UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 _____________________________________________
Form 10-Q
 _____________________________________________ 
(Mark One)
ý
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Quarterly Period Ended June 30, 2020
or
¨

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Commission file number: 001-08038
  _____________________________________________
KEY ENERGY SERVICES, INC.
(Exact name of registrant as specified in its charter)
  _____________________________________________
Delaware
 
04-2648081
(State or other jurisdiction of
incorporation or organization)
 
(I.R.S. Employer
Identification No.)
 
 
1301 McKinney Street, Suite 1800, Houston, Texas
 
77010
(Address of principal executive offices)
 
(Zip Code)
(713) 651-4300
(Registrant’s telephone number, including area code)
None
(Former name, former address and former fiscal year, if changed since last report)
  ____________________________________________
Securities registered pursuant to Section 12(b) 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  ý    No  ¨  
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files).    Yes  ý    No  ¨   
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a 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
 
ý
  
Smaller reporting company
 
ý
 
 
 
 
 
 
 
 
 
 
 
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  ý
Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court. Yes ý No  ¨  
As of August 5, 2020, the number of outstanding shares of common stock of the registrant was 13,781,347.
 



KEY ENERGY SERVICES, INC.
QUARTERLY REPORT ON FORM 10-Q
For the Quarter Ended June 30, 2020
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS
This report contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Statements that are not historical in nature or that relate to future events and conditions are, or may be deemed to be, forward-looking statements. These forward-looking statements are based on our current expectations, estimates and projections and management’s beliefs and assumptions concerning future events and financial trends affecting our financial condition and results of operations. In some cases, you can identify these statements by terminology such as “may,” “will,” “should,” “predicts,” “expects,” “believes,” “anticipates,” “projects,” “potential” or “continue” or the negative of such terms and other comparable terminology. These statements are subject to substantial risks and uncertainties and are not guarantees of performance. Future actions, events and conditions and future results of operations may differ materially from those expressed in these statements. In evaluating those statements, you should carefully consider the information herein as well as the risks outlined in Part I, “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2019 (the “2019 Form 10-K”), and in Part II “Item 1A. Risk Factors” our Quarterly Report on Form 10-Q for the quarter ended March 31, 2020 (the “Q1 2020 Form 10-Q”) and our information in the reports we file with the Securities and Exchange Commission.
We undertake no obligation to update or withdraw any forward-looking statement to reflect events or circumstances after the date of this report except as required by law. All of our written and oral forward-looking statements are expressly qualified by these cautionary statements and any other cautionary statements that may accompany such forward-looking statements.
Important factors that may affect our expectations, estimates or projections include, but are not limited to, the following:
our ability to continue as a going concern;
public health crises, such as the COVID-19 pandemic, including its impact on economic and other conditions globally, demand for oil and natural gas, and any related actions taken by businesses and governments, among others;
adverse conditions in the services and oil and natural gas industries, especially declines or volatility in oil and natural gas prices and capital expenditures by oil and natural gas companies;
our ability to satisfy our cash and liquidity needs, including our ability to generate sufficient liquidity or cash flow from operations or to obtain adequate financing to fund our operations or otherwise meet our obligations as they come due;
our ability to retain employees, customers or suppliers as a result of our financial condition generally or as a result of our recent Restructuring (as defined below);
our inability to achieve the potential benefits of the Restructuring;

2


our ability to achieve the benefits of cost-cutting initiatives, including our plan to optimize our geographic footprint (including exiting certain locations and reducing our regional and corporate overhead costs);
our ability to implement price increases or maintain pricing on our core services;
risks that we may not be able to reduce, and could even experience increases in, the costs of labor, fuel, equipment and supplies employed in our businesses;
industry capacity;
actions by OPEC and non-OPEC oil producing countries;
asset impairments or other charges;
the low demand for our services and resulting operating losses and negative cash flows;
the highly competitive nature of our industry;
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, specifically those relating to hydraulic fracturing, as well as climate change legislation or initiatives;
our historically high employee turnover rate and our ability to replace or add workers, including executive officers and skilled workers;
our ability to implement technological developments and enhancements;
severe weather impacts on our business, including from hurricane activity;
our ability to successfully identify, make and integrate acquisitions and our ability to finance future growth of our operations or future acquisitions;
our ability to achieve the benefits expected from business combinations, disposition or acquisition transactions;
the loss of one or more of our larger customers;
the amount of our debt, the limitations imposed by the covenants in the agreements governing our debt, and our ability to comply with covenants under our debt agreements;
our ability to maintain sufficient liquidity and access to capital;
an increase in our debt service obligations due to variable rate indebtedness;
our inability to achieve our financial, capital expenditure and operational projections, including quarterly and annual projections of revenue, and/or operating income and the possibility of our inaccurate assessment of future activity levels, customer demand, and pricing stability which may not materialize (whether for Key as a whole or for geographic regions and/or business segments individually);
our ability to respond to changing or declining market conditions;
adverse impact of litigation or disputes; and
other factors affecting our business and financial condition described under “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2019 and in our Quarterly Report on Form 10-Q for the quarter ended March 31, 2020.
As noted in our financial statements in this Quarterly Report on Form 10-Q for the quarter ended June 30, 2020, pursuant to accounting principles generally accepted in the United States, these conditions raise substantial doubt about our ability to continue as a going concern within the 12 months post issuance of the consolidated financial statements. The unprecedented nature of the COVID-19 pandemic and recent market decline may make it more difficult to identify potential risks, give rise to risks that are currently unknown, or amplify the impact of known risks.

3


PART I — FINANCIAL INFORMATION
ITEM 1.
FINANCIAL STATEMENTS
Key Energy Services, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets
(in thousands, except share amounts)
 
June 30,
2020
 
December 31,
2019
 
(unaudited)
 
 
ASSETS
 
 
 
Current assets:
 
 
 
Cash and cash equivalents
$
6,864

 
$
14,426

Restricted cash
250

 
250

Accounts receivable, net of allowance for doubtful accounts of $1,085 and $881, respectively
20,069

 
51,091

Inventories
13,698

 
13,565

Other current assets
17,774

 
22,260

Total current assets
58,655

 
101,592

Property and equipment
388,229

 
432,917

Accumulated depreciation
(218,409
)
 
(205,352
)
Property and equipment, net
169,820

 
227,565

Intangible assets, net
318

 
347

Other non-current assets
40,400

 
18,366

TOTAL ASSETS
$
269,193

 
$
347,870

LIABILITIES AND EQUITY

 

Current liabilities:

 

Accounts payable
$
8,641

 
$
8,700

Current portion of long-term debt
1,076

 
2,919

Other current liabilities
51,607

 
90,715

Total current liabilities
61,324

 
102,334

Long-term debt
51,954

 
240,007

Workers’ compensation, vehicular and health insurance liabilities
27,394

 
26,072

Interest payable
16,283

 

Other non-current liabilities
31,094

 
30,710

Commitments and contingencies

 

Equity:

 

Common stock, $0.01 par value; 150,000,000 and 2,000,000 shares authorized, 13,781,262 and 410,990 outstanding
340

 
206

Additional paid-in capital
307,982

 
265,588

Retained deficit
(227,178
)
 
(317,047
)
Total equity
81,144

 
(51,253
)
TOTAL LIABILITIES AND EQUITY
$
269,193

 
$
347,870

See the accompanying notes which are an integral part of these condensed consolidated financial statements.

4


Key Energy Services, Inc. and Subsidiaries
Condensed Consolidated Statements of Operations
(in thousands, except per share data)
(unaudited)
 
 
 
 
 
 
 
 
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
 
2020
 
2019
 
2020
 
2019
REVENUES
$
34,750

 
$
112,943

 
$
110,058

 
$
222,216

COSTS AND EXPENSES:
 
 
 
 
 
 
 
Direct operating expenses
29,904

 
90,564

 
91,565

 
178,758

Depreciation and amortization expense
8,054

 
14,262

 
18,280

 
28,558

General and administrative expenses
13,637

 
22,544

 
28,890

 
44,639

Impairment expense

 

 
41,242

 

Operating loss
(16,845
)
 
(14,427
)
 
(69,919
)
 
(29,739
)
Gain on debt restructuring

 

 
(170,648
)
 

Interest expense, net of amounts capitalized
2,066

 
8,520

 
10,287

 
17,753

Other income, net
(15
)
 
(239
)
 
(400
)
 
(1,381
)
Income (loss) before income taxes
(18,896
)
 
(22,708
)
 
90,842

 
(46,111
)
Income tax benefit (expense)
(229
)
 
4,405

 
(973
)
 
4,367

NET INCOME (LOSS)
$
(19,125
)
 
$
(18,303
)
 
$
89,869

 
$
(41,744
)
Loss per share:
 
 
 
 
 
 
 
Basic
$
(1.39
)
 
$
(44.86
)
 
$
10.06

 
$
(102.31
)
Diluted
$
(1.39
)
 
$
(44.86
)
 
$
10.00

 
$
(102.31
)
Weighted average shares outstanding:
 
 
 
 
 
 
 
Basic
13,781

 
408

 
8,935

 
408

Diluted
13,781

 
408

 
8,991

 
408

See the accompanying notes which are an integral part of these condensed consolidated financial statements.

5


Key Energy Services, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows
(in thousands)
(unaudited)
 
 
 
 
 
Six Months Ended
 
June 30,
 
2020
 
2019
CASH FLOWS FROM OPERATING ACTIVITIES:
 
 
 
Net income (loss)
$
89,869

 
$
(41,744
)
Adjustments to reconcile net income (loss) to net cash used in operating activities:

 

Depreciation and amortization expense
18,280

 
28,558

Impairment expense
41,242

 

Bad debt expense
1,175

 
261

Accretion of asset retirement obligations
85

 
82

Gain on debt restructuring
(170,648
)
 

Amortization of deferred financing costs
260

 
241

Gain on disposal of assets, net
(767
)
 
(1,459
)
Share-based compensation
252

 
2,230

Changes in working capital:

 

Accounts receivable
29,847

 
2,422

Other current assets
4,353

 
(1,741
)
Accounts payable, accrued interest and accrued expenses
(38,526
)
 
(4,647
)
Share-based compensation liability awards
3

 
34

Other assets and liabilities
(13,636
)
 
4,400

Net cash used in operating activities
(38,211
)
 
(11,363
)
CASH FLOWS FROM INVESTING ACTIVITIES:

 

Capital expenditures
(979
)
 
(12,362
)
Proceeds from sale of assets
3,363

 
4,780

Net cash provided by (used in) investing activities
2,384

 
(7,582
)
CASH FLOWS FROM FINANCING ACTIVITIES:
 
 
 
Proceeds from long-term debt
30,000

 

Repayments of long-term debt
(3
)
 
(1,250
)
Repayments of finance lease obligations
(340
)
 

Payment of deferred financing costs
(1,385
)
 
(828
)
Repurchases of common stock
(7
)
 
(4
)
Net cash provided by (used in) financing activities
28,265

 
(2,082
)
Net decrease in cash, cash equivalents and restricted cash
(7,562
)
 
(21,027
)
Cash, cash equivalents, and restricted cash, beginning of period
14,676

 
50,311

Cash, cash equivalents, and restricted cash, end of period
$
7,114

 
$
29,284

See the accompanying notes which are an integral part of these condensed consolidated financial statements.

