# Patterson Uti Energy Inc: Form 10-Q for the period ended Jun 30, 2024

- Company: [Patterson Uti Energy Inc](/companies/pten.md) (CIK 889900)
- Form: 10-Q
- Filed: 2024-07-29
- Accepted by EDGAR: Jul 29, 2024, 16:29 ET
- Period: 2024-06-30
- Accession: 0001628280-24-033296
- Inline XBRL: yes
- Main document: https://www.sec.gov/Archives/edgar/data/889900/000162828024033296/pten-20240630.htm
- All documents and exhibits: https://www.sec.gov/Archives/edgar/data/889900/000162828024033296/

## Figures reported in this filing

Standardized XBRL line items for the period ended 2024-06-30.

| Line item | Period | Value | XBRL concept |
| --- | --- | ---: | --- |
| Selling, general and administrative | 3 months, 2024-04-01 to 2024-06-30 | $64.6m | us-gaap:SellingGeneralAndAdministrativeExpense |
| Selling, general and administrative | 6 months, 2024-01-01 to 2024-06-30 | $129.6m | us-gaap:SellingGeneralAndAdministrativeExpense |
| Operating income | 3 months, 2024-04-01 to 2024-06-30 | $45.2m | us-gaap:OperatingIncomeLoss |
| Operating income | 6 months, 2024-01-01 to 2024-06-30 | $132.2m | us-gaap:OperatingIncomeLoss |
| Interest expense | 3 months, 2024-04-01 to 2024-06-30 | $17.9m | us-gaap:InterestExpenseNonoperating |
| Interest expense | 6 months, 2024-01-01 to 2024-06-30 | $36.2m | us-gaap:InterestExpenseNonoperating |
| Income tax | 3 months, 2024-04-01 to 2024-06-30 | $17.8m | us-gaap:IncomeTaxExpenseBenefit |
| Income tax | 6 months, 2024-01-01 to 2024-06-30 | $37.8m | us-gaap:IncomeTaxExpenseBenefit |
| Net income | 3 months, 2024-04-01 to 2024-06-30 | $11.1m | us-gaap:NetIncomeLoss |
| Net income | 6 months, 2024-01-01 to 2024-06-30 | $62.3m | us-gaap:NetIncomeLoss |
| Diluted EPS | 3 months, 2024-04-01 to 2024-06-30 | $0.03 | us-gaap:EarningsPerShareDiluted |
| Diluted EPS | 6 months, 2024-01-01 to 2024-06-30 | $0.15 | us-gaap:EarningsPerShareDiluted |
| Basic EPS | 3 months, 2024-04-01 to 2024-06-30 | $0.03 | us-gaap:EarningsPerShareBasic |
| Basic EPS | 6 months, 2024-01-01 to 2024-06-30 | $0.15 | us-gaap:EarningsPerShareBasic |
| Diluted shares (weighted) | 3 months, 2024-04-01 to 2024-06-30 | 399,558,000 shares | us-gaap:WeightedAverageNumberOfDilutedSharesOutstanding |
| Diluted shares (weighted) | 6 months, 2024-01-01 to 2024-06-30 | 403,870,000 shares | us-gaap:WeightedAverageNumberOfDilutedSharesOutstanding |
| Operating cash flow | 6 months, 2024-01-01 to 2024-06-30 | $563.4m | us-gaap:NetCashProvidedByUsedInOperatingActivities |
| Capital expenditure | 6 months, 2024-01-01 to 2024-06-30 | $357.4m | us-gaap:PaymentsToAcquirePropertyPlantAndEquipment |
| Dividends paid | 6 months, 2024-01-01 to 2024-06-30 | $64.4m | us-gaap:PaymentsOfDividends |
| Share repurchases | 6 months, 2024-01-01 to 2024-06-30 | $230.2m | us-gaap:PaymentsForRepurchaseOfCommonStock |
| Cash and equivalents | at 2024-06-30 | $72.4m | us-gaap:CashAndCashEquivalentsAtCarryingValue |
| Current assets | at 2024-06-30 | $1.28bn | us-gaap:AssetsCurrent |
| Total assets | at 2024-06-30 | $7.02bn | us-gaap:Assets |
| Current liabilities | at 2024-06-30 | $851.2m | us-gaap:LiabilitiesCurrent |
| Total liabilities | at 2024-06-30 | $2.41bn | us-gaap:Liabilities |
| Long-term debt | at 2024-06-30 | $1.22bn | us-gaap:LongTermDebtNoncurrent |
| Current portion of debt | at 2024-06-30 | $12.6m | us-gaap:LongTermDebtCurrent |
| Shareholders' equity | at 2024-06-30 | $4.60bn | us-gaap:StockholdersEquity |

## Management's discussion and analysis

As filed, 54,845 characters.

*Management Overview —* We are a Houston, Texas-based leading provider of drilling and completion services to oil and natural gas exploration and production companies in the United States and other select countries, including contract drilling services, integrated well completion services and directional drilling services in the United States, and specialized drill bit solutions in the United States, Middle East and many other regions around the world. We operate under three reportable business segments: (i) drilling services, (ii) completion services, and (iii) drilling products.

### Drilling Services

Our contract drilling business operates in the continental United States and internationally in Colombia and, from time to time, we pursue contract drilling opportunities in other select markets. We also provide a comprehensive suite of directional drilling services in most major producing onshore oil and natural gas basins in the United States, and we provide services that improve the statistical accuracy of wellbore placement for directional and horizontal wells. We also service and re-certify equipment for drilling contractors, and we provide electrical controls and automation to the energy, marine and mining industries, in North America and other select markets.

We have addressed our customers’ needs for drilling horizontal wells in shale and other unconventional resource plays by improving the capabilities of our drilling fleet. The U.S. land rig industry has in recent years referred to certain high specification rigs as “super-spec” rigs, which we consider to be at least a 1,500 horsepower, AC-powered rig that has at least a 750,000-pound hookload, a 7,500-psi circulating system, and is pad-capable. Due to evolving customer preferences, we refer to certain premium rigs as “Tier-1, super spec” rigs, which we consider as being a super-spec rig that also has a third mud pump and raised drawworks that allows for more clearance underneath the rig floor. As of June 30, 2024, our rig fleet included 173 super-spec rigs, of which 131 were Tier-1, super-spec rigs.

### Completion Services

Our well completion services business consists of services for hydraulic fracturing, wireline and pumping, completion support, and cementing. It also includes our power solutions natural gas fueling business and our proppant last mile logistics and storage business. Our completion services business operates in several of the most active basins in the continental United States including the Permian, the Marcellus Shale/Utica, the Eagle Ford, Mid-Continental, Haynesville, and the Bakken/Rockies.

