UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D. C. 20549

 

Form 10-Q

 

x Quarterly Report Pursuant to Section 13 or 15 (d) of the Securities Exchange Act of 1934 for the

 

for the Period Ended September 30, 2017March 31, 2018

 

or

 

¨ Transition Report Pursuant to Section 13 or 15 (d) of the Securities Exchange Act of 1934

 

for the Transition Period From _____________to _____________

 

Commission File Number 033-92894

 

ALY ENERGY SERVICES, INC.

(Exact name of registrant as specified in its charter)

  

Delaware

 

75-2440201

(State or other jurisdiction of incorporation or organization)

 

(I.R.S. Employer Identification No.)

 

 

 

3 Riverway, Suite 920

Houston, TX

 

77056

(Address of Principal Executive Offices)

 

(Zip Code)

 

(713) 333-4000

(Registrant’s Telephone Number, including area code.)

 

Securities registered pursuant to Section 12(b) of the Act:

 

Title of Each Class

Names of Each Exchange on which Registered

Common Stock, $0.001 par value per share

None

 

Securities registered pursuant to Section 12(g) of the Act: None

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ¨ xNo x¨

 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ¨x No x¨

 

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. ¨

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

 

Large accelerated filer

¨

Accelerated filer

¨

Non-accelerated filer

¨

Smaller reporting company

x

Emerging growth company

¨

 

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. ¨

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No x

 

At November 14, 2017,May 15, 2018, the registrant had 13,818,795 shares of common stock, $0.001 par value, outstanding.

 

Documents Incorporated by Reference: None

 

 
 
 
 

ALY ENERGY SERVICES, INC.

(A Delaware Corporation)

 

INDEX

 

 

Page

 

Part I - I—Financial Information

 

 

 

 

Item 1.

Unaudited Condensed Consolidated Financial Statements

 

3

 

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

24

15

 

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

 

34

21

 

Item 4.

Controls and Procedures

 

34

21

 

 

 

Part II - II—Other Information

 

 

 

 

Item 6.

Exhibits

 

37

24

 

Signatures

 

36

25

 

 

 
2
 
Table of Contents

PART I – FINANCIAL INFORMATION

Item 1. Unaudited Condensed Consolidated Financial Statements

 

Index

Page

Condensed Consolidated Balance Sheets as of March 31, 2018 and December 31, 2017

4

Condensed Consolidated Statements of Operations for the Three Months Ended March 31, 2018 and 2017

 5

Condensed Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2018 and 2017

 6

Notes to Condensed Consolidated Financial Statements

 

Page

Condensed Consolidated Balance Sheets as of September 30, 2017 and December 31, 2016

4

Condensed Consolidated Statements of Operations for the Three and Nine Months Ended September 30, 2017 and 2016

5

Condensed Consolidated Statement of Changes in Stockholders’ Equity (Deficit) for the Nine Months Ended September 30, 2017

6

Condensed Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2017 and 2016

7

 

Notes to Condensed Consolidated Financial Statements

8

 

3
Table of Contents

 

3
Table of Contents

ALY ENERGY SERVICES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands, except share and per share amounts)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

September 30,

2017

 

 

December 31,

2016

 

 

 

(unaudited)

 

 

 

 

ASSETS

 

 

 

 

 

 

Current assets

 

 

 

 

 

 

Cash and cash equivalents

 

$151

 

 

$681

 

Restricted cash

 

 

30

 

 

 

30

 

Receivables, net

 

 

4,049

 

 

 

1,448

 

Prepaid expenses and other current assets

 

 

82

 

 

 

496

 

Total current assets

 

 

4,312

 

 

 

2,655

 

 

 

 

 

 

 

 

 

 

Property and equipment, net

 

 

27,207

 

 

 

28,226

 

Intangible assets, net

 

 

4,295

 

 

 

4,931

 

Other assets

 

 

6

 

 

 

14

 

 

 

 

 

 

 

 

 

 

Total assets

 

$35,820

 

 

$35,826

 

 

 

 

 

 

 

 

 

 

LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)

 

 

 

 

 

 

 

 

Current liabilities

 

 

 

 

 

 

 

 

Accounts payable and accrued expenses

 

$2,278

 

 

$2,075

 

Accrued interest and other - Pelican

 

 

23

 

 

 

1,277

 

Current portion of long-term debt

 

 

5

 

 

 

1,593

 

Current portion of long-term debt - Pelican

 

 

-

 

 

 

18,880

 

Current portion of contingent payment liability

 

 

-

 

 

 

810

 

Total current liabilities

 

 

2,306

 

 

 

24,635

 

 

 

 

 

 

 

 

 

 

Long-term debt, net

 

 

-

 

 

 

10

 

Long-term debt, net - Pelican

 

 

6,127

 

 

 

1,315

 

Other long-term liabilities

 

 

516

 

 

 

708

 

Total liabilities

 

 

8,949

 

 

 

26,668

 

 

 

 

 

 

 

��

 

 

Commitments and contingencies

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Aly Operating redeemable preferred stock

 

 

-

 

 

 

4,924

 

Aly Centrifuge redeemable preferred stock

 

 

-

 

 

 

10,080

 

 

 

 

-

 

 

 

15,004

 

 

 

 

 

 

 

 

 

 

Stockholders' equity (deficit)

 

 

 

 

 

 

 

 

Series A convertible preferred stock of $0.001 par value (liquidation preference of $17,292)

Authorized - 20,000; Issued and outstanding - 17,292 as of September 30, 2017

Authorized, issued, and outstanding - none as of December 31, 2016

 

 

6,755

 

 

 

-

 

Preferred stock of $0.001 par value

Authorized - 9,980,000; none issued and outstanding as of September 30, 2017

Authorized - 10,000,000; none issued and outstanding as of December 31, 2016

 

 

-

 

 

 

-

 

Common stock of $0.001 par value

Authorized - 25,000,000; Issued - 13,819,020; Outstanding - 13,818,795 as of September 30, 2017

Authorized - 25,000,000; Issued - 6,707,039; Outstanding - 6,706,814 as of December 31, 2016

 

 

14

 

 

 

7

 

Additional paid-in-capital

 

 

53,754

 

 

 

28,307

 

Accumulated deficit

 

 

(33,650)

 

 

(34,158)

Treasury stock, 225 shares at cost

 

 

(2)

 

 

(2)

Total stockholders' equity (deficit)

 

 

26,871

 

 

 

(5,846)

 

 

 

 

 

 

 

 

 

Total liabilities and stockholders' equity (deficit)

 

$35,820

 

 

$35,826

 

See accompanying notes to

ALY ENERGY SERVICES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands, except share and per share amounts)

 

 

 

 

 

 

 

 

 

March 31,

2018

 

 

December 31,

2017

 

 

 

(unaudited)

 

 

 

 

ASSETS

 

 

 

 

 

 

Current assets

 

 

 

 

 

 

Cash

 

$929

 

 

$203

 

Restricted cash

 

 

30

 

 

 

30

 

Receivables, net

 

 

3,490

 

 

 

3,883

 

Prepaid expenses and other current assets

 

 

354

 

 

 

390

 

Total current assets

 

 

4,803

 

 

 

4,506

 

Property and equipment, net

 

 

26,449

 

 

 

26,888

 

Intangible assets, net

 

 

3,912

 

 

 

4,099

 

Other assets

 

 

9

 

 

 

9

 

Total assets

 

$35,173

 

 

$35,502

 

 

 

 

 

 

 

 

 

 

LIABILITIES AND STOCKHOLDERS' EQUITY

 

 

 

 

 

 

 

 

Current liabilities

 

 

 

 

 

 

 

 

Accounts payable, accrued expenses and other current liabilities

 

$2,204

 

 

$2,774

 

Accrued interest - related party

 

 

31

 

 

 

26

 

Total current liabilities

 

 

2,235

 

 

 

2,800

 

Long-term debt, net - related party

 

 

6,602

 

 

 

6,352

 

Other long-term liabilities

 

 

411

 

 

 

412

 

Total liabilities

 

 

9,248

 

 

 

9,564

 

 

 

 

 

 

 

 

 

 

Commitments and contingencies

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Stockholders' equity

 

 

 

 

 

 

 

 

Series A convertible preferred stock of $0.001 par value (liquidation preference of $17,292)

 

 

6,755

 

 

 

6,755

 

Authorized-20,000; issued and outstanding-17,292 as of March 31, 2018

 

 

 

 

 

 

 

 

Authorized-20,000; issued and outstanding-17,292 as of December 31, 2017

 

 

 

 

 

 

 

 

Preferred stock of $0.001 par value

 

 

-

 

 

 

-

 

Authorized-9,980,000; issued and outstanding-none as of March 31, 2018

 

 

 

 

 

 

 

 

Authorized-9,980,000; issued and outstanding-none as of December 31, 2017

 

 

 

 

 

 

 

 

Common stock of $0.001 par value

 

 

14

 

 

 

14

 

Authorized-25,000,000; Issued-13,819,020; Outstanding-13,818,795 as of March 31, 2018

 

 

 

 

 

Authorized-25,000,000; Issued-13,819,020; Outstanding-13,818,795 as of December 31, 2017

 

 

 

 

 

Additional paid-in-capital

 

 

53,754

 

 

 

53,754

 

Accumulated deficit

 

 

(34,596)

 

 

(34,583)

Treasury stock, 225 shares at cost

 

 

(2)

 

 

(2)

Total stockholders' equity

 

 

25,925

 

 

 

25,938

 

Total liabilities and stockholders' equity

 

$35,173

 

 

$35,502

 

The accompanying notes are an integral part of these condensed consolidated financial statements.

 

 
4
 
Table of Contents

 

ALY ENERGY SERVICES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except share and per share amounts)

 

 

For the Three Months

Ended September 30,

 

 

For the Nine Months

Ended September 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(unaudited)

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue

 

$4,143

 

 

$2,071

 

 

$11,179

 

 

$8,848

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Expenses:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating expenses

 

 

2,608

 

 

 

1,537

 

 

 

7,167

 

 

 

6,886

 

Depreciation and amortization

 

 

944

 

 

 

1,328

 

 

 

2,793

 

 

 

4,162

 

Selling, general and administrative expenses

 

 

522

 

 

 

841

 

 

 

2,340

 

 

 

3,527

 

Reduction in value of assets

 

 

18

 

 

 

787

 

 

 

58

 

 

 

1,630

 

Total expenses

 

 

4,092

 

 

 

4,493

 

 

 

12,358

 

 

 

16,205

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations

 

 

51

 

 

 

(2,422)

 

 

(1,179)

 

 

(7,357)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other expense (income):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Interest expense, net

 

 

2

 

 

 

629

 

 

 

18

 

 

 

1,777

 

Interest expense - Pelican

 

 

69

 

 

 

-

 

 

 

664

 

 

 

-

 

Gain on extinguishment of debt and other liabilities

 

 

-

 

 

 

-

 

 

 

(2,387)

 

 

-

 

Total other expense (income)

 

 

71

 

 

 

629

 

 

 

(1,705)

 

 

1,777

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations before income taxes

 

 

(20)

 

 

(3,051)

 

 

526

 

 

 

(9,134)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income tax expense (benefit)

 

 

6

 

 

 

(872)

 

 

18

 

 

 

(3,406)

Net income (loss) from continuing operations

 

 

(26)

 

 

(2,179)

 

 

508

 

 

 

(5,728)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss (income) from discontinued operations, net of income taxes

 

 

-

 

 

��

(37)

 

 

-

 

 

 

1,345

 

Net income (loss)

 

 

(26)

 

 

(2,142)

 

 

508

 

 

 

(7,073)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Preferred stock dividends

 

 

-

 

 

 

183

 

 

 

63

 

 

 

542

 

Accretion of preferred stock, net

 

 

-

 

 

 

(32)

 

 

-

 

 

 

(94)

Net income (loss) available to common stockholders

 

$(26)

 

$(2,293)

 

$445

 

 

$(7,521)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic earnings per share information:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income (loss) from continuing operations available to common stockholders

 

$0.00

 

 

$(0.35)

 

$0.03

 

 

$(0.92)

Income (loss) from discontinued operations, net of income taxes

 

 

-

 

 

 

0.01

 

 

 

-

 

 

 

(0.20)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income (loss) available to common stockholders

 

$0.00

 

 

$(0.34)

 

$0.03

 

 

$(1.12)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted-average shares - basic

 

 

13,818,795

 

 

 

6,706,814

 

 

 

13,011,207

 

 

 

6,706,814

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Diluted earnings per share information:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income (loss) from continuing operations available to common stockholders

 

$0.00

 

 

$(0.35)

 

$0.01

 

 

$(0.92)

Income (loss) from discontinued operations, net of income taxes

 

 

-

 

 

 

0.01

 

 

 

-

 

 

 

(0.20)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income (loss) available to common stockholders

 

$0.00

 

 

$(0.34)

 

$0.01

 

 

$(1.12)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted-average shares - diluted

 

 

13,818,795

 

 

 

6,706,814

 

 

 

70,123,810

 

 

 

6,706,814

 

See accompanying notes to

ALY ENERGY SERVICES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except share and per share amounts)

 

 

 

 

 

 

 

For the Three Months

Ended March 31,

 

 

 

2018

 

 

2017

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

Revenue

 

$4,336

 

 

$2,837

 

Expenses:

 

 

 

 

 

 

 

 

Operating expenses

 

 

2,610

 

 

 

1,940

 

Depreciation and amortization

 

 

891

 

 

 

927

 

Selling, general and administrative expenses

 

 

735

 

 

 

566

 

Total expenses

 

 

4,236

 

 

 

3,433

 

Income (loss) from operations

 

 

100

 

 

 

(596)

Other expense (income):

 

 

 

 

 

 

 

 

Interest expense, net

 

 

6

 

 

 

13

 

Interest expense - related party

 

 

86

 

 

 

211

 

Gain on extinguishment of debt and other liabilities

 

 

-

 

 

 

(2,387)

Total other expense (income)

 

 

92

 

 

 

(2,163)

Income from operations before income taxes

 

 

8

 

 

 

1,567

 

Income tax expense

 

 

21

 

 

 

9

 

Net income (loss)

 

 

(13)

 

 

1,558

 

Preferred stock dividends

 

 

-

 

 

 

63

 

Net income (loss) available to common stockholders

 

$(13)

 

$1,495

 

 

 

 

 

 

 

 

 

 

Basic earnings per share information:

 

 

 

 

 

 

 

 

Net income (loss) available to common stockholders

 

$(0.00)

 

$0.13

 

Weighted average shares - basic

 

 

13,818,795

 

 

 

11,369,113

 

Diluted earnings per share information:

 

 

 

 

 

 

 

 

Net income (loss) available to common stockholders

 

$(0.00)

 

$0.03

 

Weighted average shares - diluted

 

 

13,818,795

 

 

 

46,744,176

 

The accompanying notes are an integral part of these condensed consolidated financial statements.

 

 
5
Table of Contents

ALY ENERGY SERVICES, INC.

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' EQUITY (DEFICIT)

FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2017

(in thousands, except share amounts)

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 Series A Convertible

Preferred Stock 

 

 

 Common Stock 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 Shares 

 

 

 Amount 

 

 

 Shares 

 

 

 Amount 

 

 

 Additional Paid-In-Capital 

 

 

  Accumulated Deficit 

 

 

 Treasury Stock 

 

 

 Total 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance as of January 1, 2017 

 

 

-

 

 

$-

 

 

 

6,707,039

 

 

$7

 

 

$28,307

 

 

$(34,158)

 

$(2)

 

$(5,846)
Preferred stock dividends 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

(63)

 

 

-

 

 

 

-

 

 

 

(63)

Issuance of common shares in exchange for the extinguishment of debt and other liabilities (note 3) 

 

 

-

 

 

 

-

 

 

 

1,657,494

 

 

 

2

 

 

 

197

 

 

 

-

 

 

 

-

 

 

 

199

 

Issuance of common shares in exchange for the extinguishment of redeemable preferred stock (note 3) 

 

 

-

 

 

 

-

 

 

 

5,454,487

 

 

 

5

 

 

 

15,031

 

 

 

-

 

 

 

-

 

 

 

15,036

 

Issuance of preferred shares in exchange for the extinguishment of debt and other liabilities - Pelican (note 3) 

 

 

16,092

 

 

 

6,435

 

 

 

-

 

 

 

-

 

 

 

9,657

 

 

 

-

 

 

 

-

 

 

 

16,092

 

Issuance of preferred shares in exchange for an amendment to credit facility 

 

 

1,200

 

 

 

320

 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

320

 

Issuance of stock options 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

625

 

 

 

-

 

 

 

-

 

 

 

625

 

Net income 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

508

 

 

 

-

 

 

 

508

 

Balance as of September 30, 2017 

 

 

17,292

 

 

$6,755

 

 

 

13,819,020

 

 

$14

 

 

$53,754

 

 

$(33,650)

 

$(2)

 

$26,871

 

See accompanying notes to condensed consolidated financial statements.

6
Table of Contents

ALY ENERGY SERVICES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

 

 

 

 

 

 

 

For the Nine Months

Ended September 30,

 

 

 

2017

 

 

2016

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

Cash flows from operating activities:

 

 

 

 

 

 

Net income (loss)

 

$508

 

 

$(7,073)

Less: Loss from discontinued operations, net of income taxes

 

 

-

 

 

 

1,345

 

Net income (loss) from continuing operations

 

 

508

 

 

 

(5,728)

 

 

 

 

 

 

 

 

 

Adjustments to reconcile net income (loss) to net cash provided by operating activities:

 

 

 

 

 

 

 

 

Depreciation and amortization

 

 

2,793

 

 

 

4,162

 

Amortization of deferred loan costs

 

 

-

 

 

 

250

 

Reduction in value of assets

 

 

58

 

 

 

1,630

 

Stock-based compensation

 

 

625

 

 

 

-

 

Bad debt expense

 

 

56

 

 

 

44

 

Fair value adjustments to contingent payment liability

 

 

-

 

 

 

(198)

Gain on extinguishment of debt and other liabilities

 

 

(2,387)

 

 

-

 

Debt modification fee

 

 

320

 

 

 

-

 

Deferred taxes

 

 

-

 

 

 

(3,426)

Changes in operating assets and liabilities:

 

 

 

 

 

 

 

 

Receivables

 

 

(2,657)

 

 

2,809

 

Prepaid expenses and other assets

 

 

391

 

 

 

737

 

Accounts payable, accrued expenses and other liabilities

 

 

287

 

 

 

(209)

Accrued interest and other - Pelican

 

 

193

 

 

 

-

 

Net cash provided by continuing operations

 

 

187

 

 

 

71

 

Net cash used in discontinued operations

 

 

-

 

 

 

(5)

Net cash provided by operating activities

 

 

187

 

 

 

66

 

 

 

 

 

 

 

 

 

 

Cash flows from investing activities:

 

 

 

 

 

 

 

 

Purchases of property and equipment

 

 

(1,325)

 

 

(330)

Proceeds from disposal of property and equipment

 

 

15

 

 

 

766

 

Net cash provided by (used in) continuing operations

 

 

(1,310)

 

 

436

 

Net cash provided by discontinued operations

 

 

-

 

 

 

39

 

Net cash provided by (used in) investing activities

 

 

(1,310)

 

 

475

 

 

 

 

 

 

 

 

 

 

Cash flows from financing activities:

 

 

 

 

 

 

 

 

Borrowings on long-term debt - Pelican

 

 

600

 

 

 

-

 

Repayment of long-term debt

 

 

(7)

 

 

(628)

Net cash provided by (used in) continuing operations

 

 

593

 

 

 

(628)

Net cash used in discontinued operations

 

 

-

 

 

 

(7)

Net cash provided by (used in) financing activities

 

 

593

 

 

 

(635)

 

 

 

 

 

 

 

 

 

Net decrease in cash, cash equivalents, and restricted cash

 

 

(530)

 

 

(94)

Cash, cash equivalents, and restricted cash, beginning of period

 

 

711

 

 

 

497

 

Cash, cash equivalents, and restricted cash, end of period

 

$181

 

 

$403

 

See accompanying notes to condensed consolidated financial statements.

7
Table of Contents

NOTE 1 — NATURE OF OPERATIONS AND BASIS OF PRESENTATION

Nature of Operations

Aly Energy Services, Inc., together with its subsidiaries (“Aly Energy” or “the Company”), provides oilfield services, including equipment rental and solids control services to exploration and production companies. The Company operates in select oil and natural gas basins of the contiguous United States. Throughout this report, we refer to Aly Energy and subsidiaries as “we”, “our” or “us”. References to financial results and operations of the Company in these notes to the condensed consolidated financial statements are limited to continuing operations unless otherwise specified.

On October 26, 2012, we acquired all of the stock of Austin Chalk Petroleum Services Corp. (“Austin Chalk”). Austin Chalk provides surface rental equipment as well as roustabout services which include the rig-up and rig-down of equipment and the hauling of equipment to and from the customer’s location.

On April 15, 2014, we acquired the equity interests of United Centrifuge, LLC (“United”) as well as certain assets used in United’s business that were owned by related parties of United (collectively the “United Acquisition”). In connection with the United Acquisition, United merged with and into Aly Centrifuge Inc. (“Aly Centrifuge”), a wholly-owned subsidiary of Aly Energy. Aly Centrifuge operates within the solids control and fluids management sectors of the oilfield services and rental equipment industry, offering its customers the option of renting centrifuges and auxiliary solids control equipment without personnel or the option of paying for a full-service solids control package which includes operators on-site 24 hours a day.