6


Key Energy Services, Inc. and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS
NOTE 1. GENERAL
Key Energy Services, Inc., and its wholly owned subsidiaries (collectively, “Key,” the “Company,” “we,” “us,” “its,” and “our”) provide a full range of well services to major oil companies and independent oil and natural gas production companies. Our services include rig-based and coiled tubing-based well maintenance and workover services, well completion and recompletion services, fluid management services, fishing and rental services, and other ancillary oilfield services. Additionally, certain of our rigs are capable of specialty drilling applications. We operate in most major oil and natural gas producing regions of the continental United States. An important component of our growth strategy is to make acquisitions that will strengthen our core services or presence in selected markets, and that we also make strategic divestitures from time to time. We expect that the industry in which we operate will experience consolidation, and the we expect to explore opportunities and engage in discussions regarding these opportunities, which could include mergers, consolidations or acquisitions or further dispositions or other transactions, although there can be no assurance that any such activities will be consummated.
The accompanying unaudited condensed consolidated financial statements were prepared using generally accepted accounting principles in the United States of America (“GAAP”) for interim financial information and in accordance with the rules and regulations of the Securities and Exchange Commission (the “SEC”). The condensed December 31, 2019 balance sheet was prepared from audited financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2019 (the “2019 Form 10-K”). Certain information relating to our organization and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted in this Quarterly Report on Form 10-Q. These unaudited condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our 2019 Form 10-K.
The unaudited condensed consolidated financial statements contained in this report include all normal and recurring material adjustments that, in the opinion of management, are necessary for a fair presentation of our financial position, results of operations and cash flows for the interim periods presented herein. The results of operations for the six months ended June 30, 2020 are not necessarily indicative of the results expected for the full year or any other interim period, due to fluctuations in demand for our services, timing of maintenance and other expenditures, and other factors.
We have evaluated events occurring after the balance sheet date included in this Quarterly Report on Form 10-Q through the date on which the unaudited condensed consolidated financial statements were issued, for possible disclosure of a subsequent event.
Market Conditions, COVID-19 and Going Concern
As a company that provides services to oil and gas exploration and development companies, we are exposed to a number of risks and uncertainties that are inherent to our industry. In addition to such industry-specific risks, the global public health crisis associated with the novel coronavirus (“COVID-19”) has, and is anticipated to continue to have, an adverse effect on global economic activity for the immediate future and has resulted in travel restrictions, business closures and the institution of quarantining and other restrictions on movement in many communities. The slowdown in global economic activity attributable to COVID-19 has resulted in a dramatic decline in the demand for energy, which directly impacts our industry and the Company. In addition, global crude oil prices experienced a decline in late 2019 and a collapse starting in early March 2020 as a direct result of failed negotiations between the Organization of the Petroleum Exporting Countries (“OPEC”) and Russia regarding reduced supply of oil. As the breadth of the COVID-19 health crisis expanded throughout the month of March 2020 and governmental authorities implemented more restrictive measures to limit person-to-person contact, global economic activity continued to decline commensurately. The associated impact on the energy industry has been adverse and continued to be exacerbated by the unresolved conflict regarding production. In the second week of April, OPEC, Russia and certain other petroleum producing nations (“OPEC+”) reconvened to discuss the matter of production cuts in light of unprecedented disruption and supply and demand imbalances that expanded since the failed negotiations in early March 2020. Agreements were reached to cut production by up to 10 million barrels of oil per day with allocations to be made among the OPEC+ participants. In early June, these agreements were further extended through July 2020. These production cuts, other voluntary production curtailments and reduced drilling have helped to bring demand and supply closer to balance and stabilized commodity prices. However, US and international crude oil stocks remain at historically high levels, commodity prices remain depressed relative to 2019 levels, and there remains continued uncertainty around the timing of any recovery in economic activity and demand for energy.

7


Despite a significant decline in drilling by U.S. producers starting in mid-March 2020, domestic supply continued to exceed demand through May 2020, which led to significant operational stress with respect to capacity limitations associated with storage, pipeline and refining infrastructure, particularly within the Gulf Coast region. While these trends began to reverse in June 2020 due to production curtailments, natural well decline and reduced drilling activity, there remains a historically high amount of crude oil in storage. The combined effect of the aforementioned factors has had an adverse impact on the industry in general and our operations specifically.
These conditions and events have adversely affected the demand for oil and natural gas, as well as for our services. The collapse in the demand for oil caused by this unprecedented global health and economic crisis, coupled with oil oversupply, has had, and is reasonably likely to continue to have, a material adverse impact on the demand for our services and the prices we can charge for our services. The decline in our customers’ demand for our services has had, and is likely to continue to have, a material adverse impact on our financial condition, results of operations and cash flows.
To date, we have enhanced the cost control measures related to operational and general and administrative expenses to optimize cost during this time period with the goal of ensuring that margins are preserved as well as increased efforts on improving working capital until customer spend increases.
Due to the uncertainty of future oil and natural gas prices and the effect the COVID-19 pandemic will continue to have on our results of operations and financial condition, there is substantial doubt as to the Company’s ability to continue as a going concern. Management has prepared these consolidated condensed financial statements in accordance with US GAAP applicable to a going concern, which contemplates that assets will be realized and liabilities will be discharged in the normal course of business as they become due. These consolidated condensed financial statements do not reflect the adjustments to the carrying values of assets and liabilities and the reported revenues and expenses and balance sheet classifications that would be necessary if the Company were unable to realize its assets and settle its liabilities as a going concern in the normal course of operations. Such adjustments could be material and adverse to the financial results of the Company.
Restructuring and Reverse Stock Split
On March 6, 2020, we closed the previously announced restructuring of our capital structure and indebtedness (the “Restructuring”) pursuant to the Restructuring Support Agreement, dated as of January 24, 2020 (the “RSA”), with lenders under our Prior Term Loan Facility (as defined below) collectively holding over 99.5% (the “Supporting Term Lenders”) of the principal amount of the Company’s then outstanding term loans. Pursuant to the RSA and the Restructuring contemplated thereby, among other things, we effected the following transactions and changes to our capital structure and governance:
pursuant to exchange agreements entered into at the closing of the Restructuring, we exchanged approximately $241.9 million aggregate outstanding principal of our term loans (together with accrued interest thereon) held by Supporting Term Lenders under our Prior Term Loan Facility into (i) approximately 13.4 million newly issued shares of common stock representing 97% of the Company’s outstanding shares after giving effect to such issuance (and without giving effect to dilution by the New Warrants and MIP (each as defined below)) and (ii) $20 million of term loans under our new $51.2 million term loan facility (the “New Term Loan Facility”), each on a pro rata basis based on their holdings of term loans under the Prior Term Loan Facility;
completed a 1-for-50 reverse stock split of our outstanding common stock. All pre-Restructuring shares prices, including shares outstanding and earnings per share, have been adjusted to reflect the 1-for-50 reverse stock split;
distributed to our common stockholders of record as of February 18, 2020 two series of warrants (the “New Warrants”);
entered into the $51.2 million New Term Loan Facility, of which (i) $30 million was funded at closing of the Restructuring with new cash proceeds from the Supporting Term Lenders and $20 million was issued in exchange for term loans held by the Supporting Term Lenders under the Prior Term Loan Facility as described above and (ii) an approximate $1.2 million was a senior secured term loan tranche in respect of term loans held by lenders under the Prior Term Loan Facility who were not Supporting Term Lenders;
entered into the New ABL Facility (as defined below);
adopted a new management incentive plan (the “MIP”) representing up to 9% of the Company’s outstanding shares after giving effect to the issuance of shares described above; and
made certain changes to the Company’s governance, including changes to our Board of Directors (the “Board”), amendments to our governing documents and entry into the Stockholders Agreement (as defined below) with the Supporting Term Lenders.
In accordance with the RSA at the closing of the Restructuring, the Company amended and restated its certificate of incorporation and entered into a stockholders agreement (the “Stockholders Agreement”) with the Supporting Term Lenders in order to, among other things, provide for a Board of seven members. Pursuant to the Stockholders Agreement, our Board consists

8


of our chief executive officer and six other members appointed by various Supporting Term Lenders. Specifically, pursuant to the Stockholders Agreement, Supporting Term Lenders who hold more than 25% of the Company’s outstanding shares as of the closing of the Restructuring are entitled to nominate two directors and Supporting Term Lenders who hold between 10% and 25% of the Company’s outstanding shares as of the closing of the Restructuring are entitled to nominate one director. All appointees or nominees of Supporting Term Lenders, other than any director appointed or nominated by Soter Capital LLC (“Soter”), must meet the “independent director” requirements set forth in Section 303A of the NYSE Listed Company Manual. In addition, pursuant to the Stockholders Agreement, Supporting Term Lenders are entitled to appoint a non-voting board observer subject to specified ownership thresholds.
In accordance with the RSA and following the closing of the Restructuring, the Company distributed to stockholders of record as of February 18, 2020 the New Warrants. The New Warrants were issued in two series each with a four-year exercise period. The first series entitles the holders to purchase in the aggregate 1,669,730 newly issued shares of common stock, representing 10% of the Company’s common shares at the closing of the Restructuring on an as-exercised basis (after giving effect to the exercise of all New Warrants, but subject to dilution by issuances under the MIP). The aggregate exercise price of the first series of New Warrants is $19.23 and was determined based on the aggregate outstanding principal amount of term loans under the Prior Term Loan Facility plus accrued interest thereon at the default rate as of the closing of the Restructuring. The second series of New Warrants entitles the holders to purchase in the aggregate 1,252,297 newly issued shares of common stock, representing 7.5% of the Company’s common shares at the closing of the Restructuring on an as-exercised basis (after giving effect to the exercise of all New Warrants, but subject to dilution by issuances under the MIP). The aggregate strike price of the second series of New Warrants is $28.85 and was determined based on the product of (i) the aggregate outstanding principal amount of term loans under the Prior Term Loan Facility plus accrued interest thereon at the default rate as of the closing of the Restructuring, multiplied by (ii) 1.50.
For more information on our New Term Loan Facility and New ABL Facility entered into in connection with the Restructuring, see “Note 7. Debt.”
NOTE 2. SIGNIFICANT ACCOUNTING POLICIES AND ESTIMATES
The preparation of these unaudited condensed consolidated financial statements requires us to develop estimates and to make assumptions that affect our financial position, results of operations and cash flows. These estimates may also impact the nature and extent of our disclosure, if any, of our contingent liabilities. Among other things, we use estimates to (i) analyze assets for possible impairment, (ii) determine depreciable lives for our assets, (iii) assess future tax exposure and realization of deferred tax assets, (iv) determine amounts to accrue for contingencies, (v) value tangible and intangible assets, (vi) assess workers’ compensation, vehicular liability, self-insured risk accruals and other insurance reserves, (vii) provide allowances for our uncollectible accounts receivable, (viii) value our asset retirement obligations, and (ix) value our equity-based compensation. We review all significant estimates on a recurring basis and record the effect of any necessary adjustments prior to publication of our financial statements. Adjustments made with respect to the use of estimates relate to improved information not previously available. Because of the limitations inherent in this process, our actual results may differ materially from these estimates. We believe that the estimates used in the preparation of these interim financial statements are reasonable.
There have been no material changes or developments in our evaluation of accounting estimates and underlying assumptions or methodologies that we believe to be a “Critical Accounting Policy or Estimate” as disclosed in our 2019 Form 10-K.
Recent Accounting Developments
ASU 2016-13. In June 2016, the Financial Accounting Standards Board issued Accounting Standards Update (“ASU”) 2016-13, Financial Instruments—Credit Losses (Topic 326), Measurement of Credit Losses on Financial Instruments that will change how companies measure credit losses for most financial assets and certain other instruments that are not measured at fair value through net income. The standard will replace today’s “incurred loss” approach with an “expected loss” model for instruments measured at amortized cost. For available-for-sale debt securities, entities will be required to record allowances rather than reduce the carrying amount. The amendments in this update were effective for annual periods beginning after December 15, 2019 and interim periods within those annual periods. We adopted the new standard effective January 1, 2020 and the adoption of this standard did not have a material impact on our consolidated financial statements.
ASU 2019-12. In December 2019, the Financial Accounting Standards Board issued ASU 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes that will simplify accounting for income taxes by eliminating certain exceptions to the guidance for intra-period tax allocation, the methodology for calculating income taxes in an interim period and the recognition of deferred tax liabilities for outside basis differences. It also simplifies aspects of the accounting for franchise taxes that are partially based on income and enacted changes in tax laws or rates and clarifies the accounting for transactions that result in a step-up in the tax basis of goodwill. We adopted the new standard effective April 1, 2020. Most of the changes were not applicable to Key and there was no significant impact to the Company’s financial statements upon adoption of this standard.