### Drilling Products

We serve the energy and mining markets by manufacturing and distributing drill bits through North America and internationally in over 30 countries. Our drilling equipment is used in oil and natural gas exploration and production and in mining operations. We have manufacturing and repair facilities located in Fort Worth, Texas, Leduc, Alberta and Saudi Arabia and repair facilities located in Argentina, Colombia and Oman.

*Recent Developments in Market Conditions and Outlook —* Commodity price volatility in the second quarter of 2023 resulted in a decline in industry activity; commodity prices subsequently increased during the third quarter before declining in the fourth quarter of 2023. Oil prices increased during the first quarter of 2024 and moderately fluctuated during the second quarter of 2024. While natural gas prices declined significantly during the first quarter of 2024, natural gas prices increased slightly during the second quarter of 2024. The current demand for equipment and services remains dependent on macro conditions, including commodity prices, geopolitical environment, inflationary pressures, economic conditions in the United States and elsewhere, as well as customer consolidation and focus by exploration and production companies and service companies on capital returns. Oil prices reached a low of $74.27 per barrel and averaged $81.81 per barrel in the second quarter of 2024, as compared to $77.50 per barrel in the first quarter of 2024. Natural gas prices (based on the Henry Hub Spot Market Price) averaged $2.07 per MMBtu in the second quarter of 2024 as compared to an average of $2.31 per MMBtu in the first quarter of 2024.

Our average active rig count in the United States for the second quarter of 2024 was 114 rigs. This was a decrease from our average active rig count for the first quarter of 2024 of 121. We expect our rig count in the United States will average approximately 108 rigs during the third quarter of 2024. Term contracts help support our operating rig count. Based on contracts in place in the United States as of July 24, 2024, we expect an average of 63 rigs operating under term contracts during the third quarter of 2024 and an average of 39 rigs operating under term contracts during the four quarters ending June 30, 2025.

We maintain a backlog of commitments for contract drilling services under term contracts, which we define as contracts with a duration of six months or more. Our contract drilling backlog in the United States as of June 30, 2024 was approximately $433 million. Approximately 6% of our total contract drilling backlog in the United States at June 30, 2024 is reasonably expected to remain at June 30, 2025. See Note 3 of Notes to unaudited condensed consolidated financial statements for additional information on backlog.

In our Completion Services segment, we expect to see fewer schedule gaps in the third quarter compared to the second quarter of 2024, although we do still expect elevated schedule gaps compared to normal operations. Activity in West Texas is expected to be steady, with segment gains coming from higher activity in natural gas basins compared to the second quarter.

In our Drilling Products segment, we expect a modest increase in international activities in the third quarter of 2024, as well as a seasonal recovery in Canada after the spring breakup. Revenue in the United States is expected to decline slightly due to a lower industry rig count.

We believe we can deliver capital efficient growth over the near-term beyond our expected recovery in the rig count, including through wellsite integration and power distribution.

For the third quarter of 2024, we expect total capital expenditures of approximately $219 million.

*Recent Developments in Business Combinations —* On September 1, 2023, we completed our merger (the “NexTier merger”) with NexTier Oilfield Solutions Inc. (“NexTier”). Each share of common stock of NexTier issued and outstanding immediately prior to the effective time (including outstanding restricted shares) was converted into the right to receive 0.752 shares of our common stock, which based on the closing price of our common stock of $14.91 on September 1, 2023, valued the transaction at approximately $2.8 billion, including the assumption of debt. NexTier is a predominately U.S. land-focused oilfield service provider, with a diverse set of well completion and production services across a variety of active basins.

On August 14, 2023, we completed our acquisition (the “Ulterra acquisition”) of Ulterra Drilling Technologies, L.P. (“Ulterra”). Total consideration for the acquisition included the issuance of 34.9 million shares of our common stock and payment of approximately $373 million of cash (after purchase price adjustments), which based on the closing price of our common stock of $14.94 on August 14, 2023, valued the transaction at closing at approximately $895 million. Ulterra is a global provider of specialized drill bit solutions.

*Recent Developments in Debt Financing —* On April 5, 2024, we entered into a Commitment Increase Agreement (the “Commitment Increase Agreement”), which increased the commitments under our Amended and Restated Credit Agreement, dated as of March 27, 2018 (as modified by the Commitment Increase Agreement and as amended to date, the “Credit Agreement”), by and among us, as borrower, Wells Fargo Bank, National Association, as administrative agent, letter of credit issuer, swing line lender and lender and each of the other letter of credit issuers and lenders party thereto.

The Commitment Increase Agreement increased the commitments under our Credit Agreement to $615 million. The maturity date for $567 million of such commitments is March 27, 2026; and the maturity date for $48.3 million of such commitments is March 27, 2025.

As of June 30, 2024, we had no borrowings outstanding under our revolving credit facility. We had $2.3 million in letters of credit outstanding under the Credit Agreement at June 30, 2024 and, as a result, had available borrowing capacity of approximately $613 million at that date.

*Impact on our Business from Oil and Natural Gas Prices and Other Factors —* Our revenues, profitability and cash flows are highly dependent upon prevailing prices for oil and natural gas, expectations about future prices, and upon our customers’ ability to access, and willingness to deploy, capital to fund their operating and capital expenditures. During periods of improved oil and natural gas prices, the capital spending budgets of oil and natural gas operators tend to expand, which generally results in increased demand for our services. Conversely, in periods when oil and natural gas prices are relatively low or when our customers have a reduced ability to access, or willingness to deploy, capital, the demand for our services generally weakens, and we experience downward pressure on pricing for our services. Even during periods of historically moderate or high prices for oil and natural gas, companies exploring for oil and natural gas may cancel or curtail programs or reduce their levels of capital expenditures for exploration and production for a variety of reasons, which could reduce demand for our services. We may also be impacted by delayed customer payments and payment defaults associated with customer liquidity issues and bankruptcies.

The North American oil and natural gas services industry is cyclical and at times experiences downturns in demand. During these periods, there has been substantially more oil and natural gas service equipment available than necessary to meet demand. As a result, oil and natural gas service contractors have had difficulty sustaining profit margins and, at times, have incurred losses during the downturn periods. We cannot predict either the future level of demand for our oil and natural gas services or future conditions in the oil and natural gas service businesses.

In addition to the dependence on oil and natural gas prices and demand for our services, we are highly impacted by operational risks, competition, labor issues, weather, the availability, from time to time, of products used in our businesses, supplier delays and various other factors that could materially adversely affect our business, financial condition, cash flows and results of operations. Please see Item 1A of this Report and our Annual Report.