Discontinued Operations

In July 2014, we acquired all of the issued and outstanding stock of Evolution Guidance Systems Inc. (“Evolution”), an operator of Measurement-While-Drilling (“MWD”) downhole tools. From July 2014 through October 2016, Evolution provided directional drilling and MWD services to a variety of exploration and production companies. On October 26, 2016, we abandoned these operations as a part of a restructuring transaction. The abandonment of these operations meets the criteria established for recognition as discontinued operations under generally accepted accounting principles in the United States of America (“U.S. GAAP”). Therefore, the financial results of our directional drilling and MWD services are presented as discontinued operations in the Company’s condensed consolidated financial statements. The results of the discontinued operations are included in the line item “Loss from discontinued operations, net of income taxes” on the condensed consolidated statements of operations for all periods presented. Cash flows from discontinued operations appear in the line items “Net cash provided by (used in) discontinued operations” on the condensed consolidated statements of cash flows. By December 31, 2016, the abandonment of these operations and sell-off of the assets was completed with approximately $0.2 million of remaining liabilities assumed by the continuing operations of the Company; accordingly, there was income or loss from discontinued operations during the nine months ending September 30, 2017.

Basis of Presentation

Aly Energy has three wholly-owned subsidiaries, Aly Operating Inc. (“Aly Operating”) of which Austin Chalk is a wholly-owned subsidiary, Aly Centrifuge and Evolution. We operate as one business segment which services customers within the United States.

The condensed consolidated financial statements have been prepared in conformity with U.S. GAAP and include the accounts of Aly Energy and each of its subsidiaries in the condensed consolidated balance sheets as of September 30, 2017 and December 31, 2016, the related condensed consolidated statements of operations for each of the three- and nine-month periods ended September 30, 2017 and 2016, stockholders’ equity (deficit) for the nine months ended September 30, 2017, and cash flows for each of the nine-month periods ended September 30, 2017 and 2016. All significant intercompany transactions and account balances have been eliminated upon consolidation.

Interim Financial Information

The condensed consolidated balance sheet as of December 31, 2016 has been derived from our audited financial statements and the unaudited condensed consolidated financial statements of the Company are prepared in conformity with U.S. GAAP for interim financial reporting. Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission. Therefore, these condensed consolidated financial statements should be read along with the annual audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016. In management’s opinion, all adjustments necessary for a fair statement are reflected in the interim periods presented. Interim results for the three and nine months ended September 30, 2017 may not be indicative of results that will be realized for the full year ending December 31, 2017.

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Table of Contents

ALY ENERGY SERVICES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE THREE MONTHS ENDED MARCH 31, 2018 AND 2017

(in thousands)

 

 

 

 

 

 

 

 

 

For the Three Months

Ended March 31,

 

 

 

2018

 

 

2017

 

 

 

(unaudited)

 

Cash flows from operating activities:

 

 

 

 

 

 

Net income (loss)

 

$(13)

 

$1,558

 

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

 

 

 

 

 

Depreciation and amortization

 

 

891

 

 

 

927

 

Loss on disposal of assets

 

 

-

 

 

 

40

 

Bad debt expense

 

 

22

 

 

 

15

 

Gain on extinguishment of debt and other liabilities

 

 

-

 

 

 

(2,387)

Changes in operating assets and liabilities:

 

 

 

 

 

 

 

 

Receivables, net

 

 

371

 

 

 

(947)

Prepaid expenses and other current assets

 

 

36

 

 

 

220

 

Accounts payable, accrued expenses and other liabilities

 

 

(571)

 

 

(55)

Accrued interest - related party

 

 

5

 

 

 

191

 

Net cash provided by (used in) operating activities

 

 

741

 

 

 

(438)

 

 

 

 

 

 

 

 

 

Cash flows from investing activities:

 

 

 

 

 

 

 

 

Purchases of property and equipment

 

 

(265)

 

 

(198)

Proceeds from disposal of property and equipment

 

 

-

 

 

 

15

 

Net cash used in investing activities

 

 

(265)

 

 

(183)

 

 

 

 

 

 

 

 

 

Cash flows from financing activities:

 

 

 

 

 

 

 

 

Borrowings on long-term debt - related party

 

 

250

 

 

 

250

 

Repayment of long-term debt

 

 

-

 

 

 

(3)

Net cash provided by financing activities

 

 

250

 

 

 

247

 

 

 

 

 

 

 

 

 

 

Net increase (decrease) in cash and restricted cash

 

 

726

 

 

 

(374)

Cash and restricted cash, beginning of period

 

 

233

 

 

 

711

 

Cash and restricted cash, end of period

 

$959

 

 

$337

 

 

 

 

 

 

 

 

 

 

Supplemental disclosure of cash flow information:

 

 

 

 

 

 

 

 

Cash paid for interest - related party

 

$81

 

 

$19

 

Cash paid for interest

 

 

3

 

 

 

2

 

Cash received for income taxes, net

 

 

(20)

 

 

-

 

The accompanying notes are an integral part of these condensed consolidated financial statements.

6
Table of Contents

NOTE 1 — NATURE OF OPERATIONS AND BASIS OF PRESENTATION

Nature of Operations

Aly Energy Services, Inc., together with its subsidiaries (“Aly Energy” or the “Company”), is a growth-oriented provider of oilfield services to leading oil and gas exploration and production (“E&P”) companies operating in unconventional plays in the United States (“U.S.”). Generally, the services we offer fall within two broad categories: surface rental and solids control. Our surface rental equipment includes a wide variety of large capacity tanks with integral circulating systems, associated pumps, separators, gas busters, mud mix plants and ancillary equipment. We also provide environmental containment berms to safeguard against spills from mud systems on the drilling rig site. Our solids control equipment includes large centrifuges, shakers, cuttings dryers and ancillary components that can be integrated into a closed loop mud system. We operate in the U.S., primarily in Texas, Oklahoma, and New Mexico.

Throughout this report, we refer to Aly Energy and its subsidiaries as “we”, “our” or “us”.

Basis of Presentation

Aly Energy has two wholly-owned subsidiaries with continuing operations: Aly Operating, Inc. and Aly Centrifuge Inc. Aly Operating, Inc. has one wholly-owned subsidiary: Austin Chalk Petroleum Services Corp. We operate as one business segment which services customers within the U.S.

The condensed consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“U.S. GAAP”) and include the accounts of Aly Energy and each of its subsidiaries in the condensed consolidated balance sheets as of March 31, 2018 and December 31, 2017 and in the related condensed consolidated statements of operations and condensed consolidated statements of cash flows for the three months ended March 31, 2018 and 2017. All significant intercompany transactions and account balances have been eliminated upon consolidation.

Interim Financial Information

The condensed consolidated balance sheet as of December 31, 2017 has been derived from our audited financial statements and the unaudited condensed consolidated financial statements of the Company are prepared in conformity with U.S. GAAP for interim financial reporting. Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission. Therefore, these condensed consolidated financial statements should be read along with the annual audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017. In management’s opinion, all adjustments necessary for a fair statement are reflected in the interim periods presented. Interim results for the three months ended March 31, 2018 may not be indicative of results that will be realized for the full year ending December 31, 2018.

Recapitalization

In September 2016, certain of the Company’s principal stockholders formed Permian Pelican, LLC (“Pelican”) with the objective of consummating a recapitalization transaction (the “Recapitalization”) whereby (i) our obligations under our then existing credit facility and various capital leases would be restructured and, (ii) the Company’s then outstanding redeemable preferred stock, subordinated note payable and contingent payment liability would be exchanged into common stock. The Recapitalization, completed on January 31, 2017, had a significant impact to our capital structure and to our consolidated financial statements for the years ended December 31, 2017 and 2016. Please see our Annual Report on Form 10-K for the year ended December 31, 2017 for a complete description of the Recapitalization and the impact on our consolidated financial statements for the year ended December 31, 2017.

 

Use of Estimates

 

The preparation of condensed consolidated financial statements in conformity with U.S. GAAP requires management to make certain estimates and assumptions. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the balance sheet date and the amounts of revenue and expenses recognized during the reporting period. Areas where critical accounting estimates are made by management include:

 

·Allowance for doubtful accounts,

·Depreciation and amortization of property and equipment and intangible and other assets,

·Impairment of property and equipment, intangible and other assets, and goodwill,

·Litigation settlement accrual,

·Contingent payment liability,

·Share-based

·Allowance for doubtful accounts,

·Depreciation and amortization of property and equipment and intangible and other assets,

·Impairment of property and equipment and intangible and other assets,

·Litigation settlement accruals,

·Stock-based compensation, and

 

·Income taxes.

 

The Company analyzes its estimates based on historical experience and various other indicative assumptions that it believes to be reasonable under the circumstances. Under different assumptions or conditions, the actual results could differ, possibly materially, from those previously estimated. Many of the conditions impacting these assumptions are outside of the Company’s control.

 

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Table of Contents

Reclassifications

Certain reclassifications have been made to prior period condensed consolidated financial statements to conform to the current period presentations. These reclassifications had no effect on our consolidated financial position, results of operations or cash flows.

NOTE 2 — LONG-LIVED ASSETS

Property and Equipment

Major classifications of property and equipment are as follows (in thousands):

 

 

March 31,

2018

 

 

December 31,

2017

 

 

 

(unaudited)

 

 

 

 

Machinery and equipment

 

$33,213

 

 

$33,024

 

Vehicles, trucks and trailers

 

 

4,260

 

 

 

4,288

 

Office furniture, fixtures and equipment

 

 

566

 

 

 

560

 

Buildings

 

 

212

 

 

 

212

 

Leasehold improvements

 

 

61

 

 

 

105

 

 

 

 

38,312

 

 

 

38,189

 

Less: Accumulated depreciation and amortization

 

 

(11,994)

 

 

(11,374)

 

 

 

26,318

 

 

 

26,815

 

Assets not yet placed in service

 

 

131

 

 

 

73

 

Property and equipment, net

 

$26,449

 

 

$26,888

 

Depreciation and amortization expense related to property and equipment for the three months ended March 31, 2018 and 2017 was $0.7 million.

Intangible Assets

Intangible assets consist of the following (in thousands):

 

 

Customer Relationships

 

 

Tradename

 

 

Total

 

 

 

 

 

 

 

 

 

 

 

As of March 31, 2018 (unaudited):

 

 

 

 

 

 

 

 

 

Cost

 

$5,323

 

 

$2,174

 

 

$7,497

 

Less: Accumulated amortization

 

 

(2,565)

 

 

(1,020)

 

 

(3,585)

Net book value

 

$2,758

 

 

$1,154

 

 

$3,912

 

 

 

 

 

 

 

 

 

 

 

 

 

 

As of December 31, 2017:

 

 

 

 

 

 

 

 

 

 

 

 

Cost

 

$5,323

 

 

$2,174

 

 

 

7,497

 

Less: Accumulated amortization

 

 

(2,432)

 

 

(966)

 

 

(3,398)

Net book value

 

$2,891

 

 

$1,208

 

 

$4,099

 

Total amortization expense for the three months ended March 31, 2018 and 2017 was approximately $0.2 million.

 

Certain reclassifications have been made to prior period consolidated financial statements to conform to the current period presentations. These reclassifications had no effect on our consolidated financial position, results
8
Table of operations or cash flows.

Subsequent EventsContents

We conducted our subsequent events review through the date these condensed consolidated financial statements were filed with the U.S. Securities and Exchange Commission (“SEC”).

NOTE 2 — RECENT DEVELOPMENTS

Operational Restructuring

Our activity is tied directly to the rig count and, even though we instituted significant cost cutting measures beginning in 2015, we were unable to cut costs enough to match the decline in our business. As a result, as of December 31, 2015, we were in default of our credit agreement with Wells Fargo Bank, National Association (“Wells Fargo”).

Throughout 2015, in an effort to mitigate the significant declines in pricing and utilization of our equipment, we committed to a reorganization initiative to strengthen our sales and marketing efforts, consolidate support functions, and operate more efficiently. The reorganization effort included, but was not limited to, training our salesforce to enable the cross-selling of our product lines in certain geographical markets, sharing a common support services infrastructure across all reporting units, reducing headcount and wage rates, and rebranding and launching a new web site to increase awareness of our service lines. We recognized some benefit from these measures in late 2015 resulting in increased gross margins and lower selling, general and administrative expenses when compared to the first half of 2015.

During the year ended December 31, 2016, we entered into a series of forbearance agreements with our lender. Under the forbearance agreements, among other provisions, the lenders agreed to forbear from exercising their remedies under the credit agreement. These forbearance agreements permitted us to operate within the parameters of our normal course of business despite the continuing default under the credit agreement. Without these forbearance agreements, our outstanding debt would have been immediately due and payable. Throughout 2016, we remained in default and we did not have sufficient liquidity to repay all of the outstanding debt to the lender at any point during the year ($20.1 million as of December 31, 2015). As such, we may have been forced to file for protection under Chapter 11 of the U.S. Bankruptcy Code.

 

9
Table of Contents

In early 2016, we were hopeful that a successful operational restructuring would facilitate negotiations to modify the terms of our existing credit facility with Wells Fargo. Our operational restructuring in 2016 consisted of severe cost cuts which were incremental to the year-over-year cost cuts already achieved in 2015 when compared to 2014. In 2016, significant cost savings were primarily generated by:NOTE 3 — LONG-TERM DEBT – RELATED PARTY

 

·reductions of our employee base, both field employees and sales and administrative employees, to a headcount of approximately 50 as of December 31, 2016 from approximately 125 as of December 31, 2015,

·reduction in employer contributions to employee benefits,

·closures of certain operating yards and administrative facilities,

·strategic decision to cease operations in the northeast which resulted in the reduction of costs related to operating in an incremental market,

·modifications to insurance policies, including general liability and workers’ compensation policies, resulting in a $0.5 million or 15.5% reduction in the cost of insurance to $0.6 million for the year ended December 31, 2016 from $1.1 million for the year ended December 31, 2015,

·minimization of repair and maintenance activities, resulting in a $0.4 million or 50.0% reduction of repair and maintenance expenses to $0.4 million for the year ended December 31, 2016 from $0.8 million for the year ended December 31, 2015, and

·elimination of investments in equipment, unless required to service an existing customer, resulting in a reduction of capital expenditures to $0.4 million for the year ended December 31, 2016 from $2.5 million for the year ended December 31, 2015.

We also achieved significant cost savings from the decrease in third party costs, such as sub-rental equipment and trucking, and other variable costs which declined with the decrease in activity.

In order to further support our working capital needs, we identified and sold idle and underutilized assets. During 2016, we realized aggregate proceeds from sales of approximately $0.8 million of which $0.5 million and $0.3 million was used to fund working capital needs and pay down debt, respectively.

Capital Restructuring

Despite our successful operational restructuring efforts, particularly during the first half of 2016, the decline in our activity levels and the declines in customer pricing outpaced the impact of our cost reductions and it became evident that a capital restructuring would also be necessary to continue operations and position our business for an industry turnaround.

In the second quarter of 2016, certain of the Company’s principal stockholders (“Shareholder Group”) began negotiations with Wells Fargo with the objective of consummating a recapitalization transaction (the “Recapitalization”) whereby our obligations under the credit agreement and the outstanding capital leases in favor of Wells Fargo’s equipment finance affiliate and certain other obligations of Aly Energy (collectively the “Aly Senior Obligations”) would be restructured. In August 2016, the Shareholder Group was introduced to a third party, Tiger Finance, LLC (“Tiger”), to provide bridge financing and to extend forbearance until such date as sufficient capital could be raised to complete the Recapitalization.

In September 2016, the Shareholder Group formed Permian Pelican, LLC (“Pelican”) with the objective of raising capital and executing the steps necessary to complete the restructuring, inclusive of successfully effecting the exchange of the Aly Operating redeemable preferred stock, Aly Centrifuge redeemable preferred stock, Aly Centrifuge subordinated debt and liability for a contingent payment into approximately 10% of our common stock on a fully diluted basis.

Effective January 31, 2017, the Recapitalization was completed through the execution and delivery of a Securities Exchange Agreement and a Second Amended and Restated Credit Agreement, and, as a result, the new credit facility, now with Pelican, consisted of a term loan of $5.1 million and a revolving facility of up to $1.0 million as of January 31, 2017. Availability under the revolving credit facility is determined by a borrowing base calculated as 80% of eligible receivables (receivables less than 90 days old). See further discussion in “Note 3 – Recapitalization”.Long-term debt – related party consists of the following (in thousands):

 

10
Table of Contents

Subsequent to the Recapitalization, we entered into several further amendments to capitalize on improved market conditions and increased activity in our business:

 

 

March 31,

2018

 

 

December 31,

2017

 

 

 

(unaudited)

 

 

 

 

Credit facility

 

 

 

 

 

 

Term loan

 

$5,027

 

 

$5,027

 

Revolving credit facility

 

 

1,000

 

 

 

750

 

Delayed draw term loan

 

 

575

 

 

 

575

 

Total

 

$6,602

 

 

$6,352

 

  

·Amendment No. 1, effective March 1, 2017, provided for a delayed draw term loan to be added to the credit facility for the purpose of financing capital expenditures. The agreement permitted us to draw on the delayed draw term loan from time-to-time upAs of December 31, 2017, subsequent to multiple amendments, the Company’s credit facility with Pelican consisted of a term loan, a revolving credit facility and a delayed draw term loan. The obligations under the credit facility are guaranteed by all of our subsidiaries and secured by substantially all of our assets. The credit facility contains customary events of default and covenants including restrictions on our ability to incur additional indebtedness, pay dividends or make other distributions, grant liens and sell assets. The credit facility does not include any financial covenants. We were in full compliance with the credit facility as of March 31, 2018.

Borrowings under the credit facility are subject to monthly interest payments at an annual base rate of the six-month LIBOR rate on the last day of the calendar month plus a margin of 3.0%. To the extent the Company generates free cash flow, as defined in the credit agreement, during a given calendar year, principal payments of 50% of such free cash flow are due on the earlier of (i) 60 days after the end of such year or, (ii) the date on which the Company’s independent auditors have completed their audit of the financial statements for such year. If the Company does not generate free cash flow, there are no required principal payments until the maturity date of the facility matures on December 31, 2019 at which time all amounts outstanding under the facility become immediately due and payable.

On January 22, 2018, the Company entered into Amendment No. 4 to the credit facility which provided for a swing line without changing the aggregate available borrowings under the facility. The Company can borrow up to $0.6 million under the swing line and, to the extent amounts are drawn under the line, such amounts may be repaid and reborrowed without penalty until June 30, 2018 at which time the swing line matures and all outstanding amounts are immediately due and payable. Interest on the swing line is charged at the lower of the (i) highest lawful rate or (ii) 7.0% per annum. There are no outstanding borrowings under the swing line as of March 31, 2018.

As of March 31, 2018, the Company had the ability to borrow up to $0.6 million under the swing line and the ability to draw up to $75,000 under the delayed draw term loan to finance 90% of eligible capital expenditures. We are currently in discussions with Pelican to enter into a fifth amendment to the credit facility which will transfer the availability under both the delayed draw term loan and the swing line to the revolving facility simultaneous with the maturity of the swing line. As of May 15, 2018, the Company has no remaining availability under the term loan or the revolving credit facility.

NOTE 4 — STOCK-BASED COMPENSATION

As of March 31, 2018 and December 31, 2017, we had two stock-based compensation plans with outstanding options. Only one of our plans is currently available to grant incentive stock options, non-qualified stock options and restricted stock to employees and non-employee members of the board of directors.

2017 Stock Option Plan

Effective April 4, 2017, the 2017 Stock Option Plan (the “2017 Plan”) was approved by the board of directors. On May 30, 2017, we granted options to purchase approximately 16.9 million shares of common stock under the 2017 Plan which was the maximum amount authorized. The option contract term is 10 years and the exercise price is $0.10. The options vested and became exercisable immediately upon grant. The fair value of the award was estimated using a Black-Scholes fair value model. The valuation of stock options requires us to estimate the expected term of award, which was estimated using the simplified method, as the Company does not have sufficient historical exercise information. Additionally, the valuation of stock option awards is also dependent on historical stock price volatility. In view of our limited trading volume, volatility was calculated based on historical stock price volatility of the Company’s peer group.

Options to purchase 16.9 million common shares under the 2017 Plan were outstanding and fully vested as of March 31, 2018 and December 31, 2017. We expensed stock-based compensation of $0.6 million for the full fair value of the award in order to fund up to 80% of the cost of capital expenditures subject to a $0.5 million limit on aggregate borrowings.

·Amendment No. 2, effective May 23, 2017, increased the maximum revolving credit amount from $1.0 million to $1.8 million and extended the final maturity date of the facility to December 31, 2019. In consideration of the increase in the revolving credit facility and the extension of the final maturity date, we agreed to issue to Pelican, the lender, as an amendment fee, 1,200 shares of our Series A convertible preferred stock. See further discussion in “Note 7 – Controlling Shareholder and Other Related Party Transactions”.

·Amendment No. 3, effective June 15, 2017, modified maximum potential borrowings under each of the revolving credit facility and the delayed draw term loan without changing the aggregate available borrowings under the credit facility. The amendment reduced the maximum revolving credit amount from $1.8 million to $1.0 million and increased the maximum delayed draw loan borrowings from $0.5 million to $1.3 million and the amendment also increased permitted draws on the delayed draw loan from 80% of the cost of capital expenditures being funded to 90% of the cost of capital expenditures being funded.

To the extent there is free cash flow as defined in the credit agreement, principal payments of 50% of such free cash flow are due annually. The maturity date of all remaining outstanding balances under the credit facility is December 31, 2019.

The obligations under the credit facility are guaranteed by all of our subsidiaries and secured by substantially all of our assets. The credit agreement contains customary events of default and covenants including restrictions on our ability to incur additional indebtedness, make capital expenditures, pay dividends or make other distributions, grant liens and sell assets. The credit facility does not include any financial covenants. We are in full compliance with the credit facility as of September 30, 2017.

