HOUSTON


,


Aug. 4, 2022


/PRNewswire/ — Independence Contract Drilling, Inc. (the “Company” or “ICD”) (NYSE: ICD) today reported financial results for the three months ended June 30, 2022.

Second quarter 2022 Highlights

• Net loss, as defined below, of
  
  $2.8 million
  
  , or
  
  $0.21
  
  per share.
• Adjusted net loss, as defined below, of
  
  $9.8 million
  
  , or
  
  $0.72
  
  per share.
• Adjusted EBITDA, as defined below, of
  
  $9.2 million
  
  , representing an approximate 158% sequential improvement from the first quarter of 2022.
• Adjusted net debt, as defined below, of
  
  $158.0 million
  
  .
• Marketed fleet utilization of 71%.
• Fully burdened margin of
  
  $8,946
  
  per day, representing an approximate 56% sequential improvement from the first quarter of 2022.

In the second quarter of 2022, the Company reported revenues of

$42.3 million

, a net loss of

$2.8 million

, or

$0.21

per share, adjusted net loss (defined below) of

$9.8 million

, or

$0.72

per share, and adjusted EBITDA (defined below) of

$9.2 million

. These results compare to revenues of

$19.8 million

, a net loss of

$14.9 million

, or

$2.22

per share, adjusted net loss of

$14.6 million

, or

$2.18

per share, and adjusted EBITDA loss of

$0.4 million

in the second quarter of 2021, and revenues of

$35.0 million

, a net loss of

$58.8 million

, or

$5.20

per share, an adjusted net loss of

$11.1 million

, or

$0.98

per share, and adjusted EBITDA of

$3.6 million

in the first quarter of 2022.

Chief Executive Officer

Anthony Gallegos

commented, “I am extremely pleased with our performance during the second quarter, on both a financial and operational front. Sequential margin improvements of 56% drove sequential EBITDA improvements of over 150%. Dayrates for ICD rigs continue to increase with most ICD rigs now set to reprice one to two additional times before year-end. Based on contracts in hand and current spot prices, we expect to see incremental margin per day improvements in the third quarter of approximately 14% and further meaningful improvements in the fourth quarter as well. All of this should drive meaningful EBITDA improvements through the remainder of this year and into 2023.

Operationally, I believe the second quarter was pivotal for ICD. We reactivated our 18th rig on schedule, and on budget, and it has commenced operations in the Haynesville effective

August 1, 2022

on a one-year contract with a large independent. Our 19th rig is scheduled to reactivate at the beginning of the fourth quarter and our 20th rig is scheduled to reactivate late in the fourth quarter. We also have begun preparing to reactivate our 21st rig early in the first quarter of 2023. Based upon current spot dayrates for 300 series rigs, all of these rigs should pay back their reactivation costs in one year or less.

But more importantly, we completed all engineering work necessary to convert the significant majority of our 200 series rigs to 300 series specifications with very modest incremental investments of approximately

$650,000

per rig. Rigs meeting 300 series specifications are in the shortest supply and command the highest dayrates, and we expect to earn less than one-year paybacks on these conversions based upon dayrate differentials today. These conversions require minimal rig downtime and we plan to execute these conversions as our customer base requires. Today, nine of our ten operating 200 series rigs are eligible for this conversion, and we have already signed two contracts for such conversions in the third and fourth quarters of 2022. In addition, six of our non-marketed rigs are eligible for this conversion, and we have now added two of these rigs to our marketed fleet, increasing our marketed fleet from 24 rigs to 26 rigs.

With this backdrop, I could not be more excited about ICD’s strategic positioning in this market dynamic. Our focus on short-term, pad-to-pad contracts is allowing us to quickly convert rapidly improving dayrate momentum into our reported results, and we have now started to build our contractual backlog into 2023. Our overall rig reactivation plan and schedule remains intact, and with our 200-300 series conversion program announced, we have the ability to offer from top to bottom what we believe is one of the most competitive rig fleets in the industry. This is not only driving improved financial performance, but continual high-grading of our customer base. During the second quarter, we added two additional large independents to our customer base, and today, of our 18 operating rigs, approximately 80% are working for public companies or the two largest private operators in the Permian and Haynesville plays.”

Quarterly Operational Results

In the second quarter of 2022, operating days increased sequentially by 5% compared to the first quarter of 2022. The Company’s marketed fleet operated at 71% utilization and recorded 1,540 revenue days, compared to 1,077 revenue days in the second quarter of 2021, and 1,463 revenue days in the first quarter of 2022.

Operating revenues in the second quarter of 2022 totaled

$42.3 million

, compared to

$19.8 million

in the second quarter of 2021 and

$35.0 million

in the first quarter of 2022. Revenue per day in the second quarter of 2022 was

$24,875

, compared to

$16,514

in the second quarter of 2021 and

$21,823

in the first quarter of 2022. The sequential increase quarter over quarter in revenue per day was driven by higher dayrates on contract renewals and reactivated rigs.

