Precision Drilling Corporation Announces 2016 Third Quarter Financial Results
(firmenpresse) - CALGARY, ALBERTA -- (Marketwired) -- 10/21/16 -- Precision Drilling Corporation (TSX: PD)(NYSE: PDS) -
(Canadian dollars except as indicated)
This news release contains "forward-looking information and statements" within the meaning of applicable securities laws. For a full disclosure of the forward-looking information and statements and the risks to which they are subject, see the "Cautionary Statement Regarding Forward-Looking Information and Statements" later in this news release.
For the third quarter of 2016, we recorded earnings before income taxes, gain on repurchase of unsecured senior notes, finance charges, foreign exchange, impairment of goodwill, impairment of property, plant and equipment and depreciation and amortization (adjusted EBITDA see "Additional GAAP Measures") of $41 million, 63% lower than the third quarter of 2015. Our activity for the quarter, as measured by drilling rig utilization days, decreased 37% in Canada, 42% in the U.S. and 36% internationally, compared to the third quarter of 2015. Our adjusted EBITDA as a percentage of revenue was 21% this quarter, compared to 30% in the third quarter of 2015. The decrease in adjusted EBITDA as a percent of revenue was mainly due to decreased activity in all of our businesses and lower spot market pricing.
We recorded a net loss this quarter of $47 million, or $0.16 per diluted share, compared to a net loss of $87 million, or $0.30 per diluted share, in the third quarter of 2015.
During the third quarter of 2015, significant decreases in industry activity resulting from the decline in oil and natural gas prices and its impact on current and future business were indicators of impairment in some of our cash generating asset groups resulting in an after tax impairment charges of $74 million, or $0.25 per share.
Revenue this quarter was $202 million or 45% lower than the third quarter of 2015, mainly due to decreased activity in all of our operations. Revenue from our Contract Drilling Services and Completion and Production Services segments decreased over the comparative prior year period by 45% and 44%, respectively.
Net loss for the first nine months of 2016 was $125 million, or $0.43 per diluted share, compared to a net loss of $92 million, or $0.32 per diluted share in 2015, while revenue was $668 million, or 45% less than 2015.
Our current expected capital plan for 2016 is $222 million, an increase of $20 million compared to the $202 million capital plan announced in July 2016. The capital increase relates to upgrade capital backed by customer contracts.
Kevin Neveu, Precision''s President and Chief Executive Officer, stated: "Customer sentiment has substantially improved on the backdrop of strengthening commodity prices supported by OPEC strategic intentions and improving supply and demand fundamentals. This improved outlook is evident in the conversations we are having with customers, but more importantly in our activity increases, recent contract bookings and improving pricing environment. We continue to remain cautious as we believe this optimism may be fragile and sensitive to commodity price volatility."
"Earlier this month our fourth rig in Kuwait commenced operations and we expect the fifth rig to start later in November. Both rigs were on budget and delivered ahead of schedule. We are pleased with our growth in this region, and with improved commodity prices we expect customer inquiries will increase."
"During the third quarter, we gained visibility through rig commitments in both the U.S. and Canada and report seven rig years added to our 2017 contract book, bringing average rigs under contract for next year to 42. With 37 rigs operating in the U.S. today, our activity is up 70% from second quarter lows, while the industry increase is approximately 35%. We believe our market share increase and contract additions reflect both the desirability of Precision''s high performance Super Triple rigs and our customers'' improving outlook."
"While the Permian Basin is attracting the most attention, Precision has met customer needs reactivating rigs in several U.S. basins including the Permian, STACK, SCOOP, DJ, Marcellus and Bakken. Customer demand for XY walking, long-reach capable rigs is strong, industry supply is limited and pricing power is emerging as we have begun to successfully implement price increases on our Super Triple rigs."
"In Canada, while industry activity has seasonally improved and is now approaching 2015 levels, it is still historically low and pricing remains highly competitive. For Precision, the Canadian Deep Basin continues to be an area of strength where Super Triple rigs have a strong market share. We expect this segment of our fleet to be fully utilized through the coming winter drilling season."
"At the end of the quarter, we had a cash balance of $352 million and an undrawn revolving credit facility. With improved visibility during the quarter our capital structure priorities continued to evolve from solely protecting cash balances, to taking additional steps to reduce total debt. In 2016, Precision has repurchased approximately US$56 million of face value debt from our 2020 and 2021 notes, reducing total debt levels and generating interest savings of approximately $5 million annually. We intend to continue reducing our total debt levels, while ensuring adequate liquidity, using cash and cash flow from operations over the next few years."