 

As
9
Table of September 30, 2017, there were outstanding borrowings of $5.0 million, $0.8 million, and $0.4 million on the term loan, revolving credit facility, and delayed draw term loan, respectively. As of September 30, 2017, we have the availability to borrow an incremental $0.3 million under the revolving credit facility and, if we have capital expenditures which are eligible to be financed, an incremental $0.9 million under the delayed draw term loan to finance 90% of such expenditures.

Severance Expense – Operational RestructuringContents

During 2016 and 2015, the Company recorded $0.5 million and $0.3 million, respectively, in charges relating to severance due to the significant downturn in the industry. The accrued severance liability balance of $0.7 million as of December 31, 2016 was reduced to $0.5 million as a result of the settlement of certain obligations during the three months ended September 30, 2017. There have been no incremental severance charges during 2017.

NOTE 3 — RECAPITALIZATION

Summary

To complete the transaction, the Company’s directors and principal stockholders formed and organized Pelican. Pursuant to the Recapitalization, Pelican agreed to acquire the Aly Senior Obligations, provided the Company was successful in effecting the exchange of the Aly Operating redeemable preferred stock, Aly Centrifuge redeemable preferred stock, Aly Centrifuge subordinated debt and liability for a contingent payment into approximately 10% of our common stock on a fully diluted basis.

The Recapitalization consisted of three restructuring events which took place in the period beginning October 26, 2016 and ending on January 31, 2017. The first two restructuring events occurred before January 1, 2017 and any impact is presented in the Company’s historical consolidated financial statements for the year ended December 31, 2016. Below is a description of each event:

The first restructuring event occurred on October 26, 2016 when Tiger acquired the Aly Senior Obligations from Wells Fargo and its equipment affiliate. Simultaneously, Tiger entered into an assignment agreement with Pelican whereby it agreed to sell the Aly Senior Obligations to Pelican on the conditions that (i) Pelican provide $0.5 million of unsecured working capital financing to the Company pending the closing and (ii) the Company transfer to Tiger (in consideration of Tiger’s reduction of the Aly Senior Obligations in the amount of $2.0 million) certain excess equipment and vehicles which the Company was not utilizing and considered unnecessary for its continuing operations.

 

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Table of ContentsOmnibus Incentive Plan

As a result of the above, we transferred property and equipment with an estimated fair value of $2.6 million, inclusive of $0.4 million of assets associated with discontinued operations, to Tiger and recognized a corresponding reduction in the Aly Senior Obligations of $2.0 million and debt modification fee of $0.6 million. Property and equipment transferred had an aggregate net book value of $18.6 million resulting in our recording an impairment charge of $16.0 million, inclusive of a $0.4 million impairment associated with discontinued operations. As part of this transaction and upon satisfaction of such conditions, Tiger extended the forbearance period to December 9, 2016.

The second restructuring event occurred on December 12, 2016 when Pelican acquired the Aly Senior Obligations from Tiger. As the new holder of the Aly Senior Obligations, Pelican further extended the forbearance period for the obligations to January 31, 2017, provided the Company was successful in completing the third and final restructuring event on or before such date.

Effective January 31, 2017, the final restructuring event occurred and the Recapitalization was completed which resulted in the following:

·an exchange of certain of the Company’s outstanding obligations (namely, Aly Operating redeemable preferred stock, Aly Centrifuge redeemable preferred stock, Aly Centrifuge subordinated debt and its contingent payment liability) for approximately 10% of our common stock, or 7,111,981 common shares, on a fully diluted basis;

·an exchange of certain amendments to the Aly Senior Obligations (namely, a $16.1 million principal reduction, removal of restrictive covenants and extended maturity of payment obligations) for shares of our Series A convertible preferred stock which represents approximately 80% of our common stock, or 53,628,842 common shares, on a fully diluted basis (liquidation preference of $16.1 million or $1,000 per share); and

·the formation of a new credit agreement with Pelican (consisting of a $5.1 million term loan and $1.0 million revolving credit facility) with an extended maturity date of December 31, 2018.

The Recapitalization had a significant impact to our capital structure and to our consolidated financial statements and there was a significant dilutive effect to those shareholders who held common stock immediately before the transaction was completed. The Recapitalization has been accounted for in accordance with ASC 470, including (i) the exchange of debt and equity securities accounted for as a troubled debt restructuring and (ii) the issuance of preferred shares in exchange for the extinguishment of debt and other liabilities and for the issuance of a new credit facility.

Troubled Debt Restructuring

Except for the Pelican exchange, each exchange was accounted for as a troubled debt restructuring (“TDR”) since an equity interest in the Company was issued to fully satisfy each debt. A gain on TDR is recognized for the excess of the carrying amount of the debt over the fair value of each equity interest granted. The impact of the Recapitalization includes a “gain on the extinguishment of debt and other liabilities” from the debtors of Aly Centrifuge subordinated debt and the contingent payment liability and a “gain on the extinguishment of redeemable preferred stock” from the holders of Aly Operating redeemable preferred stock and Aly Centrifuge redeemable preferred stock. The share price of common stock as of January 31, 2017 of $0.12 per share was used as the basis of fair value for each equity interested granted.

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The impact of the TDR is as follows:

Extinguishment of Debt and Other Liabilities. The exchange of subordinated debt and contingent payment liability for common stock resulted in a gain of $2.4 million, or $0.36 per share, on the condensed consolidated statement of operations and was recorded as an “Issuance of common stock in exchange for the extinguishment of debt and other liabilities” on the condensed consolidated statement of changes in stockholders’ equity (deficit). The table below summarizes stock issued and the resulting gain for each extinguishment:

Gain on the Extinguishment of Debt and Other Liabilities

Debt and Other Obligations Extinguished

Common Stock Issued

Gain Included in Other Expense (Income)

Subordinated Debt and accrued interest of $1.5 million and $0.3 million, respectively

1,200,000

$1.6 million

Contingent payment liability of $0.8 million

457,494

$0.8 million

Extinguishment of Redeemable Preferred Stock. Represents the exchange of Aly Operating redeemable preferred stock and Aly Centrifuge redeemable preferred stock for common stock resulting in a gain of $14.4 million, or $2.14 per share, and recorded as an “Issuance of common stock in exchange for the extinguishment of redeemable preferred stock” on the condensed consolidated statement of changes in stockholders’ equity (deficit). The table below summarizes stock issued and the resulting gain for each extinguishment:

Gain on the Extinguishment of Redeemable Preferred Stock

Redeemable Preferred Stock and Other Obligations

Common Stock Issued

Gain Included in Additional Paid-in-Capital

Aly Centifuge preferred and accrued dividends of $8.9 million and $1.2 million, respectively

3,039,517

$9.8 million

Aly Operating preferred and accrued dividends of $4.0 million and $0.9 million, respectively

2,414,971

$4.6 million

On January 31, 2017, we issued 7,111,981 shares of our common stock to the former holders of Aly Operating redeemable preferred stock, Aly Centrifuge redeemable preferred stock, Aly Centrifuge subordinated debt, and liability for contingent payment in exchange for the above mentioned extinguishments in connection with our TDR.

Credit Facility Restructuring

Given the nature of the related party relationship between the Company and Pelican, the extinguishment of our Aly Senior Obligations was accounted for as a capital transaction whereby we issued Series A convertible preferred stock in exchange for the extinguishment of our Aly Senior Obligations and the issuance of a new credit facility which resulted in a gain on the extinguishment of debt and other liabilities calculated as the amount above the estimated fair value of the equity interest granted. The share price of common stock as of January 31, 2017 of $0.12 per share was used as the basis of fair value for the equity interested granted.

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The impact of the exchange and extinguishment of our Aly Senior Obligations is as follows:

Old Credit Facility. The partial extinguishment and exchange of our Aly Senior Obligations ($16.1 million principal reduction) for shares of our Series A convertible preferred stock resulted in a gain of $9.7 million which is recorded as an “Issuance of preferred shares in exchange for the extinguishment of debt and other liabilities - Pelican” on the condensed consolidated statement of changes in stockholders’ equity (deficit). The components of the Aly Senior Obligations are as follows (in thousands):

Aly Senior Obligations as of January 31, 2017

 

 

 

 

Debt and Other Obligations Extinguished

 

Amount

 

 

 

 

 

Credit facility

 

$17,772

 

Accrued fees and interest on credit facility

 

 

1,414

 

Capital lease obligations

 

 

1,930

 

Accrued interest on capital lease obligations

 

 

26

 

Line of Credit - Pelican

 

 

500

 

 

 

 

 

 

Total

 

$21,642

 

New Credit Facility. Our new credit agreement with Pelican consists of a $5.1 million term loan and $1.0 million revolving credit facility ($5.1 million and $0.5 million outstanding as of January 31, 2017) completing the full extinguishment of our old credit facility.

On January 31, 2017, we issued 16,092 shares of our Series A convertible preferred stock to Pelican in exchange for the above mentioned $16.1 million reduction of the Aly Senior Obligations.

Professional Fees - Recapitalization

During 2016, we recorded $0.2 million of expenses for professionals engaged by our former lender, Wells Fargo, whom the Company was required to pay under the terms of our credit facility. On December 12, 2016, these fees were assumed by Pelican and, on January 31, 2017, included within the Aly Senior Obligations refinanced in connection with the Recapitalization. These fees are included in “Accrued interest and other – Pelican” on our consolidated balance sheet as of December 31, 2016.

NOTE 4 — LONG-LIVED ASSETS

Property and Equipment

Major classifications of property and equipment are as follows (in thousands):

 

 

September 30,

2017

 

 

December 31,

2016

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

Machinery and equipment

 

$32,691

 

 

$31,541

 

Vehicles, trucks and trailers

 

 

4,275

 

 

 

4,523

 

Office furniture, fixtures and equipment

 

 

547

 

 

 

544

 

Leasehold improvements

 

 

95

 

 

 

203

 

Buildings

 

 

212

 

 

 

212

 

 

 

 

37,820

 

 

 

37,023

 

 

 

 

 

 

 

 

 

 

Less: Accumulated depreciation and amortization

 

 

(10,666)

 

 

(8,807)

 

 

 

27,154

 

 

 

28,216

 

 

 

 

 

 

 

 

 

 

Assets not yet placed in service

 

 

53

 

 

 

10

 

Property and equipment, net

 

$27,207

 

 

$28,226

 

Depreciation and amortization expense related to property and equipment for the three months ended September 30, 2017 and 2016 was $0.7 million and $1.0 million, respectively. Depreciation and amortization expense related to property and equipment for the nine months ended September 30, 2017 and 2016 was $2.2 million and $3.1 million, respectively.

 

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The Omnibus Incentive Plan (the “2013 Plan”) was approved by the board of directors on May 2, 2013. The option contract term is 10 years and the exercise price is $4.00. The options vest and are exercisable if a liquidity event, as defined in the 2013 Plan, occurs and certain conditions are met.

On May 2, 2013, we granted 338,474 common shares under the 2013 Plan. Options to purchase 234,144 common shares under the 2013 Plan were outstanding as of March 31, 2018 and December 31, 2017. Subsequent to the adoption of the 2017 Plan, options are no longer are permitted to be granted under the 2013 Plan and no options were vested as of March 31, 2018 and December 31, 2017. The aggregate unrecognized compensation cost related to these non-vested stock option awards was approximately $0.3 million as of March 31, 2018 (see Note 13 – Stock-Based Compensation in our Annual Report on Form 10-K for the year ended December 31, 2017 for additional detail). Such amount will be recognized in the future upon occurrence of an event that results in a vesting of the options. During the three months ended March 31, 2018, there were no forfeited options. Forfeited options during the three months ended March 31, 2017 totaled 8,363.

NOTE 5 —CONTROLLING SHAREHOLDER

Controlling Shareholder – Pelican

On January 31, 2017 upon completion of the Recapitalization, Pelican had the power to vote the substantial majority of the Company’s outstanding common stock. As of March 31, 2018, seven of our eight board members, including two of our executive officers, and our chief financial officer hold an ownership interest in Pelican.

During the three months ended March 31, 2018, we recorded interest expense due to Pelican of approximately $86,000. During the three months ended March 31, 2017, we recorded interest expense due to Pelican of $0.2 million of which approximately $40,000 was paid in cash during the year ended December 31, 2017 and the remainder was included in the obligations exchanged as part of the Recapitalization. Please see our Annual Report on Form 10-K for the year ended December 31, 2017 for a complete description of the Recapitalization, including related party transactions with Pelican.

As of March 31, 2018 and December 31, 2017, our condensed consolidated balance sheet includes accrued interest due to Pelican of approximately $31,000 and $26,000, respectively.

From time-to-time, the Company engages in business transactions with its controlling shareholder, Pelican, and other related parties.

NOTE 6 — REVENUE FROM CONTRACTS WITH CUSTOMERS

Adoption of New Accounting Standards - ASU 2014-09, Revenue - Revenue from Contracts with Customers

On January 1, 2018, we adopted accounting standards update (“ASU”) 2014-09, Revenue from Contracts with Customers and all the related amendments (“new revenue standard” or “ASC 606”) to all contracts using the full retrospective method. The Company does not incur significant contract costs. The Company’s services and rental contracts are primarily short-term in nature, and therefore, based on management’s assessment, the impact of the adoption of the new revenue standard is not significant.

Revenue Recognition

The core principle of ASC 606 is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This is accomplished by applying the following steps:

 

Repurchase of Assets - Recapitalization

1.Identify the contract with a customer

2.Identify the performance obligations in the contract

3.Determine the transaction price

4.Allocate the transaction price to the performance obligations

5.Recognize revenue as the performance obligations are satisfied

Our services are generally sold based upon quotes or contracts with customers that include fixed or determinable prices. Our typical payment terms are 30 days and our sales arrangements do not contain any significant financing component for our customers. Our customer arrangements do not generate contract assets or liabilities.

We have concluded that our performance obligations to provide equipment rental, rig-up/rig-down and transportation services constitute a series of distinct goods or services that are substantially the same and that have the same pattern of transfer to our customer. The activities included in the “other revenue” stream are not distinct as our customers would not benefit from these activities separately.

 

In 2016, and as a part
10
Table of the Recapitalization, we sold certain excess equipment and vehicles. In June 2017, we repurchased $0.3 million of certain equipment to be deployed and utilized for operations. Upon repurchase, the cost basis for these assets was recorded at the fair value for which they were sold in the transaction and, accordingly, there was no step-up in basis.Contents

Rental Services – We are a provider of solids control systems and surface rental equipment, including centrifuges and auxiliary solids control equipment, mud circulating tanks (400 and 500 barrel capacity) and auxiliary surface rental equipment (e.g. portable mud mixing plants, and containment systems). We generate revenue primarily from renting this equipment at per-day rates. In connection with certain of our solids control operations, we also provide personnel to operate our equipment at the customer’s location at per-day or per-hour rates. We recognize revenue on rental services upon completion of each day of services.

Transportation of Equipment and Rig-Up/Rig-Down Services – We offer transportation of our rental equipment to the well site and rig-up/rig-down of such equipment. These services are charged to the client at flat rates per job or at an hourly rate. We recognize revenue on transportation and rig-up/rig-down services at the point in time when such services have been completed.

Other – Upon request, we sometimes sell chemicals, supplies and other consumables to our customers. We recognize revenue from the sale of consumables when they are used on site.

Reimbursable Expenses – Customer charges for reimbursable expenses (consisting primarily of repairs to assets) are considered reimbursable revenue and are reported within operating expenses net of the associated expense. Customer charges for damaged equipment for which there is a recovery under the contract are considered asset sales and are reported within selling, general and administrative expenses net of the associated net book value for the damaged asset.

Sales and Other Related Taxes – Taxes assessed on sales transactions are not included in revenue.

The primary method used to determine standalone selling prices for our services is a “cost plus margin” approach under which we forecast the aggregate cost of satisfying a performance obligation and then add an appropriate margin for that distinct good or service. The prices we are able to charge and the margins we require depend on the demand of our potential and existing customers and the supply of equipment and services available to such customers from us and our competitors. When the supply exceeds the demand, the competitive environment intensifies significantly, particularly because many of the products we supply are not differentiated from the products provided by our competitors. Our customers choose to use our equipment and services primarily based upon the pricing we offer and our ability to execute efficiently and safely.

The following table presents our service revenue disaggregated by revenue source (in thousands):

 

 

For the Three Months Ended March 31,

 

 

 

2018

 

 

2017

 

 

 

(unaudited)

 

Rental services

 

$3,005

 

 

$1,888

 

Rig-up/rig-down services

 

 

626

 

 

 

434

 

Transportation services

 

 

691

 

 

 

505

 

Other

 

 

14

 

 

 

10

 

Total revenue

 

$4,336

 

 

$2,837

 

We maintain an allowance for doubtful accounts to reflect estimated losses resulting from the failure of customers to make required payments. On an ongoing basis, the collectability of accounts receivable is assessed based upon historical collection trends, current economic factors and the assessment of the collectability of specific accounts. We evaluate the collectability of specific accounts and determine when to grant credit to our customers using a combination of factors, including the age of the outstanding balances, evaluation of customers’ current and past financial condition, recent payment history, current economic environment, and discussions with our personnel and with the customers directly. Accounts are written off when it is determined the receivable will not be collected. If circumstances change, our estimates of the collectability of amounts could change by a material amount.

Arrangements with Multiple Performance Obligations

Our contracts with customers may include multiple performance obligations. For such arrangements, we allocate revenue to each performance obligation based on its relative standalone selling price.

 

11
Intangible Assets

Intangible assets consistTable of the following (in thousands):

 

 

Customer Relationships

 

 

Tradename

 

 

Non-Compete

 

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

 

As of September 30, 2017 (unaudited):

 

 

 

 

 

 

 

 

 

 

Cost

 

$5,323

 

 

$2,174

 

 

$492

 

 

$7,989

 

Less: Accumulated amortization

 

 

(2,299)

 

 

(912)

 

 

(483)

 

 

(3,694)

Net book value

 

$3,024

 

 

$1,262

 

 

$9

 

 

$4,295

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

As of December 31, 2016:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cost

 

$5,323

 

 

$2,174

 

 

$492

 

 

$7,989

 

Less: Accumulated amortization

 

 

(1,900)

 

 

(749)

 

 

(409)

 

 

(3,058)

Net book value

 

$3,423

 

 

$1,425

 

 

$83

 

 

$4,931

 

Total amortization expense for the three months ended September 30, 2017 and 2016 was approximately $0.2 million and $0.3 million, respectively. Total amortization expense for the nine months ended September 30, 2017 and 2016 was approximately $0.6 million and $1.1 million, respectively.

NOTE 5 — LONG-TERM DEBT – PELICAN

Line of Credit – PelicanContents

On October 26, 2016, we entered into an agreement with Tiger and Pelican, in conjunction with the Recapitalization transaction, requiring Pelican to provide a working capital line of credit of $0.5 million. As of December 31, 2016, there was $0.5 million outstanding under the line and no further availability to borrow under the line.

Borrowings under the line accrued interest at a rate of 5% per annum. The line was unsecured and had a maturity date of January 31, 2017.

On January 31, 2017, in conjunction with the Recapitalization transaction, the line matured, and the balance was aggregated with the Aly Senior Obligations in the new credit facility with Pelican.

Credit Facility - Pelican: Term Loan, Delayed Draw Term Loan, and Revolving Credit Facility

Effective October 26, 2016, our credit facility with Wells Fargo was included in the Aly Senior Obligations which were acquired by Tiger, then subsequently acquired on December 12, 2016 by Pelican. During this time, interest and ticking fees continued to accrue and there were no modifications to the components of the credit facility as a result of these transactions; however, a Fourth Limited Forbearance Agreement was executed with Pelican. The agreement extended the forbearance period to January 31, 2017, conditioned upon the Company using its best efforts to consummate a recapitalization plan, satisfactory to Pelican, that would, at a minimum, result in the conversion of Aly Operating redeemable preferred stock, Aly Centrifuge redeemable preferred stock, subordinated note payable, and contingent payment liability into common stock prior to January 31, 2017.

Effective January 31, 2017, the Recapitalization was completed, and the credit facility was amended in its entirety. The amended facility consisted of a term loan of $5.1 million and a revolving credit facility of up to $1.0 million (“Pelican Credit Facility”, as amended).

Availability under the revolving credit facility is determined by a borrowing base calculated as 80% of eligible receivables (less than 90 days old). Borrowings under the Pelican Credit Facility are subject to monthly interest payments at an annual base rate of the six-month LIBOR rate on the last day of the calendar month plus a margin of 3.0%. To the extent there is free cash flow, as defined in the credit agreement, principal payments of 50% of such free cash flow are due annually.

 

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Subsequent to the Recapitalization, we entered into several further amendments to capitalize on improved market conditions and increased activity in our business:Practical Expedients and Exemptions

 

·Amendment No. 1, effective March 1, 2017, provided for a delayed draw term loan to be added to the Pelican Credit Facility for the purpose of financing capital expenditures. The amendment permitted us to draw on an added delayed draw term loan from time-to-time up until December 31, 2018 in order to fund up to 80% of the cost of capital expenditures subject to a $0.5 million limit on aggregate borrowings.

·Amendment No. 2, effective May 23, 2017, increased the maximum revolving credit amount from $1.0 million to $1.8 million and extended the final maturity date of the facility to December 31, 2019. In consideration of the increase in the revolving credit facility and the extension of the final maturity date, we agreed to issue to Pelican an amendment fee of 1,200 shares of our Series A convertible preferred stock. See further discussion in “Note 7 – Controlling Shareholder and Other Related Party Transactions”.