Operating costs in the second quarter of 2022 totaled

$28.9 million

, compared to

$17.0 million

in the second quarter of 2021 and

$27.2 million

in first quarter of 2022. Fully burdened operating costs were

$15,929

per day in the second quarter of 2022, compared to

$13,352

in the second quarter of 2021 and

$16,069

in the first quarter of 2022. Sequential decreases in operating costs per day were driven primarily by improved cost absorption, partially offset by higher labor costs associated with increases in field-level wages during the latter part of the second quarter of 2022.

Fully burdened rig operating margins in the second quarter of 2022 were

$8,946

per day, compared to

$3,162

per day in the second quarter of 2021 and

$5,754

per day in the first quarter of 2022. The Company currently expects per day operating margins in the third quarter of 2022 to increase sequentially approximately 14% compared to the second quarter of 2022, driven primarily by favorable dayrate momentum as well as reactivation of the Company’s 18th rig.

Selling, general and administrative expenses in the second quarter of 2022 were

$4.9 million

(including

$0.7 million

of non-cash compensation), compared to

$4.1 million

(including

$0.9 million

of non-cash compensation) in the second quarter of 2021 and

$5.2 million

(including

$1.0 million

of non-cash compensation) in the first quarter of 2022. Cash selling, general and administrative expenses continue to remain elevated due to higher recruiting and onboarding expenses.

During the quarter, the Company recorded interest expense of

$8.2 million

, including

$2.0 million

, or

$0.15

per share, relating to non-cash amortization of debt discount and debt issuance costs.  The Company has excluded these non-cash expenses when presenting adjusted net income/loss per share.  Following approval of matters submitted to the Company’s stockholders at the Company’s 2022 Annual Meeting on

June 8, 2022

, embedded derivative features within the Company’s Senior Secured PIK Toggle Convertible Notes due 2026 were deemed extinguished for financial accounting purposes.  As a result, during the second quarter of 2022 the Company reclassified the conversion rate feature (

$69.2 million

) of the derivative liability on its balance sheet to additional paid-in capital and recognized a non-cash gain on the extinguishment of the PIK interest rate feature of

$10.8 million

. This non-cash gain was excluded when presenting adjusted net income/loss per share.

The Company’s forecasted effective tax rate was adjusted during the second quarter of 2022, resulting in tax expense of

$2.2 million

, or

$0.16

per share, compared to a tax benefit during the first quarter of 2022. Of this tax expense,

$0.3 million

relates to cash taxes, which are attributable to state and local franchise taxes.

Drilling Operations Update

The Company exited the second quarter with 17 rigs operating, with our 18th rig commencing operations

August 1, 2022

. Overall, the Company’s operating rig count averaged 16.9 rigs during the quarter. The Company’s backlog of drilling contracts with original terms of six months or longer was

$54.3 million

as of

June 30, 2022

. This backlog excludes rigs operating on short term pad-to-pad drilling contracts. Approximately 64% of this backlog is expected to be realized in 2022.

Capital Expenditures and Liquidity Update

Cash outlays for capital expenditures in the second quarter of 2022, net of asset sales and recoveries, were

$4.5 million

. This included

$3.8 million

associated with prior period deliveries.

As of June 30, 2022, the Company had cash on hand of

$7.3 million

, a revolving line of credit with availability of

$14.0 million

, and

$157.5 million

principal amount outstanding under its new convertible notes.

During the second quarter of 2022, the Company did not issue any shares of its common stock through its at-the-market (“ATM”) offering program.

Conference Call Details

A conference call for investors will be held today,

August 4, 2022

, at

11:00 a.m. Central Time

(

12:00 p.m. Eastern Time

) to discuss the Company’s second quarter 2022 results.

The call can be accessed live over the telephone by dialing (855) 239-3115 or for international callers, (412) 542-4125. A replay will be available shortly after the call and can be accessed by dialing (877) 344-7529 or for international callers, (412) 317-0088. The passcode for the replay is 8212928. The replay will be available until

August 11, 2022

.

Interested parties may also listen to a simultaneous webcast of the conference call by logging onto the Company’s website at

www.icdrilling.com

in the Investor Relations section.  A replay of the webcast will also be available for approximately 30 days following the call.

Certain Defined Terms

Pad-Optimal, Super-Spec Rig is defined as an AC powered rig with minimum 20,000ft racking capacity, 1500HP+ drawworks, 750,000lb hookload, three high pressure pumps, four engines and omni-directional walking system.  Such rigs also include dual fuel, hi-line power and drilling optimization software options.

300 Series Rigs are defined as a Pad-Optimal, Super-Spec rig with the following additional characteristics: 25,000ft+ racking capacity capable, and hi-torque top drive capable.

About Independence Contract Drilling, Inc.

Independence Contract Drilling provides land-based contract drilling services for oil and natural gas producers in

the United States

. The Company constructs, owns and operates a fleet of pad-optimal ShaleDriller rigs that are specifically engineered and designed to accelerate its clients’ production profiles and cash flows from their most technically demanding and economically impactful oil and gas properties. For more information, visit

www.icdrilling.com

.