"For the remainder of the year, we will continue to focus on providing operational excellence to the field, reactivating rigs in multiple basins in the U.S., preparing for winter drilling season in Canada, and keeping an active recruitment and training program to crew up rigs. We have reactivated 51 rigs since 2016 lows and are pleased to have hired nearly 1,000 field personnel, many of whom were previously part of the Precision family," concluded Mr. Neveu.
SELECT FINANCIAL AND OPERATING INFORMATION
Adjusted EBITDA and funds provided by operations are additional GAAP measures. See "ADDITIONAL GAAP MEASURES".
Financial Highlights
Operating Highlights
Financial Position
Our portfolio of term customer contracts, a scalable operating cost structure and economies achieved through vertical integration of the supply chain all help us manage our business through the industry cycles.
Precision''s strategic priorities for 2016 are as follows:
For the third quarter of 2016, the average AECO natural gas price and the average West Texas Intermediate price of oil were lower than the 2015 comparable averages while the average Henry Hub natural gas price was higher.
Summary for the three months ended September 30, 2016:
Summary for the nine months ended September 30, 2016:
OUTLOOK
Contracts
Our portfolio of term customer contracts provides a base level of activity and revenue. As of October 20, 2016, for the fourth quarter of 2016 we had, on average, term contracts for 27 rigs in Canada, 24 in the U.S. and eight internationally and an average of 31 rigs contracted in Canada, 23 in the U.S. and seven internationally for the full year. As of October 20, 2016, for the full year of 2017 we had a total average of 42 rigs on term contract including 19 in Canada, 15 in the U.S. and eight internationally. In Canada, term contracted rigs normally generate 250 utilization days per year because of the seasonal nature of well site access. In most regions in the U.S. and internationally, term contracts normally generate 365 utilization days per year.
Drilling Activity
In the U.S., our average active rig count in the quarter was 29 rigs, down 22 rigs over the third quarter in 2015 but up five rigs from the second quarter of 2016. We currently have 37 rigs active in the U.S.
In Canada, our average active rig count in the quarter was 31 rigs, a decrease of 18 over the third quarter in 2015 but up 18 rigs from the second quarter of 2016. We currently have 45 rigs active in Canada.
In general, to date in 2016, lower oil prices have caused producers to significantly reduce drilling budgets decreasing demand for drilling rigs, resulting in pricing pressure on spot market day rates. We have recently experienced increased activity and if current commodity prices hold we expect our customers to increase their capital budgets for 2017. We expect Tier 1 rigs to remain the preferred rigs of customers globally and for us to benefit from our completed fleet enhancements.
Internationally, our average active rig count in the quarter was seven rigs, down four rigs over the third quarter in 2015 and in line with the second quarter of 2016. The decrease from the prior year period is the result of three fewer rigs working in Mexico and no rigs currently working in Kurdistan. We currently have eight rigs active internationally. In Kuwait, one new-build rig began working in October and the second new-build rig is expected to begin working later in the fourth quarter.
Industry Conditions
To date in 2016, drilling activity has decreased relative to this time last year for both Canada and the U.S. According to industry sources, as of October 14, 2016, the U.S. active land drilling rig count was down approximately 32% from the same point last year and the Canadian active land drilling rig count was down approximately 9%. The decrease in the North American rig count has resulted in the trend of high-grading toward Tier 1 rigs, which continue to show relative strength given the current market conditions.
In Canada there has been strength in natural gas and gas liquids drilling activity related to deep basin drilling in northwestern Alberta and northeastern British Columbia while the trend towards oil-directed drilling in the U.S. continues. To date in 2016, approximately 48% of the Canadian industry''s active rigs and 80% of the U.S. industry''s active rigs were drilling for oil targets, compared to 45% for Canada and 77% for the U.S. at the same time last year.
Capital Spending
Capital spending in 2016 is expected to be $222 million:
SEGMENTED FINANCIAL RESULTS
Precision''s operations are reported in two segments: the Contract Drilling Services segment, which includes the drilling rig, directional drilling, oilfield supply and manufacturing divisions; and the Completion and Production Services segment, which includes the service rig, snubbing, coil tubing, rental, camp and catering and wastewater treatment divisions.
SEGMENT REVIEW OF CONTRACT DRILLING SERVICES
Revenue from Contract Drilling Services was $178 million this quarter, or 45% lower than the third quarter of 2015, while adjusted EBITDA decreased by 56% to $52 million. The decreases were mainly due to lower drilling rig utilization days in our Canadian, U.S. and international contract drilling businesses.