·Amendment No. 3, effective June 15, 2017, modified maximum potential borrowings under each of the revolving credit facility and the delayed draw term loan without changing the aggregate available borrowings under the credit facility. The amendment reduced the maximum revolving credit amount from $1.8 million to $1.0 million and increased the maximum delayed draw loan borrowings from $0.5 million to $1.3 million and the amendment also increased permitted draws on the delayed draw loan from 80% of the cost of capital expenditures being funded to 90% of the cost of capital expenditures being funded.

The obligations under the Pelican Credit Facility are guaranteed by all of our subsidiaries and secured by substantially all of our assets. The Pelican Credit Facility contains customary events of default and covenants including restrictions on our ability to incur additional indebtedness, pay dividends or make other distributions, grant liens and sell assets. The Pelican Credit Facility does not include any financial covenants. We are in full compliance with the credit facility as of September 30, 2017.

Under the Pelican Credit Facility, as of September 30, 2017, we have the availability to borrow an incremental $0.3 million under the revolving credit facility and, if we have capital expenditures which are eligible to be financed, an incremental $0.9 million under the delayed draw term loan to finance 90% of such expenditures.

Equipment Financing and Capital Leases - Pelican

Effective December 12, 2016, Pelican acquired the Aly Senior Obligations which included $1.9 million of outstanding equipment financing and capital leases plus associated accrued interest.

On January 31, 2017, in connection with the Recapitalization, the Aly Senior Obligations, including the equipment financing and capital leases, were refinanced under the Pelican Credit Facility, see “Note 3 – Recapitalization”. Future borrowings required for equipment financing are likely to be funded through the delayed term loan included in the Pelican Credit Facility.

Long-term debt – Pelican consists of the following (in thousands):

 

 

September 30, 2017

 

 

December 31, 2016

 

 

 

Current

 

 

Long-Term

 

 

Current

 

 

Long-Term

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Credit facility

 

 

 

 

 

 

 

 

 

 

 

 

Term loan

 

$-

 

 

$5,027

 

 

$13,339

 

 

$-

 

Revolving credit facility

 

 

-

 

 

 

750

 

 

 

-

 

 

 

-

 

Delayed draw term loan

 

 

-

 

 

 

350

 

 

 

4,433

 

 

 

-

 

Line of credit - Pelican

 

 

-

 

 

 

-

 

 

 

494

 

 

 

-

 

Equipment financing and capital leases

 

 

-

 

 

 

-

 

 

 

614

 

 

 

1,315

 

Total

 

$-

 

 

$6,127

 

 

$18,880

 

 

$1,315

 

Based on the beneficial impact of the Recapitalization on January 31, 2017, coupled with the Company’s current forecasts, cash-on-hand, cash flow from operations and borrowing capacity under the Pelican Credit Facility, the Company expects to have sufficient liquidity and capital resources to meet its obligations for at least the next twelve months; however, our forecasts are based on many factors outside the Company’s control. See further details at “Note 2 – Recent Developments” and “Note 3 – Recapitalization”.We generally expense sales commissions when incurred because the amortization period would have been one year or less. These costs are recorded within selling, general and administrative expenses.

 

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NOTE 6 — REDEEMABLE PREFERRED STOCK

Two of our subsidiaries had redeemable preferred stock outstanding as of December 31, 2016. Aly Operating issued redeemable preferred stock in connection with the acquisition of Austin Chalk (“Aly Operating Redeemable Preferred Stock”) and Aly Centrifuge issued redeemable preferred stock in connection with the United Acquisition (“Aly Centrifuge Redeemable Preferred Stock”).

On January 31, 2017, in connection with the Recapitalization, the Aly Operating Redeemable Preferred Stock, the Aly Centrifuge Redeemable Preferred Stock and all accrued dividends on such stock were converted into 5,454,487 shares of common stock.

Aly Operating Redeemable Preferred Stock

As part of the acquisition of Austin Chalk, Aly Operating agreed to issue up to 4 million shares of Aly Operating Redeemable Preferred Stock, with a par value of $0.01, to the seller, with a fair value and liquidation value of $3.8 million and $4.0 million, respectively. The preferred stock was valued as of the date of acquisition by discounting the sum of (i) the liquidation value at issuance and (ii) the future cumulative accrued dividends as of the date of optional redemption for a lack of marketability.

The Aly Operating Redeemable Preferred Stock was entitled to a cumulative paid-in-kind dividend of 5% per year on its liquidation preference, compounded quarterly. Aly Operating was not required to pay cash dividends.

The following table describes the changes in Aly Operating Redeemable Preferred Stock (in thousands, except for shares) for the nine months ended September 30, 2017:

 

 

Carrying

Value of Aly Operating Redeemable Preferred

Stock

 

 

Number of Outstanding

Aly Operating Redeemable Preferred Shares

 

 

Liquidation

Value of Aly Operating Redeemable Preferred

Stock

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

January 1, 2017

 

$4,924

 

 

 

4,000,000

 

 

$4,924

 

Accrued dividends

 

 

21

 

 

 

-

 

 

 

21

 

Exchange for common stock in connection with Recapitalization

 

 

(4,945)

 

 

(4,000,000)

 

 

(4,945)

September 30, 2017

 

$-

 

 

 

-

 

 

$-

 

The Aly Operating Redeemable Preferred Stock was classified outside of permanent equity in our condensed consolidated balance sheet because the settlement provisions provided the holder the option to require Aly Operating to redeem the Aly Operating Redeemable Preferred Stock at the liquidation price plus any accrued dividends upon a liquidity event, as defined in the agreement, or upon an initial public offering, as defined in the agreement.

On January 31, 2017, the Aly Operating Redeemable Preferred Stock and all accrued dividends were converted into 2,414,971 shares of common stock in connection with the Recapitalization. This conversion was accounted for as a trouble debt restructuring, see further details in “Note 3 – Recapitalization”.

Aly Centrifuge Redeemable Preferred Stock

On April 15, 2014, as part of the United Acquisition, Aly Centrifuge issued 5,000 shares of Aly Centrifuge Redeemable Preferred Stock, with a par value of $0.01, to the sellers in the transaction, with a fair value and liquidation value of $5.1 million and $5.0 million, respectively. The preferred stock was valued as of the date of acquisition by discounting the sum of (i) the value of the preferred stock without a conversion option using the option pricing method and (ii) the value of the conversion option using the Black-Scholes option pricing model for a lack of marketability. In 2015, Aly Centrifuge asserted an indemnification claim of 124 shares against shares that were subject to an eighteen-month holdback for general indemnification purposes pursuant to the purchase agreement.

On August 15, 2014, in connection with a bulk equipment purchase, Aly Centrifuge issued an additional 4,000 shares of Aly Centrifuge Redeemable Preferred Stock, with a par value of $0.01, to the sellers in the transaction, with a fair value and liquidation value of $4.3 million and $4.0 million, respectively. The preferred stock was valued as of the date of the equipment purchase by discounting the sum of (i) the value of the preferred stock without a conversion option using the option pricing method and (ii) the value of the conversion option using the Black-Scholes option pricing model for a lack of marketability.

The Aly Centrifuge Redeemable Preferred Stock was entitled to a cumulative paid-in-kind dividend of 5% per year on its liquidation preference, compounded quarterly. Aly Centrifuge was not required to pay cash dividends.We do not incur any incremental costs to obtain or fulfill our customer contracts which require capitalization under ASC 606 and have elected the practical expedient afforded to expense such costs if incurred.

 

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The following table describes the changes in the Aly Centrifuge Redeemable Preferred Stock (in thousands, except for shares) for the nine months ended September 30, 2017:

 

 

Carrying

Value of Aly Centrifuge Redeemable Preferred

Stock

 

 

Number of Outstanding

Aly Centrifuge Redeemable Preferred

Shares

 

 

Liquidation

Value of

Aly Centrifuge Redeemable Preferred

Stock

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

January 1, 2017

 

$10,080

 

 

 

8,876

 

 

$10,080

 

Accrued dividends

 

 

42

 

 

 

-

 

 

 

42

 

Exchange for common stock in connection with Recapitalization

 

 

(10,122)

 

 

(8,876)

 

 

(10,122)

September 30, 2017

 

$-

 

 

 

-

 

 

$-

 

The Aly Centrifuge Redeemable Preferred Stock was classified outside of permanent equity in our condensed consolidated balance sheet because the settlement provisions provided the holder the option to require Aly Centrifuge to redeem the Aly Centrifuge Redeemable Preferred Stock at the liquidation price plus any accrued dividends.

Aly Centrifuge Redeemable Preferred Stock also included a conversion feature; specifically, the right to exchange into shares of our common stock on any date, from time-to-time, at the option of the holder, into the number of shares equal to the quotient of (i) the sum of (A) the liquidation preference plus (B) an amount per share equal to accrued but unpaid dividends not previously added to the liquidation preference on such share of preferred stock, divided by (ii) 1,000, and (iii) multiplied by the exchange rate in effect at such time (“Conversion Feature”). The exchange rate in effect as of December 31, 2016 was 71.4285 or $14.00 per share of our common stock.

On January 31, 2017, the Aly Centrifuge Redeemable Preferred Stock and all accrued dividends were converted into 3,039,516 shares of common stock in connection with the Recapitalization; however, the shares were not converted according to the terms of the Conversion Feature but instead the conversion rate was negotiated independently as a part of the Recapitalization. This conversion was accounted for as a trouble debt restructuring, see further details in “Note 3 – Recapitalization”.

NOTE 7 —CONTROLLING SHAREHOLDER ANDRELATED PARTY TRANSACTIONS

From time-to-time, the Company engages in business transactions with its controlling shareholder, Pelican, and other related parties.

Controlling Shareholder – PelicanChange to Full Retrospective Method for ASC 606 Adoption

On December 12, 2016, Pelican purchased our Aly Senior Obligations from Tiger for $5.1 million as a part of the Recapitalization. Effective January 31, 2017, the Recapitalization was completed and resulted in the following:

 

·Pelican’s contribution of approximately $16.1 million of the Aly Senior Obligations into shares of Series A convertible preferred stock that represents approximately 80% of our common stock, or 53,628,842 common shares, on a fully diluted basis. The preferred shares carry a liquidation preference of $1,000 per share or $16.1 million upon issuance.

·Amendment of the Company’s credit agreement acquired by Pelican into a new credit agreement (consisting of a $5.1 million term loan and $1.0 million revolving credit arrangement) with an extended maturity date of December 31, 2018.

On January 31, 2017 upon completion of the Recapitalization, Pelican had the power to vote the substantial majority of the Company’s outstanding common stock. Currently six of our board members and all four of our executive officers hold an ownership interest in Pelican.

On May 23, 2017 and in consideration of the increase in the revolving credit facility and the extension of the maturity date of December 31, 2019, the Company agreed to issue Pelican an amendment fee of 1,200 shares of our Series A convertible preferred stock. Given the nature of the related party relationship between the Company and Pelican, the debt modification fee was accounted for as a capital transaction whereby we issued Series A convertible preferred stock in exchange for the modification of our Pelican Credit Facility which resulted in a debt modification fee equal to the estimated fair value of the equity interest granted. The share price of common stock as of May 23, 2017 of $0.08 per share was used as the basis of fair value for the equity interested granted. The debt modification fee is included in “Interest expense – Pelican” on the condensed consolidated statement of operations recorded as an “Issuance of preferred shares in exchange for the amendment to credit facility - Pelican” on the condensed consolidated statement of changes in stockholders’ equity (deficit).

See further details at “Note 2 – Recent Developments” and “Note 3 – Recapitalization”.As there is no impact on equity and due to the isolated impact of the effect on the financial statements for ASC 606 adoption, Aly Energy has determined it more beneficial to change from the modified retrospective method to the full retrospective method.

  

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Other Related Party Transactions

One of our directors, Tim Pirie, appointedAdjustments to Previously Reported Financial Statements from the Adoption of ASC 606

In accordance with the new revenue standard requirements, there was no impact of adoption on our condensed consolidated balance sheet. The impact of adoption on our condensed consolidated statement of operations on the three months ended March 3, 2015, was one of the sellers of United to us in April 2014. Part of the acquisition price was payable in contingent consideration of which $0.9 million was paid in 2015. Of that amount, approximately $0.1 million was allocable to Mr. Pirie. We did not make any contingent payments during 2016. As of December 31, 2016, we estimated the fair value of future payments to be $0.8 million. On January 31, 2017, in connection with the Recapitalization, the aggregate contingent payment liability was converted into 457,494 shares of the Company’s common stock, of which Mr. Pirie controls all of the voting rights to 326,834 shares. See further discussion in “Note 2 – Recent Developments” and “Note 3 – Recapitalization”.

As part of the acquisition price of United, the sellers also received Aly Centrifuge Redeemable Preferred Stock. On January 31, 2017, the outstanding Aly Centrifuge Redeemable Preferred Stock and accrued dividends were converted into 3,039,516 shares of the Company’s common stock of which Mr. Pirie controls all of the voting rights to 593,815 shares. See further discussion in “Note 2 – Recent Developments”, “Note 3 – Recapitalization” and “Note 6 –Redeemable Preferred Stock (Aly Centrifuge Redeemable Preferred Stock)”.

NOTE 8 — EARNINGS PER SHARE

Basic earnings per share is computed by dividing income available to common stockholders by the weighted average number of shares of common stock outstanding during the period. Diluted earnings per share is computed in the same manner as basic earnings per share except that the denominator is increased to include the number of additional shares of common stock that could have been outstanding assuming the exercise of outstanding stock options and restricted stock or other convertible instruments, as appropriate.

For the three months ended September 30, 2017 and 2016 and for the nine months ended September 30, 2016, the effect of incremental shares is antidilutive so the diluted earnings per share will be the same as the basic earnings per share. The calculations of basic and diluted earnings per share for the nine months ended September 30, 2017 is reflected below (in thousands):

 

 

 

 

 

Adoption of  

 

 

 

 

`

 

As Reported

 

 

ASC 606

 

 

As Adjusted

 

 

 

(unaudited)

 

 

 

 

 

(unaudited)

 

Rental services

 

$1,888

 

 

$-

 

 

 

1,888

 

Rig-up/rig-down services

 

 

434

 

 

 

-

 

 

 

434

 

Transportation services

 

 

505

 

 

 

-

 

 

 

505

 

Other

 

 

25

 

 

 

(15)

 

 

10

 

Total revenue

 

 

2,852

 

 

 

(15)

 

 

2,837

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating expenses

 

 

1,940

 

 

 

-

 

 

1,940

 

Depreciation and amortization

 

 

927

 

 

 

-

 

 

 

927

 

Selling, general and administrative expenses

 

 

581

 

 

 

(15

 

 

566

 

Total expenses

 

 

3,448

 

 

 

(15)

 

 

3,433

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss from operations

 

$(596)

 

$-

 

 

$(596)

NOTE 7 – EARNINGS PER SHARE

Basic earnings per share is computed by dividing income available to common stockholders by the weighted average number of shares of common stock outstanding during the period. Diluted earnings per share is computed in the same manner as basic earnings per share except that the denominator is increased to include the number of additional shares of common stock that could have been outstanding assuming the exercise of outstanding stock options and restricted stock or other convertible instruments, as appropriate.

For the three months ended March 31, 2018, the effect of incremental shares is antidilutive so the diluted earnings per share will be the same as the basic earnings per share. The calculations of basic and diluted earnings per share for the three months ended March 31, 2017 are shown below (in thousands, except for shares):

 

 

 

For the Nine

Months Ended September 30,

 

 

 

 

For the Nine

Months Ended September 30,

 

 

 

2017

 

 

 

 

2017

 

 

 

(unaudited)

 

 

 

(unaudited)

 

Numerator:

 

 

 

 

Denominator: (1)

 

 

 

Net income from continuing operations

 

$508

 

 

Weighted average shares used in basic earnings per share

 

 

13,011,207

 

Less: Aly Operating Redeemable Preferred Stock dividends

 

 

(21)

 

Effect of dilutive shares:

 

 

 

 

Numerator for diluted earnings per share - continuing operations

 

 

487

 

 

Aly Centrifuge Redeemable Preferred Stock (2)

 

 

71,993

 

Less: Loss from discontinued operations, net of income taxes

 

 

-

 

 

Series A Convertible Preferred Stock

 

 

49,443,487

 

Numerator for diluted earnings per share

 

 

487

 

 

Stock options

 

 

7,597,123

 

 

 

 

 

 

 

Weighted average shares used in diluted earnings per share

 

 

70,123,810

 

Numerator for diluted earnings per share - continuing operations

 

 

487

 

 

 

 

 

 

 

Less: Aly Centrifuge Redeemable Preferred Stock dividends

 

 

(42)

 

Basic earnings per share - continuing operations

 

$0.03

 

Numerator for basic earnings per share - continuing operations

 

 

445

 

 

Basic earnings per share - discontinued operations

 

$-

 

Less: Loss from discontinued operations, net of income taxes

 

 

-

 

 

Diluted earnings per share - continuing operations

 

$0.01

 

Numerator for basic earnings per share

 

$445

 

 

Diluted earnings per share - discontinued operations

 

$-

 

__________
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Table of Contents

 

For the Three Months Ended March 31,

 

2017

 

(unaudited)

 

Numerator:

 

Net income from continuing operations

 

$

1,558

 

Less: Aly Operating redeemable preferred stock dividends

 

(21

)

Numerator for diluted earnings per share

 

1,537

 

Numerator for diluted earnings per share

 

1,537

 

Less: Aly Centrifuge redeemable preferred stock dividends

 

(42

)

Numerator for basic earnings per share

 

$

1,495

 

Denominator: (1)

 

Weighted average shares used in basic earnings per share

 

11,369,113

 

Effect of dilutive shares:

 

Aly Centrifuge redeemable preferred stock (2)

 

218,378

 

Series A convertible preferred stock

 

35,156,686

 

Weighted average shares used in diluted earnings per share

 

46,744,176

 

Basic earnings per share

 

$

0.13

 

Diluted earnings per share

 

$

0.03

________

(1)
(1)The exchange of Aly Operating Redeemable Preferred Stockredeemable preferred stock into common shares is not considered within the calculation of the numerator or denominator of diluted earnings per share because, during the month ended January 31, 2017, the Aly Operating Redeemable Preferred Stockredeemable preferred stock was not exchangeable into common shares. In connection with the Recapitalization, the Aly Operating Preferred Stockpreferred stock was converted into common shares and is included in our weighted average shares used for basic earnings per share effective February 1, 2017. Please see our Annual Report on Form 10-K for the year ended December 31, 2017 for a complete description of the Recapitalization, including the exchange of the Aly Operating redeemable preferred stock. Unvested stock options are not considered within the calculation of the denominator of diluted earnings per share because thethey vest upon the occurrence of certain events which may or may not occur.

 

(2)During the month ended January 31, 2017, the Aly Centrifuge Redeemable Preferred Stockredeemable preferred stock was convertible into 634,000 shares. In connection with the Recapitalization, the Aly Centrifuge Preferred Stockredeemable preferred stock was converted into common shares and is included in our weighted average shares used for basic earnings per share effective February 1, 2017. See further discussion in “Note 3 – Recapitalization” and “Note 6 – Redeemable Preferred Stock (AlyPlease see our Annual Report on Form 10-K for the year ended December 31, 2017 for a complete description of the Recapitalization, including the exchange of the Aly Centrifuge Redeemable Preferred Stock)”.

redeemable preferred stock.

  

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Securities excluded from the computation of basic and diluted earnings per share are shown below:

 

Securities excluded from

For the computationThree Months Ended March 31,

2017

Unvested stock options (1)

236,932

Exchange of basic and diluted earnings per share are shown below:

For the Nine Months Ended

September 30, 2017

(unaudited)

UnvestedAly Operating redeemable preferred stock options (1)

235,094

Aly Operating Redeemable Preferred Stock (2)

 

 

-

 

________

(1)The stock options vest upon the occurrence of certain events as defined in the Omnibus Incentive2013 Plan. As of September 30,March 31, 2017, the stock options were unvested.

(2)Prior to January 31, 2017, the Aly Operating Redeemable Preferred Stockredeemable preferred stock was exchangeable only upon the occurrence of certain events, as defined in the Aly Operating Redeemable Preferred Stock Agreement.redeemable preferred stock agreement. Upon occurrence of such events, the Aly Operating Redeemable Preferred Stockredeemable preferred stock could have been, at the holder’sholder's option, converted into common shares. The conversion ratio, determined by a calculation defined in the agreement of which the components included trailing twelve-month financial performance and magnitude of investment in new equipment, remained undeterminable until an event would cause the Aly Operating Redeemable Preferred Stockredeemable preferred stock to become exchangeable. In connection with the Recapitalization, the Aly Operating Redeemable Preferred Stockredeemable preferred stock was converted into common shares and is included in our weighted average shares used for basic earnings per share effective February 1, 2017.

NOTE 9 — STOCK-BASED COMPENSATION

Stock Options

Effective April 4, Please see our Annual Report on Form 10-K for the year ended December 31, 2017 the 2017 Stock Option Plan (the “2017 Plan”) was approved by the board of directors. On May 30, we granted approximately 16.9 million common shares under the 2017 Plan which was the maximum amount authorized. The option contract term is 10 years and the exercise price is $0.10. The options vested and became exercisable immediately upon grant. The fair valuefor a complete description of the award was estimated using a Black-Scholes fair value model. The valuation of stock options requires us to estimateRecapitalization, including the expected term of award, which was estimated using the simplified method, as the Company does not have sufficient historical exercise information. Additionally, the valuation of stock option awards is also dependent on historical stock price volatility. In view of our being listed on the Over-the-Counter Bulletin Board, volatility was calculated based on historical stock price volatilityexchange of the Company’s peer group. As a result, we recorded share-based compensationAly Operating redeemable preferred stock.