For the three months ended June 30, 2024 and March 31, 2024 and the six months ended June 30, 2024 and 2023 our operating revenues consisted of the following (dollars in thousands):

|  | Three Months Ended June 30, 2024 |  | March 31, 2024 |  | Six Months Ended June 30, 2024 |  | June 30, 2023 |  |
| --- | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: |
| Drilling Services | $440,289 | 32.7% | $457,573 | 30.3% | $897,862 | 31.4% | $967,386 | 62.4% |
| Completion Services | 805,373 | 59.7% | 944,997 | 62.6% | 1,750,370 | 61.2% | 543,509 | 35.0% |
| Drilling Products | 86,054 | 6.4% | 89,973 | 6.0% | 176,027 | 6.2% | — | 0.0% |
| Other | 16,478 | 1.2% | 17,817 | 1.1% | 34,295 | 1.2% | 39,792 | 2.6% |
|  | $1,348,194 | 100.0% | $1,510,360 | 100.0% | $2,858,554 | 100.0% | $1,550,687 | 100.0% |

### Results of Operations

Effective as of the third quarter of 2023, we revised our reportable segments to align with certain changes in how our Chief Operating Decision Maker (“CODM”) manages and allocates resources to our business as a result of the Ulterra acquisition and NexTier merger. We now have the following reportable business segments: (i) drilling services, (ii) completion services and (iii) drilling products. Accordingly, we recast our results of operations for the six months ended June 30, 2023 to align with our revised reportable segments.

#### The following tables summarize results of operations by business segment for the three months ended June 30, 2024 and March 31, 2024:

*(dollars in thousands)*

| Drilling Services (1) | Three Months Ended June 30, 2024 | March 31, 2024 | % Change Sequential |
| --- | ---: | ---: | ---: |
| Revenues | $440,289 | $457,573 | (3.8)% |
| Direct operating costs | 261,497 | 271,737 | (3.8)% |
| Adjusted gross profit (2) | 178,792 | 185,836 | (3.8)% |
| Selling, general and administrative | 4,073 | 3,879 | 5.0% |
| Depreciation, amortization and impairment | 98,607 | 92,345 | 6.8% |
| Operating income | $76,112 | $89,612 | (15.1)% |
| Capital expenditures | $58,426 | $82,793 | (29.4)% |
| Operating days – U.S. (3) | 10,388 | 11,024 | (5.8)% |
| Average revenue per operating day – U.S. (3) | $36.43 | $35.68 | 2.1% |
| Average direct operating costs per operating day – U.S. (3) | $20.23 | $19.51 | 3.7% |
| Average adjusted gross profit per operating day – U.S. (3) | $16.19 | $16.17 | 0.2% |

(1) Drilling services segment represents our contract drilling, directional drilling, oilfield technology and electrical controls and automation businesses.

(2) Adjusted gross profit is defined as revenues less direct operating costs (excluding depreciation, amortization and impairment expense). See Non-GAAP Financial Measures below for a reconciliation of GAAP gross profit to adjusted gross profit by segment.

(3) Operational data relates to our contract drilling business. A rig is considered to be operating if it is earning revenue pursuant to a contract on a given day.

Generally, the revenues in our drilling services segment are most impacted by two primary factors: day rates and our average number of rigs operating.

Total revenues and direct operating costs decreased primarily due to a decrease in operating days in our contract drilling business within the United States. Average revenue and average direct operating costs per operating day were relatively flat between sequential quarters.

Capital expenditures decreased primarily due to the timing of order placement and spending on committed deliveries that more heavily impacted the first quarter of 2024.

*(dollars in thousands)*

| Completion Services (1) | Three Months Ended June 30, 2024 | March 31, 2024 | % Change Sequential |
| --- | ---: | ---: | ---: |
| Revenues | $805,373 | $944,997 | (14.8)% |
| Direct operating costs | 653,240 | 745,594 | (12.4)% |
| Adjusted gross profit (2) | 152,133 | 199,403 | (23.7)% |
| Selling, general and administrative | 10,637 | 10,964 | (3.0)% |
| Depreciation, amortization and impairment | 138,693 | 148,680 | (6.7)% |
| Other operating income, net | (7,922) | (9,870) | (19.7)% |
| Operating income | $10,725 | $49,629 | (78.4)% |
| Capital expenditures | $48,728 | $123,377 | (60.5)% |

(1) Completion services represents the combination of well completion business from the NexTier merger and our legacy pressure pumping business.

(2) Adjusted gross profit is defined as revenues less direct operating costs (excluding depreciation, amortization and impairment expense). See Non-GAAP Financial Measures below for a reconciliation of GAAP gross profit to adjusted gross profit by segment.

Completion services revenues and direct operating costs decreased primarily due to lower activity.

Capital expenditures decreased due to the timing of order placement and spending on committed deliveries that more heavily impacted the first quarter of 2024.

*(dollars in thousands)*

| Drilling Products | Three Months Ended June 30, 2024 | March 31, 2024 | % Change Sequential |
| --- | ---: | ---: | ---: |
| Revenues | $86,054 | $89,973 | (4.4)% |
| Direct operating costs | 46,147 | 48,630 | (5.1)% |
| Adjusted gross profit (1) | 39,907 | 41,343 | (3.5)% |
| Selling, general and administrative | 8,092 | 7,661 | 5.6% |
| Depreciation, amortization and impairment | 23,176 | 27,182 | (14.7)% |
| Operating income | $8,639 | $6,500 | 32.9% |
| Capital expenditures | $13,958 | $15,586 | (10.4)% |

(1) Adjusted gross profit is defined as revenues less direct operating costs (excluding depreciation, amortization and impairment expense). See Non-GAAP Financial Measures below for a reconciliation of GAAP gross profit to adjusted gross profit by segment.

Revenues and direct operating costs were relatively flat between sequential quarters.

Direct operating costs and depreciation, amortization and impairment were approximately $1.5 million and $3.2 million higher than they would have otherwise been for the three months ended June 30, 2024, respectively, as a result of the step up to fair value of our drill bits in accordance with purchase accounting. For the three months ended March 31, 2024, direct operating costs and depreciation, amortization and impairment were approximately $2.2 million and $5.8 million higher, respectively, as a result of the step up to fair value of our drill bits.

*(dollars in thousands)*

| Other | Three Months Ended June 30, 2024 | March 31, 2024 | % Change Sequential |
| --- | ---: | ---: | ---: |
| Revenues | $16,478 | $17,817 | (7.5)% |
| Direct operating costs | 10,280 | 11,178 | (8.0)% |
| Adjusted gross profit (1) | 6,198 | 6,639 | (6.6)% |
| Selling, general and administrative | 253 | 240 | 5.4% |
| Depreciation, depletion, amortization and impairment | 5,512 | 5,411 | 1.9% |
| Operating income | $433 | $988 | (56.2)% |
| Capital expenditures | $9,213 | $3,797 | 142.6% |

(1) Adjusted gross profit is defined as revenues less direct operating costs (excluding depreciation, depletion, amortization and impairment expense). See Non-GAAP Financial Measures below for a reconciliation of GAAP gross profit to adjusted gross profit by segment.

Revenue and direct operating costs decreased due to a lower volume of services provided by our oilfield rentals business.