9


Coronavirus Aid, Relief and Economic Security Act (“CARES Act”)
On March 27, 2020, the Coronavirus Aid, Relief, and Economic Security Act (“CARES Act”) was enacted in response to the COVID-19 pandemic. It is a large tax-and-spending package intended to provide additional economic relief to address the impact of the COVID-19 pandemic. The CARES Act includes several significant business tax provisions that, among other things, eliminate the taxable income limit for certain net operating losses (NOL) and allow businesses to carry back NOLs arising in 2018, 2019, and 2020 to the five prior tax years; accelerate refunds of previously generated corporate alternative minimum tax (AMT) credits; and generally increased the business interest limitation under section 163(j) from 30 percent to 50 percent. Key has analyzed the income tax provisions under the CARES Act, and concluded that none of the provisions have a significant impact to the Company's income tax positions. Future regulatory guidance under the CARES Act or additional legislation enacted by Congress in connection with the COVID-19 pandemic could impact our tax provision in future periods. In addition to income tax provisions, the CARES Act also includes tax provisions relating to refundable payroll tax credits and deferment of employer’s social security tax payments. Specifically, the CARES Act permits an employer to defer 50 percent of its 2020 social security tax payments to the end of 2021 and the remaining 50 percent to the end of 2022. Beginning in April of 2020, we began deferring our employer social security payments. The Company continues to evaluate the impact of the CARES Act on our financial position, results of operations and cash flows.
NOTE 3. REVENUE FROM CONTRACTS WITH CUSTOMERS
Revenues are recognized when control of the promised goods or services is transferred to our customers, in an amount that reflects the consideration we expect to be entitled to in exchange for those goods or services. The following table presents our revenues disaggregated by revenue source (in thousands). Sales taxes are excluded from revenues.
 
 
Six Months Ended
 
 
June 30,
 
 
2020
 
2019
Rig Services
 
$
68,734

 
$
132,910

Fishing and Rental Services
 
13,563

 
29,399

Coiled Tubing Services
 
6,704

 
22,420

Fluid Management Services
 
21,057

 
37,487

Total
 
$
110,058

 
$
222,216

Disaggregation of Revenue
We have disaggregated our revenues by our reportable segments which include Rig Services, Fishing & Rental Services, Coiled Tubing Services and Fluid Management Services segments.
Rig Services
Our Rig Services segment include the completion of newly drilled wells, workover and recompletion of existing oil and natural gas wells, well maintenance, and the plugging and abandonment of wells at the end of their useful lives. We also provide specialty drilling services to oil and natural gas producers with certain of our larger rigs that are capable of providing conventional and horizontal drilling services. Our rigs encompass various sizes and capabilities, allowing us to service all types of oil and gas wells.
We recognize revenue within the Rig Services segment by measuring progress toward satisfying the performance obligation in a manner that best depicts the transfer of goods or services to the customer. The control over services is transferred as the services are rendered to the customer. Specifically, we recognize revenue as the services are provided, typically daily, as we have the right to invoice the customer for the services performed. Rig Services are billed monthly, and payment terms are usually 30 days from invoice receipt.
Fishing and Rental Services
We offer a full line of services and rental equipment designed for use in providing drilling and workover services. Fishing services involve recovering lost or stuck equipment in the wellbore utilizing a broad array of “fishing tools.” Our rental tool inventory consists of drill pipe, tubulars, handling tools (including our patented Hydra-Walk® pipe-handling units and services), pressure-control equipment, pumps, power swivels, reversing units, foam air units.
We recognize revenue within the Fishing and Rental Services segment by measuring progress toward satisfying the performance obligation in a manner that best depicts the transfer of goods or services to the customer. The control over services is transferred as the services are rendered to the customer. Specifically, we recognize revenue as the services are provided, typically

10


daily, as we have the right to invoice the customer for the services performed. Fishing and Rental Services are billed and paid monthly. Payment terms for Fishing and Rental Services are usually 30 days from invoice receipt.
Coiled Tubing Services
Coiled Tubing Services involve the use of a continuous metal pipe spooled onto a large reel, which is then deployed into oil and natural gas wells to perform various applications, such as wellbore clean-outs, nitrogen jet lifts, through-tubing fishing, and formation stimulations utilizing acid and chemical treatments. Coiled tubing is also used for a number of horizontal well applications such as milling temporary isolation plugs that separate frac zones, and various other pre- and post-hydraulic fracturing well preparation services.
We recognize revenue within the Coiled Tubing Services segment by measuring progress toward satisfying the performance obligation in a manner that best depicts the transfer of goods or services to the customer. The control over services is transferred as the services are rendered to the customer. Specifically, we recognize revenue, typically daily, as the services are provided as we have the right to invoice the customer for the services performed. Coiled Tubing Services are billed and paid monthly. Payment terms for Coiled Tubing Services are usually 30 days from invoice receipt.
Fluid Management Services
We provide transportation and well-site storage services for various fluids utilized in connection with drilling, completions, workover and maintenance activities. We also provide disposal services for fluids produced subsequent to well completion. These fluids are removed from the well site and transported for disposal in saltwater disposal wells owned by us or a third party.
We recognize revenue within the Fluid Management Services segment by measuring progress toward satisfying the performance obligation in a manner that best depicts the transfer of goods or services to the customer. The control over services is transferred as the services are rendered to the customer. Specifically, we recognize revenue as the services are provided, typically daily, as we have the right to invoice the customer for the services performed. Fluid Management Services are billed and paid monthly. Payment terms for Fluid Management Services are usually 30 days from invoice receipt.
Arrangements with Multiple Performance Obligations
While not typical for our business, our contracts with customers may include multiple performance obligations. For such arrangements, we allocate revenues to each performance obligation based on its relative standalone selling price. We generally determine standalone selling prices based on the prices charged to customers or using expected cost-plus margin. For combined products and services within a contract, we account for individual products and services separately if they are distinct –- i.e., if a product or service is separately identifiable from other items in the contract and if a customer can benefit from it on its own or with other resources that are readily available to the customer. The consideration (including any discounts) is allocated between separate products and services within a contract based on the prices at which we separately sell our services. For items that are not sold separately, we estimate the standalone selling prices using the expected cost-plus margin approach.
Contract Balances
Under our revenue contracts, we invoice customers once our performance obligations have been satisfied, at which point payment is unconditional. Accordingly, our revenue contracts do not give rise to contract assets or liabilities under ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASC 606”).
Practical Expedients and Exemptions
We generally expense sales commissions when incurred because the amortization period would have been one year or less. These costs are recorded within general and administrative expenses.
The majority of our services are short-term in nature, with a contract term of one year or less. For those contracts, we have utilized the practical expedient in ASC 606-10-50-14 exempting the Company from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less.
Additionally, our payment terms are short-term in nature with settlements of one year or less. We have, therefore, utilized the practical expedient in ASC 606-10-32-18 exempting the Company from adjusting the promised amount of consideration for the effects of a significant financing component given that the period between when the entity transfers a promised good or service to a customer and when the customer pays for that good or service will be one year or less.

Further, in many of our service contracts we have a right to consideration from a customer in an amount that corresponds directly with the value to the customer of the entity’s performance completed to date (for example, a service contract in which an

11


entity bills a fixed amount for each hour of service provided). For those contracts, we have utilized the practical expedient in ASC 606-10-55-18 exempting the Company from disclosure of the recognition of revenue in the amount that the Company has a right to invoice.
Accordingly, we do not disclose the value of unsatisfied performance obligations for (i) contracts with an original expected length of one year or less and (ii) contracts for which we recognize revenue at the amount to which we have the right to invoice for services performed.
NOTE 4. EQUITY
A reconciliation of the total carrying amount of our equity accounts for the six months ended June 30, 2020 is as follows (in thousands):
 
COMMON STOCKHOLDERS
 
 
 
Common Stock
 
Additional Paid-in Capital
 
Retained Deficit
 
Total
 
Number of Shares
 
Amount at Par
 
 
Balance at December 31, 2019
411

 
$
206

 
$
265,588

 
$
(317,047
)
 
$
(51,253
)
Common stock purchases
(1
)
 
(1
)
 
(7
)
 

 
(8
)
Share-based compensation
3

 
2

 
(75
)
 

 
(73
)
Issuance of shares pursuant to the Restructuring Support Agreement
13,368

 
133

 
41,855

 

 
41,988

Issuance of warrants pursuant to the Restructuring Support Agreement

 

 
296

 

 
296

Net income

 

 

 
108,994

 
108,994

Balance at March 31, 2020
13,781

 
340

 
$
307,657

 
(208,053
)
 
99,944

Share-based compensation

 

 
325

 

 
325

Net loss

 

 

 
(19,125
)
 
(19,125
)
Balance at June 30, 2020
13,781

 
$
340

 
$
307,982

 
$
(227,178
)
 
$
81,144

A reconciliation of the total carrying amount of our equity accounts for the six months ended June 30, 2019 is as follows (in thousands):
 
COMMON STOCKHOLDERS
 
 
 
Common Stock
 
Additional Paid-in Capital
 
Retained Deficit
 
Total
 
Number of Shares
 
Amount at Par
 
 
 
Balance at December 31, 2018
407

 
$
204

 
$
264,945

 
$
(219,629
)
 
$
45,520

Share-based compensation

 

 
816

 

 
816

Net loss

 

 

 
(23,441
)
 
(23,441
)
Balance at March 31, 2019
407

 
204

 
265,761

 
(243,070
)
 
22,895

Common stock purchases

 

 
(4
)
 

 
(4
)
Share-based compensation
1

 

 
1,414

 

 
1,414

Net loss

 

 

 
(18,303
)
 
(18,303
)
Balance at June 30, 2019
408

 
$
204

 
$
267,171

 
$
(261,373
)
 
$
6,002


12


NOTE 5. OTHER BALANCE SHEET INFORMATION
The table below presents comparative detailed information about other current assets at June 30, 2020 and December 31, 2019 (in thousands):
 
 
 
 
 
June 30, 2020
 
December 31, 2019
Other current assets:
 
 
 
Prepaid current assets
$
7,545

 
$
13,118

Reinsurance receivable
6,636

 
6,475

Operating lease right-of-use assets
3,593

 
2,394

Other

 
273

Total
$
17,774

 
$
22,260

The table below presents comparative detailed information about other non-current assets at June 30, 2020 and December 31, 2019 (in thousands):
 
 
 
 
 
June 30, 2020
 
December 31, 2019
Other non-current assets:
 
 
 
 Reinsurance receivable
$
7,054

 
$
6,887

 Deposits
32,612

 
8,689

 Operating lease right-of-use assets
439

 
2,404

 Other
295

 
386

Total
$
40,400

 
$
18,366

The table below presents comparative detailed information about other current liabilities at June 30, 2020 and December 31, 2019 (in thousands):
 
 
 
 
 
June 30, 2020
 
December 31, 2019
Other current liabilities:
 
 
 
Accrued payroll, taxes and employee benefits
$
8,504

 
$
14,463

Accrued operating expenditures
7,111

 
12,919

Income, sales, use and other taxes
2,869

 
5,115

Self-insurance reserve
24,543

 
25,366

Accrued interest
2,204

 
15,476

Accrued insurance premiums
1,721

 
4,990

Unsettled legal claims
2,013

 
7,020

Accrued severance

 
2,636

Operating leases
2,599

 
2,502

Other
43

 
228

Total
$
51,607

 
$
90,715


13


The table below presents comparative detailed information about other non-current liabilities at June 30, 2020 and December 31, 2019 (in thousands):
 
 
 
 
 
June 30, 2020
 
December 31, 2019
Other non-current liabilities:
 
 
 
Asset retirement obligations
$
8,803

 
$
9,035

Environmental liabilities
1,851

 
2,047

Accrued sales, use and other taxes
17,005

 
17,005

Deferred tax liabilities
484

 

Operating leases
1,783

 
2,590

Federal insurance contributions act tax
1,137

 

Other
31

 
33

Total
$
31,094

 
$
30,710

NOTE 6. INTANGIBLE ASSETS
The components of our other intangible assets as of June 30, 2020 and December 31, 2019 are as follows (in thousands):
 
 
 
 
 
June 30, 2020
 
December 31, 2019
Trademark:
 
 
 
Gross carrying value
$
520

 
$
520

Accumulated amortization
(202
)
 
(173
)
Net carrying value
$
318

 
$
347

The weighted average remaining amortization periods and expected amortization expense for the next five years for our definite lived intangible assets are as follows:
 
Weighted
average remaining
amortization
period (years)
 
Expected amortization expense (in thousands)
 
Remainder
of 2020
 
2021
 
2022
 
2023
 
2024
Trademarks
5.5
 
$
29

 
$
58

 
$
58

 
$
58

 
$
58

Amortization expense for our intangible assets was less than $0.1 million for the three and six months ended June 30, 2020 and 2019.
NOTE 7. DEBT
As of June 30, 2020 and December 31, 2019, the components of our debt were as follows (in thousands):
 
 
 
 
 
June 30, 2020
 
December 31, 2019
Term Loan Facility due 2025
$
50,000

 
$

Term Loan Facility due 2021
1,207

 
243,125

Unamortized debt issuance costs
(2,923
)
 
(1,799
)
Finance lease obligation
4,746

 
1,600

Total
53,030

 
242,926

Less current portion(1)
(1,076
)
 
(2,919
)
Long-term debt
$
51,954

 
$
240,007

(1)
Of the current portion of debt, $1.1 million and $0.4 million is related to finance leases as of June 30, 2020 and December 31, 2019, respectively.

