per-share amounts)
 
Year Ended December 31, 2018
 
Year Ended December 31, 2017
Revenues:
 
 
 
Oil and gas sales
$
257,286

 
$
195,910

 
 
 
 
Operating Expenses:
 
 
 

General and administrative, net
22,570

 
30,000

Depreciation, depletion, and amortization
68,035

 
46,933

Accretion of asset retirement obligations
419

 
2,322

Lease operating expense
17,643

 
21,908

Transportation and gas processing
23,848

 
19,360

Severance and other taxes
11,394

 
8,205

Total Operating Expenses
143,909

 
128,728

 
 
 
 
Operating Income (Loss)
113,377

 
67,182

 
 
 
 
Non-Operating Income (Expense)
 
 
 
Net gain (loss) on commodity derivatives
(9,777
)
 
17,913

Interest expense, net
(27,666
)
 
(15,070
)
Other income (expense), net
(391
)
 
(8
)
 
 
 
 
Income (Loss) Before Income Taxes
75,543

 
70,017

 
 
 
 
Provision (Benefit) for Income Taxes
928

 
(1,954
)
 
 
 
 
Net Income (Loss)
$
74,615

 
$
71,971

 
 
 
 
Per Share Amounts:
 
 
 

 
 
 
 
Basic:  Net Income (Loss)
$
6.40

 
$
6.28

 
 
 
 
Diluted:  Net Income (Loss)
$
6.34

 
$
6.25

 
 
 
 
Weighted Average Shares Outstanding - Basic
11,655

 
11,453

 
 
 
 
Weighted Average Shares Outstanding - Diluted
11,764

 
11,514

 
 
 
 














Consolidated Statements of Operations (Unaudited)
SilverBow Resources, Inc. and Subsidiaries (in thousands, except per-share amounts)

 
Three Months Ended December 31, 2018
 
Three Months Ended December 31, 2017
Revenues:
 
 
 
Oil and gas sales
$
88,152

 
$
58,694

 
 
 
 
Operating Expenses:
 
 
 

General and administrative, net
5,714

 
7,324

Depreciation, depletion, and amortization
23,041

 
14,558

Accretion of asset retirement obligations
88

 
600

Lease operating expense
4,715

 
5,528

Transportation and gas processing
7,263

 
5,293

Severance and other taxes
3,238

 
1,828

Total Operating Expenses
44,059

 
35,131

 
 
 
 
Operating Income (Loss)
44,093

 
23,563

 
 
 
 
Non-Operating Income (Expense)
 
 
 
Net gain (loss) on commodity derivatives
20,930

 
3,448

Interest expense, net
(7,979
)
 
(3,953
)
Other income (expense), net
86

 
125

 
 
 
 
Income (Loss) Before Income Taxes
57,130

 
23,183

 
 
 
 
Provision (Benefit) for Income Taxes
379

 
(1,954
)
 
 
 
 
Net Income (Loss)
$
56,751

 
$
25,137

 
 
 
 
Per Share Amounts:
 
 
 

 
 
 
 
Basic:  Net Income (Loss)
$
4.85

 
$
2.17

 
 
 
 
Diluted:  Net Income (Loss)
$
4.82

 
$
2.17

 
 
 
 
Weighted Average Shares Outstanding - Basic
11,692

 
11,561

 
 
 
 
Weighted Average Shares Outstanding - Diluted
11,783

 
11,602

 
 
 
 








Consolidated Statements of Cash Flows
SilverBow Resources, Inc. and Subsidiaries (in thousands)
 
Year Ended December 31, 2018
 
Year Ended December 31, 2017
Cash Flows from Operating Activities:
 
 
 
Net income (loss)
$
74,615

 
$
71,971

Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities-
 
 
 

Depreciation, depletion, and amortization
68,035

 
46,933

Accretion of asset retirement obligations
419

 
2,322

Deferred income tax benefit
1,014

 

Share-based compensation expense
5,980

 
6,849

(Gain) Loss on derivatives, net
9,777

 
(17,913
)
Cash settlements (paid) received on derivatives
(19,677
)
 
(1,411
)
Settlements of asset retirement obligations
(187
)
 
(2,335
)
Write-down of debt issuance cost

 
2,676

Other
5,293

 
(559
)
Change in operating assets and liabilities-
 
 
 

(Increase) decrease in accounts receivable and other assets
(20,470
)
 
(7,169
)
Increase (decrease) in income taxes payable
53

 

Increase (decrease) in accrued interest
(593
)
 
385

Net Cash Provided by (Used in) Operating Activities
121,573

 
107,838

Cash Flows from Investing Activities:
 
 
 

Additions to property and equipment
(266,532
)
 
(192,982
)
Acquisition of producing properties
(1,002
)
 
(9,426
)
Proceeds from the sale of property and equipment
27,673

 
702

Payments on property sale obligations
(8,740
)
 

Transfer of company funds in restricted cash
(222
)
 