Capital expenditures increased primarily related to incremental spending in our oilfield rentals business.

*(dollars in thousands)*

| Corporate | Three Months Ended June 30, 2024 | March 31, 2024 | % Change Sequential |
| --- | ---: | ---: | ---: |
| Selling, general and administrative | $41,523 | $42,240 | (1.7)% |
| Merger and integration expense | $10,645 | $12,233 | (13.0)% |
| Depreciation | $1,650 | $1,338 | 23.3% |
| Other operating income, net | $(2,864) | $(1,312) | 118.3% |
| Credit loss expense | $(273) | $5,231 | NA |
| Interest income | $1,867 | $2,189 | (14.7)% |
| Interest expense, net of amount capitalized | $(17,913) | $(18,335) | (2.3)% |
| Other income | $224 | $850 | (73.6)% |
| Capital expenditures | $183 | $1,388 | (86.8)% |

Corporate activities were relatively flat between sequential quarters.

### Results of Operations

#### The following tables summarize results of operations by business segment for the six months ended June 30, 2024 and June 30, 2023:

*(dollars in thousands)*

| Drilling Services (1) | Six Months Ended June 30, 2024 | June 30, 2023 | % Change |
| --- | ---: | ---: | ---: |
| Revenues | $897,862 | $967,386 | (7.2%) |
| Direct operating costs | 533,234 | 562,834 | (5.3%) |
| Adjusted gross margin (2) | 364,628 | 404,552 | (9.9%) |
| Selling, general and administrative | 7,952 | 8,240 | (3.5%) |
| Depreciation, amortization and impairment | 190,952 | 181,693 | 5.1% |
| Other operating expenses, net | — | 34 | (100.0%) |
| Operating income | $165,724 | $214,585 | (22.8%) |
| Capital expenditures | $141,219 | $171,913 | (17.9%) |
| Operating days - U.S. (3) | 21,412 | 23,420 | (8.6%) |
| Average revenue per operating day - U.S. (3) | $36.04 | $35.35 | 2.0% |
| Average direct operating costs per operating day - U.S. (3) | $19.86 | $18.96 | 4.8% |
| Average adjusted gross margin per operating day - U.S. (3) | $16.18 | $16.39 | (1.3%) |

(1) Drilling services segment represents our contract drilling, directional drilling, oilfield technology and electrical controls and automation businesses.

(2) Adjusted gross margin is defined as revenues less direct operating costs (excluding depreciation, amortization and impairment expense). See Non-GAAP Financial Measures below for a reconciliation of GAAP gross margin to adjusted gross margin by segment.

(3) Operational data relates to our contract drilling business. A rig is considered to be operating if it is earning revenue pursuant to a contract on a given day.

Total revenues and direct operating costs decreased primarily due to a decrease in operating days in our contract drilling business within the United States. Average revenue and direct operating costs per operating day were relatively flat between sequential quarters.

Capital expenditures decreased primarily due to reduced investment in our ancillary drilling services not included within our contract drilling business.

*(dollars in thousands)*

| Completion Services (1) | Six Months Ended June 30, 2024 | June 30, 2023 | % Change |
| --- | ---: | ---: | ---: |
| Revenues | $1,750,370 | $543,509 | 222.0% |
| Direct operating costs | 1,398,834 | 416,589 | 235.8% |
| Adjusted gross margin (2) | 351,536 | 126,920 | 177.0% |
| Selling, general and administrative | 21,601 | 5,183 | 316.8% |
| Depreciation, amortization and impairment | 287,373 | 52,001 | 452.6% |
| Other operating income, net | (17,792) | — | NA |
| Operating income | $60,354 | $69,736 | (13.5)% |
| Capital expenditures | $172,105 | $51,065 | 237.0% |

(1) Completion services represents the combination of well completion business from the NexTier merger and our legacy pressure pumping business.

(2) Adjusted gross margin is defined as revenues less direct operating costs (excluding depreciation, amortization and impairment expense). See Non-GAAP Financial Measures below for a reconciliation of GAAP gross margin to adjusted gross margin by segment.

The changes for the six months ended June 30, 2024 as compared to June 30, 2023 can be primarily attributed to the NexTier merger, which closed on September 1, 2023. The NexTier merger had a material impact on our reported results of operations. The results for the six months ended June 30, 2024 represent the combination of the well completion business from the NexTier merger and our legacy pressure pumping business. Due to the full integration of our legacy pressure pumping business into the NexTier legal entity in the first quarter of 2024, we are unable to provide a meaningful year-over-year comparison excluding the impact of the NexTier merger.

*(dollars in thousands)*

| Drilling Products | Six Months Ended June 30, 2024 | June 30, 2023 | % Change |
| --- | ---: | ---: | --- |
| Revenues | $176,027 | $— | NA |
| Direct operating costs | 94,777 | — | NA |
| Adjusted gross margin (1) | 81,250 | — | NA |
| Selling, general and administrative | 15,753 | — | NA |
| Depreciation, amortization and impairment | 50,358 | — | NA |
| Operating income | $15,139 | $— | NA |
| Capital expenditures | $29,544 | $— | NA |

(1) Adjusted gross margin is defined as revenues less direct operating costs (excluding depreciation, amortization and impairment expense). See Non-GAAP Financial Measures below for a reconciliation of GAAP gross margin to adjusted gross margin by segment.

The results of our drilling products segment reflect the operations of our Ulterra acquisition, which closed on August 14, 2023. As such, there were no comparable results for the six months ended June 30, 2023.

Direct operating costs and depreciation, amortization and impairment were approximately $3.8 million and $9.1 million higher than they would have otherwise been for the six months ended June 30, 2024, respectively, as a result of the step up to fair value of our drill bits in accordance with purchase accounting.

*(dollars in thousands)*

| Other | Six Months Ended June 30, 2024 | June 30, 2023 | % Change |
| --- | ---: | ---: | ---: |
| Revenues | $34,295 | $39,792 | (13.8)% |
| Direct operating costs | 21,458 | 21,321 | 0.6% |
| Adjusted gross margin (1) | 12,837 | 18,471 | (30.5)% |
| Selling, general and administrative | 493 | 468 | 5.3% |
| Depreciation, depletion, amortization and impairment | 10,923 | 16,627 | (34.3%) |
| Operating income | $1,421 | $1,376 | 3.3% |
| Capital expenditures | $13,010 | $12,415 | 4.8% |

(1) Adjusted gross margin is defined as revenues less direct operating costs (excluding depreciation, depletion, amortization and impairment expense). See Non-GAAP Financial Measures below for a reconciliation of GAAP gross margin to adjusted gross margin by segment.

Revenue decreased due to a lower volume of services provided by our oilfield rentals business.

Depreciation, depletion, amortization and impairment decreased primarily due to a $5.8 million impairment recorded in our oil and natural gas business during the six months ended June 30, 2023.