13
Table of $0.6 million for the full value of the grant as a component of selling, general and administrative expenses during the nine months ended September 30, 2017.

NOTE 10 — SUPPLEMENTAL CASH FLOW INFORMATION

Supplemental cash flows and non-cash investing and financing activities are as follows (in thousands):

 

 

For the Nine Months

Ended September 30,

 

 

 

2017

 

 

2016

 

 

 

(unaudited)

 

Supplemental disclosure of cash flow information:

 

 

 

 

 

 

Cash paid for interest

 

$156

 

 

$835

 

Cash paid for interest - discontinued operations

 

 

-

 

 

 

1

 

Cash paid for income taxes, net

 

 

50

 

 

 

5

 

 

 

 

 

 

 

 

 

 

Non-cash investing and financing activities:

 

 

 

 

 

 

 

 

Accretion of preferred stock liquidation preference, net

 

$-

 

 

$94

 

Paid-in-kind dividends on preferred stock

 

 

63

 

 

 

542

 

Returned equipment to lessor in exchange for release from capital lease obligation

 

 

91

 

 

 

-

 

Principal payments financed through disposition of assets

 

 

23

 

 

 

-

 

Extinguishment of redeemable preferred stock in exchange for common stock in connection with Recapitalization

 

 

15,036

 

 

 

-

 

Extinguishment of debt and other liabilities - Pelican in exchange for Series A convertible preferred stock

 

 

16,092

 

 

 

-

 

Contents

 

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NOTE 11 — NEW ACCOUNTING STANDARDS

Accounting Standards Recently Adopted

In January 2017, the Financial Accounting Standards Board (FASB) issued accounting standards update (ASU) 2017-04, Intangibles- Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment. The amendments eliminate Step 2 from the goodwill impairment test. The annual or interim goodwill impairment test is performed by comparing the fair value of a reporting unit with its carrying amount. An impairment charge should be recognized for the amount by which the carrying amount exceeds the reporting unit’s fair value. The amendments should be applied on a prospective basis. The new standard is effective for the Company on January 1, 2020. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. The Company adopted the accounting guidance as of January 1, 2017. The newly adopted accounting principle is preferable because it reduces the cost and complexity of evaluating goodwill for impairment. The adoption of this ASU did not have a material impact on the Company’s condensed consolidated financial statements.

In January 2017, the FASB issued ASU 2017-03, Accounting Changes and Error Corrections (Topic 250) and Investments - Equity Method and Joint Ventures (Topic 323): Amendments to SEC Paragraphs Pursuant to Staff Announcements at the September 22, 2016 and November 17, 2016 EITF Meetings (SEC Update). Among other things, this ASU incorporates into the FASB ASC Topic 250, SEC guidance about disclosing, under SEC SAB Topic 11.M, the effect on the financial statements of recently issued accounting standards when adopted, and specifically for ASU 2014-09, ASU 2016-02, and ASU 2016-03. If a registrant does not know or cannot reasonably estimate the impact of adoption of the above standards, the SEC staff expects the registrant to make a statement to that effect. Consistent with SAB Topic 11.M, the SEC staff also expects the registrant to provide qualitative disclosures to help users assess the significance the adoption will have on the financial statements. Other than our continued assessment of ASU 2014-09 through the date of adoption, the adoption of ASU 2017-03 did not have an impact on our financial statements.

In November 2016, the FASB issued ASU No. 2016-18 Statement of Cash Flows (Topic 230), Restricted Cash. This standard provides guidance on the presentation of restricted cash and restricted cash equivalents in the statement of cash flows. Restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period amounts shown on the statements of cash flows. The amendments of this ASU should be applied using a retrospective transition method and are effective for reporting periods beginning after December 15, 2017, with early adoption permitted. Other than the revised statement of cash flows presentation of restricted cash, the adoption of ASU 2016-18 did not have an impact on our consolidated financial statements.

In March 2016, the FASB Issued ASU 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. The updated guidance changes how companies account for certain aspects of share-based payment awards to employees, including the accounting for income taxes, forfeitures, and statutory tax withholding requirements, as well as classification in the statement of cash flows. The Company will adopt the accounting guidance as of January 1, 2017. The adoption of this ASU did not have a material impact on the Company’s consolidated financial statements.

In November 2015, the FASB issued ASU 2015-17, Income Taxes: Balance Sheet Classification of Deferred Taxes, which eliminates the existing requirement for organizations to present deferred tax assets and liabilities as current and noncurrent in a classified balance sheet and now requires that all deferred tax assets and liabilities be classified as noncurrent. The ASU is effective for annual periods beginning after December 15, 2016, with early application permitted. We elected to early adopt the provisions of this ASU and classified our deferred tax balances as a non-current liability as of December 31, 2016 and 2015. The adoption has no effect on net income or cash flows.

In September 2015, the FASB issued ASU 2015-16, Business Combinations: Simplifying the Accounting for Measurement-Period Adjustments, which requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The amendments in the ASU require that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. The amendments are effective for annual reporting periods beginning after December 15, 2015. The adoption of ASU 2015-16NOTE 8 – NEW ACCOUNTING STANDARDS

Adoption of New Accounting Standards - ASU 2014-09, Revenue - Revenue from Contracts with Customers

On January 1, 2018, we adopted the new accounting standard ASC 606, Revenue from Contracts with Customers and all the related amendments to all contracts using the full retrospective method. Please see Note 6 – Revenue from Contracts with Customers for additional disclosure related to ASC 606.

Other Accounting Standards Recently Adopted

In May 2017, the FASB issued ASU 2017-09, Compensation – Stock Compensation (Topic 718): Scope of Modification Accounting. The guidance in this ASU applies to all entities that change the terms or conditions of a share-based payment award. The amendments provide clarity and reduce diversity in practice as well as cost and complexity when applying the guidance in Topic 718, Compensation – Stock Compensation, to the modification of the terms and conditions of a share-based payment award. The amendments in ASU 2017-09 include guidance on determining which changes to the terms and conditions of share-based payment awards require an entity to apply modification accounting under Topic 718. The new standard is effective for the Company beginning on January 1, 2018 and should be applied prospectively to awards modified on or after the adoption date. The adoption of ASU 2017-09 did not have an impact on our financial condition or results of operations.

 

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In August 2015, the FASB issued ASU 2015-15, Interest - Imputation of Interest: Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements, which adds comments from the Securities and Exchange Commission (SEC) addressing ASU 2015-03, as discussed above, and debt issuance costs related to line-of-credit arrangements. The SEC commented it would not object to an entity deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. We adopted ASU 2015-15 in connection with our adoption of ASU 2015-03 effective January 1, 2016.In January 2017, the FASB issued ASU 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business. The amendments affect all companies and other reporting organizations that must determine whether they have acquired or sold a business. The amendments are intended to help companies and other organizations evaluate whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The amendments provide a more robust framework to use in determining when a set of assets and activities is a business. The new standard is effective for the Company beginning on January 1, 2018. The adoption of ASU 2017-01 did not have an impact on our financial condition or results of operations.

In December 2016, the FASB issued ASU 2016-19, Technical Corrections and Improvements, which makes minor corrections and clarifications that affect a wide variety of topics in the Accounting Standards Codification, including an amendment to ASC Topic 820, Fair Value Measurement, which clarifies the difference between a valuation approach and a valuation technique when applying the guidance of that Topic. The amendment also requires an entity to disclose when there has been a change in either or both a valuation approach and/or a valuation technique. The transition guidance for the ASC Topic 820 amendment must be applied prospectively because it could potentially involve the use of hindsight that includes fair value measurements. The new guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. The Company adopted ASU 2016-19 on January 1, 2018. The adoption of ASU 2015-15 did not have an impact on our financial condition or results of operations.

In April 2015, the FASB issued ASU 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The amendments in the ASU change the balance sheet presentation requirements for debt issuance costs by requiring them to be presented as a direct reduction to the carrying amount of the related debt liability. The amendments are effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption is permitted. Transitioning to the new guidance requires retrospective application. We implemented the required change to the presentation of our debt issuance costs in the first quarter of fiscal year 2016, as expected such change did not have a material impact to our consolidated financial statements.

In November 2014, the FASB issued ASU 2014-16, Determining Whether the Host Contract in a Hybrid Financial Instrument Issued in the Form of a Share Is More Akin to Debt or to Equity, which clarifies how to evaluate the economic characteristics and risks of a host contract in a hybrid financial instrument that is issued in the form of a share. Specifically, the ASU requires that an entity consider all relevant terms and features in evaluating the nature of the host contract and clarifies that the nature of the host contract depends upon the economic characteristics and the risks of the entire hybrid financial instrument. An entity should assess the substance of the relevant terms and features, including the relative strength of the debt-like or equity-like terms and features given the facts and circumstances, when considering how to weight those terms and features. The adoption of ASU 2014-16 did not have an impact on our financial condition or results of operations.

In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements – Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern, which defines management’s responsibility to evaluate whether there is substantial doubt about the company’s ability to continue as a going concern and provides guidance on the related footnote disclosure. Management should evaluate whether there are conditions or events that raise substantial doubt about the company’s ability to continue as a going concern within one year after the date the annual or interim financial statements are issued. We adopted these provisions in the first quarter of 2016 and will provide such disclosures as required if there are conditions and events that raise substantial doubt about our ability to continue as a going concern, as expected such change did not have a material impact to our consolidated financial statements.

In June 2014, the FASB issued Accounting Standards Update No. 2014-12, Compensation — Stock Compensation (Topic 718), Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period (a consensus of the FASB Emerging Issues Task Force). The guidance applies to all reporting entities that grant their employees share-based payments in which the terms of the award provide that a performance target that affects vesting could be achieved after the requisite service period. The amendments require that a performance target that affects vesting and that could be achieved after the requisite service period is treated as a performance condition. For all entities, the amendments in this Update are effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. Earlier adoption is permitted. The effective date is the same for both public business entities and all other entities. The adoption of ASU 2014-12 did not have an impact on our financial condition or results of operations.

 

Accounting Standards Not Yet Adopted

In May 2017, the FASB issued ASU 2017-09, Compensation – Stock Compensation (Topic 718): Scope of Modification Accounting. The guidance in this ASU applies to all entities that change the terms or conditions of a share-based payment award. The amendments provide clarity and reduce diversity in practice as well as cost and complexity when applying the guidance in Topic 718, Compensation – Stock Compensation, to the modification of the terms and conditions of a share-based payment award. The amendments in ASU 2017-09 include guidance on determining which changes to the terms and conditions of share-based payment awards require an entity to apply modification accounting under Topic 718. The new standard is effective for the Company beginning on January 1, 2018 and should be applied prospectively to awards modified on or after the adoption date. The Company does not expect the adoption of this ASU to have a material impact on its condensed consolidated financial statements.

In January 2017, the FASB issued ASU 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business. The amendments affect all companies and other reporting organizations that must determine whether they have acquired or sold a business. The amendments are intended to help companies and other organizations evaluate whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The amendments provide a more robust framework to use in determining when a set of assets and activities is a business. The new standard is effective for the Company beginning on January 1, 2018. The Company does not expect the adoption of this ASU to have a material impact on its condensed consolidated financial statements.

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In December 2016, the FASB issued ASU 2016-19, Technical Corrections and Improvements, which makes minor corrections and clarifications that affect a wide variety of topics in the Accounting Standards Codification, including an amendment to ASC Topic 820, Fair Value Measurement, which clarifies the difference between a valuation approach and a valuation technique when applying the guidance of that Topic. The amendment also requires an entity to disclose when there has been a change in either or both a valuation approach and/or a valuation technique. The transition guidance for the ASC Topic 820 amendment must be applied prospectively because it could potentially involve the use of hindsight that includes fair value measurements. The new guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. Early application is permitted for any fiscal year or interim period for which the entity’s financial statements have not yet been issued. We are currently evaluating the impact this ASU will have on the financial position or financial statement disclosures.

In October 2016, the FASB issued ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory. The guidance in this ASU requires entities to recognize at the transaction date the income tax consequences of intercompany asset transfers other than inventory. The new standard is effective for the Company beginning on January 1, 2018. The Company is evaluating the effect that ASU 2016-16 will have on its condensed consolidated financial statements and related disclosures.

In August 2016, the FASB issued ASU 2016-15, “Statement of Cash Flows (Topic 230), Classification of Certain Cash Receipts and Cash Payments (a consensus of the FASB Emerging Issues Task Force) (ASU 2016-15)”, that clarifies how entities should classify certain cash receipts and cash payments on the statement of cash flows. The guidance also clarifies how the predominance principle should be applied when cash receipts and cash payments have aspects of more than one class of cash flows. The guidance will be effective for annual periods beginning after December 15, 2017 and interim periods within those annual periods. Early adoption is permitted. The Company is evaluating the effect of ASU 2016-15 on its consolidated financial statements.

 

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which will replace the existing lease guidance. The standard is intended to provide enhanced transparency and comparability by requiring lessees to record right-of-use assets and corresponding lease liabilities on the balance sheet. Additional disclosure requirements include qualitative disclosures along with specific quantitative disclosures with the objective of enabling users of financial statements to assess the amount, timing, and uncertainty of cash flows arising from leases. ASU 2016-02 is effective for the Company for annual reporting periods beginning after December 15, 2018, including interim periods within those fiscal years, with early adoption permitted. The new standard is required to be applied with a modified retrospective approach to each prior reporting period presented. We are currently evaluating the standard to determine the impact of its adoption on the consolidated financial statements.

 

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), which will replace most existing revenue recognition guidance in GAAP and align GAAP more closely with International Financial Reporting Standards (IFRS). The objective of this ASU is to establish the principles to report useful information to users of financial statements about the nature, amount, timing, and uncertainty of revenue from contracts with customers. The core principle is to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.

Entities must apply a five-step process to (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when (or as) the entity satisfies a performance obligation. ASU 2014-09 also mandates disclosure of sufficient information to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The disclosure requirements include qualitative and quantitative information about contracts with customers, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill a contract. ASU 2014-09 must be adopted using either a full retrospective method or a modified retrospective method. The new standard is effective for the Company beginning on January 1, 2018.

The Company is in the process of determining the impacts the new standard will have on its various revenue streams. The Company’s approach includes performing a detailed review of key contracts representative of the different businesses and comparing historical accounting policies and practices to the new accounting guidance. The Company does not incur significant contract costs. The Company’s services and rental contracts are primarily short-term in nature, and therefore, based on the initial assessment, the Company does not expect the adoption of this ASU to have a material impact on its condensed consolidated financial statements, other than the additional disclosure requirements. Remaining implementation matters include establishing new policies, procedures, controls, and quantifying any adoption date adjustments. The Company will adopt this standard on January 1, 2018 utilizing the modified retrospective method and elect to apply the revenue standard only to contracts that are not completed as of the date of initial application.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

The following discussion and analysis of our financial condition and results of operations is intended to assist you in understanding our business and results of operations together with our present financial condition. Unless otherwise noted, all discussion and analysis relate to continuing operations. This section should be read in conjunction with the condensed consolidated financial statements and the related notes thereto included elsewhere in “Item 1. Condensed Consolidated Financial Statements” in this Form 10-Q.

 

Cautionary Note Regarding Forward-Looking Statements

 

This Current Report on Form 10-Q (this “Report”) contains certain statements and information that may constitute “forward-looking statements”"forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Theamended. Statements which are not historical in nature, including the words “anticipate,” “believe,“estimate,“ensure,“should,” “expect,” “if,“believe,” “intend,” “plan,” “estimate,“may,” “project,” “forecasts,” “predict,” “outlook,” “aim,” “will,” “could,” “should,” “potential,” “would,” “may,” “probable,” “likely,“plan” or “continue,” and similar expressions that convey the uncertainty of future events or outcomes, and the negative thereof, are intended to identify forward-looking statements. Forward-looking statements, which are not generally historical in nature, include those that express a belief, expectation or intention regarding our future activities, plans and goals and our current expectations with respect to, among other things:

·

projected operating or financial results, including any accretion/dilution to earnings and cash flow;

·

any plans to obtain financing to fund future operations;

·

prospects for services and expected activity in potential and existing areas of operations;

·

the effects of competition in areas of operations;

·

the outlook of oil and gas prices;

·

the current economic conditions and expected trends in the industry we serve;

·

the amount, nature and timing of capital expenditures and availability of capital resources;

·

future financial condition or results of operations and future revenue and expenses; and

·

business strategy and other plans and objectives for future operations.

 

Forward-looking statements are not assurances of future performance and actual results could differ materially from our historical experience and our present expectations or projections. Forward-looking statements involve risks and uncertainties, some of which are not currently known to us, that may cause our actual results, performance or financial condition to be materially different from the expectations of future results, performance or financial condition we express or imply in any forward-looking statements. These forward-looking statements are based on management’sour current plans and expectations and beliefs, forecasts for our existing operations, experience,are subject to a number of uncertainties and risks that could significantly affect current plans and expectations and perception of historical trends, current conditions, anticipatedour future developmentsfinancial condition and their effect on us, and other factors believed to be appropriate. Although management believes the expectations and assumptions reflected in these forward-looking statements are reasonable as and when made, no assurance can be given that these assumptions are accurate or that any of these expectations will be achieved (in full or at all). Our forward-looking statements involve significant risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control.results. Known material factors that could cause actual results to differ materially from those in the forward-looking statements include, but are not limited to, the following:volatility in oil and natural gas price, fluctuations in the domestic rig count, our highly competitive industry and the other risk factors described in our Annual Report on Form 10-K for the year ended December 31, 2017.

 

·conditions in the oil and natural gas industry, especially oil and natural gas prices and capital expenditures by oil and natural gas companies;

·volatility in oil and natural gas prices;

·fluctuations in the domestic land-based rig count;

·changes in laws and regulations;

·our ability to implement price increases or maintain pricing on our core services;

·risks that we may not be able to reduce, and we may experience increases in, the costs of labor, fuel, equipment and supplies employed in our businesses;

·industry capacity;

·asset impairments or other charges;

·the periodic low demand for our services and resulting operating losses and negative cash flows;

·our highly competitive industry as well as operating risks, which are primarily self-insured, and the possibility that our insurance may not be adequate to cover all of our losses or liabilities;

·significant costs and potential liabilities resulting from compliance with applicable laws, including those resulting from environmental, health and safety laws and regulations;

·our historically high employee turnover rate and our ability to replace or add workers, including executive officers and skilled workers;

·our ability to incur debt or long-term lease obligations;

·our ability to implement technological developments and enhancements;

·severe weather impacts on our business;

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·our ability to successfully identify, make and integrate future acquisitions and our ability to finance such acquisitions;

·our ability to successfully identify, make and integrate future acquisitions and our ability to finance such acquisitions;

 

·our ability to finance future growth of our operations through investments in new equipment and service offerings;

·our ability to finance future growth of our operations through investments in new equipment and service offerings;

 

·our ability to achieve the benefits expected from disposition transactions;

·our ability to achieve the benefits expected from disposition transactions;

 

·the loss of one or more of our larger customers;

·the loss of one or more of our larger customers;

 

·our ability to generate sufficient cash flow to meet future debt service obligations;

·our ability to generate sufficient cash flow to meet future debt service obligations;

 

·our inability to achieve our financial, capital expenditure and operational projections, including quarterly and annual projections of revenue and/or operating income, and our inaccurate assessment of future activity levels, customer demand, and pricing stability which may not materialize (whether for Aly Energy Services, Inc. as a whole or for geographic regions and/or certain business operations individually);

·our inability to achieve our financial, capital expenditure and operational projections, including quarterly and annual projections of revenue and/or operating income, and our inaccurate assessment of future activity levels, customer demand, and pricing stability which may not materialize (whether for Aly Energy Services, Inc. as a whole or for geographic regions and/or certain business operations individually);

 

·business opportunities (or lack thereof) that may be presented to our company and may be pursued;

·business opportunities (or lack thereof) that may be presented to our company and may be pursued;

 

·our ability to respond to changing or declining market conditions, including our ability to reduce the costs of labor, fuel, equipment and supplies employed and used in our businesses;

·our ability to respond to changing or declining market conditions, including our ability to reduce the costs of labor, fuel, equipment and supplies employed and used in our businesses;

 

·our ability to maintain sufficient liquidity;

·our ability to maintain sufficient liquidity;

 

·adverse impact of litigation; and

·adverse impact of litigation; and

 

·other factors affecting our business described in “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2016 and in the other reports we file with the Securities and Exchange Commission.

·other factors affecting our business described in “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2016 and in the other reports we file with the Securities and Exchange Commission.

Should oneWe undertake no obligation to publicly update or more of the factors, risks or uncertainties described above materialize (or the other consequences of such a development worsen), or should underlying assumptions prove incorrect, actual results and plans could differ materially from those expressed inrevise any forward-looking statements.statements, whether as a result of new information, future events or otherwise. In light of these risks, uncertainties and assumptions, the forward-looking events discussed in this Current Report on Form 10-Q might not occur. We qualify any and all of our forward-looking statements entirely by these cautionary factors. You are cautioned not to place undue reliance on these statements, which speak only as of the date of this Report.Current Report on Form 10-Q.