26

Net Cash Provided by (Used in) Investing Activities
(248,823
)
 
(201,680
)
Cash Flows from Financing Activities:
 
 
 

Proceeds from long-term debt issuances

 
198,000

Proceeds from bank borrowings
306,800

 
404,700

Payments of bank borrowings
(184,800
)
 
(529,700
)
Net proceeds from issuances of common stock
709

 
39,179

Purchase of treasury shares
(418
)
 
(777
)
Payments of debt issuance costs
(602
)
 
(10,031
)
Net Cash Provided by (Used in) Financing Activities
121,689

 
101,371

 
 
 
 
Net Increase (Decrease) in Cash and Cash Equivalents and Restricted Cash
(5,561
)
 
7,529

Cash, Cash Equivalents and Restricted Cash at Beginning of Year
8,026

 
497

Cash, Cash Equivalents and Restricted Cash at End of Year
$
2,465

 
$
8,026

 
 
 
 
Supplemental Disclosures of Cash Flows Information:
 
 
 

Cash paid during period for interest, net of amounts capitalized
$
24,794

 
$
10,428

Changes in capital accounts payable and capital accruals
$
45,349

 
$
9,894

Changes in other long-term liabilities for capital expenditures
$
(5,000
)
 
$
5,000








SilverBow Resources, Inc.
Non-GAAP Financial Measures
Reconciliation of Net Income (GAAP) to Adjusted EBITDA (Non-GAAP)
(In thousands)
(Unaudited)

We present adjusted EBITDA attributable to common stockholders (“Adjusted EBITDA”) in addition to our reported net income (loss) in accordance with U.S. GAAP. Adjusted EBITDA is a non-GAAP financial measure that is used as a supplemental financial measure by our management and by external users of our financial statements, such as investors, commercial banks and others, to assess our operating performance as compared to that of other companies in our industry, without regard to financing methods, capital structure or historical costs basis. It is also used to assess our ability to incur and service debt and fund capital expenditures. When we refer to the term Adjusted EBITDA margin, we mean Adjusted EBITDA divided by Oil and Gas Sales.

Our Adjusted EBITDA should not be considered an alternative to net income (loss), operating income (loss), cash flows provided by (used in) operating activities or any other measure of financial performance or liquidity presented in accordance with U.S. GAAP. Our Adjusted EBITDA may not be comparable to similarly titled measures of another company because all companies may not calculate Adjusted EBITDA in the same manner.


 
Year Ended December 31, 2018
Year Ended December 31, 2017
Net Income (Loss)
$
74,615

$
71,971

Plus:
 
 
Depreciation, depletion and amortization
68,035

46,933

Accretion of asset retirement obligations
419

2,322

Interest expense
27,666

15,070

Derivative (gain)/loss
9,777

(17,913
)
Derivative cash settlements collected/(paid) (1)
(19,060
)
(1,545
)
Income tax expense/(benefit)
928

(1,954
)
Share-based compensation expense
5,980

6,849

Adjusted EBITDA
$
168,360

$
121,733

(1) This includes accruals for settled contracts covering commodity deliveries during the period where the actual cash settlements occur outside of the period.

 
Three Months Ended December 31, 2018
Three Months Ended December 31, 2017
Net Income (Loss)
$
56,751

$
25,137

Plus:
 
 
Depreciation, depletion and amortization
23,041

14,558

Accretion of asset retirement obligations
88

600

Interest expense
7,979

3,953

Derivative (gain)/loss
(20,930
)
(3,448
)
Derivative cash settlements collected/(paid) (1)
(12,523
)
807

Income tax expense/(benefit)
379

(1,954
)
Share-based compensation expense
1,739

2,311

Adjusted EBITDA
$
56,524

$
41,964

(1) This includes accruals for settled contracts covering commodity deliveries during the period where the actual cash settlements occur outside of the period.







Standardized Measure of Discounted Future Net Cash Flows

The following table provides a reconciliation between the Standardized Measure (the most directly comparable financial measure calculated in accordance with U.S. GAAP) and PV-10 Value of the Company's proved reserves:
 
As of December 31,
(in millions)
2018
 
2017
 
2016
PV-10 Value
$
1,128

 
$
805

 
$
442

Less: Future income taxes (discounted at 10%)
134

 
73

 
35

Standardized Measure of Discounted Future Net Cash Flows
$
994

 
$
732

 
$
407








Production Volumes & Pricing (Unaudited)
SilverBow Resources, Inc. and Subsidiaries

 
 
Year Ended December 31, 2018
Year Ended December 31, 2017
Production volumes:
 
 
 
Oil (MBbl) (1)
 
688

685

Natural gas (MMcf)
 
56,665

45,751

Natural gas liquids (MBbl) (1)
 
1,123

1,046

Total (MMcfe)
 
67,530

56,135

 
 
 
 
Oil, Natural gas and Natural gas liquids sales:
 
 
 