14


Prior Long-Term Debt Arrangements
Prior to the Restructuring, the Company was party to two credit facilities. The Company and Key Energy Services, LLC, were borrowers (the “ABL Borrowers”) under an ABL Facility with the financial institutions party thereto from time to time as lenders (the “ABL Lenders”), Bank of America, N.A., as administrative agent for the lenders (the “Administrative Agent”) and Bank of America, N.A., as sole collateral agent for the lenders, providing for aggregate commitments from the ABL Lenders of $80 million (the “Prior ABL Facility”). In addition, on December 15, 2016, the Company entered into the term loan facility among the Company, as borrower, certain subsidiaries of the Company named as guarantors therein, the financial institutions party thereto from time to time as Lenders (collectively, the “Term Loan Lenders”) and Cortland Capital Market Services LLC and Cortland Products Corp., as agent for the Lenders (the “Prior Term Loan Facility”).
As previously announced, on October 29, 2019, the Company entered into a forbearance agreement (as amended on December 6, 2019, December 20, 2019, January 10, 2020 and January 31, 2020, the “ABL Forbearance Agreement”) with Bank of America, N.A., as administrative agent (the “Administrative Agent”), and all of the lenders party thereto (the “Lenders”) regarding a cross-default under the Loan and Security Agreement, dated as of December 15, 2016, by and among Key, the Administrative Agent and the Lenders.
On February 28, 2020, the Company and the Lenders party thereto amended the ABL Forbearance Agreement (the “Forbearance Agreement Amendment”). Pursuant to the Forbearance Agreement Amendment, the Lenders party thereto agreed, among other things, to extend the forbearance period until the earliest of (i) March 6, 2020, (ii) the occurrence of certain specified early termination events and (iii) the date on which the previously announced RSA between the Company and certain lenders under the Company’s term loan facility is terminated in accordance with its terms. In connection with the ABL Forbearance Agreement, the Company elected not to make scheduled interest payments due October 18, 2019 and January 20, 2020 under the Prior Term Loan Facility. The Company’s failure to make these interest payments resulted in a default under the Prior Term Loan Facility and a cross-default under the Prior ABL Facility.
Effective March 6, 2020, upon the closing of the Restructuring, we entered into the New Term Loan Facility and the New ABL Facility, which superseded the Prior Term Loan Facility and Prior ABL Facility. A description of each of the new and prior facilities follows.
New ABL Facility
On March 6, 2020, the Company and Key Energy Services, LLC, as borrowers (the “ABL Borrowers”), entered into Amendment No. 3 to the Company’s existing ABL facility, dated as of December 15, 2016 (as amended, the “New ABL Facility”) with the financial institutions party thereto from time to time as lenders (the “ABL Lenders”) and Bank of America, N.A., as administrative agent and collateral agent (the “ABL Agent”) for the ABL Lenders. The New ABL Facility provides for aggregate commitments from the ABL Lenders of $70 million, which mature on the earlier of (x) April 5, 2024 and (y) 181 days prior to the scheduled maturity date of the Company’s term loan facility or the scheduled maturity date of the Company’s other material debt in an aggregate principal amount exceeding $15 million.
The New ABL Facility provides the ABL Borrowers with the ability to borrow up to an aggregate principal amount equal to the lesser of (i) the aggregate revolving commitments then in effect and (ii) the sum of (a) 85% of the value of eligible accounts receivable plus (b) 80% of the value of eligible unbilled accounts receivable, subject to a limit equal to the greater of (x) $30 million and (y) 25% of the commitments. The amount that may be borrowed under the New ABL Facility is subject to increase or reduction based on certain segregated cash or reserves provided for by the New ABL Facility. In addition, the percentages of accounts receivable and unbilled accounts receivable included in the calculation described above is subject to reduction to the extent of certain bad debt write-downs and other dilutive items provided in the New ABL Facility.     
Borrowings under the New ABL Facility bears interest, at the ABL Borrowers’ option, at a per annum rate equal to (i) LIBOR for 30, 60, 90, 180, or, with the consent of the ABL Lenders, 360 days, plus an applicable margin that varies from 2.75% to 3.25% depending on the ABL Borrowers’ fixed charge coverage ratio at such time or (ii) a base rate equal to the sum of (a) the greatest of (x) the prime rate, (y) the federal funds rate, plus 0.50% or (z) 30-day LIBOR plus 1.0% plus (b) an applicable margin that varies from 1.75% to 2.25% depending on the ABL Borrowers’ fixed charge coverage ratio at such time. The New ABL Facility provides that, in the event LIBOR becomes unascertainable for the requested interest period or otherwise becomes unavailable or replaced by other benchmark interest rates, then the Company and the ABL Agent may amend the New ABL Facility for the purpose of replacing LIBOR with one or more SOFR-based rates or another alternate benchmark rate giving consideration to the general practice in similar U.S. dollar denominated syndicated credit facilities.
In addition, the New ABL Facility provides for unused line fees of 0.5% to 0.375% per year, depending on utilization, letter of credit fees and certain other factors. The New ABL Facility may in the future be guaranteed by certain of the Company’s existing and future subsidiaries (the “ABL Guarantors,” and together with the ABL Borrowers, the “ABL Loan Parties”). To secure their obligations under the New ABL Facility, each of the ABL Loan Parties has granted or will grant, as applicable, to the ABL Agent a first-priority security interest for the benefit of the ABL Lenders in its present and future accounts receivable, inventory

15


and related assets and proceeds of the foregoing (the “ABL Priority Collateral”). In addition, the obligations of the ABL Loan Parties under the ABL Facility are secured by second-priority liens on the Term Priority Collateral (as described below under “New Term Loan Facility”).
The revolving loans under the New ABL Facility may be voluntarily prepaid, in whole or in part, without premium or penalty, subject to breakage or similar costs.
The New ABL Facility contains certain affirmative and negative covenants, including covenants that restrict the ability of the ABL Loan Parties to take certain actions including, among other things and subject to certain significant exceptions, the incurrence of debt, the granting of liens, the making of investments, entering into transactions with affiliates, the payment of dividends and the sale of assets. The New ABL Facility also contains a requirement that the ABL Borrowers comply, during certain periods, with a fixed charge coverage ratio of at least 1.00 to 1.00.
On May 20, 2020, the ABL Borrowers, the ABL Lenders and Administrative Agent, entered into Amendment No. 4 to the New ABL Facility. Pursuant to the Fourth Amendment, the parties agreed, among other things, to (i) reduce the Lenders’ aggregate commitments to make revolving loans to $50 million, (ii) increase the applicable interest rate margin by 100 basis points to 375-425 basis points for LIBOR borrowings (with a 1.00% LIBOR floor) and 275-325 basis points for base rate borrowings (with a 2.00% base rate floor), in each case depending on the fixed charge coverage ratio at the time of determination, (iii) lower the availability thresholds for triggering certain covenants and (iv) add certain reporting requirements.
As of June 30, 2020, we had no borrowings outstanding, $36.3 million of letters of credit, $28.6 million posted as additional collateral ($21.2 million of which was posted in the second quarter of 2020) recorded in deposits on our balance sheet and $7.8 million of borrowing capacity available under our New ABL Facility. The letters of credit are related to our workers’ compensation and auto insurance costs. The additional collateral is required to collateralize our outstanding letters of credit and maintain compliance with the minimum borrowing capacity available under our New ABL Facility.
As of June 30, 2020, we were in compliance with all covenants under our New ABL Facility.
New Term Loan Facility
On March 6, 2020, the Company entered into an amendment and restatement agreement with the Supporting Term Lenders and Cortland Capital Market Services LLC and Cortland Products Corp., as agent (the “Term Agent”), which amended and restated the Prior Term Loan Facility, among the Company, as borrower, certain subsidiaries of the Company named as guarantors therein, the financial institutions party thereto from time to time as lenders and the Term Agent (as amended and restated by the amendment and restatement agreement, the “New Term Loan Facility”). Prior to the closing of the Restructuring, there were approximately $243.1 million aggregate principal amount of term loans outstanding under the Prior Term Loan Facility. Following the closing of the Restructuring, the New Term Loan Facility is comprised of (i) $30 million new money term loans funded by the Supporting Term Lenders and $20 million new term loans excluding new money issued in exchange for existing term loans held by the Supporting Term Lenders (collectively, the “New Term Loans”) and (ii) an approximate $1.2 million senior secured term loan tranche in respect of the existing term loans held by lenders who are not Supporting Term Lenders (the “Continuing Term Loans”). As of June 30, 2020, there was $51.2 million outstanding under the New Term Loan Facility.
For the $20 million new term loans excluding new money which were accounted for as a troubled debt restructuring with a modification of terms in accordance with ASC 470-60, “Troubled Debt Restructurings by Debtors”, which addresses certain aspects of the accounting for debt, a total of $16.3 million of estimated future undiscounted interest payments has been accrued per ASC 470-60 and presented as Interest Payable in the accompanying balance sheet. Interest payments made in the future associated with the modified $20 million new term loans will be a reduction to interest payable, which is recorded as a long-term liability on our consolidated balance sheet, and not to interest expense. Fluctuations in the effective interest rate used to estimate future cash flows will be accounted for as changes in estimates for the period in which the change occurred. However, the carrying amount of the restructured payable will remain unchanged, and future cash payments will reduce the carrying amount until the time that any gain recognized cannot be offset by future cash payments.
The New Term Loan Facility will mature on August 28, 2025, with respect to the New Term Loans, and on December 15, 2021 with respect to the Continuing Term Loans. Such maturity date may, at the Company’s request, be extended by one or more of the term loan lenders pursuant to the terms of the New Term Loan Facility. The New Term Loans will bear interest at a per annum rate equal to LIBOR for six months, plus 10.25%. The Company has the option to pay interest in kind at an annual rate of LIBOR plus 12.25% on the outstanding principal amount of the New Term Loans for the first two years following the closing of the Restructuring. The Continuing Term Loans will bear interest at a per annum rate equal to LIBOR for one, two, three, six or, with the consent of all term loan lenders, up to 12 months, and the Company has the option to pay interest in kind of up to 100 basis points of the per annum interest due on the Continuing Term Loans.
The New Term Loan Facility is guaranteed by certain of the Company’s existing and future subsidiaries (the “Term Loan Guarantors,” and together with the Company, the “Term Loan Parties”). To ensure their obligations under the New Term Loan