 

HistoryOverview of Our Business

 

On July 17, 2012, Munawar “Micki” Hidayatallah founded Aly Energy withServices, Inc. (“Aly Energy”, the strategic objective“Company”, or “we”) is a growth-oriented provider of creating an oilfield services company that servesto leading oil and gas exploration and production (“E&P”) companies from well planning to plug and abandonment. We have grown our business both through organic growth resulting from investment in existing operations and through the strategic acquisition of certain businesses operating in our industry.unconventional plays in the United States (“U.S.”). Generally, the services we offer fall within two broad categories: surface rental and solids control. Our surface rental equipment includes a wide variety of large capacity tanks with integral circulating systems, associated pumps, separators, gas busters, mud mix plants and ancillary equipment necessary to manage the flow of mud in and out of the well bore during drilling operations. We also provide environmental containment berms to safeguard against spills from the mud system. Our solids control equipment and services remove low gravity formation particulates that accumulate in mud systems during the drilling process. Solids control equipment includes large centrifuges, shakers, cuttings dryers and ancillary components that can be integrated into a closed loop mud system. Once processed, the mud can be reused which eliminates unnecessary waste and disposal.

 

To date, we have acquired three businesses:

·Austin Chalk Petroleum Services Corp. (“Austin Chalk”) - In October 2012, we acquired Austin Chalk a provider of high performance, explosion-resistant rental equipment used primarily in land-based horizontal drilling. Austin Chalk currently offers a robust inventory of surface rental equipment as well as roustabout services, including the rig-up and rig-down of equipment and the hauling of equipment to and from the customer’s location;

·United Centrifuge LLC and the leased fixed assets associated with that business (collectively “United”) - United, acquired in April 2014, operates within the solids control sector of the oilfield services industry, offering its customers the option of renting centrifuges and auxiliary solids control equipment without personnel or the option of paying for a full-service solids control package which includes operators on-site 24 hours a day. United owns centrifuges which are differentiated from the competition due to the ability to remove the rotating assembly from a centrifuge within 45 minutes while on the rig site thereby minimizing customer down time; and

·Evolution Guidance Systems Inc. (“Evolution”) - In July 2014, we acquired Evolution which specialized as an operator of Measurement-While-Drilling (“MWD”) downhole tools. Effective October 26, 2016, we abandoned these operations as a part of a restructuring event (see further details in Capital Restructuring below).

Subsequent to the acquisition of each of these businesses, we have made significant investments to expand their operations and capitalize on organic growth opportunities in existing and expansion markets. We consistently seek opportunities to bundle product offerings and to cross sell services across markets and product lines, which we believe improves client retention and increases the utilization of our equipment.

 
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Overview of Our Business

We are a provider of solids control systems and surface rental equipment. Our equipment and services are primarily designed for and used in land-based horizontal drilling. Our equipment includes centrifuges and auxiliary solids control equipment, mud circulating tanks (400- and 500-barrel capacity) and auxiliary surface rental equipment, portable mud mixing plants and containment systems. In conjunction with the rental of some of our solids control packages, we provide personnel at the customer’s well site to operate our equipment. We also provide personnel to rig-up/rig-down and haul our equipment to and from the customer’s location. We operate primarily in Texas (West Texas and South Texas), Oklahoma, New Mexico, and Louisiana. Our primary operating yards, shop and repair facilities, and division management are located in Giddings, Texas, San Angelo, Texas, and Houston, Texas.

We derive the majority of our revenue from day rates or hourly rates charged for the rental of our equipment and for the services provided by our personnel. The price we charge for our services depends on both the level of activity within the geographic area in which we operate and also the competitive environment.

Our operating costs do not fluctuate in direct proportion to changes in revenue. Our operating costs include both fixed and variable costs; although most variable costs are highly correlated with revenue and activity, certain variable costs, such as sub-rental equipment expenses and third-party trucking expenses, can be reduced as a percentage of revenue by our investment in new rental and transportation equipment.

Industry Trends

We operate in the commodity-driven, cyclicalU.S., primarily in Texas, Oklahoma, and New Mexico. Within these states, we have a very strong footprint in the Permian Basin, one of the largest and most prolific shale plays in the U.S., and we also provide services in the Scoop/Stack region and Eagle Ford shale.

We cultivate and maintain strong relationships with our customers which include some of the largest independent oil and gas industry. From 2011 through mid-2014,E&P companies operating in the industry operated in an environment where crude oil prices were relatively stableU.S. shale basins. Our major customers include leading companies such as EOG Resources, Inc., Pioneer Natural Resources, XTO Energy Inc., Sanchez Oil and except for comparatively short intervals, generally traded at prices at or in excess of $100 per barrel. However, subsequent to the third quarter of 2014, crude oil prices declined significantly dueGas Corporation and Devon Energy Corporation.

General Trends and Outlook

Our business depends to a varietysignificant extent on the level of factors, including, but not limited to, continued growthunconventional resource development activity and corresponding capital spending of E&P companies onshore in the U.S. These activity and spending levels are strongly influenced by the current and expected oil production, weakened outlooksprice. Commodity prices increased significantly between the beginning of 2017 and the beginning of 2018 stimulating an increase in onshore drilling and completion activity and a consequent increase in demand for the global economy and continued strong international crude oil supply resulting in part from OPEC’s unexpected decision to maintain oil production levels. As a result of the weaker crude oil price environment, many crude oil development prospects became less economical for exploration and production operators, leading to a dramatic reduction inour services. The average U.S. land-based drilling rig count and weaker demand for oilfield services, such as the services we provide.

The decline in both oil prices and the U.S. land-based rig count continued during the first half of 2016. Barring a few brief rallies, the price of oil bottomed out in February 2016 at less than $30 per barrel and the U.S. land-based rig count reached its low of less than 400was approximately 650 rigs in July 2016. After reaching its low point, the price of oil thenJanuary 2017 and increased steadily for several months and has hovered between $45 per barrel and $50 per barrel since June 2016. With the price of oil fairly constant for the past twelve months at a level which is economical for exploration and production operators, the U.S. land-based rig count has increased steadily, and in July 2017, the count had increasedapproximately 50.0% to over 900more than 975 rigs an increase of greater than 100% compared to its low of less than 400 rigs in July 2016.

during March 2018. The favorable impact of the recent increase in the U.S. land-based rig count on demand for our services has been magnifiedbolstered by an increase in thea consistently high proportion of rigs drilling directional and horizontal wells. As illustrated in the graph below, the proportion of rigs drilling directional and horizontal wells as a percentage of total U.S. land-based rigs has increased from approximately 80% in the first quarter of 2014 to 92% in the second quarter of 2017. Rigs drilling directional and horizontal wells typically utilize oil-based or other sophisticated mud systems which creates demand for the Company’sour specialized mud circulating tanks, pumps, containment systems, solids control and associated equipment. The proportion of rigs drilling directional and horizontal wells as a percentage of total U.S. land-based drilling rigs was approximately 89.0% and 93.9% in January 2017 and March 2018, respectively.

If the current commodity price environment holds or continues to improve, we anticipate a further increase in demand for our services. In addition, our customers are increasingly focused on efficient drilling of high intensity wells with long laterals which further enhances the demand for our services. As demand increases, we expect that utilization will increase and our ability to increase the prices for our equipment and services will improve resulting in greater margins and increased margins as a percent of revenue. These increased margins will be partially offset to the extent we are required to use third-party providers of equipment and personnel to meet the increased demand. Our equipment and personnel are currently fully utilized; however, given our cash-on-hand, our positive operating cash flow and our availability to borrow additional funds under our existing credit facility, we are planning to invest in newly purchased, refurbished or fabricated equipment which will meet increased demand and/or replace existing sub-rented equipment.

How We Generate Revenue and the Costs of Conducting Our Business

We generate our revenue by providing drilling-related support services to E&P companies operating in some of the major onshore unconventional basins in the U.S. During the three months ended March 31, 2018, approximately 69.3% of our revenue was derived from charges for the rental of equipment and, in certain cases, the use of personnel to operate such equipment, 30.4% was derived from charges for services we provide, such as the rig-up/rig-down and hauling of our equipment and the remainder of our revenue was derived from the sale of consumable items, including chemicals.

Our revenue fluctuates with the utilization of and the prices we charge for our equipment and services. Utilization of our equipment is primarily determined by the U.S. land-based drilling rig count as it is typically representative of the level of activity of E&P companies. The prices we charge for our products and services depend on the relationship between the level of activity of E&P companies, or the demand of our potential and existing customers, and the supply of equipment and services available to such E&P companies from us and our competitors.

Due to the significant impact of the volatility of the oil and gas industry on the activity of E&P companies, both the utilization of our equipment and related services and the prices we charge have been, and may be, significantly impacted by numerous factors outside of our control, such as oil and natural gas prices, the supply of and demand for oil and natural gas, domestic and worldwide economic conditions, political instability in oil producing countries and available supply of and demand for the services we provide.

Our operating expenses consist primarily of variable costs, such as labor and third-party expenses. Labor-related expenses typically fluctuate with the utilization of our equipment and services. Expenses associated with services provided by third-parties typically increase with activity as well. Demand for our equipment has increased so significantly over the past two years that most of our available owned equipment has been fully utilized since early 2017 and we have been required to increase our available equipment fleet and our available labor resources to meet the demand from our customers. We accomplish this by sub-renting equipment, primarily surface rental equipment, and by using sub-contractors to operate our solids control equipment. Because our equipment and labor force are fully utilized, incremental dollars of revenue resulting from increased activity in the future will continue to require the use of third-party equipment and services and third-party expenses will increase as a percent of revenue. In addition, with increased demand for oilfield services, the demand for sub-rental equipment and labor will also increase and we may experience increases in costs for third-party equipment and personnel which would further increase third-party expenses as a percent of revenue. As we invest in new rental equipment and increase headcount, we can partially offset the cost increases by reducing our reliance on third-party providers of equipment and personnel.

In the near-term, our ability to service a portion of our existing customers and our ability to service new customers is largely dependent on our ability to access equipment, especially tanks and pumps, from third-party vendors. The availability of sub-rental equipment, as well as the prices charged by such suppliers, are factors beyond our control which could impact our results of operations. In response to this risk, we have implemented a capital expenditure plan for 2018 which will assist us in reducing our reliance on third-party vendors.

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How We Evaluate Our Operations

We utilize multiple metrics to evaluate the results of our operations and efficiently allocate personnel, equipment and capital resources, including, but not limited to, the following:

·Revenue: We monitor our revenue monthly to analyze trends in the business as it relates to historical revenue drivers and prevailing market metrics. We are particularly interested in understanding the underlying utilization and pricing metrics that drive the positive or negative revenue trends each month.

·Gross profit: Gross profit is a key metric that we use to evaluate our profitability and determine allocation of equipment and personnel resources. We define gross profit as our revenue less operating expenses. Operating expenses include direct and indirect labor costs, the cost of third-party services, including the sub-rental of equipment and the use of sub-contractors, costs for repairs and maintenance of our equipment and other miscellaneous costs. We continually evaluate our gross profit margin to assist us in making decisions regarding bidding new jobs, allocating resources among various jobs and managing our overall cost structure.

·EBITDA and Adjusted EBITDA: EBITDA and Adjusted EBITDA are financial metrics used by management as (i) supplemental internal measures for planning and forecasting and for evaluating actual results against such expectations; (ii) significant criteria for incentive compensation paid to our executive officers and management; (iii) reference points to compare to the EBITDA and Adjusted EBITDA of other companies when evaluating potential acquisitions; and, (iv) assessments of our ability to service existing fixed charges and incur additional indebtedness.

 

We disclose and discuss EBITDA as a non-GAAP financial measure in our public releases, including quarterly earnings releases, investor conference calls and other filings with the Securities and Exchange Commission.

We define EBITDA as earnings (net income) before interest, income taxes, and depreciation and amortization. Our measure of EBITDA may not be comparable to similarly titled measures presented by other companies, which may limit its usefulness as a comparative measure.

 

We also make certain adjustments to EBITDA for (i) non-cash charges such as reduction in value of assets, bad debt expense, share-based compensation expense, and changes in fair value of our liability for contingent payments and (ii) certain expenses, such as severance, legal settlements, and professional fees and other expenses related to transactions outside the ordinary course of business, to derive a normalized EBITDA run-rate (“("Adjusted EBITDA”EBITDA"), which we believe is a useful measure of operating results and the underlying cash generating capability of our business.

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Because EBITDA and Adjusted EBITDA are not measures of financial performance calculated in accordance with GAAP, these metrics should not be considered in isolation or as a substitute for operating income, net income or loss, cash flows provided by operating, investing and financing activities, or other income or cash flow statement data prepared in accordance with GAAP.

 

EBITDA and Adjusted EBITDA are widely used by investors and other users of our financial statements as supplemental financial measures that, when viewed with our GAAP results and the accompanying reconciliation, we believe provide additional information that is useful to gain an understanding of our ability to service debt, pay income taxes and fund growth and maintenance capital expenditures. We also believe the disclosure of EBITDA and Adjusted EBITDA helps investors meaningfully evaluate and compare our cash flow generating capacity from quarter-to-quarter and year-to-year.

 

EBITDA and Adjusted EBITDA are also financial metrics used by management as (i) supplemental internal measures for planning and forecasting and for evaluating actual results against such expectations; (ii) significant criteria for incentive compensation paid to our executive officers and management; (iii) reference points to compare to the EBITDA and Adjusted EBITDA of other companies when evaluating potential acquisitions; and, (iv) assessments of our ability to service existing fixed charges and incur additional indebtedness.

The following table provides the detailed components of EBITDA and Adjusted EBITDA as we define that term for the three and nine months ended September 30, 2017 and 2016, respectively (in thousands):

 

 

For the Three Months

Ended September 30,

 

 

For the Nine Month

 Ended September 30,

 

 

 

2017

 

 

2016

 

2017

 

 

2016

 

 

 

(unaudited)

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Components of EBITDA:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income (loss)

 

$(26)

 

$(2,142)

 

$508

 

 

$(7,073)

 

 

Loss (income) from discontinued operations, net of income taxes

 

 

-

 

 

 

(37)

 

 

-

 

 

 

1,345

 

 

 

Net income (loss) from continuing operations

 

 

(26)

 

 

(2,179)

 

 

508

 

 

 

(5,728)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Non-GAAP adjustments:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Depreciation and amortization

 

 

944

 

 

 

1,328

 

 

 

2,793

 

 

 

4,162

 

 

 

Interest expense, net

 

 

2

 

 

 

629

 

 

 

18

 

 

 

1,777

 

 

 

Interest expense, net - Pelican

 

 

69

 

 

 

-

 

 

 

664

 

 

 

-

 

 

 

Income tax expense (benefit)

 

 

6

 

 

 

(872)

 

 

18

 

 

 

(3,406)

 

 

EBITDA

 

 

995

 

 

 

(1,094)

 

 

4,001

 

 

 

(3,195)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Adjustments to EBITDA:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Reduction in value of assets

 

 

18

 

 

 

787

 

 

 

58

 

 

 

1,630

 

 

 

Gain on extinguishment of debt and other liabilities

 

 

-

 

 

 

-

 

 

 

(2,387)

 

 

-

 

 

 

Expenses in connection with lender negotiations and Recapitalization

 

 

47

 

 

 

281

 

 

 

112

 

 

 

387

 

 

 

Employee-related restructuring expenses, including severance

 

 

(145)

 

 

-

 

 

 

(145)

 

 

456

 

 

 

Bad debt expense

 

 

21

 

 

 

10

 

 

 

56

 

 

 

44

 

 

 

Settlements and other losses

 

 

47

 

 

 

6

 

 

 

77

 

 

 

69

 

 

 

Fair value adjustments to contingent payment liability

 

 

-

 

 

 

8

 

 

 

-

 

 

 

(198)

 

 

Stock-based compensation

 

 

-

 

 

 

-

 

 

 

625

 

 

 

-

 

 

 

Adjusted EBITDA

 

$983

 

 

$(2)

 

$2,397

 

 

$(807)

 

 

Set forth below are the material limitations associated with using EBITDA and Adjusted EBITDA as non-GAAP financial measures compared to cash flows provided by and used in operating, investing and financing activities:

 

 

·EBITDA and Adjusted EBITDA do not reflect growth and maintenance capital expenditures,

 

·EBITDA and Adjusted EBITDA do not reflect the interest, potential principal payments and other financing-related charges necessary to service theour debt, that we have incurred to finance acquisitions and invest in our fixed asset base,

 

·EBITDA and Adjusted EBITDA do not reflect the payment of income taxes, and

 

·EBITDA and Adjusted EBITDA do not reflect changes in our net working capital position.

 

Management compensates for the above-described limitations in using EBITDA and Adjusted EBITDA as non-GAAP financial measures by only using EBITDA and Adjusted EBITDA to supplement our GAAP results.

 

Business Outlook

Our core businesses depend on our customers’ willingness to make expenditures to produce, develop and explore for oil and natural gas. Industry conditions are influenced by numerous factors, such as oil and natural gas prices, the supply of and demand for oil and natural gas, domestic and worldwide economic conditions, political instability in oil producing countries and available supply of and demand for the services we provide. Oil and natural gas prices began a rapid and substantial decline in the fourth quarter of 2014. Depressed commodity price conditions persisted and worsened during 2015 and that trend continued into 2016. As a result, the rig count and demand for our products and services declined substantially, and the prices we are able to charge our customers for our products and services have also declined substantially.

 
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Oil prices have improved offThe following table provides the low pointdetailed components of 2016 with the November 2016 decision by OPEC to curtail the cartel’s oil production, the Baker Hughes U.S. land drilling rig count has increased significantly from its low point in mid-2016,EBITDA and our revenue has improved substantially during the first nine months of 2017. We believeAdjusted EBITDA as we define that stability in oil prices at an attractive price to our customers coupled with the increases in drilling activity during the first half of 2017 will result in further increases in demand for our services and will provide us opportunities to increase the price of our products and services, particularly in 2018. However, with increased demand for oilfield services broadly, the demand for qualified employees and the demandterm for the sub-rental equipment we require to increase our activity will increasethree months ended March 31, 2018 and we may experience increases in costs which we cannot completely offset with price increases to our customers. As of September 30, 2017, based on our expectations of improved activity levels and pricing throughout the remainder of 2017 and 2018, we believe that we will be able to service our debt obligations and ongoing operations through operating cash flow and, if necessary, availability under our credit facility.respectively (in thousands):

 

Operational Restructuring

 

 

For the Three Months

Ended March 31,

 

 

 

2018

 

 

2017

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

Components of EBITDA:

 

 

 

 

 

 

Net income (loss)

 

$(13)

 

$1,558

 

Non-GAAP adjustments:

 

 

 

 

 

 

 

 

Depreciation and amortization

 

 

891

 

 

 

927

 

Interest expense, net

 

 

6

 

 

 

13

 

Interest expense - related party

 

 

86

 

 

 

211

 

Income tax expense

 

 

21

 

 

 

9

 

EBITDA

 

 

991

 

 

 

2,718

 

Adjustments to EBITDA:

 

 

 

 

 

 

 

 

Gain on extinguishment of debt and other liabilities

 

 

-

 

 

 

(2,387)

Loss on disposal of assets

 

 

-

 

 

 

40

 

Bad debt expense

 

 

22

 

 

 

15

 

Settlements and other losses

 

 

24

 

 

 

21

 

Expenses in connection with lender negotiations and Recapitalization

 

 

-

 

 

 

6

 

Adjusted EBITDA

 

$1,037

 

 

$413

 

  

OurAdjusted EBITDA for the three months ended March 31, 2018 increased to $1.0 million from $0.4 million for the three months ended March 31, 2017. The 151.1% increase in Adjusted EBITDA was primarily due to incremental revenue resulting from increased activity is tied directly to the rig count and even though we instituted significant cost cutting measures beginningimproved pricing. The increase in 2015, we were unable to cut costs enough to match the decline in our business. As a result, as of December 31, 2015, we were in default of our credit agreement with Wells Fargo Bank, National Association (“Wells Fargo”).

Throughout 2015, in an effort to mitigate the significant declines in pricingrevenue was partially offset by greater operating expenses and utilization of our equipment, we committed to a reorganization initiative to strengthen our sales and marketing efforts, consolidate support functions, and operate more efficiently. The reorganization effort included, but was not limited to, training our salesforce to enable the cross-selling of our product lines in certain geographical markets, sharing a common support services infrastructure across all reporting units, reducing headcount and wage rates, and rebranding and launching a new web site to increase awareness of our service lines. We recognized some benefit from these measures in late 2015 resulting in increased gross margins and lowergreater selling, general and administrative expenses; however, expenses when compared to the first half of 2015.

During the year ended December 31, 2016, we entered intoincreased at a series of forbearance agreements with our lender. Under the forbearance agreements, among other provisions, the lenders agreed to forbear from exercising their remedies under the credit agreement. These forbearance agreements permitted us to operate within the parameters of our normal course of business despite the continuing default under the credit agreement. Without these forbearance agreements, our outstanding debt would have been immediately due and payable. Throughout 2016, we remainedslower rate than revenue which resulted in default and we did not have sufficient liquidity to repay all of the outstanding debt to the lender at any point during the year ($20.1 million as of December 31, 2015). As such, we may have been forced to file for protection under Chapter 11 of the U.S. Bankruptcy Code.

In early 2016, we were hopeful that a successful operational restructuring would facilitate negotiations to modify the terms of our existing credit facility with Wells Fargo. Our operational restructuringan increase in 2016 consisted of severe cost cuts which were incremental to the year-over-year cost cuts already achieved in 2015 when compared to 2014. In 2016, significant cost savings were primarily generated by:

·reductions of our employee base, both field employees and sales and administrative employees, to a headcount of approximately 50 as of December 31, 2016 from approximately 125 as of December 31, 2015,

·reduction in employer contributions to employee benefits,

·closures of certain operating yards and administrative facilities,

·strategic decision to cease operations in the northeast which resulted in the reduction of costs related to operating in an incremental market,

·modifications to insurance policies, including general liability and workers’ compensation policies, resulting in a $0.5 million or 15.5% reduction in the cost of insurance to $0.6 million for the year ended December 31, 2016 from $1.1 million for the year ended December 31, 2015,

·minimization of repair and maintenance activities, resulting in a $0.4 million or 50.0% reduction of repair and maintenance expenses to $0.4 million for the year ended December 31, 2016 from $0.8 million for the year ended December 31, 2015, and

·elimination of investments in equipment, unless required to service an existing customer, resulting in a reduction of capital expenditures to $0.4 million for the year ended December 31, 2016 from $2.5 million for the year ended December 31, 2015.