Drilling rig utilization days in Canada (drilling days plus move days) were 2,853 during the third quarter of 2016, a decrease of 37% compared to 2015 primarily due to the decrease in industry activity resulting from lower commodity prices. Drilling rig utilization days in the U.S. were 2,689 or 42% lower than the same quarter of 2015 as U.S. activity was down due to lower industry activity. Drilling rig utilization days in our international business were 644 or 36% lower than the same quarter of 2015 due to lower activity in Mexico and the Middle East.
Compared to the same quarter in 2015, drilling rig revenue per utilization day was down 22% in Canada due to the decline of spot market rates as industry activity has dropped. Drilling rig revenue per utilization day for the current quarter in the U.S. was down 9% from the prior comparative period, while international revenue per day was up 13%. The decrease in the U.S. average rate was due to lower spot market rates, a lower percentage of revenue coming from turnkey activity, and lower relative idle but contracted revenue. International revenue per day was up due to rig mix.
In Canada, 33% of utilization days in the quarter were generated from rigs under term contract, compared to 54% in the third quarter of 2015. In the U.S., 53% of utilization days were generated from rigs under term contract as compared to 71% in the third quarter of 2015. At the end of the quarter, we had 29 drilling rigs under contract in Canada, 22 in the U.S. and seven internationally.
Operating costs were 65% of revenue for the quarter, which was six percentage points higher than the prior year period. On a per utilization day basis, operating costs for the drilling rig division in Canada were lower than the prior year primarily because of 2015 move rig move costs partially offset by the impact of fixed costs on lower activity and cost saving initiatives. In the U.S., operating costs for the quarter on a per day basis were lower than the prior year primarily due to lower turnkey activity and cost saving initiatives partially offset by fixed costs spread over lower activity.
General and administrative costs are lower than the prior year by $3 million due to cost saving initiatives taken throughout 2015 and in the first nine months of 2016.
Restructuring costs in the quarter relate to cost cutting measures taken in response to the continued downturn in industry activity levels.
Depreciation expense in the quarter was 24% lower than in the third quarter of 2015 because of a lower asset base after decommissioning equipment and the recording of an impairment charge to our property, plant and equipment in the fourth quarter of 2015 partially offset by new-build rigs deployed in 2015 and 2016.
SEGMENT REVIEW OF COMPLETION AND PRODUCTION SERVICES
Revenue from Completion and Production Services was down $19 million or 44% compared to the third quarter of 2015 due to lower activity levels in all service lines and lower average rates. In response to lower oil prices, customers curtailed spending and activity including well completion and production programs. Our well servicing activity in the quarter was down 28% from the third quarter of 2015. Approximately 83% of our third quarter Canadian service rig activity was oil related.
During the quarter, Completion and Production Services generated 90% of its revenue from Canadian and 10% from U.S. operations.
Average service rig revenue per operating hour in the third quarter was $599 or $187 lower than the third quarter of 2015. The decrease was primarily the result of industry pricing pressure.
Adjusted EBITDA was $4 million lower than the third quarter of 2015 due to a decline in activity and pricing.
Operating costs as a percentage of revenue increased to 91% in the third quarter of 2016, from 86% in the third quarter of 2015. The increase is the result of the impact of fixed costs spread across lower activity levels, as well as lower revenue from pricing pressure.
Depreciation in the quarter was 22% lower than the third quarter of 2015 because of a lower asset base after an impairment charge in the third quarter of 2015.
SEGMENT REVIEW OF CORPORATE AND OTHER
Our Corporate and Other segment provides support functions to our operating segments. The Corporate and Other segment had an adjusted EBITDA loss of $12 million for the third quarter of 2016, slightly higher than the prior year comparable as higher share based incentive compensation was partially offset by cost saving initiatives.
OTHER ITEMS
Net finance charges were $35 million, in line with the third quarter of 2015.
Income tax expense for the quarter was a recovery of $36 million compared with a recovery of $46 million in the same quarter in 2015. Income tax expense is recognized by applying the income tax rate expected for the full financial year to the pre-tax income of the interim reporting period with adjustments for transactions specific to the quarter.
LIQUIDITY AND CAPITAL RESOURCES
The oilfield services business is inherently cyclical in nature. To manage this, we focus on maintaining a strong balance sheet in order to have the financial flexibility we need to continue to manage our growth and cash flow throughout the business cycle.
We apply a disciplined approach to managing and tracking results of our operations to keep costs down. We maintain a variable cost structure so we can respond to changes in demand.
Our maintenance capital expenditures are tightly governed by and highly responsive to activity levels with additional cost savings leverage provided through our internal manufacturing and supply divisions. Term contracts on expansion capital for new-build rig programs provide more certainty of future revenues and return on our capital investments.