*(dollars in thousands)*

| Corporate | Six Months Ended June 30, 2024 | June 30, 2023 | % Change |
| --- | ---: | ---: | ---: |
| Selling, general and administrative | $83,763 | $49,932 | 67.8% |
| Merger and integration expense | $22,878 | $7,940 | 188.1% |
| Depreciation | $2,988 | $4,673 | (36.1%) |
| Credit loss expense | $4,958 | $— | NA |
| Other operating income, net | $(4,176) | $(7,393) | (43.5)% |
| Interest income | $4,056 | $2,452 | 65.4% |
| Interest expense | $(36,248) | $(18,564) | 95.3% |
| Other income | $1,074 | $3,809 | (71.8)% |
| Capital expenditures | $1,571 | $14,602 | (89.2%) |

Selling, general and administrative expense increased primarily due to the reorganization of acquired Ulterra and NexTier support personnel to corporate following the NexTier merger and the Ulterra acquisition.

Merger and integration expense increased due to the NexTier merger and the Ulterra acquisition. The increase was primarily attributable to compensation associated with severance and retention payments.

Credit loss expense increased due to a deterioration in the financial condition of a customer.

Interest expense increased primarily due to the offering of 2033 Notes in the third quarter of 2023. See Note 9 of Notes to unaudited condensed consolidated financial statements for additional information on our long-term debt.

The decrease in capital expenditures was primarily due to the purchase of an aircraft in the second quarter of 2023.

### Income Taxes

Our effective income tax rate fluctuates from the U.S. statutory tax rate based on, among other factors, changes in pretax income in jurisdictions with varying statutory tax rates, the impact of U.S. state and local taxes, the realizability of deferred tax assets and other differences related to the recognition of income and expense between GAAP and tax accounting.

Our effective income tax rate for the three months ended June 30, 2024 was 60.5%, compared with 27.9% for the three months ended March 31, 2024. The higher effective income tax rate for the six months ended June 30, 2024 was primarily attributable to the impact of valuation allowances on deferred tax assets between periods, as well as the impact of permanent differences against earnings between periods.

Our effective income tax rate for the six months ended June 30, 2024 was 37.4%, compared with 15.6% for the six months ended June 30, 2023. The higher effective income tax rate for the six months ended June 30, 2024 was primarily attributable to the impact of valuation allowances on deferred tax assets between periods, as well as the impact of permanent differences against earnings between periods.

We continue to monitor income tax developments in the United States and other countries where we have legal entities. We will incorporate into our future financial statements the impacts, if any, of future regulations and additional authoritative guidance when finalized.

### Liquidity and Capital Resources

Our primary sources of liquidity are cash and cash equivalents, availability under our revolving credit facility and cash provided by operating activities. As of June 30, 2024, we had approximately $428 million in working capital, including $75 million of cash and cash equivalents, and approximately $613 million available under our revolving credit facility.

As part of the NexTier merger, we assumed the obligations of NexTier Completions Solutions Inc. (“NCS”) under a Master Loan and Security Agreement (as amended, the “Master Agreement”) with Caterpillar Financial Services Corporation. The Master Agreement allows NCS to enter into secured equipment financing term loans from time to time (the “Equipment Loans”). The

Equipment Loans may be drawn in multiple tranches, with each loan evidenced by a separate promissory note. The Master Agreement and the Equipment Loans contain customary affirmative and negative covenants, including limitations on further encumbrance of the collateral other than the applicable loans under the Master Agreement. We were in compliance with these covenants at June 30, 2024. The Equipment Loans bear interest at a rate of 5.25% per annum, and we pay interest on the 1st of each month. The Equipment Loans will mature on June 1, 2025.

On April 5, 2024, we entered into the Commitment Increase Agreement, which increased the commitments under our Credit Agreement to $615 million. The maturity date for $567 million of such commitments is March 27, 2026; and the maturity date for $48.3 million of such commitments is March 27, 2025.

The Credit Agreement is a committed senior unsecured revolving credit facility that permits aggregate borrowings of up to $615 million, including a letter of credit facility that, at any time outstanding, is limited to $100 million and a swing line facility that, at any time outstanding, is limited to the lesser of $50.0 million and the amount of the swing line provider’s unused commitment.

Loans under the Credit Agreement bear interest by reference, at our election, to the SOFR rate (subject to a 0.10% per annum adjustment) or base rate, in each case subject to a 0% floor. The applicable margin on SOFR rate loans varies from 1.00% to 2.00% and the applicable margin on base rate loans varies from 0.00% to 1.00%, in each case determined based on our credit rating. As of June 30, 2024, the applicable margin on SOFR rate loans was 1.75% and the applicable margin on base rate loans was 0.75%. A letter of credit fee is payable by us equal to the applicable margin for SOFR rate loans times the daily amount available to be drawn under outstanding letters of credit. The commitment fee rate payable to the lenders varies from 0.10% to 0.30% based on our credit rating.

None of our subsidiaries are currently required to be a guarantor under the Credit Agreement. However, if any subsidiary guarantees or incurs debt, which does not qualify for certain limited exceptions and is otherwise, in the aggregate with all other similar debt, in excess of Priority Debt (as defined in the Credit Agreement), such subsidiary is required to become a guarantor under the Credit Agreement.

The Credit Agreement contains representations, warranties, affirmative and negative covenants and events of default and associated remedies that we believe are customary for agreements of this nature, including certain restrictions on our ability and the ability of each of our subsidiaries to grant liens and on the ability of each of our non-guarantor subsidiaries to incur debt. If our credit rating is below investment grade at both Moody’s and S&P, we will become subject to a restricted payment covenant, which would generally require us to have a Pro Forma Debt Service Coverage Ratio (as defined in the Credit Agreement) greater than or equal to 1.50 to 1.00 immediately before and immediately after making any restricted payment. Restricted payments include, among other things, dividend payments, repurchases of our common stock, distributions to holders of our common stock or any other payment or other distribution to third parties on account of our or our subsidiaries’ equity interests. Our credit rating is currently investment grade at both credit rating agencies. The Credit Agreement also requires that our total debt to capitalization ratio, expressed as a percentage, not exceed 50% as of the last day of each fiscal quarter. The Credit Agreement generally defines the total debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the end of the most recently ended fiscal quarter. We were in compliance with these covenants at June 30, 2024.

On March 16, 2015, we entered into a Reimbursement Agreement (the “Reimbursement Agreement”) with The Bank of Nova Scotia (“Scotiabank”), pursuant to which we may from time to time request that Scotiabank issue an unspecified amount of letters of credit. As of June 30, 2024, we had $43.8 million in letters of credit outstanding under the Reimbursement Agreement.