Oil
 
$
45,375

$
34,903

Natural gas
 
183,272

138,404

Natural gas liquids
 
28,639

22,602

Total
 
$
257,286

$
195,910

 
 
 
 
Average realized price:
 
 
 
Oil (per Bbl)
 
$
65.93

$
50.98

Natural gas (per Mcf)
 
3.23

3.03

Natural gas liquids (per Bbl)
 
25.51

21.61

Average per Mcfe
 
$
3.81

$
3.49

 
 
 
 
(1) Oil and NGLs are converted at the rate of one barrel of oil equivalent to six Mcfe

 
 
Three Months Ended December 31, 2018
Three Months Ended December 31, 2017
Production volumes:
 
 
 
Oil (MBbl) (1)
 
215

229

Natural gas (MMcf)
 
17,584

12,847

Natural gas liquids (MBbl) (1)
 
330

347

Total (MMcfe)
 
20,855

16,302

 
 
 
 
Oil, Natural gas and Natural gas liquids sales:
 
 
 
Oil
 
$
13,173

$
13,180

Natural gas
 
67,455

37,055

Natural gas liquids
 
7,526

8,459

Total
 
$
88,154

$
58,694

 
 
 
 
Average realized price:
 
 
 
Oil (per Bbl)
 
$
61.19

$
57.64

Natural gas (per Mcf)
 
3.84

2.88

Natural gas liquids (per Bbl)
 
22.81

24.37

Average per Mcfe
 
$
4.23

$
3.60

 
 
 
 
(1) Oil and NGLs are converted at the rate of one barrel of oil equivalent to six Mcfe







Finding and Development (“F&D”) Cost Calculation:
(Unaudited)

F&D costs are commonly used to assist in the evaluation of how much it costs the Company, on a per Mcfe basis, to add proved reserves. We present F&D costs in addition to and used in conjunction with our financial statements prepared in accordance with U.S. GAAP. Due to various factors, including but not limited to timing differences, F&D costs do not necessarily reflect precisely the costs associated with particular reserves. Further, our F&D costs may not be comparable to similarly titled measures of another company because all companies may not calculate F&D costs in the same manner.
F&D All-In costs are calculated by dividing the total acquisition, exploration, and development costs for the year by extensions, discoveries, and other additions, purchases of minerals in place, and total revisions for the year.
Reserve replacement ratio is calculated by dividing the sum of extensions, discoveries, and other additions, purchases of minerals in place, and total revisions for the year by production.
F&D Cost Reconciliation
 
(in thousands)
Year Ended December 31, 2018
Lease acquisitions and prospect costs
$
22,681

Exploration

Development
284,525

Acquisition of property
1,096

Total acquisition, exploration and development
$
308,302

 
 
(in MMcfe)
 
Proved reserves as of December 31, 2017
1,024,421

Extensions, discoveries, and other additions (1)
450,354

Revisions of previous estimates

(34,443
)
Purchases of minerals in place

427

Sales of minerals in place

(27,867
)
Production

(67,530
)
 
 
Proved reserves as of December 31, 2018

1,345,362

 
 
F&D Costs ($/Mcfe)
$
0.74

 
 
Reserve replacement ratio
617
%
(1) The additions in 2018 were primarily due to additions from drilling results and leasing of adjacent acreage.







First Quarter 2019 & Full Year 2019 Guidance

 
 
Guidance
 
 
1Q 2019
 
FY 2019
Production Volumes:
 
 
 
 
 
Oil (Bbls/d)
 
2,650 - 2,750
 
3,500 - 3,800
 
Natural Gas (MMcf/d)
 
173 - 179
 
176 - 187
 
NGLs (Bbls/d)
 
3,450 - 3,550
 
4,600 - 4,900
Total Reported Production (MMcfe/d)
 
210 - 217
 
225 - 239
 
 
 
 
 
Product Pricing :
 
 
 
 
 
Crude Oil NYMEX Differential ($/Bbl)
 
$1.50 - $2.50
 
N/A
 
Natural Gas NYMEX Differential ($/Mcf)
 
$0.05 - $0.10
 
N/A
 
Natural Gas Liquids (% of WTI)
 
35% - 37%
 
N/A
 
 
 
 
 
 
Operating Costs & Expenses :
 
 
 
 
 
Lease Operating Expenses ($/Mcfe)
 
$0.29 - $0.30
 
$0.30 - $0.33
 
Transportation & Processing ($/Mcfe)
 
$0.35 - $0.36
 
$0.32 - $0.34
 
Production Taxes (% of Revenue)
 
5.5% - 6.5%
 
5.5% - 6.5%
 
Cash G&A, net ($MM)
 
$5.2 - $5.7
 
$20.0 - $23.0
 
DD&A Expense ($/Mcfe)
 
$1.10 - $1.15
 
$1.10 - $1.25
 
Cash Interest Expense ($MM)
 
$7.5 - $8.5
 
N/A



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