Liquidity
In April, 2016 we agreed with our lending group to the following amendments to our senior credit facility:
During the year we have acquired and cancelled US$28 million face value of our 6.625% unsecured senior notes due 2020 and US$28 million face value of our 6.5% unsecured senior notes due 2021 for a total of $64 million, realizing a total gain on repurchase of $10 million.
As at September 30, 2016 we had $2,028 million outstanding under our senior unsecured notes. The current blended cash interest cost of our debt is approximately 6.2%.
Covenants
Senior Facility
The senior credit facility requires that we comply with certain financial covenants including a leverage ratio of consolidated senior debt to earnings before interest, taxes, depreciation and amortization as defined in the agreement (Adjusted EBITDA) of less than 2.5:1. For purposes of calculating the leverage ratio consolidated senior debt only includes secured indebtedness. Adjusted EBITDA, as defined in our revolving term facility, agreement differs from Adjusted EBITDA as defined under Additional GAAP Measures by the exclusion of bad debt expense, restructuring costs and certain foreign exchange amounts. As at September 30, 2016 our consolidated senior debt to Adjusted EBITDA ratio was negative 0.80:1.
Under the senior credit facility we are required to maintain an Adjusted EBITDA coverage ratio, calculated as Adjusted EBITDA to interest expense, of greater than 1.5:1 reverting to 2.5:1 for periods ending after March 31, 2018 for the most recent four consecutive fiscal quarters. As at September 30, 2016 our Adjusted EBITDA coverage ratio was 2.12:1.
The senior credit facility also prevents us from making distributions prior to April 1, 2018 and restricts our ability to repurchase our unsecured notes subject to a pro forma liquidity test of US$500 million.
In addition, the senior credit facility contains certain covenants that place restrictions on our ability to incur or assume additional indebtedness; dispose of assets; pay dividends, share redemptions or other distributions; change our primary business; incur liens on assets; engage in transactions with affiliates; enter into mergers, consolidations or amalgamations; and enter into speculative swap agreements.
At September 30, 2016, we were in compliance with the covenants of the senior credit facility.
Senior Notes
The senior notes require that we comply with certain financial covenants including an incurrence based test of Adjusted EBITDA, as defined in the senior note agreements, to interest coverage ratio of greater than 2.0:1 for the most recent four consecutive fiscal quarters. In the event that our Adjusted EBITDA to interest coverage ratio is less than 2.0:1 for the most recent four consecutive fiscal quarters the senior notes restrict our ability to incur additional indebtedness. As at September 30, 2016, Precision is in compliance with this covenant. Based on company projections for the fourth quarter of 2016, the possibility exists that we will not meet the minimum ratio of 2.0:1 for the most recent four consecutive quarters. If this occurs, it would limit our ability to incur additional indebtedness, except as permitted under the agreements, until such time as we are in compliance but would not restrict our access to available funds under the senior credit facility or to refinance existing debt. Furthermore, it does not give rise to any cross-covenant violations, give the lenders the right to demand repayment of any outstanding portion of the senior notes prior to the stated maturity dates, or provide any other forms of recourse to the lenders. The senior notes contain a restricted payments covenant that limits our ability to make payments in the nature of dividends, distributions and repurchases from shareholders. This restricted payment basket grows by, among other things, 50% of consolidated net earnings and decreases by 100% of consolidated net losses as defined in the note agreements, and payments made to shareholders. As at September 30, 2016 our restricted payments basket is negative and we are no longer able to make dividend payments until such time as the basket once again becomes positive. For further information please see the senior note indentures which are available on SEDAR and EDGAR.
In addition, the senior notes contain certain covenants that limit our ability, and the ability of certain subsidiaries, to incur additional indebtedness and issue preferred shares; create liens; create or permit to exist restrictions on our ability or certain subsidiaries to make certain payments and distributions; engage in amalgamations, mergers or consolidations; make certain dispositions and engage in transactions with affiliates. At September 30, 2016, we were in compliance with the covenants of our senior notes.
Hedge of investments in foreign operations
We utilize foreign currency long-term debt to hedge our exposure to changes in the carrying values of our net investment in certain foreign operations as a result of changes in foreign exchange rates.
We have designated our U.S. dollar denominated long-term debt as a net investment hedge in our U.S. operations and other foreign operations that have a U.S. dollar functional currency. To be accounted for as a hedge, the foreign currency denominated long-term debt must be designated and documented as such and must be effective at inception and on an ongoing basis. We recognize the effective amount of this hedge (net of tax) in other comprehensive income. We recognize ineffective amounts (if any) in earnings.