16


Facility, each of the Term Loan Parties has granted or will grant, as applicable, to the Term Agent a first-priority security interest for the benefit of the Term Loan Lenders in substantially all of each Term Loan Party’s assets other than certain excluded assets and the ABL Priority Collateral (the “Term Priority Collateral”). In addition, the obligations of the Term Loan Parties under the New Term Loan Facility are secured by second-priority liens on the ABL Priority Collateral (as described above under “ABL Facility”).
The New Term Loans may be prepaid at the Company’s option, subject to the payment of a prepayment premium (which may be waived by lenders holding New Term Loans under the New Term Loan Facility representing at least two-thirds of the aggregate outstanding principal amount of the New Term Loans) in certain circumstances as provided in the New Term Loan Facility. If a prepayment is made prior to the first anniversary of the closing of the Restructuring, such prepayment premium is equal to 3% of the principal amount of the New Term Loans prepaid; if a prepayment is made from the first anniversary to the second anniversary of the closing of the Restructuring, the prepayment premium is equal to 2% of the principal amount of the New Term Loans prepaid; if a prepayment is made from the second anniversary to the third anniversary of the closing of the Restructuring, the prepayment premium is equal to 1% of the principal amount of the New Term Loans prepaid; and there is no prepayment premium thereafter. The Company is required to make principal payments in respect of the Continuing Term Loans in the amount of $3,125 per quarter commencing with the quarter ended March 31, 2020 and is required to pay $1,190,625 on the maturity date of the Continuing Term Loans.
In addition, pursuant to the New Term Loan Facility, the Company must prepay or offer to prepay, as applicable, term loans with the net cash proceeds of certain debt incurrences and asset sales, excess cash flow, receipt of extraordinary cash proceeds (e.g., tax and insurance) and upon certain change of control transactions, subject in each case to certain exceptions.
The New Term Loan Facility contains certain affirmative and negative covenants, including covenants that restrict the ability of the Term Loan Parties to take certain actions including, among other things and subject to certain significant exceptions, the incurrence of debt, the granting of liens, the making of investments, entering into transactions with affiliates, the payment of dividends and the sale of assets. The New Term Loan Facility also contains a financial covenant requiring that the Company maintain Liquidity (as defined in the New Term Loan Facility) of not less than $10 million as of the last day of any fiscal quarter, subject to certain exceptions and cure rights.
As of June 30, 2020, we were in compliance with all covenants under our New Term Loan Facility.
The weighted average interest rate on the outstanding borrowings under the New Term Loan Facility for the three month periods ended June 30, 2020 and from March 6, 2020, the beginning of the New Term Loan Facility, to June 30, 2020 were 13.17%.
Prior ABL Facility
As described above, the Company and Key Energy Services, LLC were borrowers under the Prior ABL Facility that provided for aggregate commitments from the ABL Lenders of $80 million.
On April 5, 2019, the ABL Borrowers, as borrowers, the financial institutions party thereto as lenders and Bank of America, N.A. (the “ABL Agent”), as administrative agent for the lenders, entered into Amendment No. 1 (“Amendment No. 1”) to the Prior ABL Facility, among the ABL Borrowers, the financial institutions party thereto from time to time as lenders, the ABL Agent and the co-collateral agents for the lenders, Bank of America, N.A. and Wells Fargo Bank, National Association. The amendment, among other things, lowered the applicable margin for borrowings to (i) from between 2.50% and 4.50% to between 2.00% and 2.50% for LIBOR borrowings and (ii) from 1.50% and 3.50% to between 1.00% and 1.50% for base rate borrowings. On December 20, 2019, the Company and the Lenders amended the ABL Forbearance Agreement and the Loan Agreement to, among other things, (i) reduce the minimum availability Key is required to maintain under the ABL Forbearance Agreement from $12.5 million to $10 million and (ii) reduce the aggregate revolving commitments under the Loan Agreement from $100 million to $80 million.
The Prior ABL Facility provided the ABL Borrowers with the ability to borrow up to an aggregate principal amount equal to the lesser of (i) the aggregate revolving commitments then in effect and (ii) the sum of (a) 85% of the value of eligible accounts receivable plus (b) 80% of the value of eligible unbilled accounts receivable, subject to a limit equal to the greater of (x) $35 million and (y) 25% of the Commitments.
The contractual interest rates under the Prior ABL Facility were, at the ABL Borrowers’ option, at a per annum rate equal to (i) LIBOR for 30, 60, 90, 180, or, with the consent of the ABL Lenders, 360 days, plus an applicable margin that varies from 2.50% to 4.50% depending on the ABL Borrowers’ fixed charge coverage ratio at such time or (ii) a base rate equal to the sum of (a) the greatest of (x) the prime rate, (y) the federal funds rate, plus 0.50% or (z) 30-day LIBOR, plus 1.0% plus (b) an applicable margin that varied from 1.50% to 3.50% depending on the ABL Borrowers’ fixed charge coverage ratio at such time. In addition, the Prior ABL Facility provided for unused line fees of 1.0% to 1.25% per year, depending on utilization, letter of credit fees and certain other factors.

17


Prior Term Loan Facility
As described above, the Company and certain subsidiaries were parties to the Prior Term Loan Facility, which had an initial outstanding principal amount of $250 million.
Borrowings under the Prior Term Loan Facility bore interest, at the Company’s option, at a per annum rate equal to (i) LIBOR for one, two, three, six, or, with the consent of the Term Loan Lenders, 12 months, plus 10.25% or (ii) a base rate equal to the sum of (a) the greatest of (x) the prime rate, (y) the Federal Funds rate, plus 0.50% and (z) 30-day LIBOR, plus 1.0% plus (b) 9.25%.
The weighted average interest rate on the outstanding borrowings under the Prior Term Loan Facility in 2020, prior to the Restructuring, was 15.45%.
NOTE 8. OTHER INCOME
The table below presents comparative detailed information about our other income and expense, shown on the condensed consolidated statements of operations as “other income, net” for the periods indicated (in thousands):
 
 
 
 
 
 
 
 
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
 
2020
 
2019
 
2020
 
2019
Interest income
$
(25
)
 
$
(195
)
 
$
(82
)
 
$
(517
)
Other
10

 
(44
)
 
(318
)
 
(864
)
Total
$
(15
)
 
$
(239
)
 
$
(400
)
 
$
(1,381
)
NOTE 9. INCOME TAXES
We are subject to U.S. federal income tax as well as income taxes in multiple state and foreign jurisdictions. Our effective tax rates for the three months ended June 30, 2020 and 2019 were (1.2)% and 19.4%, respectively, and 1.1% and 9.5% for the six months ended June 30, 2020 and 2019, respectively. The variance between our effective rate and the U.S. statutory rate is due to the impact of permanent differences and other tax adjustments, such as valuation allowances against deferred tax assets and a true-up adjustment to income tax receivable.
We continued recording income taxes using a year-to-date effective tax rate method for the three and six months ended June 30, 2020 and 2019. The use of this method was based on our expectations that a small change in our estimated ordinary income could result in a large change in the estimated annual effective tax rate. We will re-evaluate our use of this method each quarter until such time as a return to the annualized effective tax rate method is deemed appropriate.
The Company assesses the realizability of its deferred tax assets each period by considering whether it is more likely than not that all or a portion of the deferred tax assets will not be realized. Due to the history of losses in recent years and the continued challenges affecting the oil and gas industry and global economy, management continues to believe it is more likely than not that we will not be able to realize our net deferred tax assets. No release of our deferred tax asset valuation allowance was made during the six months ended June 30, 2020.
The Company did not recognize any unrecognized tax benefits during three or six months ended June 30, 2020. As of June 30, 2020, we had no unrecognized tax benefits.
Cancellation of Indebtedness Income (“CODI”)
Under the RSA, a substantial portion of the Company’s term loans were exchanged for newly issued shares and new term loans of the Company. Absent an exception, a debtor recognizes CODI upon discharge of its outstanding indebtedness for an amount of consideration that is less than the adjusted issue price. The Internal Revenue Code of 1986, as amended (“IRC”), provides that an insolvent debtor may exclude CODI from taxable income up to the amount of insolvency but must reduce certain of its tax attributes by the amount of any CODI excluded pursuant to the insolvency exception. The amount of CODI realized by a taxpayer is the adjusted issue price of any indebtedness discharged less the sum of (i) the amount of cash paid, (ii) the issue price of any new indebtedness issued and (iii) the fair market value of any other consideration, including equity, issued. Based on the market value of the Company’s equity, and the adjusted issue price of the term loans issued in the exchange, the estimated amount of U.S. CODI is approximately $206.0 million, $197.8 million of which is excluded pursuant to the insolvency exception and $8.2 million of which will be included in taxable income. Due to the application of the insolvency exception, the Company will reduce the value of its U.S. net operating losses that had a value of $476.8 million as of June 30, 2020. The actual reduction in tax attributes does not occur until the first day of the Company’s tax year subsequent to the date of the restructuring, or January 1, 2021. Further

18


any remaining net operating losses, tax credits, and certain built-in-losses or deductions existing as of the date of the ownership change will be limited under IRC Section 382 due to the change in control resulting from the restructuring.
The CARES Act    
As noted above in Note 2 under the heading—Significant Accounting Policies Coronavirus Aid, Relief and Economic Security Act, the CARES Act includes several significant business tax provisions that, among other things, eliminate the taxable income limit for certain net operating losses (NOL) and allow businesses to carry back NOLs arising in 2018, 2019, and 2020 to the five prior tax years; accelerate refunds of previously generated corporate alternative minimum tax (AMT) credits; and generally increased the business interest limitation under section 163(j) from 30 percent to 50 percent. Key has analyzed the income tax provisions under the CARES Act, and concluded that none of the provisions have a significant impact to the Company's income tax positions. Future regulatory guidance under the CARES Act or additional legislation enacted by Congress in connection with the COVID-19 pandemic could impact our tax provision in future periods. In addition to income tax provisions, the CARES Act also includes tax provisions relating to refundable payroll tax credits and deferment of employer’s social security tax payments. Specifically, the CARES Act permits an employer to defer 50 percent of its 2020 social security tax payments to the end of 2021 and the remaining 50 percent to the end of 2022. Beginning in April of 2020, we began deferment of employer’s social security payments. The Company continues to evaluate the impact of the CARES Act on our financial position, results of operations and cash flows.
NOTE 10. COMMITMENTS AND CONTINGENCIES
Litigation
Various suits and claims arising in the ordinary course of business are pending against us. We conduct business throughout the continental United States and may be subject to jury verdicts or arbitrations that result in outcomes in favor of the plaintiffs. We continually assess our contingent liabilities, including potential litigation liabilities, as well as the adequacy of our accruals and our need for the disclosure of these items, if any. We establish a provision for a contingent liability when it is probable that a liability has been incurred and the amount is reasonably estimable. We have $2.0 million of other liabilities related to litigation that is deemed probable and reasonably estimable as of June 30, 2020. We do not believe that the disposition of any of these matters will result in an additional loss materially in excess of amounts that have been recorded.
Self-Insurance Reserves
We maintain reserves for workers’ compensation and vehicle liability on our balance sheet based on our judgment and estimates using an actuarial method based on claims incurred. We estimate general liability claims on a case-by-case basis. We maintain insurance policies for workers’ compensation, vehicle liability and general liability claims. These insurance policies carry self-insured retention limits or deductibles on a per occurrence basis. The retention limits or deductibles are accounted for in our accrual process for all workers’ compensation, vehicular liability and general liability claims. The deductibles have a $5 million maximum per vehicular liability claim, and a $2 million maximum per general liability claim and a $1 million maximum per workers’ compensation claim. As of June 30, 2020 and December 31, 2019, we have recorded $51.9 million and $51.4 million, respectively, of self-insurance reserves related to workers’ compensation, vehicular liabilities and general liability claims. Partially offsetting these liabilities, we had $13.7 million and $13.4 million of insurance receivables as of June 30, 2020 and December 31, 2019, respectively. We believe that the liabilities we have recorded are appropriate based on the known facts and circumstances and do not expect further losses materially in excess of the amounts already accrued for existing claims.
Environmental Remediation Liabilities
For environmental reserve matters, including remediation efforts for current locations and those relating to previously disposed properties, we record liabilities when our remediation efforts are probable and the costs to conduct such remediation efforts can be reasonably estimated. As of each of June 30, 2020 and December 31, 2019, we have recorded $1.9 million and $2.0 million, respectively, for our environmental remediation liabilities. We believe that the liabilities we have recorded are appropriate based on the known facts and circumstances and do not expect further losses materially in excess of the amounts already accrued.
NOTE 11. EARNINGS (LOSS) PER SHARE
Basic earnings (loss) per share is determined by dividing net loss attributable to Key by the weighted average number of common shares actually outstanding during the period. Diluted earnings (loss) per common share is based on the increased number of shares that would be outstanding assuming conversion of potentially dilutive outstanding securities using the treasury stock and “as if converted” methods.