Under the terms of the Reimbursement Agreement, we will reimburse Scotiabank on demand for any amounts that Scotiabank has disbursed under any of our letters of credit issued thereunder. Fees, charges and other reasonable expenses for the issuance of letters of credit are payable by us at the time of issuance at such rates and amounts as are in accordance with Scotiabank’s prevailing practice. We are obligated to pay to Scotiabank interest on all amounts not paid by us on the date of demand or when otherwise due at the LIBOR rate plus 2.25% per annum, calculated daily and payable monthly, in arrears, on the basis of a calendar year for the actual number of days elapsed, with interest on overdue interest at the same rate as on the reimbursement amounts. A letter of credit fee is payable by us equal to 1.50% times the amount of outstanding letters of credit.

We have also agreed that if obligations under the Credit Agreement are secured by liens on any of our or our subsidiaries’ property, then our reimbursement obligations and (to the extent similar obligations would be secured under the Credit Agreement) other obligations under the Reimbursement Agreement and any letters of credit will be equally and ratably secured by all property subject to such liens securing the Credit Agreement.

Pursuant to a Continuing Guaranty dated as of March 16, 2015, our payment obligations under the Reimbursement Agreement are jointly and severally guaranteed as to payment and not as to collection by our subsidiaries that from time to time guarantee payment under the Credit Agreement. None of our subsidiaries are currently required to guarantee payment under the Credit Agreement.

We had $48.0 million of outstanding letters of credit at June 30, 2024, which was comprised of $43.8 million outstanding under the Reimbursement Agreement, $2.3 million outstanding under the Credit Agreement, and $1.9 million outstanding with financial institutions providing for short-term borrowing capacity, overdraft protection and bonding requirements. We maintain these letters of credit primarily for the benefit of various insurance companies as collateral for retrospective premiums and retained losses which could become payable under terms of the underlying insurance contracts and compliance with contractual obligations. These letters of credit expire annually at various times during the year and are typically renewed. As of June 30, 2024, no amounts had been drawn under the letters of credit. As of June 30, 2024, we had $35 million in surety bond exposure issued as financial assurance on an insurance agreement.

Our outstanding long-term debt at June 30, 2024 was $1.2 billion and consisted of $483 million of our 2028 Notes, $345 million of our 2029 Notes, $400 million of our 2033 Notes and $12.6 million of our Equipment Loans. We were in compliance with all covenants under the associated agreements and indentures at June 30, 2024.

For a full description of the Credit Agreement, the Reimbursement Agreement, the 2028 Notes, the 2029 Notes, the 2033 Notes and the Equipment Loans, see Note 9 of Notes to unaudited condensed consolidated financial statements.

### Cash Requirements

We believe our current liquidity, together with cash expected to be generated from operations, should provide us with sufficient ability to fund our current plans to maintain and make improvements to our existing equipment, service our debt, pay cash dividends and repurchase our common stock and senior notes for at least the next 12 months.

If we pursue other opportunities that require capital, we believe we would be able to satisfy these needs through a combination of working capital, cash flows from operating activities, borrowing capacity under our revolving credit facility or additional debt or equity financing. However, there can be no assurance that such capital will be available on reasonable terms, if at all.

A portion of our capital expenditures can be adjusted and managed by us to match market demand and activity levels. For the third quarter, we expect total capital expenditures of approximately $219 million.

We anticipate $41.1 million of expenditures for the remainder of 2024 related to various contractual obligations such as certain commitments to purchase proppants and lease liabilities.

The majority of these expenditures are expected to be used for normal, recurring items necessary to support our business.

During the six months ended June 30, 2024, our sources of cash flow included:

- $563 million from operating activities, and
- $9.3 million in proceeds from the disposal of property and equipment.

During the six months ended June 30, 2024, our uses of cash flow included:

- $357 million to make capital expenditures for the betterment and refurbishment of drilling services and completion services equipment and, to a much lesser extent, equipment for our other businesses, to acquire and procure equipment to support our drilling services, completion services, drilling products, and other operations,
- $230 million for repurchases of our common stock,
- $64.4 million to pay dividends on our common stock, and
- $31.9 million for finance lease payments.

We paid cash dividends during the six months ended June 30, 2024 as follows:

*(in thousands)*

|  | Per Share | Total |
| --- | ---: | ---: |
| Paid on March 15, 2024 | $0.08 | $32,553 |
| Paid on June 17, 2024 | $0.08 | $31,815 |
|  | $0.16 | $64,368 |

On July 24, 2024, our Board of Directors approved a cash dividend on our common stock in the amount of $0.08 per share to be paid on September 16, 2024 to holders of record as of September 3, 2024. The amount and timing of all future dividend payments, if any, are subject to the discretion of the Board of Directors and will depend upon business conditions, results of operations, financial condition, terms of our debt agreements and other factors. Our Board of Directors may, without advance notice, reduce or suspend our dividend to improve our financial flexibility and position our company for long-term success. There can be no assurance that we will pay a dividend in the future.

We may, at any time and from time to time, seek to retire or purchase our outstanding debt for cash through open-market purchases, privately negotiated transactions, redemptions or otherwise. Such repurchases, if any, will be upon such terms and at such prices as we may determine, and will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material.

In September 2013, our Board of Directors approved a stock buyback program. In February 2024, our Board of Directors approved an increase of the authorization under the stock buyback program to allow for an aggregate of $1.0 billion of future share repurchases. All purchases executed to date have been through open market transactions. Purchases under the buyback program are made at management’s discretion, at prevailing prices, subject to market conditions and other factors. Purchases may be made at any time without prior notice. There is no expiration date associated with the buyback program. As of June 30, 2024, we had remaining authorization to purchase approximately $819 million of our outstanding common stock under the stock buyback program. Shares of stock purchased under the buyback program are held as treasury shares.

Treasury stock acquisitions during the six months ended June 30, 2024 were as follows (dollars in thousands):

|  | Shares | Cost |
| --- | ---: | ---: |
| Treasury shares at beginning of period | 105,580,011 | $1,657,675 |
| Purchases pursuant to stock buyback program | 19,821,972 | 219,614 |
| Acquisitions pursuant to long-term incentive plans (1) | 1,146,823 | 12,486 |
| Treasury shares at end of period | 126,548,806 | $1,889,775 |

(1) We withheld 1,146,823 shares during the six months ended June 30, 2024 with respect to employees’ tax withholding obligations upon the vesting of restricted stock units. These shares were acquired at fair market value. These acquisitions were made pursuant to the terms of the Patterson-UTI Energy, Inc. 2021 Long-Term Incentive Plan, as amended, the NexTier Oilfield Solutions Inc. Equity and Incentive Award Plan and the NexTier Oilfield Solutions Inc. (Former C&J Energy) Management Incentive Plan and not pursuant to the stock buyback program.