Forward-Looking Statements

This news release contains certain forward-looking statements within the meaning of the federal securities laws. Words such as “anticipated,” “estimated,” “expected,” “planned,” “scheduled,” “targeted,” “believes,” “intends,” “objectives,” “projects,” “strategies” and similar expressions are used to identify such forward-looking statements. However, the absence of these words does not mean that a statement is not forward-looking. Forward-looking statements relating to Independence Contract Drilling’s operations are based on a number of expectations or assumptions which have been used to develop such information and statements but which may prove to be incorrect. These statements are not guarantees of future performance and involve certain risks, uncertainties and assumptions that are difficult to predict, and there can be no assurance that actual outcomes and results will not differ materially from those expected by management of Independence Contract Drilling. For more information concerning factors that could cause actual results to differ materially from those conveyed in the forward-looking statements, please refer to the “Risk Factors” section of the Company’s Annual Report on Form 10-K, filed with the SEC and the information included in subsequent amendments and other filings. These forward-looking statements are based on and include the Company’s expectations as of the date hereof. Independence Contract Drilling does not undertake any obligation to update or revise such forward-looking statements to reflect events or circumstances that occur, or which Independence Contract Drilling becomes aware of, after the date hereof.

The following table provides various financial and operational data for the Company’s operations for the three months ended

June 30, 2022

and 2021 and

March 31, 2022

and the six months ended

June 30, 2022

and 2021. This information contains non-GAAP financial measures of the Company’s operating performance. The Company believes this non-GAAP information is useful because it provides a means to evaluate the operating performance of the Company on an ongoing basis using criteria that are used by the Company’s management. Additionally, it highlights operating trends and aids analytical comparisons. However, this information has limitations and should not be used as an alternative to operating income (loss) or cash flow performance measures determined in accordance with GAAP, as this information excludes certain costs that may affect the Company’s operating performance in future periods.

Non-GAAP Financial Measures

Adjusted net debt, adjusted net (loss) income, EBITDA and adjusted EBITDA are supplemental non-GAAP financial measures that are used by management and external users of the Company’s financial statements, such as industry analysts, investors, lenders and rating agencies.  In addition, adjusted EBITDA is consistent with how EBITDA is calculated under the Company’s credit facility for purposes of determining the Company’s compliance with various financial covenants.  The Company defines “adjusted net debt” as long-term notes less cash.  The Company defines “adjusted net (loss) income” as net (loss) income before: asset impairment, net; gain or loss on disposition of assets, net; amortization of debt discount; amortization of issuance costs; gain or loss on extinguishment of debt; change in fair value of embedded derivative liability, gain on extinguishment of derivative and other adjustments.  The Company defines “EBITDA” as earnings (or loss) before interest, taxes, depreciation and amortization, and asset impairment, net and the Company defines “adjusted EBITDA” as EBITDA before stock-based compensation, gain or loss on disposition of assets, gain or loss on extinguishment of debt, gain on extinguishment of derivative and other non-recurring items added back to, or subtracted from, net income for purposes of calculating EBITDA under the Company’s credit facilities.  Neither adjusted net (loss) income, EBITDA or adjusted EBITDA is a measure of net income as determined by U.S. generally accepted accounting principles (“GAAP”).

Management believes adjusted net debt, adjusted net (loss) income, EBITDA and adjusted EBITDA are useful because they allow the Company’s stockholders to more effectively evaluate the Company’s operating performance and compliance with various financial covenants under the Company’s credit facility and compare the results of the Company’s operations from period to period and against the Company’s peers without regard to the Company’s financing methods or capital structure or non-recurring, non-cash transactions. The Company excludes the items listed above from net income (loss) in calculating adjusted net (loss) income, EBITDA and adjusted EBITDA because these amounts can vary substantially from company to company within the Company’s industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. None of adjusted net (loss) income, EBITDA or adjusted EBITDA should be considered an alternative to, or more meaningful than, net income (loss), the most closely comparable financial measure calculated in accordance with GAAP, or as an indicator of the Company’s operating performance or liquidity. Certain items excluded from adjusted net (loss) income, EBITDA and adjusted EBITDA are significant components in understanding and assessing a company’s financial performance, such as a company’s return on assets, cost of capital and tax structure. The Company’s presentation of adjusted net debt, adjusted net (loss) income, EBITDA and adjusted EBITDA should not be construed as an inference that the Company’s results will be unaffected by unusual or non-recurring items. The Company’s computations of adjusted net debt, adjusted net (loss) income, EBITDA and adjusted EBITDA may not be comparable to other similarly titled measures of other companies.

INVESTOR CONTACTS:

Independence Contract Drilling, Inc.

E-mail inquiries to:

[email protected]

Phone inquiries: (281) 598-1211

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SOURCE Independence Contract Drilling, Inc.