19


The components of our income (loss) per share are as follows (in thousands, except per share amounts):
 
 
 
 
 
 
 
 
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
 
2020
 
2019
 
2020
 
2019
Basic Calculation:
 
 
 
 
 
 
 
Numerator
 
 
 
 
 
 
 
Net income (loss)
$
(19,125
)
 
$
(18,303
)
 
$
89,869

 
$
(41,744
)
Denominator
 
 
 
 
 
 
 
Weighted average shares outstanding
13,781

 
408

 
8,935

 
408

Basic earnings (loss) per share
$
(1.39
)
 
$
(44.86
)
 
$
10.06

 
$
(102.31
)
Diluted EPS Calculation:
 
 

 
 
 
 
Numerator
 
 

 
 
 
 
Net income (loss)
$
(19,125
)
 
$
(18,303
)
 
$
89,869

 
$
(41,744
)
Denominator
 
 

 
 
 
 
Weighted average shares outstanding
13,781

 
408

 
8,935

 
408

RSUs

 

 
56

 

Total
13,781

 
408

 
8,991

 
408

Diluted earnings (loss) per share
$
(1.39
)
 
$
(44.86
)
 
$
10.00

 
$
(102.31
)
Restricted stock units (“RSUs”), stock options, and warrants are included in the computation of diluted earnings per share using the treasury stock method. Restricted stock awards are legally considered issued and outstanding when granted and are included in basic weighted average shares outstanding.
The Company has issued potentially dilutive instruments such as RSUs, stock options and warrants. However, the Company did not include these instruments in its calculation of diluted loss per share during the periods presented, because to include them would be anti-dilutive. The following table shows potentially dilutive instruments (in thousands):
 
 
 
 
 
 
 
 
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
 
2020
 
2019
 
2020
 
2019
RSUs
301

 
40

 
58

 
41

Stock options
1

 
1

 
1

 
1

Warrants
2,924

 
37

 
1,880

 
37

Total
3,226

 
78

 
1,939

 
79

No events occurred after June 30, 2020 that would materially affect the number of weighted average shares outstanding.
NOTE 12. SHARE-BASED COMPENSATION
Common Stock Awards
We recognized employee share-based compensation expense of $0.3 million and $1.4 million during the three months ended June 30, 2020 and 2019, respectively. We recognized employee share-based compensation expense of $0.3 million and $2.1 million during the six months ended June 30, 2020 and 2019, respectively. Our employee share-based awards, including common stock awards, stock option awards and phantom shares, vest in equal installments over a three-year period or vest in a 40%-60% split respectively over a two-year period. Additionally, we recognized share-based compensation expense related to our outside directors of zero and$0.1 million during the three months ended June 30, 2020 and 2019, respectively. We recognized share-based compensation expense related to our outside directors of less than negative $0.1 million and $0.2 million during the six months ended June 30, 2020 and 2019, respectively. The unrecognized compensation cost related to our unvested share-based awards as of June 30, 2020 is estimated to be $3.1 million and is expected to be recognized over a weighted-average period of 1.3 years.

20


Stock Option Awards
As of June 30, 2020, all outstanding stock options are vested and there are no unrecognized costs related to our stock options.
Phantom Share Plan
We recognized compensation expense related to our phantom shares of less than $0.1 million and less than negative $0.1 million during the three months ended June 30, 2020 and 2019, respectively. We recognized compensation expense related to our phantom shares of less than $0.1 million and less than $0.1 million during the six months ended June 30, 2020 and 2019, respectively. The unrecognized compensation cost related to our unvested phantom shares as of June 30, 2020 is estimated to be less than $0.1 million and is expected to be recognized over a weighted-average period of 0.5 years.
NOTE 13. TRANSACTIONS WITH RELATED PARTIES
The Company previously had a corporate advisory services agreement between with Platinum Equity Advisors, LLC (“Platinum”), an affiliate of Soter, pursuant to which Platinum provides certain business advisory services to the Company. The dollar amounts related to these related party activities were material to the Company’s condensed consolidated financial statements.
In March 2020, the Company and Platinum Equity Advisors, LLC (“Platinum”), entered into a letter agreement (the “CASA Letter Agreement”) regarding outstanding payments owed to Platinum by the Company under the Corporate Advisory Services Agreement, dated as of December 15, 2016 (the “Advisory Agreement”). Pursuant to the CASA Letter Agreement, Platinum agreed to release the Company from its outstanding payment obligations under the Advisory Agreement in exchange for the right to a potential payment of $4.0 million upon the occurrence of certain reorganization events involving the Company and ceased providing any business advisory services to the Company.
NOTE 14. ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS
Cash, cash equivalents, accounts receivable, accounts payable and accrued liabilities. These carrying amounts approximate fair value because of the short maturity of the instruments or because the carrying value is equal to the fair value of these instruments.
New Term Loan Facility. Because of the variable interest rates feature and recent initiation of these loans, we believe the carrying value approximates the fair value of the loans borrowed under this facility.
NOTE 15. LEASES
We have operating leases for certain corporate offices and operating locations and finance leases for certain vehicles. We determine if a contract is a lease or contains an embedded lease at the inception of the contract. Operating lease right-of-use (“ROU”) assets are included in other current and other non-current assets, and operating lease liabilities are included in other current and other non-current liabilities in our consolidated balance sheets. Finance lease ROU assets are included in property and equipment, net, and finance lease liabilities are included in our current portion of long-term debt, and long-term debt on our consolidated balance sheets.
ROU assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. Operating and finance lease ROU assets and liabilities are recognized at commencement date based on the present value of lease payments over the lease term. As most of our leases do not provide an implicit rate, we use our risk adjusted incremental borrowing rate based on the information available at the commencement date in determining the present value of lease payments. We use the implicit rate when readily determinable. Our lease terms may include options to extend or terminate the lease. Our leases have remaining lease terms of less than one year to five years, some of which include options to extend the leases for up to five years, and some of which include options to terminate the leases within one year. Lease expense for lease payments is recognized on a straight-line basis over the non-cancelable term of the lease.
We recognized $0.7 million and $0.7 million of costs related to our operating leases during the three months ended June 30, 2020 and June 30, 2019, respectively. We recognized $1.4 million and $1.4 million of costs related to our operating leases during the six months ended June 30, 2020 and June 30, 2019, respectively. As of June 30, 2020, our operating leases have a weighted average remaining lease term of 2.3 years and a weighted average discount rate of 5.63%.
We recognized $0.3 million and zero of costs related to our finance leases during the three months ended June 30, 2020 and June 30, 2019, respectively. We recognized $0.4 million and zero of costs related to our finance leases during the six months ended June 30, 2020 and June 30, 2019, respectively. As of June 30, 2020, our finance leases have a weighted average remaining lease term of 4.3 years and a weighted average discount rate of 5.11%.
Supplemental balance sheet information related to leases as of June 30, 2020 and December 31, 2019are as follows (in thousands):

21


 
 
 
 
 
June 30, 2020
 
December 31, 2019
Right-of-use assets under operating leases
 
 
 
Operating lease right-of-use assets, current portion
$
3,593

 
$
2,394

Operating lease right-of-use assets, non-current portion
439

 
2,404

Total operating lease assets
$
4,032

 
$
4,798

 
 
 
 
Operating lease liabilities, current portion
$
2,599

 
$
2,502

Operating lease liabilities, non-current portion
1,783

 
2,590

Total operating lease liabilities
$
4,382

 
$
5,092

 
 
 
 
Right-of-use assets under finance leases
 
 
 
Property and equipment, at cost
$
5,246

 
$
1,760

Less accumulated depreciation
554

 
183

Property and equipment, net
$
4,692

 
$
1,577

 
 
 
 
Current portion of long-term debt
$
1,063

 
$
419

Long-term debt
3,683

 
1,181

Total finance lease liabilities
$
4,746

 
$
1,600


The maturities of our operating and finance lease liabilities as of June 30, 2020 are as follows (in thousands):
 
June 30, 2020
 
Operating Leases
 
Finance Leases
Remainder of 2020
$
1,492

 
$
638

2021
1,747

 
1,277

2022
705

 
1,277

2023
528

 
1,075

2024
189

 
792

Thereafter

 
225

Total lease payments
4,661

 
5,284

Less imputed interest
(279
)
 
(538
)
Total
$
4,382

 
$
4,746

NOTE 16. SEGMENT INFORMATION
Our reportable business segments are Rig Services, Fishing and Rental Services, Coiled Tubing Services and Fluid Management Services. We also have a “Functional Support” segment associated with overhead and other costs in support of our reportable segments. We evaluate the performance of our segments based on gross margin measures. All inter-segment sales pricing is based on current market conditions.
Rig Services
Our Rig Services include the completion of newly drilled wells, workover and recompletion of existing oil and natural gas wells, well maintenance, and the plugging and abandonment of wells at the end of their useful lives. We also provide specialty drilling services to oil and natural gas producers with certain of our larger rigs that are capable of providing conventional and horizontal drilling services. Our rigs encompass various sizes and capabilities, allowing us to service all types of wells. Many of our rigs are outfitted with our proprietary KeyView® technology, which captures and reports well site operating data and provides safety control systems. We believe that this technology allows our customers and our crews to better monitor well site operations, improves efficiency and safety, and adds value to the services that we offer.
The completion and recompletion services provided by our rigs prepare wells for production, whether newly drilled, or recently extended through a workover operation. The completion process may involve selectively perforating the well casing to access production zones, stimulating and testing these zones, and installing tubular and downhole equipment. We typically provide

22


a well service rig and may also provide other equipment to assist in the completion process. Completion services vary by well and our work may take a few days to several weeks to perform, depending on the nature of the completion.
The workover services that we provide are designed to enhance the production of existing wells and generally are more complex and time consuming than normal maintenance services. Workover services can include deepening or extending wellbores into new formations by drilling horizontal or lateral wellbores, sealing off depleted production zones and accessing previously bypassed production zones, converting former production wells into injection wells for enhanced recovery operations and conducting major subsurface repairs due to equipment failures. Workover services may last from a few days to several weeks, depending on the complexity of the workover.
Maintenance services provided with our rig fleet are generally required throughout the life cycle of an oil or natural gas well. Examples of these maintenance services include routine mechanical repairs to the pumps, tubing and other equipment, removing debris and formation material from wellbores, and pulling rods and other downhole equipment from wellbores to identify and resolve production problems. Maintenance services are generally less complicated than completion and workover related services and require less time to perform.
Our rig fleet is also used in the process of permanently shutting-in oil or natural gas wells that are at the end of their productive lives. These plugging and abandonment services generally require auxiliary equipment in addition to a well servicing rig. The demand for plugging and abandonment services is not significantly impacted by the demand for oil and natural gas because well operators are required by state regulations to plug wells that are no longer productive.
Fishing and Rental Services
We offer a full line of fishing services and rental equipment designed for use in providing drilling and workover services. Fishing services involve recovering lost or stuck equipment in the wellbore utilizing a broad array of “fishing tools.” Our rental tool inventory consists of drill pipe, tubulars, handling tools (including our patented Hydra-Walk® pipe-handling units and services), pressure-control equipment, pumps, power swivels, reversing units and foam air units. We sold our well testing assets and our frac stack equipment used to support hydraulic fracturing operations and the associated flowback of frac fluids in the second quarter of 2017.
Demand for our fishing and rental services is closely related to capital spending by oil and natural gas producers, which is generally a function of oil and natural gas prices.
Coiled Tubing Services
Coiled Tubing Services involve the use of a continuous metal pipe spooled onto a large reel which is then deployed into oil and natural gas wells to perform various applications, such as wellbore clean-outs, nitrogen jet lifts, through-tubing fishing, and formation stimulations utilizing acid and chemical treatments. Coiled tubing is also used for a number of horizontal well applications such as milling temporary isolation plugs that separate frac zones, and various other pre- and post-hydraulic fracturing well preparation services.
Fluid Management Services
We provide transportation and well-site storage services for various fluids utilized in connection with drilling, completions, workover and maintenance activities. We also provide disposal services for fluids produced subsequent to well completion. These fluids are removed from the well site and transported for disposal in saltwater disposal wells owned by us or a third party. In addition, we operate a fleet of hot oilers capable of pumping heated fluids used to clear soluble restrictions in a wellbore. Demand and pricing for these services generally correspond to demand for our well service rigs.
Functional Support
Our Functional Support segment includes unallocated overhead costs associated with administrative support for our reporting segments.