We also achieved significant cost savings from the decrease in third party costs, such as sub-rental equipment and trucking, and other variable costs which declined with the decrease in activity.

In order to further support our working capital needs, we identified and sold idle and underutilized assets. During 2016, we realized aggregate proceeds from sales of approximately $0.8 million of which $0.5 million and $0.3 million was used to fund working capital needs and pay down debt, respectively.

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We believe that the completion of the Recapitalization in January 2017, significant increases in demand for our services, particularly in Texas, and an efficient cost structureAdjusted EBITDA as a resultpercent of revenue to 23.9% for the cost-cutting initiatives described above, will generate significant improvements in financial results duringthree months ended March 31, 2018 from 14.6% for the second half of 2017 if the U.S. land-based rig countthree months ended March 31, 2017. We anticipate that ongoing and price of oil remain stable or increase.

Capital Restructuring

Despite our successful operational restructuring efforts, particularly during the first half of 2016, the decline in our activity levels and the declinesplanned increases in customer pricing outpacedwill drive additional increases in Adjusted EBITDA and Adjusted EBITDA as a percent of revenue during the impactremainder of our cost reductions and it became evident2018. We anticipate that a capital restructuring wouldthere will also be necessarysome increase in activity which will contribute to continue operations and position our business for an industry turnaround.

In the second quarter of 2016, certain of the Company’s principal stockholders (“Shareholder Group”) began negotiations with Wells Fargo with the objective of consummating a recapitalization transaction (the “Recapitalization”) whereby our obligations under the credit agreement and the outstanding capital leasesincrease in favor of Wells Fargo’s equipment finance affiliate and certain other obligations of Aly Energy (collectively the “Aly Senior Obligations”) would be restructured. In August 2016, the Shareholder Group was introduced to a third party, Tiger Finance, LLC (“Tiger”), to provide bridge financing and to extend forbearance until such date as sufficient capital could be raised to complete the Recapitalization.

In September 2016, the Shareholder Group formed Permian Pelican, LLC (“Pelican”) with the objective of raising capital and executing the steps necessary to complete the restructuring, inclusive of successfully effecting the exchange of the Aly Operating redeemable preferred stock, Aly Centrifuge redeemable preferred stock, Aly Centrifuge subordinated debt and liability for a contingent payment into approximately 10% of our common stock on a fully diluted basis.

Effective January 31, 2017, the Recapitalization was completed through the execution and delivery of a Securities Exchange Agreement and a Second Amended and Restated Credit Agreement. As a result of the Recapitalization, the Company became a “Controlled Company” as defined under the listing standards of the principal national securities exchanges;Adjusted EBITDA; however, since the Shareholder Group’s proportionate interest did not change significantly, a change in control did not occur and the transaction was accounted for at historical cost.

As a result of the Recapitalization, the credit facility, now with Pelican, consisted of a term loan of $5.1 million and a revolving facility of up to $1.0 million as of January 31, 2017. Availability under the revolving credit facility is determined by a borrowing base calculated as 80% of eligible receivables (receivables less than 90 days old).

Subsequent to the Recapitalization,extent we entered into several further amendmentsneed to capitalize on improved market conditionsuse third-party equipment and increasedpersonnel to meet the demand, the increases in activity may result in our business:

·Amendment No. 1, effective March 1, 2017, provided for a delayed draw term loan to be added to the credit facility for the purpose of financing capital expenditures. The agreement permitted us to draw on the delayed draw term loan from time-to-time up until the maturity date of the facility in order to fund up to 80% of the cost of capital expenditures subject to a $0.5 million limit on aggregate borrowings.

·Amendment No. 2, effective May 23, 2017, increased the maximum revolving credit amount from $1.0 million to $1.8 million and extended the final maturity date of the facility to December 31, 2019. In consideration of the increase in the revolving credit facility and the extension of the final maturity date, we agreed to issue to Pelican, the lender, as an amendment fee, 1,200 shares of our Series A convertible preferred stock. See further discussion in “Note 7 – Controlling Shareholder and Other Related Party Transactions” in the notes to our condensed consolidated financial statements included elsewhere in this document.

·Amendment No. 3, effective June 15, 2017, modified maximum potential borrowings under each of the revolving credit facility and the delayed draw term loan without changing the aggregate available borrowings under the credit facility. The amendment reduced the maximum revolving credit amount from $1.8 million to $1.0 million and increased the maximum delayed draw loan borrowings from $0.5 million to $1.3 million and the amendment also increased permitted draws on the delayed draw loan from 80% of the cost of capital expenditures being funded to 90% of the cost of capital expenditures being funded.

To the extent there is free cash flowAdjusted EBITDA remaining flat or declining slightly as defined in the credit agreement, principal paymentsa percent of 50% of such free cash flow are due annually. The maturity date of all remaining outstanding balances under the credit facility is December 31, 2019.

The obligations under the credit facility are guaranteed by all of our subsidiaries and secured by substantially all of our assets. The credit agreement contains customary events of default and covenants including restrictions on our ability to incur additional indebtedness, pay dividends or make other distributions, grant liens and sell assets. The credit facility does not include any financial covenants. We are in full compliance with the credit facility as of September 30, 2017.

As of September 30, 2017, there were outstanding borrowings of $5.0 million, $0.8 million, and $0.3 million on the term loan, revolving credit facility, and delayed draw term loan, respectively. As of September 30, 2017, we have the availability to borrow an incremental $0.3 million under the revolving credit facility and, if we have capital expenditures which are eligible to be financed, an incremental $0.9 million under the delayed draw term loan to finance 90% of such expenditures.

For a discussion of the accounting treatment for the Recapitalization, see “Note 3 – Recapitalization” in the notes to our condensed consolidated financial statements included elsewhere in this document.

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revenue.

 

Results of Operations

Results for the Three Months Ended September 30, 2017 Compared to the Three Months Ended September 30, 2016

 

The following table summarizes the change in our results of operations for the three months ended September 30, 2017 when compared toMarch 31, 2018 from the three months ended September 30, 2016March 31, 2017 (in thousands):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

For the Three Months Ended September 30,

 

 

Variance

 

 

 

2017

 

 

% of

Revenue

 

 

2016

 

 

% of Revenue

 

 

$

 

 

%

 

 

 

(unaudited)

 

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue

 

$4,143

 

 

 

100.0%

 

$2,071

 

 

 

100.0%

 

$2,072

 

 

 

100.0%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Expenses:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating expenses

 

 

2,608

 

 

 

62.9%

 

 

1,537

 

 

 

74.2%

 

 

1,071

 

 

 

69.7%

Depreciation and amortization

 

 

944

 

 

 

22.8%

 

 

1,328

 

 

 

64.1%

 

 

(384)

 

 

-28.9

%

Selling, general and administrative expenses

 

 

522

 

 

 

12.6%

 

 

841

 

 

 

40.6%

 

 

(319)

 

 

-37.9

%

Reduction in value of assets

 

 

18

 

 

 

0.4%

 

 

787

 

 

 

38.0%

 

 

(769)

 

 

-97.7

%

Total expenses

 

 

4,092

 

 

 

98.8%

 

 

4,493

 

 

 

216.9%

 

 

(401)

 

 

-8.9

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations

 

 

51

 

 

 

1.2%

 

 

(2,422)

 

NM

 

 

 

2,473

 

 

NM

 

Other expense:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Interest expense, net

 

 

2

 

 

 

0.0%

 

 

629

 

 

 

15.2%

 

 

(627)

 

 

-99.7

%

Interest expense - Pelican

 

 

69

 

 

 

1.7%

 

 

-

 

 

 

0.0%

 

 

69

 

 

NM

 

Total other expense

 

 

71

 

 

 

1.7%

 

 

629

 

 

 

15.2%

 

 

(558)

 

 

-88.7

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss from continuing operations before income taxes

 

 

(20)

 

NM

 

 

 

(3,051)

 

NM

 

 

 

3,031

 

 

NM

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income tax expense (benefit)

 

 

6

 

 

 

0.1%

 

 

(872)

 

NM

 

 

 

878

 

 

NM

 

Net loss from continuing operations

 

 

(26)

 

NM

 

 

 

(2,179)

 

NM

 

 

 

2,153

 

 

NM

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income from discontinued operations, net of income taxes

 

 

-

 

 

 

0.0%

 

 

(37)

 

NM

 

 

 

37

 

 

NM

 

Net loss

 

$(26)

 

NM

 

 

$(2,142)

 

NM

 

 

$2,116

 

 

NM

 

 

 

For the Three Months

Ended March 31,

 

 

 

 

 

% of

 

 

Change

 

 

 

2018

 

 

% of Revenue

 

 

2017

 

 

Revenue

 

 

$

 

 

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue

 

$4,336

 

 

 

100.00%

 

$2,837

 

 

 

100.00%

 

$1,499

 

 

 

52.84%

Expenses:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating expenses

 

 

2,610

 

 

 

60.19%

 

 

1,940

 

 

 

68.38%

 

 

670

 

 

 

34.54%

Depreciation and amortization

 

 

891

 

 

 

20.55%

 

 

927

 

 

 

32.68%

 

 

(36)

 

 

-3.88

%

Selling, general and administrative expenses

 

 

735

 

 

 

16.95%

 

 

566

 

 

 

19.95%

 

 

169

 

 

 

29.86%

Total expenses

 

 

4,236

 

 

 

97.69%

 

 

3,433

 

 

 

121.01%

 

 

803

 

 

 

23.39%

Income (loss) from operations

 

 

100

 

 

 

2.31%

 

 

(596)

 

NM

 

 

 

696

 

 

NM

 

Other expense (income):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Interest expense, net

 

 

6

 

 

 

0.14%

 

 

13

 

 

 

0.46%

 

 

(7)

 

 

-53.85

%

Interest expense - related party

 

 

86

 

 

 

1.98%

 

 

211

 

 

 

7.44%

 

 

(125)

 

 

-59.24

%

Gain on extinguishment of debt and other liabilities

 

 

-

 

 

 

0.00%

 

 

(2,387)

 

NM

 

 

 

2,387

 

 

NM

 

Total other expense (income)

 

 

92

 

 

 

2.12%

 

 

(2,163)

 

NM

 

 

 

2,255

 

 

NM

 

Income from operations before income taxes

 

 

8

 

 

NM

 

 

 

1,567

 

 

 

55.23%

 

 

(1,559)

 

 

-99.49

%

Income tax expense

 

 

21

 

 

 

0.48%

 

 

9

 

 

 

0.32%

 

 

12

 

 

 

133.33%

Net income (loss)

 

 

(13)

 

NM

 

 

 

1,558

 

 

 

54.92%

 

 

(1,571)

 

NM

 

Preferred stock dividends

 

 

-

 

 

 

0.00%

 

 

63

 

 

 

2.22%

 

 

(63)

 

NM

 

Net income (loss) available to common stockholders

 

$(13)

 

NM

 

 

$1,495

 

 

 

52.70%

 

$(1,508)

 

NM

 

  

NM - Not meaningful
18
Table of Contents

Results for the Three Months Ended March 31, 2018 Compared to the Three Months Ended March 31, 2017

 

Overview. Our results of operations dependimproved significantly when comparing the three months ended March 31, 2018 to the three months ended March 31, 2017. Two of the most significant drivers of demand for our services, the price of oil and the U.S. land-based drilling rig count, increased substantially when comparing the two periods: the price of oil increased over 20.0% and the U.S. land-based drilling rig count increased over 35.0%. The positive impact of these improved industry conditions on the demand forCompany was reflected in the increased utilization of our equipment and services and our ability to provide high quality equipmentraise the prices we charge to our customers. Increased utilization and service to satisfy that demand while maintaining an efficient cost structure. Duringincreased pricing resulted in a significant amount of incremental revenue during the three months ended September 30, 2017, the average U.S. land-based rig count was over 900March 31, 2018 when compared to approximately 450 for the three months ended September 30, 2016. The substantial increaseMarch 31, 2017 and a significant overall improvement in rig count was heavily concentrated in Texas, particularly in the Permian Basin, and our operations in Texas expanded significantly year-over-year. The increase in demand for our services in Texas was slightly offset by the decrease in revenue from the northeast region where we ceased operations during the fourth quarter of 2016. The financial results for the three months ended September 30, 2017 reflect the benefit of minimal variable and fixed costs in the northeast and increased efficiencies year-over-year due to extensive cost cuts during 2016.liquidity.

 

Revenue. Our revenue for the three months ended September 30, 2017March 31, 2018 was $4.1$4.3 million, an increase of 100.0%52.8%, compared to $2.1$2.8 million for the three months ended September 30, 2016. TheMarch 31, 2017. During the three months ended March 31, 2018 and 2017, our primary driverrevenue generating surface rental products, tanks and pumps, were fully utilized and our labor force was fully utilized. In order to take advantage of the improvement was anincreased demand for our services, we invested in additional equipment, sub-rented equipment from third parties, and used sub-contractors on certain solids control jobs. A combination of increased activity and increased pricing were the primary drivers of the increase in utilization of our equipment and services in Texas, primarily in the Permian Basin, due to increased demand. In addition, we were able to increase pricing on our primary rental products by approximately 10%revenue when comparing the three months ended September 30, 2017March 31, 2018 to the three months ended September 30, 2016. The substantial increase in activity in our Texas operations was slightly offset byMarch 31, 2017. During the eliminationthree months ended March 31, 2018, the count of revenue generated fromgenerating days for our tanks, pumps and centrifuges increased approximately 15.0% to 20.0% when compared to the northeast region duethree months ended March 31, 2017. Pricing for our tanks and pumps, our lead surface rental products, increased by approximately 15.0% and 30.0%, respectively, when comparing the three months ended March 31, 2018 to our decision to cease operations in that area in the fourth quarter of 2016.three months ended March 31, 2017.

 

Operating Expenses. Our operating expenses for the three months ended September 30, 2017March 31, 2018 increased 34.5% to $2.6 million or 62.9% of revenue, from $1.5$1.9 million or 74.2% of revenue, for the three months ended September 30, 2016.March 31, 2017. The 69.7% increase in costs is a direct reflection of the increased activity when comparing the three months ended March 31, 2018 to the three months ended March 31, 2017. Although operating expenses increased in dollars, the rate at which operating expenses increased was less than the rate at which revenue increased resulting in a decline of operating expenses as a percent of revenue to 60.2% for the three months ended March 31, 2018 from 68.4% for the three months ended March 31, 2017. The decrease in operating expenses was significantly less thanas a percent of revenue is primarily due to our discipline in maintaining a lean cost structure despite the 100.0% increase in revenue which reflects the substantial efficiencies achieved throughdemand, our cost cuts in 2016, particularly those relatedability to labor (see further discussion of cost cuts in “Operational Restructuring” section above). We also experienced a substantial period-over-period increase in third-party services as the primary surface rental products inpricing to our inventory have been fully utilized since early 2017customers more quickly than our costs increased, and the vast majorityspread of certain fixed costs across a larger revenue base. Our primary operating expenses consist of payroll and third-party costs. Payroll and related expenses increased by approximately $0.2 million, or 19.1%, as a result of increases in headcount and labor hours required to support incremental rentalactivity in Texas, Oklahoma and New Mexico; however, the expenses increased at a slower rate than revenue throughout 2017 has been derived fromreflecting our successful efforts to monitor labor productivity and efficiency. Third-party expenses, including the sub-rental of equipment, which we sub-rent.

Depreciationthe use of third-party trucking and Amortization. Depreciationwashout services, and amortization expense decreased 28.9%the use of sub-contractors, increased to $0.9 million for the three months ended September 30,March 31, 2018, or 21.8% of revenue, from $0.6 million, or 20.2% of revenue, for the three months ended March 31, 2017. Throughout 2017 comparedand year-to-date in 2018, our owned equipment and our labor force have been fully utilized requiring us to $1.3use third-party providers of equipment and personnel to satisfy the significant increases in demand.

Depreciation and Amortization. Due to minimal capital investment and insignificant asset disposals during 2017, depreciation and amortization remained fairly flat year-over-year at $0.9 million for the three months ended September 30, 2016. The decrease is due primarily to the disposition of assets to Tiger in connection with the Recapitalization (see further discussion in “Note 3 – Recapitalization” in the notes to our condensed consolidated financial statements).March 31, 2018 and 2017.

 

Selling, General and Administrative Expenses. Selling, general and administrative expenses decreasedincreased to $0.5$0.7 million, or 12.6%17.0% of revenue, for the three months ended September 30, 2017 from $0.8March 31, 2018 compared to $0.6 million, or 40.6%20.0% of revenue, for the three months ended September 30, 2016.March 31, 2017. Selling, general and administrative expenses consist of overhead costs which we generally consider to be fixed. The significant declineyear-over-year increase of $0.2 million, or 29.9%, is primarily due to the increase in headcount of selling, general and administrative expenses as a percentage of revenue reflectsemployees to 16 in March 2018 from 11 in January 2017. With the improved financial results we are experiencing, we have increased headcount in order to improve our ability to maintain an efficientsegregate duties and lean overhead cost structure while experiencing significant increases in activity. Duringstrengthen our internal controls as well as to manage the three months ended September 30, 2017, selling,increased activity levels. Selling, general and administrative expenses were offset by an aggregate net benefit of approximately $30,000 from itemsalso include expenses that are either non-recurring or non-cash in nature. The comparable items aggregated to a net expensenature with an aggregate value of $0.3 million forapproximately $60,000 and $42,000 during the three months ended September 30, 2016March 31, 2018 and 2017, respectively (see further discussion in “How We Evaluate Our Operations” section above).

 

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Interest Expense, net.Net. Interest expense, net, consisting of interest on insurance financing and other miscellaneous interest expense, was reduced to approximately $2,000$6,000 for the three months ended September 30, 2017 compared to $0.6 million forMarch 31, 2018. For the three months ended September 30, 2016. The decrease is dueMarch 31, 2017, interest expense, net was approximately $13,000 and consisted primarily of interest on a subordinated note payable which was converted to common stock on January 31, 2017 in connection with the impactRecapitalization. Please see our Annual Report on Form 10-K for the year ended December 31, 2017 for a complete description of the Recapitalization.Recapitalization, including the conversion of the subordinated note payable.

 

Interest Expense – Pelican.Related Party. During the three months ended September 30,March 31, 2018 and 2017, we recorded approximately $69,000$86,000 and $0.2 million of interest expense, respectively, due to Pelican, a related party. The reduction in interest expense is a direct result of the Recapitalization on January 31, 2017. Please see our Annual Report on Form 10-K for a complete description of the Recapitalization, including the reduction in principal on our long-term debt with Pelican.

 

Gain on Extinguishment of Debt and Other Liabilities. During the three months ended March 31, 2017, we recorded a gain on extinguishment of debt and other liabilities of $2.4 million due to our troubled debt restructuring in connection with the Recapitalization. Please see our Annual Report on Form 10-K for a complete description of the Recapitalization, including the gain on extinguishment of debt and other liabilities.

Income Taxes.The difference in the effective tax rate from the statutory rate is due to our continued full valuation allowance on net deferred tax assets. Income tax expense is from Texas Margin Tax. The Company has sufficient NOL carryforwards to offset Federalcurrent year federal income tax and other state income taxes.

 

Discontinued Operations. Discontinued operations include Evolution which specialized as an operator of MWD downhole tools. Income from discontinued operations, net of income taxes, was approximately $37,000 during the three months ended September 30, 2016. The operations were completely abandoned by December 31, 2016 and there was no income or loss from discontinued operations during the three months ended September 30, 2017.