Average shares outstanding
The following table reconciles the weighted average shares outstanding used in computing basic and diluted earnings per share:
ADDITIONAL GAAP MEASURES
We reference Generally Accepted Accounting Principles (GAAP) measures that are not defined terms under International Financial Reporting Standards to assess performance because we believe they provide useful supplemental information to investors.
Adjusted EBITDA
We believe that adjusted EBITDA (earnings before income taxes, gain on repurchase of unsecured senior notes, financing charges, foreign exchange, impairment of goodwill, impairment of property, plant and equipment and depreciation and amortization) as reported in the Consolidated Statement of Loss is a useful measure, because it gives an indication of the results from our principal business activities prior to consideration of how our activities are financed and the impact of foreign exchange, taxation and non-cash depreciation and amortization charges.
Operating Earnings (Loss)
We believe that operating earnings (loss), as reported in the Consolidated Statements of Loss, is a useful measure because it provides an indication of the results of our principal business activities before consideration of how those activities are financed and the impact of foreign exchange and taxation.
Funds Provided By (Used In) Operations
We believe that funds provided by (used in) operations, as reported in the Consolidated Statements of Cash Flow is a useful measure because it provides an indication of the funds our principal business activities generate prior to consideration of working capital, which is primarily made up of highly liquid balances.
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION AND STATEMENTS
Certain statements contained in this report, including statements that contain words such as "could", "should", "can", "anticipate", "estimate", "intend", "plan", "expect", "believe", "will", "may", "continue", "project", "potential" and similar expressions and statements relating to matters that are not historical facts constitute "forward-looking information" within the meaning of applicable Canadian securities legislation and "forward-looking statements" within the meaning of the "safe harbor" provisions of the United States Private Securities Litigation Reform Act of 1995 (collectively, "forward-looking information and statements").
In particular, forward looking information and statements include, but are not limited to, the following:
These forward-looking information and statements are based on certain assumptions and analysis made by Precision in light of our experience and our perception of historical trends, current conditions, expected future developments and other factors we believe are appropriate under the circumstances. These include, among other things:
Undue reliance should not be placed on forward-looking information and statements. Whether actual results, performance or achievements will conform to our expectations and predictions is subject to a number of known and unknown risks and uncertainties which could cause actual results to differ materially from our expectations. Such risks and uncertainties include, but are not limited to:
Readers are cautioned that the forgoing list of risk factors is not exhaustive. Additional information on these and other factors that could affect our business, operations or financial results are included in reports on file with applicable securities regulatory authorities, including but not limited to Precision''s Annual Information Form for the year ended December 31, 2015, which may be accessed on Precision''s SEDAR profile at or under Precision''s EDGAR profile at . The forward-looking information and statements contained in this news release are made as of the date hereof and Precision undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a results of new information, future events or otherwise, except as required by law.
INTERIM CONSOLIDATED STATEMENTS OF FINANCIAL POSITION (UNAUDITED)
INTERIM CONSOLIDATED STATEMENTS OF LOSS (UNAUDITED)
INTERIM CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS (UNAUDITED)
INTERIM CONSOLIDATED STATEMENTS OF CASH FLOW (UNAUDITED)
INTERIM CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (UNAUDITED)
THIRD QUARTER 2016 EARNINGS CONFERENCE CALL AND WEBCAST
Precision Drilling Corporation has scheduled a conference call and webcast to begin promptly at 12:00 p.m. MT (2:00 p.m. ET) on Friday, October 21, 2016.
The conference call dial in numbers are 1-866-696-5910 or 416-340-2217.
A live webcast of the conference call will be accessible on Precision''s website at by selecting "Investor Centre", then "Webcasts and Presentations". Shortly after the live webcast, an archived version will be available for approximately 30 days.
An archived recording of the conference call will be available approximately one hour after the completion of the call until November 21, 2016 by dialing 1-800-408-3053 or 905-694-9451, pass code 5065869
About Precision
Precision is a leading provider of safe and High Performance, High Value services to the oil and gas industry. Precision provides customers with access to an extensive fleet of contract drilling rigs, directional drilling services, well service and snubbing rigs, coil tubing services, camps, rental equipment, and wastewater treatment units backed by a comprehensive mix of technical support services and skilled, experienced personnel.
Precision is headquartered in Calgary, Alberta, Canada. Precision is listed on the Toronto Stock Exchange under the trading symbol "PD" and on the New York Stock Exchange under the trading symbol "PDS".
Contacts:
Carey Ford
Senior Vice President & Chief Financial Officer
Precision Drilling Corporation
403.716.4566
403.716.4755 (FAX)
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Datum: 21.10.2016 - 04:00 Uhr
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