23


Financial Summary
The following tables set forth our unaudited segment information as of and for the three and six months ended June 30, 2020 and 2019 (in thousands):
As of and for the three months ended June 30, 2020
 
Rig Services
 
Fishing and Rental Services
 
Coiled Tubing Services
 
Fluid Management Services
 
Functional
Support
 
Reconciling
Eliminations
 
Total
Revenues from external customers
$
20,825

 
$
3,971

 
$
1,867

 
$
8,087

 
$

 
$

 
$
34,750

Intersegment revenues
10

 
54

 

 
5

 

 
(69
)
 

Depreciation and amortization
4,138

 
1,349

 
1,164

 
717

 
686

 

 
8,054

Other operating expenses
18,992

 
4,340

 
2,521

 
7,259

 
10,429

 

 
43,541

Operating income (loss)
(2,305
)
 
(1,718
)
 
(1,818
)
 
111

 
(11,115
)
 

 
(16,845
)
Interest expense, net of amounts capitalized
68

 
6

 
14

 
11

 
1,967

 

 
2,066

Income (loss) before income taxes
(2,364
)
 
(1,718
)
 
(1,831
)
 
104

 
(13,087
)
 

 
(18,896
)
Long-lived assets(1)
115,036

 
16,001

 
14,135

 
15,202

 
50,164

 

 
210,538

Total assets
136,287

 
20,014

 
17,766

 
20,577

 
64,048

 
10,501

 
269,193

Capital expenditures
102

 
88

 
105

 
(9
)
 
11

 

 
297

As of and for the three months ended June 30, 2019
 
Rig Services
 
Fishing and Rental Services
 
Coiled Tubing Services
 
Fluid Management Services
 
Functional
Support
 
Reconciling
Eliminations
 
Total
Revenues from external customers
$
67,884

 
$
14,812

 
$
11,747

 
$
18,500

 
$

 
$

 
$
112,943

Intersegment revenues
166

 
287

 

 
32

 

 
(485
)
 

Depreciation and amortization
6,141

 
4,204

 
1,270

 
2,182

 
465

 

 
14,262

Other operating expenses
55,861

 
12,430

 
11,926

 
16,119

 
16,772

 

 
113,108

Operating income (loss)
5,882

 
(1,822
)
 
(1,449
)
 
199

 
(17,237
)
 

 
(14,427
)
Interest expense, net of amounts capitalized
26

 
6

 
14

 
10

 
8,464

 

 
8,520

Income (loss) before income taxes
5,867

 
(1,823
)
 
(1,461
)
 
185

 
(25,476
)
 

 
(22,708
)
Long-lived assets(1)
128,945

 
45,616

 
17,340

 
51,175

 
23,909

 

 
266,985

Total assets
178,747

 
59,541

 
27,949

 
63,880

 
58,610

 
14,788

 
403,515

Capital expenditures
983

 

 
1,151

 
1,898

 
3,290

 

 
7,322


24


As of and for the six months ended June 30, 2020
 
Rig Services
 
Fishing and Rental Services
 
Coiled Tubing Services
 
Fluid Management Services
 
Functional
Support
 
Reconciling
Eliminations
 
Total
Revenues from external customers
$
68,734

 
$
13,563

 
$
6,704

 
$
21,057

 
$

 
$

 
$
110,058

Intersegment revenues
125

 
225

 

 
34

 
5

 
(389
)
 

Depreciation and amortization
8,167

 
4,182

 
2,338

 
2,228

 
1,365

 

 
18,280

Impairment expense

 
17,551

 

 
23,691

 

 

 
41,242

Other operating expenses
59,546

 
13,298

 
7,140

 
18,889

 
21,582

 

 
120,455

Operating income (loss)
1,021

 
(21,468
)
 
(2,774
)
 
(23,751
)
 
(22,947
)
 

 
(69,919
)
Gain on debt restructuring

 

 

 

 
(170,648
)
 

 
(170,648
)
Interest expense, net of amounts capitalized
100

 
12

 
27

 
23

 
10,125

 

 
10,287

Income (loss) before income taxes
941

 
(21,468
)
 
(2,800
)
 
(23,769
)
 
137,938

 

 
90,842

Long-lived assets(1)
115,036

 
16,001

 
14,135

 
15,202

 
50,164

 

 
210,538

Total assets
136,287

 
20,014

 
17,766

 
20,577

 
64,048

 
10,501

 
269,193

Capital expenditures
390

 
106

 
272

 
123

 
88

 

 
979

As of and for the six months ended June 30, 2019
 
Rig Services
 
Fishing and Rental Services
 
Coiled Tubing Services
 
Fluid Management Services
 
Functional
Support
 
Reconciling
Eliminations
 
Total
Revenues from external customers
$
132,910

 
$
29,399

 
$
22,420

 
$
37,487

 
$

 
$

 
$
222,216

Intersegment revenues
254

 
1,195

 

 
75

 

 
(1,524
)
 

Depreciation and amortization
12,130

 
8,354

 
2,526

 
4,623

 
925

 

 
28,558

Other operating expenses
110,442

 
23,990

 
23,481

 
32,556

 
32,928

 

 
223,397

Operating income (loss)
10,338

 
(2,945
)
 
(3,587
)
 
308

 
(33,853
)
 

 
(29,739
)
Interest expense, net of amounts capitalized
36

 
13

 
30

 
21

 
17,653

 

 
17,753

Income (loss) before income taxes
10,336

 
(2,947
)
 
(3,614
)
 
291

 
(50,177
)
 

 
(46,111
)
Long-lived assets(1)
128,945

 
45,616

 
17,340

 
51,175

 
23,909

 

 
266,985

Total assets
178,747

 
59,541

 
27,949

 
63,880

 
58,610

 
14,788

 
403,515

Capital expenditures
2,813

 
2,073

 
1,917

 
2,055

 
3,504

 

 
12,362

(1)
Long-lived assets include fixed assets, intangibles and other non-current assets.
NOTE 17. ASSET IMPAIRMENT
Asset Impairments
During the six months ended June 30, 2020 the Company recognized an asset impairment of $41.2 million. The COVID-19 pandemic has resulted in significant economic disruption globally. Government action to restrict travel and suspend business operations has significantly reduced global economic activity. In addition, the recent steep decline in the price of crude oil has decreased the value in some of our long-lived assets.
The Company assesses triggering events in accordance with ASC 360-10-35-21. Triggering events that were deemed to be present included: a significant adverse change in the extent or manner in which a long-lived asset (asset group) is being used or in its physical location, an accumulation of costs significantly in excess of the amount originally expected for the acquisition or construction of a long-lived asset (asset group), and a current expectation that, more likely than not, a long-lived asset (asset group) will be sold or otherwise disposed of significantly before the end of its previously estimated useful life. During the first quarter of 2020, we recognized an impairment expense to long-lived assets.

25


Impairment of Long-Lived Assets    
The Company’s long-lived assets are reviewed for impairment in accordance with ASC 360, “Property, Plant and Equipment”, whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Long-lived assets used in operations are assessed for impairment whenever changes in circumstances indicate that the carrying value of the assets may not be recoverable based on the expected undiscounted future cash flow of an asset group. Long-lived assets must be grouped at the lowest level for which independent cash flows can be identified (asset groups). If the sum of the undiscounted cash flows is less than the carrying value of an asset group, the fair value of each asset group must be calculated and the carrying value is written down to the calculated fair value if necessary. If the fair value of an asset group exceeds the carrying value, no impairment expense is necessary for that asset group.
During the first quarter of 2020, we identified long-lived asset impairment triggers relating to all five of our asset groups as a result of the significant economic impacts and the effects of COVID-19. The five asset groups were determined to be Rigs, Fluid Management Services - Trucks, Fluid Management Services - Saltwater Disposal Wells, Fishing & Rental Services, and Coiled Tubing Services. We assessed each asset group for impairment by comparing the undiscounted pretax cash flows to the carrying value of each asset group. We determined that all our asset groups, excluding Rigs, had carrying values that exceeded the undiscounted cash flows. The determination of undiscounted cash flows included management’s best estimates of the expected future cash flows per asset group for the next five years. The determinations of expected future cash flows and the salvage value of long-lived assets require considerable judgement and are sensitive to changes in underlying assumptions and factors. As a result, there can be no assurance that the estimates and assumptions made for the purposes of this impairment analysis will prove to be an accurate prediction of the future. Should our assumptions change significantly in future periods, it is possible we may determine the carrying values of the Rigs asset group exceeds the undiscounted pretax cashflows, which would result in an impairment expense.
It was determined that the fair value of the Fluid Management Services - Trucks, Fluid Management Services - Saltwater Disposal Wells, and Fishing & Rental Service asset groups was less than the carrying value of the respective asset groups by approximately $8.8 million, $14.8 million and $17.6 million, respectively, as of March 31, 2020. As a result, we recorded a total impairment charge of $41.2 million to asset impairment on the consolidated statements of income at March 31, 2020. We determined that the fair value of our Coiled Tubing Services asset group exceeded the carrying value. As such, no impairment expense was charged to the Coiled Tubing Services asset group.
The Company incorporated the income, market, and cost approaches to determine the fair value of each asset group. The income approach utilized significant assumptions including management’s best estimates of the expected future cash flows and the estimated useful life of the asset group. The market approach was utilized when there was an observable secondary market or where there was ample asset data available. The cost approach utilized assumptions for the current replacement costs of similar assets adjusted for estimated depreciation and deterioration of the existing equipment and economic obsolescence. Fair value determination requires a considerable amount of judgement and is sensitive to changes in underlying assumptions and economic factors. As a result, there can be no assurance that the fair value estimates made for the impairment analysis will prove to be an accurate prediction for the future. 