*Commitments —* As of June 30, 2024, we had commitments to purchase major equipment totaling approximately $154 million. Our completion services segment has entered into agreements to purchase minimum quantities of proppants from certain vendors. As of June 30, 2024, the remaining minimum obligation under these agreements was approximately $25.8 million, of which approximately $16.9 million, $6.5 million, and $2.4 million relate to the remainder of 2024, 2025 and 2026, respectively.

See Note 10 of Notes to unaudited condensed consolidated financial statements for additional information on our current commitments and contingencies as of June 30, 2024.

Operating lease liabilities totaled $51.7 million and finance lease liabilities totaled $30.2 million as of June 30, 2024.

*Trading and Investing —* We have not engaged in trading activities that include high-risk securities, such as derivatives and non-exchange traded contracts. We invest cash primarily in highly liquid, short-term investments such as overnight deposits and money market accounts.

### Non-GAAP Financial Measures

### Adjusted EBITDA

Adjusted earnings before interest, taxes, depreciation and amortization (“Adjusted EBITDA”) is not defined by accounting principles generally accepted in the United States of America (“GAAP”). We define Adjusted EBITDA as net income plus income tax expense, net interest expense, depreciation, depletion, amortization and impairment expense and merger and integration expense. We present Adjusted EBITDA as a supplemental disclosure because we believe it provides to both management and investors additional information with respect to the performance of our fundamental business activities and a comparison of the results of our operations from period to period and against our peers without regard to our financing methods or capital structure. We exclude the items listed above from net income in arriving at Adjusted EBITDA because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDA should not be construed as an alternative to the GAAP measure of net income (loss). Our computations of Adjusted EBITDA may not be the same as similarly titled measures of other companies. Set forth below is a reconciliation of the non-GAAP financial measure of Adjusted EBITDA to the GAAP financial measure of net income (loss).

*(in thousands)*

|  | Three Months Ended June 30, 2024 | March 31, 2024 | Six Months Ended June 30, 2024 | 2023 |
| --- | ---: | ---: | ---: | ---: |
| Net income | $11,621 | $51,706 | $63,327 | $184,292 |
| Income tax expense | 17,785 | 19,997 | 37,782 | 33,950 |
| Net interest expense | 16,046 | 16,146 | 32,192 | 16,112 |
| Depreciation, depletion, amortization and impairment | 267,638 | 274,956 | 542,594 | 254,994 |
| Merger and integration expense | 10,645 | 12,233 | 22,878 | 7,940 |
| Adjusted EBITDA | $323,735 | $375,038 | $698,773 | $497,288 |

39

### Adjusted Gross Profit

We define “Adjusted gross profit” as revenues less direct operating costs (excluding depreciation, depletion, amortization and impairment expense). Adjusted gross profit is included as a supplemental disclosure because it is a useful indicator of our operating performance.

*(in thousands)*

| For the three months ended June 30, 2024 | Drilling Services | Completion Services | Drilling Products | Other |
| --- | ---: | ---: | ---: | ---: |
| Revenues | $440,289 | $805,373 | $86,054 | $16,478 |
| Less direct operating costs | (261,497) | (653,240) | (46,147) | (10,280) |
| Less depreciation, depletion, amortization and impairment | (98,607) | (138,693) | (23,176) | (5,512) |
| GAAP gross profit | 80,185 | 13,440 | 16,731 | 686 |
| Depreciation, depletion, amortization and impairment | 98,607 | 138,693 | 23,176 | 5,512 |
| Adjusted gross profit | $178,792 | $152,133 | $39,907 | $6,198 |
| **For the three months ended March 31, 2024** |  |  |  |  |
| Revenues | $457,573 | $944,997 | $89,973 | $17,817 |
| Less direct operating costs | (271,737) | (745,594) | (48,630) | (11,178) |
| Less depreciation, depletion, amortization and impairment | (92,345) | (148,680) | (27,182) | (5,411) |
| GAAP gross profit | 93,491 | 50,723 | 14,161 | 1,228 |
| Depreciation, depletion, amortization and impairment | 92,345 | 148,680 | 27,182 | 5,411 |
| Adjusted gross profit | $185,836 | $199,403 | $41,343 | $6,639 |
| **For the six months ended June 30, 2024** |  |  |  |  |
| Revenues | $897,862 | $1,750,370 | $176,027 | $34,295 |
| Less direct operating costs | (533,234) | (1,398,834) | (94,777) | (21,458) |
| Less depreciation, depletion, amortization and impairment | (190,952) | (287,373) | (50,358) | (10,923) |
| GAAP gross margin | 173,676 | 64,163 | 30,892 | 1,914 |
| Depreciation, depletion, amortization and impairment | 190,952 | 287,373 | 50,358 | 10,923 |
| Adjusted gross margin | $364,628 | $351,536 | $81,250 | $12,837 |
| **For the six months ended June 30, 2023** |  |  |  |  |
| Revenues | $967,386 | $543,509 | $— | $39,792 |
| Less direct operating costs | (562,834) | (416,589) | — | (21,321) |
| Less depreciation, depletion, amortization and impairment | (181,693) | (52,001) | — | (16,627) |
| GAAP gross profit | 222,859 | 74,919 | — | 1,844 |
| Depreciation, depletion, amortization and impairment | 181,693 | 52,001 | — | 16,627 |
| Adjusted gross profit | $404,552 | $126,920 | $— | $18,471 |

### Critical Accounting Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“GAAP”) requires management to make certain estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from such estimates. There have been no material changes to our critical accounting estimates previously disclosed in Item 7 of our Annual Report, except as follows:

*Goodwill —* We assess goodwill at least annually on July 31, or more frequently when events and circumstances occur indicating recorded goodwill may be impaired. Goodwill is tested at the reporting unit level, which is at or one level below our operating segments. We determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying value after considering qualitative, market and other factors, and if that is the case, any necessary goodwill impairment is determined using a quantitative impairment test. If the resulting fair value of goodwill is less than the carrying value of goodwill, an impairment loss would be recognized for the amount of the shortfall.

We determined our drilling products operating segment consists of a single reporting unit and, accordingly, goodwill acquired from the Ulterra acquisition was allocated to that reporting unit. We determined our completion services operating segment consists of two reporting units; completion services, which is primarily comprised of our hydraulic fracturing operations and other integrated service offerings, and cementing services.

During the second quarter of 2024, we lowered our expectations with respect to near-term future activity levels in certain of our operating segments. This decline was deemed a triggering event that warranted a quantitative assessment for goodwill impairment.

We estimated the fair value of the drilling products and the completion services reporting units using the income approach. Under this approach, we used a discounted cash flow model, which utilizes present values of cash flows to estimate fair value. Forecasted cash flows considered known market conditions in the second quarter of 2024, and management's anticipated business outlook for each reporting unit. Future cash flows were projected based on estimates of revenue, gross profit, selling, general and administrative expense, changes in working capital, and capital expenditures. The terminal period used within the discounted cash flow model for each reporting unit consisted of a 1% growth estimate. Future cash flows were then discounted using a market-participant, risk-adjusted weighted average cost of capital of 11% for the drilling products reporting unit and 12% for the completion services reporting unit.