Results for the Nine Months Ended September 30, 2017 Compared to the Nine Months Ended September 30, 2016

The following table summarizes the change in our results of operations for the nine months ended September 30, 2017 when compared to the nine months ended September 30, 2016 (in thousands):

 

 

For the Nine Months Ended September 30,

 

 

Variance

 

 

 

2017

 

 

% of

Revenue

 

 

2016

 

 

% of Revenue

 

 

$

 

 

%

 

 

 

(unaudited)

 

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue

 

$11,179

 

 

 

100.0%

 

$8,848

 

 

 

100.0%

 

$2,331

 

 

 

26.3%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Expenses:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating expenses

 

 

7,167

 

 

 

64.1%

 

 

6,886

 

 

 

77.8%

 

 

281

 

 

 

4.1%

Depreciation and amortization

 

 

2,793

 

 

 

25.0%

 

 

4,162

 

 

 

47.0%

 

 

(1,369)

 

 

-32.9

%

Selling, general and administrative expenses

 

 

2,340

 

 

 

20.9%

 

 

3,527

 

 

 

39.9%

 

 

(1,187)

 

 

-33.7

%

Reduction in value of assets

 

 

58

 

 

 

0.5%

 

 

1,630

 

 

 

18.4%

 

 

(1,572)

 

 

-96.5

%

Total expenses

 

 

12,358

 

 

 

110.5%

 

 

16,205

 

 

 

183.1%

 

 

(3,847)

 

 

-23.7

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss from continuing operations

 

 

(1,179)

 

NM

 

 

 

(7,357)

 

NM

 

 

 

6,178

 

 

NM

 

Other expense (income):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Interest expense, net

 

 

18

 

 

 

0.2%

 

 

1,777

 

 

 

15.9%

 

 

(1,759)

 

 

-99.0

%

Interest expense - Pelican

 

 

664

 

 

 

5.9%

 

 

-

 

 

 

0.0%

 

 

664

 

 

NM

 

Gain on extinguishment of debt and other liabilities

 

 

(2,387)

 

NM

 

 

 

-

 

 

 

0.0%

 

 

(2,387)

 

NM

 

Total other expense (income)

 

 

(1,705)

 

NM

 

 

 

1,777

 

 

 

15.9%

 

 

(3,482)

 

NM

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from continuing operations before income taxes

 

 

526

 

 

 

4.7%

 

 

(9,134)

 

NM

 

 

 

9,660

 

 

NM

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income tax expense (benefit)

 

 

18

 

 

 

0.2%

 

 

(3,406)

 

NM

 

 

 

3,424

 

 

NM

 

Net income (loss) from continuing operations

 

 

508

 

 

 

4.5%

 

 

(5,728)

 

NM

 

 

 

6,236

 

 

NM

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss from discontinued operations, net of income taxes

 

 

-

 

 

 

0.0%

 

 

1,345

 

 

 

15.2%

 

 

(1,345)

 

NM

 

Net income (loss)

 

$508

 

 

 

4.5%

 

$(7,073)

 

NM

 

 

$7,581

 

 

NM

 

NM - Not meaningful

Overview. Our results of operations depend on the demand for our services and our ability to provide high quality equipment and service to satisfy that demand while maintaining an efficient cost structure. During the nine months ended September 30, 2017, the average U.S. land-based rig count was over 800, an increase of over 300 rigs when compared to less than 500 for the nine months ended September 30, 2016. The increase in rig count was heavily concentrated in Texas, particularly in the Permian Basin, and our operations in Texas expanded throughout the first nine months of 2017 in conjunction with the increase in rig count.

Revenue. Our revenue for the nine months ended September 30, 2017 was $11.2 million, an increase of 26.3%, compared to $8.8 million for the nine months ended September 30, 2016. There was a substantial increase in demand for our services during the nine months ended September 30, 2017 compared to the nine months ended September 30, 2016, particularly in Texas. However, the resulting increase in revenues in 2017 was significantly offset by the elimination of revenue generated from the northeast region due to our decision to cease operations in that area in the fourth quarter of 2016.

Operating Expenses. Our operating expenses for the nine months ended September 30, 2017 increased to $7.2 million, or 64.1% of revenue, from $6.9 million, or 77.8% of revenue, for the nine months ended September 30, 2016. The 4.1% increase in operating expenses was significantly less than the 26.3% increase in revenue which reflects the substantial efficiencies achieved through our cost cuts in 2016, particularly those related to labor (see further discussion of cost cuts in “Operational Restructuring” section above) and the elimination of variable and fixed costs associated with our decision to cease operations in the northeast in the fourth quarter of 2016. These decreases were partially offset by a substantial increase in third-party services as the primary surface rental products in our inventory have been fully utilized since early 2017 and the vast majority of incremental rental revenue throughout 2017 has been derived from equipment which we sub-rent.

 
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Depreciation and Amortization. Depreciation and amortization expense decreased 32.9% to $2.8 million for the nine months ended September 30, 2017 compared to $4.2 million for the nine months ended September 30, 2016. The decrease is due primarily to the disposition of assets to Tiger in connection with the Recapitalization (see further discussion in “Note 3 – Recapitalization” in the notes to our condensed consolidated financial statements).

Selling, General and Administrative Expenses. Selling, general and administrative expenses decreased to $2.3 million, or 20.9% of revenue, for the nine months ended September 30, 2017 from $3.5 million, or 39.9% of revenue, for the nine months ended September 30, 2016. The 33.7% decline in expenses reflects the severe cost cutting initiatives started in 2015 which continued throughout 2016. These initiatives, implemented in response to the massive downturn in the industry, included headcount and wage rate decreases, the reduction of executive management salaries and elimination of bonuses, and significant reductions in travel, entertainment and office expense. Selling, general and administrative expenses also include expenses that are either non-recurring or non-cash in nature with an aggregate value of approximately $0.7 million and $0.8 million during the nine months ended September 30, 2017 and 2016, respectively (see further discussion in “How We Evaluate Our Operations” section above).

Interest Expense, net. Interest expense was reduced to approximately $18,000 for the nine months ended September 30, 2017 compared to $1.8 million for the nine months ended September 30, 2016. The decrease is due primarily to the impact of the Recapitalization.

Interest Expense – Pelican. During the nine months ended September 30, 2017, we recorded $0.7 million of interest expense due to Pelican, a related party, which includes a debt modification fee of $0.3 million. The debt modification fee reflects the value of 1,200 shares of our Series A convertible preferred stock issued to Pelican in exchange for an amendment to our credit facility in May 2017.

Gain on Extinguishment of Debt and Other Liabilities. During the nine months ended September 30, 2017, we recorded a gain on extinguishment of debt and other liabilities of $2.4 million due to our troubled debt restructuring in connection with the Recapitalization (see further discussion in “Note 3 – Recapitalization” in the notes to our condensed consolidated financial statements).

Income Taxes. The difference in the effective tax rate from the statutory rate is due to our continued full valuation allowance on net deferred tax assets. Income tax expense is from Texas Margin Tax. The Company has sufficient NOL carryforwards to offset Federal income tax and other state income taxes.

Discontinued Operations. Discontinued operations include Evolution which specialized as an operator of MWD downhole tools. Losses from discontinued operations, net of income taxes, were $1.3 million during the nine months ended September 30, 2016. The operations were completely abandoned by December 31, 2016 and there was no income or loss from discontinued operations during the nine months ended September 30, 2017.

   

Liquidity and Capital Resources

 

Net Cash Provided by Operating Activities. OperatingDuring the three months ended March 31, 2018 and 2017, operating activities provided $0.2generated $0.7 million and used $0.4 million in cash, respectively. The increase in cash flows from operating activities is primarily due to the significant improvement in operating results year-over-year and improved collections during the ninethree months ended September 30, 2017 comparedMarch 31, 2018, partially offset by increased vendor payments in the period. Due primarily to approximately $71,000a lack of resources, billing and collection efforts were delayed during the nine months ended September 30, 2016 due to improved operating results after adjusting net income for non-cash items offset by significant increases in working capital resulting from our rapid growth in 2017.

Liquidity. As a result of the industry downturn, many customers have experienced a significant reduction in their liquidity and have faced challenges accessing the capital markets. Several energy service and equipment companies have declared bankruptcy, or have had to exchange equity for the forgiveness of debt, while others have been forced to sell assets in an effort to preserve liquidity. We faced similar challenges requiring us to undergo a capital restructuring. For a discussion of the Recapitalization and its restructuring of our credit facility, see “Note 2 – Recent Developments” in the notes to our condensed consolidated financial statements included elsewhere in this document.

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While our liquidity was increased by the Recapitalization, we have continued to use our sources of liquidity to fund working capital needs resulting from the increase in activity and, to a lesser extent, to purchase equipment needed to service existing contracts. During the nine months ended September 30, 2017, we used $1.8 million to fund working capital needs. We anticipate that working capital requirements will decrease significantly during the fourthlast quarter of 2017 and may even be a sourcewe received the benefit of cash, as the pace of growth in activity slows. As of October 31, our cash on hand had increased substantially to a closing bank balance of $0.9 million, compared to a closing bank balance of $0.4 million as of September 30, 2017, due primarily to extremely strong“catch-up” collections during the monththree months ended March 31, 2018. Each quarter, we anticipate collecting an amount similar to the revenue reported for the prior quarter. During the three months ended March 31, 2018, we collected over $4.9 million which was significantly greater than fourth quarter revenue of October after a slow collection month$3.5 million. The increase in September. The table below reflectscash inflow enabled us to “catch-up” on vendor payments which we had previously stretched beyond our liquidity astypical payment terms of September 30, 2017 (in thousands):

 

 

 

 

 

As of

 

 

 

 

 

 

September 30,

2017

 

 

 

 

 

 

(unaudited)

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

 

 

 

$151

 

Revolving facility availability (1),(3)

 

 

 

 

 

250

 

Delayed draw term loan availability (2),(3)

 

 

 

 

 

900

 

Total liquidity

 

 

 

 

 

$1,301

 

 

 

 

 

 

 

 

 

 

____________

 

 

 

 

 

 

 

 

(1) Based on eligible receivables as of September 30, 2017.

(2) Available to finance 90% of the purchase price for capital expenditures, including 90% of existing purchase commitments of $0.2 million for 4 diesel mud pumps.

(3) With Permian Pelican, our controlling shareholder.

60 days.

 

Capital Expenditures. Capital expenditures are the main component of our investing activities. Since 2015, ourCash capital expenditures have been limitedfor the three months ended March 31, 2018 and 2017 were $0.3 million and $0.2 million, respectively. Approximately $0.1 million was spent to maintenance capital expenditures, purchasesrefurbish centrifuges and related auxiliary equipment and approximately $97,000 was spent to purchase diesel mud pumps during the three months ended March 31, 2018. During the remainder of 2018, we anticipate spending approximately $0.3 million to continue our centrifuge refurbishment program so that we can meet increasing demand for our solids control services. We also anticipate spending an incremental $1.2 million on new equipment requested by existing customers for ongoing jobs, and the acquisition of assetsequipment fabricated in-house to meet increasing demand and to replace equipment we are currently sub-renting. Other capital expenditures in 2018 will likely consist of liners, hoses, vehicles and similar assets which are required to support the ongoing operations. The successful implementation of our capital expenditure plan will enable us to service additional customers and rigs if demand continues to grow and, even if there is no incremental demand for our services, our investment in items which we sub-rent, to meet customer demand when our owned equipment is fully utilized. During the nine months ended September 30, 2017, due to significant increases in demand, we spent $0.3 million to repurchase certain assets which had been disposed of in connection with the Recapitalization and we spent $0.3 million onsuch as diesel mud pumps to replace the use of certain sub-rentedand transfer pumps and open top tanks, will reduce our expenses and reduce our reliance on existing jobs.third-party vendors.

 

Although we do not budget acquisitions in the normal course of business, we regularly engage in discussions related to potential acquisitions of companies which provide oilfield services.

 

Liquidity and Credit Facility. AsWe ended the first quarter of September 30, 2017, we have availability to borrow an incremental $1.22018 with a cash balance of approximately $1.0 million and debt of $6.6 million. Because the lender under our credit facility is Pelican, a related party and owner of over 65.0% of the Company on a fully diluted basis, we benefit from a credit facility which is structured with Pelicanno financial covenants and effective January 31, 2017 through the maturity date of December 31, 2019, principal payments based solely on free cash flow and we have significant flexibility to modify our credit facility, are based solely on excess free cash flows, significantly reducing our overall debt service requirements. For a discussion of the Recapitalizationif and the restructuring of our credit facility, see “Note 2 – Recent Developments” in the notes to our condensed consolidated financial statements included elsewhere in this document.when needed.

 

We have experienced significant growth during the beginning
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The table below reflects our liquidity as of 2017 and weMarch 31, 2018 (in thousands):

 

 

March 31, 2018

 

 

 

(unaudited)

 

Cash and restricted cash

 

$959

 

Revolving facility availability (1)

 

 

-

 

Delayed draw term loan availability (1) , (2)

 

 

75

 

Swing line availability (1) (3)

 

 

600

 

Total liquidity

 

$1,634

 

________________

(1) With Permian Pelican LLC, our controlling shareholder.

(2) Available to finance 90% of purchase price for capital expenditures.

(3) We are currently in discussions with Pelican to enter into a fifth amendment to the credit facility which will transfer the availability under both the delayed draw term loan and the swing line to the revolving facility simultaneous with the maturity of the swing line on June 30, 2018. (See further discussion in “Note 3 – Long-Term Debt – Related Party”) in the notes to our condensed consolidated financial statements.)

We believe that our cash flow from operations combined with access to capital through our lender and controlling shareholder, Pelican, will be sufficient to fund our working capital needs, contractual obligations and maintenance capital expendituresexpenditure plan for the next twelve months. Our existing capital expenditure plan focuses primarily on reducing sub-rental expense at existing activity levels. In order to achieve more substantial activity growth, we would likely require additional funding to invest in equipment, particularly tanks, which we are currently sub-renting and which are becoming increasingly difficult to obtain at a reasonable cost.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements, other than normal operating leases and employee contracts, that have or are likely to have a current or future material effect on our financial condition, changes in financial condition, revenue, expenses, results of operations, liquidity, capital expenditures, or capital resources.

 

Net Operating Losses

 

As of December 31, 2016,2017, we had approximately $29.5$31.5 million of federal net operating loss carryforwards. As a result of the Recapitalization, it is possible that the net operating losses may be subject to limitation under Internal Revenue Code Section 382. The Company is currently in the process of completing an analysis to determine the extent, if any, of any limitation under this section. Based on the weight of all available evidence including the future reversal of existing U.S. taxable temporary differences as of March 31, 2018 and December 31, 2017, we believe that it is more likely than not that the benefit from certain federal and state net operating loss carryforwards and other deductible temporary differences will not be realized. In recognition of this risk, we have provided a valuation allowance on the net deferred tax asset as a result of the Company being in a cumulative three-year pre-tax book loss position and the absence of other objectively verifiable positive evidence including reversal of existing taxable temporary differences in these certain state tax jurisdictions.

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Table of Contents

 

Item 3. Quantitative and Qualitative Disclosures About Market Risk

 

As a smaller reporting company, we are not required to provide the information required by this Item.

 

Item 4. Controls and Procedures

 

Evaluation of Disclosure Controls and Procedures

 

Our management, under supervision and with the participation of the Company’s Principal Executive Officer and Principal Financial Officer, evaluated the effectiveness of our disclosure controls and procedures, as defined under Exchange Act Rule 13a-15(e). Based upon this evaluation, the Principal Executive Officer and Principal Financial Officer concluded that, as of December 31, 2016, because2017, due to a combination of the material weaknessesdeficiencies in our internal controlcontrols over financial reporting (“ICFR”) described below,, a material weakness in ICFR existed and our disclosure controls and procedures were not effective.

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Table of Contents

  

Disclosure controls and procedures are controls and other procedures that are designed to ensure that required information to be disclosed in our reports filed or submitted under the Securities Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that required information to be disclosed in our reports filed under the Exchange Act is accumulated and communicated to our management, including our principal executive officerPrincipal Executive Officer and our principal financial officer,Principal Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

 

Management’s Report on Internal Control over Financial Reporting

 

Our management is responsible for establishing and maintaining adequate internal control over financial reporting,ICFR, as defined under Exchange Act Rules 13a-15(f) and 14d-14(f). Our internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.

All internal control systems, no matter how well designed, have inherent limitations and may not prevent or detect misstatements. Therefore, even those systems determined to be effective can only provide reasonable assurance with respect to financial reporting reliability and financial statement preparation and presentation. In addition, projections of any evaluation of effectiveness to future periods are subject to risk that controls become inadequate because of changes in conditions and that the degree of compliance with the policies or procedures may deteriorate.

 

Management assessedupdated the assessment of the effectiveness of our internal control over financial reportingICFR as of DecemberMarch 31, 2016.2018. In making the assessment, management used the criteria issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control-Integrated Framework 2013. Based on its assessment, management concluded that, as of December 31, 2016, our internal control over financial reporting was not effective and that material weaknesses in ICFR existed as more fully described below.

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Table of Contents

As defined by Auditing Standard No. 5, “An Audit of Internal Control Over Financial Reporting that is Integrated with an Audit of Financial Statements” established by the Public Company Accounting Oversight Board (“PCAOB”), a material weakness is a deficiency or combination of deficiencies that results in more than a remote likelihood that a material misstatement of annual or interim financial statements will not be prevented or detected. In connection with theBased on its assessment, described above, management identified the following control deficienciesconcluded that, represent material weaknesses as of DecemberMarch 31, 2016:2018, a combination of deficiencies in ICFR resulted in a material weakness.

 

1)Lack of an independent audit committee or audit committee financial expert. These factors may be counter to corporate governance practices as defined by the various stock exchanges and may lead to less supervision over management;

2)Insufficient written policies and procedures, and personnel, for accounting and financial reporting with respect to the requirements and application of US GAAP and SEC disclosure requirements, specifically to address technical accounting around complex transactions;

3)Control over information technology applications and the processing of transactions, specifically segregation of duties and elevated access privileges; and

4)Controls were not designed and in place to ensure that all disclosures required were originally addressed in our financial statements or other required reports filed or submitted under the Securities Exchange Act.

Management’s Remediation Initiatives

As of December 31, 2016, management assessed the effectiveness of our internal control over financial reporting. Based on thatour evaluation, it was concluded that during the period covered by this report, the internal controls and procedures were not effective due to deficiencies that existed in the design or operation of our internal controls over financial reporting. However, management believes these weaknessesthis weakness did not have an effect on our financial results. During the course of our evaluation,results and we did not discover any fraud involving management or any other personnel who play a significant role in our disclosure controls and procedures or internal controls over financial reporting. Management believes that the material weakness in ICFR was a direct result of our significant reduction in headcount in 2015 and 2016 in response to the downturn in the industry as well as the overall scale of our operations.

 

Due toIn connection with the assessment described above, management identified the following combination of control deficiencies that result in a lackmaterial weakness as of financial and personnel resources, weMarch 31, 2018. These deficiencies are not able to, and do not intend to, immediately take any action to remediate these material weaknesses. We will not be able to do so until, if ever, we acquire sufficient financing and staff to do so. in various stages of remediation as described below:

Material Weakness

Remediation Actions

Insufficient written policies and procedures, and personnel, for accounting and financial reporting with respect to the requirements and application of U.S. GAAP and SEC disclosure requirements, specifically to address technical accounting around complex transactions.

During the second quarter of 2017, we engaged an accounting consultant with expertise in U.S. GAAP to address technical accounting for complex transactions and financial reporting requirements and disclosures. Management is currently in the process of documenting these new reporting and disclosure controls that were implemented in 2017.

Lack of control over information technology applications and the processing of transactions, specifically segregation of duties and elevated access to our accounting information systems.

During 2018, management has hired additional personnel which will enable us to segregate duties more effectively and minimize elevated access privileges. In addition, management is in the process of seeking an experienced external resource to assess the information technology general control environment for purposes of remediation during 2018.

22
Table of Contents

We will implement further controls as circumstances, cash flows, and working capital permits. Notwithstanding the assessment that there was a material weakness in our ICFR was not effective and that there were material weaknesses asresulting from a combination of deficiencies identified in this report,above, we believe that our financial statements contained in our Quarterly Report on Form 10-Q for the period ended September 30, 2017,March 31, 2018 fairly presentspresent our financial position, results of operations, and cash flows for the periods covered as identified, in all material respects.

Management believes that the material weaknesses set forth above were the result of the scale of our operations and intrinsic to our small size.

 

Changes in Internal Control over Financial Reporting

 

During the beginning of 2017, controls were not designed and in place to ensure all disclosures required were originally addressed in our financial statements or other required reports filed or submitted under the Securities Exchange Act. We later implemented a review process with an accounting consultant with expertise in U.S. GAAP to ensure financial statements disclosures comply with the Securities Exchange Act and, simultaneous with the filing of our 10-Q for the period ended September 30, 2017, we returned to being a timely filer under SEC guidelines.

During the period covered by this report, therewe strengthened the governance of our board by identifying and bringing on a financial expert that now serves as our independent audit committee chair. See Item 10 in our Annual Report on Form 10-K for further background on James Hennessy.

There were no other changes (including corrective actions with regard to significant deficiencies or material weaknesses) in our internal controls over financial reportingICFR during the period, other than the changes implemented as detailed in our remediation plan above, that occurred that have materially affected, or are reasonably likely to materially affect, our ICFR.

This Quarterly Report does not include an attestation report of our independent registered public accounting firm regarding internal control over financial reporting.reporting due to an exemption provided by the Dodd-Frank Wall Street Reform and Consumer Protection Act (the “Dodd-Frank Act”) enacted into law in July 2010. The Dodd-Frank Act provides smaller public companies and debt-only issuers with a permanent exemption from the requirement to obtain an external audit on the effectiveness of internal financial reporting controls provided in Section 404(b) of the Sarbanes-Oxley Act. Aly Energy is a smaller reporting company and is eligible for this exemption under the Dodd-Frank Act.

 

 
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SIGNATURES

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 thereunto duly authorized.

ALY ENERGY SERVICES, INC.
Date November 14, 2017By:/s/ Shauvik Kundagrami

Shauvik Kundagrami

Vice-Chairman and Chief Executive Officer
(Principal Executive Officer)

3623
 
Table of Contents

  

PART II – OTHER INFORMATION

 

Item 6. Exhibits

 

Exhibit

Number

 

Exhibit Description

31.1

Certification of Chief Executive Officer

31.2

Certification of Chief Financial Officer

32.1

Certification of Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2

Certification of Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

  

101.INS **

XBRL Instance Document

101.SCH **

XBRL Taxonomy Extension Schema Document

101.CAL **

XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF **

XBRL Taxonomy Extension Definition Linkbase Document

101.LAB **

XBRL Taxonomy Extension Label Linkbase Document

101.PRE **

XBRL Taxonomy Extension Presentation Linkbase Document

_____________

** XBRL (Extensible Business Reporting Language) information is furnished and not filed or a part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, is deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise is not subject to liability under these sections.

 

24
Table of Contents

SIGNATURES

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 thereunto duly authorized.

 

ALY ENERGY SERVICES, INC.
Date: May 15, 2018By:/s/ Shauvik Kundagrami

37

Shauvik Kundagrami
Vice-Chairman and Chief Executive Officer
(Principal Executive Officer)

25