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ITEM 2.
MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
OVERVIEW    
Key Energy Services, Inc., and its wholly owned subsidiaries provide a full range of well services to major oil companies and independent oil and natural gas production companies. Our services include rig-based and coiled tubing-based well maintenance and workover services, well completion and recompletion services, fluid management services, fishing and rental services, and other ancillary oilfield services. Additionally, certain of our rigs are capable of specialty drilling applications. We operate in most major oil and natural gas producing regions of the continental United States. An important component of the Company’s growth strategy is to make acquisitions that will strengthen its core services or presence in selected markets, and the Company also makes strategic divestitures from time to time. The Company expects that the industry in which it operates will experience consolidation, and the Company expects to explore opportunities and engage in discussions regarding these opportunities, which could include mergers, consolidations or acquisitions or further dispositions or other transactions, although there can be no assurance that any such activities will be consummated.
The following discussion and analysis should be read in conjunction with the accompanying unaudited condensed consolidated financial statements and related notes as of and for the three and six months ended June 30, 2020 and 2019, included elsewhere herein, and the audited consolidated financial statements and notes thereto included in the 2019 Form 10-K and the Q1 2020 Form 10-Q.
We provide information regarding four business segments: Rig Services, Fishing and Rental Services, Coiled Tubing Services and Fluid Management Services. We also have a “Functional Support” segment associated with overhead and other costs in support of our reportable segments. See “Note 16. Segment Information” in “Item 1. Financial Statements” of Part I of this report for a summary of our business segments.
Restructuring and Reverse Stock Split
On March 6, 2020, we closed the previously announced restructuring of our capital structure and indebtedness (the “Restructuring”) pursuant to the Restructuring Support Agreement, dated as of January 24, 2020 (the “RSA”), with lenders under our Prior Term Loan Facility (as defined below) collectively holding over 99.5% (the “Supporting Term Lenders”) of the principal amount of the Company’s then outstanding term loans. Pursuant to the RSA and the Restructuring contemplated thereby, among other things we effected the following transactions and changes to our capital structure and governance:
pursuant to exchange agreements entered into at the closing of the Restructuring, we exchanged approximately $241.9 million aggregate outstanding principal of our term loans (together with accrued interest thereon) held by Supporting Term Lenders under our Prior Term Loan Facility into (i) approximately 13.4 million newly issued shares of common stock representing 97% of the Company’s outstanding shares after giving effect to such issuance (and without giving effect to dilution by the New Warrants and MIP (each as defined below)) and (ii) $20 million of term loans under our new $51.2 million term loan facility (the “New Term Loan Facility”), each on a pro rata basis based on their holdings of term loans under the Prior Term Loan Facility;
completed a 1-for-50 reverse stock split of our outstanding common stock. All pre-Restructuring shares prices, including shares outstanding and earnings per share, have been adjusted to reflect the 1-for-50 reverse stock split;
distributed to our common stockholders of record as of February 18, 2020 two series of warrants (the “New Warrants”);
entered into the $51.2 million New Term Loan Facility, of which (i) $30 million was funded at closing of the Restructuring with new cash proceeds from the Supporting Term Lenders and $20 million was issued in exchange for term loans held by the Supporting Term Lenders under the Prior Term Loan Facility as described above and (ii) an approximate $1.2 million was a senior secured term loan tranche in respect of term loans held by lenders under the Prior Term Loan Facility who were not Supporting Term Lenders;
entered into the New ABL Facility (as defined below);
adopted a new management incentive plan (the “MIP”) representing up to 9% of the Company’s outstanding shares after giving effect to the issuance of shares described above; and
made certain changes to the Company’s governance, including changes to our Board of Directors (the “Board”), amendments to our governing documents and entry into the Stockholders Agreement (as defined below) with the Supporting Term Lenders.
In accordance with the RSA at the closing of the Restructuring, the Company amended and restated its certificate of incorporation and entered into a stockholders agreement (the “Stockholders Agreement”) with the Supporting Term Lenders in order to, among other things, provide for a Board of seven members. Pursuant to the Stockholders Agreement, our Board consists

27


of our chief executive officer and six other members appointed by various Supporting Term Lenders. Specifically, pursuant to the Stockholders Agreement, Supporting Term Lenders who hold more than 25% of the Company’s outstanding shares as of the closing of the Restructuring are entitled to nominate two directors and Supporting Term Lenders who hold between 10% and 25% of the Company’s outstanding shares as of the closing of the Restructuring are entitled to nominate one director. All appointees or nominees of Supporting Term Lenders, other than any director appointed or nominated by Soter Capital LLC (“Soter”), must meet the “independent director” requirements set forth in Section 303A of the NYSE Listed Company Manual. In addition, pursuant to the Stockholders Agreement, Supporting Term Lenders are entitled to appoint a non-voting board observer subject to specified ownership thresholds.
In accordance with the RSA and following the closing of the Restructuring, the Company distributed to stockholders of record as of February 18, 2020 the New Warrants. The New Warrants were issued in two series each with a four-year exercise period. The first series entitles the holders to purchase in the aggregate 1,669,730 newly issued shares of common stock, representing 10% of the Company’s common shares at the closing of the Restructuring on an as-exercised basis (after giving effect to the exercise of all New Warrants, but subject to dilution by issuances under the MIP). The aggregate exercise price of the first series of New Warrants is $19.23 and was determined based on the aggregate outstanding principal amount of term loans under the Prior Term Loan Facility plus accrued interest thereon at the default rate as of the closing of the Restructuring. The second series of New Warrants entitles the holders to purchase in the aggregate 1,252,297 newly issued shares of common stock, representing 7.5% of the Company’s common shares at the closing of the Restructuring on an as-exercised basis (after giving effect to the exercise of all New Warrants, but subject to dilution by issuances under the MIP). The aggregate strike price of the second series of New Warrants is $28.85 and was determined based on the product of (i) the aggregate outstanding principal amount of term loans under the Prior Term Loan Facility plus accrued interest thereon at the default rate as of the closing of the Restructuring, multiplied by (ii) 1.50.
For more information on our New Term Loan Facility and New ABL Facility entered into in connection with the Restructuring, see “Note 7. Debt” in Part I, Item 1 of this report.
PERFORMANCE MEASURES
In assessing overall activity in the U.S. onshore oilfield service industry in which we operate, we believe that the Baker Hughes U.S. land drilling rig count, which is publicly available on a weekly basis, is the best available barometer of exploration and production (“E&P”) companies’ capital spending and resulting activity levels. Historically, our activity levels have been highly correlated with U.S. onshore capital spending by our E&P company customers as a group.
 
 
WTI Cushing Oil(1)
 
NYMEX Henry
Hub Natural Gas(1)
 
Average Baker
Hughes U.S. Land
Drilling Rigs(2)
 
Average AESC Well Service Active Rig Count(3)
2020:
 
 
 
 
 
 
 
 
First Quarter
 
$
41.00

 
$
1.90

 
764

 
978

Second Quarter
 
$
27.96

 
$
1.70

 
378

 
498

 
 
 
 
 
 
 
 
 
2019:
 
 
 
 
 
 
 
 
First Quarter
 
$
54.82

 
$
2.92

 
1,023

 
1,295

Second Quarter
 
$
59.88

 
$
2.57

 
967

 
1,311

Third Quarter
 
$
56.34

 
$
2.38

 
894

 
1,263

Fourth Quarter
 
$
56.82

 
$
2.40

 
797

 
1,143

(1)
Represents the average of the monthly average prices for each of the periods presented. Source: EIA and Bloomberg
(2)
Source: www.bakerhughes.com
(3)
Source: Association of Energy Service Companies data at www.aesc.net
Internally, we measure activity levels for our well servicing operations primarily through our rig and trucking hours. Generally, as capital spending by E&P companies increases, demand for our services also rises, resulting in increased rig and trucking services and more hours worked. Conversely, when activity levels decline due to lower spending by E&P companies, we generally provide fewer rig and trucking services, which results in fewer hours worked.

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Rig activity occurs primarily on weekdays during daylight hours. Accordingly, we track rig activity on a “per working day” basis. Key’s working days per quarter, which exclude national holidays, are indicated in the table below. Our trucking activity tends to occur on a 24/7 basis. Accordingly, we track our trucking activity on a “per calendar day” basis. The following table presents our quarterly rig and trucking hours from 2019 through the second quarter of 2020:
 
 
Rig Hours
 
Trucking Hours
 
Key’s 
Working Days(1)
2020:
 
 
 
 
 
 
First Quarter
 
101,341

 
106,786

 
64

Second Quarter
 
43,526

 
71,007

 
63

Total 2020
 
144,867

 
177,793

 
127

 
 
 
 
 
 
 
2019:
 
 
 
 
 
 
First Quarter
 
151,309

 
150,740

 
63

Second Quarter
 
154,017

 
144,996

 
63

Third Quarter
 
142,151

 
150,518

 
64

Fourth Quarter
 
114,727

 
121,152

 
62

Total 2019
 
562,204

 
567,406

 
252

(1)
Key’s working days are the number of weekdays during the quarter minus national holidays.
MARKET AND BUSINESS CONDITIONS AND OUTLOOK    
The outbreak of COVID-19 has caused an unprecedented global health crisis and significant economic disruption. National, state and local governments have instituted various measures including quarantining, stay-at-home orders and travel restrictions designed to slow the spread of COVID-19 and protect their populations and economies, including in the areas in which the Company operates. These actions have significantly curtailed economic activity, disrupted global supply chains and materially reduced demand for oil and natural gas, creating a supply and demand imbalance that has negatively impacted commodity prices. The decline in the demand and pricing for oil and natural gas has negatively impacted our customers and the demand for and pricing we receive for our services. These production cuts, other voluntary production curtailments and reduced new well drilling have helped to bring supply and demand closer to balance and stabilized commodity prices. However, US and international crude stocks remain at historically high levels and there remains a high degree of uncertainty regarding the timing and extent of any recovery in economic activity and energy demand. Although commodity prices have recovered from the lows of April 2020, pricing remains depressed compared to 2019 levels. Additionally, recent increases in COVID-19 infections have resulted in the re-implementation of travel and other restrictions on economic activity that were recently relaxed, which could further delay any improvement in energy demand. COVID-19 has also impacted how we conduct our business. While we have taken steps to keep our employees safe by supporting those affected, mandating that as many employees as possible work from home, and monitoring those who cannot do so and are required to be at work, our ability to serve our customers and execute our business could be adversely affected should a significant number of our employees contract COVID-19 and require quarantine. The extent to which our future results are affected by the COVID-19 pandemic and related economic downturn will depend on various factors and consequences beyond our control, such as the duration and scope of the pandemic; additional actions by businesses and governments in response to the pandemic, and the speed and effectiveness of responses to combat the virus. COVID-19 may also adversely affect our results in a manner that is either not currently known or that we do not currently consider to be a significant risk to our business. For additional detail, please refer to Risk Factors in our 2019 Form 10-K and our Q1 2020 Form 10-Q.
We experienced a downturn in demand for our services in 2019, and this decline has increased in 2020 for the reasons discussed above. The macroeconomic events that began in March 2020 resulted in significant revisions to our customers’ capital spending programs for 2020. We expect reduced demand for our services and pricing pressure to continue for the foreseeable future, particularly as compared to the previous year. While activity levels have improved to 63 well service rigs working in July 2020 as compared to 47 well service rigs working in May 2020, as of the date of this filing, we have limited visibility into whether our customers will continue to resume their production maintenance activities, the timing of any increase in activity, or the extent of any improvement in demand for our services. However, as oil supply adjusts to demand and commodity prices stabilize, we expect demand for our services to increase as our customers begin to bring shut-in wells back on line and resume normal well maintenance work.
We initiated a number of actions in the fourth quarter 2019 aimed at conserving cash and protecting our liquidity, and these actions have continued into the second quarter of 2020, including: completing the refinancing of our capital structure,

29


internally realigning our operations, exiting operations and areas to focus on certain markets where we had the best competitive positions, and reducing our overhead costs, including suspension of our 401K match, given the reduced operating footprint. We remain focused on maximizing our current equipment fleet, but we may further reduce our planned expenditures and defer acquisition of new equipment or maintenance if market conditions decline further.
Given the dynamic nature of the macroeconomic events discussed above, we are unable to reasonably estimate the period of time that these market conditions will exist, the extent of the impact they will have on our business, liquidity, results of operations, financial condition, or the timing of any subsequent recovery.
RESULTS OF OPERATIONS
The following table shows our consolidated results of operations for the three and six months ended June 30, 2020 and 2019 (in thousands):
 
 
 
 
 
 
 
 
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
 
2020
 
2019
 
2020
 
2019
REVENUES
$
34,750

 
$
112,943

 
$
110,058

 
$
222,216

COSTS AND EXPENSES:
 
 
 
 

 

Direct operating expenses
29,904

 
90,564

 
91,565

 
178,758

Depreciation and amortization expense
8,054

 
14,262

 
18,280

 
28,558

General and administrative expenses
13,637

 
22,544

 
28,890

 
44,639

Impairment expense

 

 
41,242

 

Operating loss