The forecast for the drilling products reporting unit assumes continued growth domestically as well as in international markets. Geopolitical instability in regions in which we expect to maintain and grow market share, a global decrease in the demand of drilling products, or other unforeseen macroeconomic considerations could negatively impact the key assumptions used in our goodwill assessment for our drilling products reporting unit.

The forecast for the completion services reporting unit assumes lower activity in 2024 compared to 2023 exit levels and increases in activity of 7% to 9% beginning in 2025 through 2027, which was based on rig count forecasts in the second quarter and estimated market share. A sustained decrease in oil prices and rig count could negatively affect the key assumptions used in our goodwill assessment for completion services.

Based on the results of the goodwill impairment tests, the fair values of the drilling products, completion services, and cementing services reporting units exceeded their carrying values by approximately 10%, 9%, and 77%, respectively. Accordingly, no impairment was recorded for any of the reporting units.

Assuming all changes are isolated, a decrease of 100 bps in our long-term revenue growth rate for our drilling products and completion services reporting unit would reduce our estimated fair values by approximately 5%, while a 100 bps increase to our discount rate would reduce our estimated fair values by approximately 8%, respectively.

A decrease in fair value resulting from unfavorable changes to these assumptions, or others, could result in goodwill impairment in future periods that could be material to our results of operations and financial statements as a whole.

### Recently Issued Accounting Standards

See Note 1 of Notes to unaudited condensed consolidated financial statements for a discussion of the impact of recently issued accounting standards.

### Volatility of Oil and Natural Gas Prices and its Impact on Operations and Financial Condition

Our revenues, profitability and cash flows are highly dependent upon prevailing prices for oil and natural gas and expectations about future prices. The current demand for equipment and services remains dependent on macro conditions, including commodity prices, geopolitical environment, inflationary pressures, economic conditions in the United States and elsewhere, as well as customer consolidation and focus by exploration and production companies and service companies on capital returns. Commodity price volatility in the second quarter of 2023 resulted in a decline in industry activity; commodity prices subsequently increased during the third quarter before declining in the fourth quarter of 2023. Oil prices increased during the first quarter of 2024 and moderately fluctuated during the second quarter of 2024. While natural gas prices declined significantly during the first quarter of 2024, natural gas prices increased slightly during the second quarter of 2024. Oil prices averaged $81.81 per barrel the second quarter of 2024, as compared to $77.50 per barrel in the first quarter of 2024. Natural gas prices (based on the Henry Hub Spot Market Price) averaged $2.07 per MMBtu in the second quarter of 2024 as compared to an average of $2.31 per MMBtu in the first quarter of 2024.

In light of these and other factors, we expect oil and natural gas prices to continue to be volatile and to affect our financial condition, operations and ability to access sources of capital. Higher oil and natural gas prices do not necessarily result in increased activity because demand for our services is generally driven by our customers’ expectations of future oil and natural gas prices, as well as our customers’ ability to access, and willingness to deploy, capital to fund their operating and capital expenditures. A decline in demand for oil and natural gas, prolonged low oil or natural gas prices, expectations of decreases in oil and natural gas prices or a reduction in the ability of our customers to access capital would likely result in reduced capital expenditures by our customers and decreased demand for our services, which could have a material adverse effect on our operating results, financial condition and cash flows. Even during periods of historically moderate or high prices for oil and natural gas, companies exploring for oil and natural gas may cancel or curtail programs or reduce their levels of capital expenditures for exploration and production for a variety of reasons, which could reduce demand for our services.

## Market risk

As filed, 2,517 characters.

We may be exposed to certain market risks arising from the use of financial instruments in the ordinary course of business. For quantitative and qualitative disclosures about market risk, see Part II, Item 7A, “Quantitative and Qualitative Disclosures About Market Risk,” in our Annual Report. There have been no material changes in our exposure to market risk.

As of June 30, 2024, we would have had exposure to interest rate market risk associated with any outstanding borrowings and letters of credit that we had under the Credit Agreement and amounts owed under the Reimbursement Agreement.

Loans under the Credit Agreement bear interest by reference, at our election, to the SOFR rate (subject to a 0.10% per annum adjustment) or base rate, in each case subject to a 0% floor. The applicable margin on SOFR rate loans varies from 1.00% to 2.00% and the applicable margin on base rate loans varies from 0.00% to 1.00%, in each case determined based on our credit rating. As of June 30, 2024, the applicable margin on SOFR rate loans was 1.75% and the applicable margin on base rate loans was 0.75%. A letter of credit fee is payable by us equal to the applicable margin for SOFR rate loans times the daily amount available to be drawn under outstanding letters of credit. The commitment fee rate payable to the lenders varies from 0.10% to 0.30% based on our credit rating. As of June 30, 2024, we had $2.3 million in letters of credit outstanding under the Credit Agreement and, as a result, had available borrowing capacity of approximately $613 million at that date.

Under the terms of the Reimbursement Agreement, we will reimburse Scotiabank on demand for any amounts that Scotiabank has disbursed under any of our letters of credit issued thereunder. We are obligated to pay Scotiabank interest on all amounts not paid by us on the date of demand or when otherwise due at the LIBOR rate plus 2.25% per annum.

Some of our revenues in foreign countries are denominated in U.S. dollars, and therefore, changes in foreign currency exchange rates impact our earnings to the extent that costs associated with those U.S. dollar revenues are denominated in the local currency. Similarly, some of our revenues are denominated in foreign currencies, but have associated U.S. dollar costs, which also give rise to foreign currency exchange rate exposure.

The carrying values of cash and cash equivalents, trade receivables and accounts payable approximate fair value due to the short-term maturity of these items.

## Controls and procedures

As filed, 1,405 characters.

*Disclosure Controls and Procedures —* We maintain disclosure controls and procedures (as such terms are defined in Rules 13a-15(e) and 15d-15(e) promulgated under the Exchange Act), designed to ensure that the information required to be disclosed in the reports that we file with the SEC under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), as appropriate, to allow timely decisions regarding required disclosure.

Under the supervision and with the participation of our management, including our CEO and CFO, we conducted an evaluation of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this Quarterly Report on Form 10‑Q. Based on that evaluation, our CEO and CFO concluded that our disclosure controls and procedures were effective as of June 30, 2024.

*Changes in Internal Control Over Financial Reporting —*There were no changes in our internal control over financial reporting during our most recently completed fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting, as defined in Rule 13a-15(f) under the Exchange Act.

Filed Jul 29, 2024.
Source: SEC EDGAR, the filing index for accession 0001628280-24-033296. Last ingested by Listed: Oct 24, 2026, 14:59 ET. No prices; not investment advice.