CALGARY, Alberta, Aug. 02, 2018 (GLOBE NEWSWIRE) -- Commenting on second quarter 2018 results, Steve Laut, Executive Vice-Chairman of Canadian Natural stated, "The Company's balanced strategy was once again evident in the quarter as our robust long life low decline asset base provided record quarterly funds flow of approximately $2.7 billion. The allocation of funds flow was balanced among our four pillars to maximize value for our shareholders through strengthening the balance sheet, returns to shareholders through dividends and share buybacks, economic resource development, and some minor opportunistic acquisitions year to date. The Company's ability to execute on our strategy is reflected in our second quarter results, and continues a long track record of strong results."
Canadian Natural's President, Tim McKay, added, "In the second quarter of 2018, operations were strong and cost control remained a focus, specifically at our Oil Sands Mining and Upgrading assets, where costs continue to come down. Operating costs of $22.94/bbl (US$17.77/bbl) of Synthetic Crude Oil ("SCO") were impressive given the successfully completed turnaround and pit stop activities in the quarter.
Canadian Natural's ability to effectively allocate capital was demonstrated in the quarter as we have made strategic and proactive decisions to take advantage of our large, balanced and diverse asset base due to changing market conditions. Our asset base is a key competitive advantage providing significant capital flexibility and as a result, to maximize value, we are shifting capital from primary heavy crude oil to light crude oil.
At Kirby North, top tier execution and strong productivity have resulted in accelerating the projects time line, bringing forward targeted first oil of the project's 40,000 bbl/d, by three months into Q4/19, one quarter earlier than originally planned.
At Horizon, the Company has identified opportunities to increase reliability, lower costs and add production growth of between 75,000 bbl/d and 95,000 bbl/d in the near and long term. The near term opportunities are targeted to add production growth of 35,000 bbl/d to 45,000 bbl/d of SCO. High grading of these near term opportunities and further defining of substantial long term growth opportunities is ongoing and is targeted to be completed by the end of the year. Additionally, early results from engineering and design specification work at the potential Paraffinic Froth Treatment expansion has indicated that the optimal production range for the expansion has increased by 10,000 bbl/d and is now targeted to add 40,000 bbl/d to 50,000 bbl/d. All of the these identified production growth opportunities at Horizon are over and above the previously disclosed annual corporate growth target of approximately 4% or 45,000 BOE/d of organic production over the next few years. These Horizon opportunities will be executed in a disciplined and step wise manner which preserves Canadian Natural's capital flexibility."
Canadian Natural's Chief Financial Officer, Corey Bieber, continued, "In the second quarter of 2018, the strength of our asset base and effective and efficient operations delivered net earnings of $982 million and funds flow from operations of $2,706 million. Our strong financial results allowed the Company to further strengthen the balance sheet by decreasing absolute long term net debt by over $600 million from the previous quarter, and returning over $850 million to shareholders by way of dividends and share buybacks in the quarter.
The Company's acquisitions in 2017 were transformational and our results continue to show the accretive nature and resilience of these assets. Supported by successful expansions at Horizon, long life low decline and low capital exposure assets, we have been able to reduce long term net debt in the last 12 months since the Athabasca Oil Sands Project ("AOSP") acquisition by approximately $2,500 million, including the retirement of the deferred AOSP acquisition liability, improving our debt to book capitalization to 39.6% from 42.8% and debt to adjusted EBITDA to 2.1x from 3.4x over the same time frame, clearly demonstrating our commitment to strengthening the balance sheet."
HIGHLIGHTS
Three Months Ended | Six Months Ended | ||||||||||||||||||||||||||||||||||||||||||||
($ millions, except per common share amounts) | Jun 30 2018 | Mar 31 2018 | Jun 30 2017 | Jun 30 2018 | Jun 30 2017 | ||||||||||||||||||||||||||||||||||||||||
Net earnings | |||||||||||||||||||||||||||||||||||||||||||||
$ | 982 | $ | 583 | $ | 1,072 | $ | 1,565 | $ | 1,317 | ||||||||||||||||||||||||||||||||||||
Per common share | – basic | $ | 0.80 | $ | 0.48 | $ | 0.93 | $ | 1.28 | $ | 1.16 | ||||||||||||||||||||||||||||||||||
– diluted | $ | 0.80 | $ | 0.47 | $ | 0.93 | $ | 1.27 | $ | 1.16 | |||||||||||||||||||||||||||||||||||
Adjusted net earnings from operations (1) | $ | 1,279 | $ | 885 | $ | 332 | $ | 2,164 | $ | 609 | |||||||||||||||||||||||||||||||||||
Per common share | – basic | $ | 1.05 | $ | 0.72 | $ | 0.29 | $ | 1.77 | $ | 0.54 | ||||||||||||||||||||||||||||||||||
– diluted | $ | 1.04 | $ | 0.71 | $ | 0.29 | $ | 1.76 | $ | 0.54 | |||||||||||||||||||||||||||||||||||
Funds flow from operations (2) | $ | 2,706 | $ | 2,323 | $ | 1,726 | $ | 5,029 | $ | 3,365 | |||||||||||||||||||||||||||||||||||
Per common share | – basic | $ | 2.20 | $ | 1.90 | $ | 1.50 | $ | 4.10 | $ | 2.97 | ||||||||||||||||||||||||||||||||||
– diluted | $ | 2.19 | $ | 1.89 | $ | 1.49 | $ | 4.08 | $ | 2.95 | |||||||||||||||||||||||||||||||||||
Total net capital expenditures (3) | $ | 974 | $ | 1,103 | $ | 13,046 | $ | 2,077 | $ | 13,892 | |||||||||||||||||||||||||||||||||||
Daily production, before royalties | |||||||||||||||||||||||||||||||||||||||||||||
Natural gas (MMcf/d) | 1,539 | 1,614 | 1,656 | 1,576 | 1,664 | ||||||||||||||||||||||||||||||||||||||||
Crude oil and NGLs (bbl/d) | 793,899 | 854,558 | 637,127 | 824,060 | 617,728 | ||||||||||||||||||||||||||||||||||||||||
Equivalent production (BOE/d) (4) | 1,050,376 | 1,123,546 | 913,171 | 1,086,757 | 895,139 |
(1) | Adjusted net earnings from operations is a non-GAAP measure that the Company utilizes to evaluate its performance. The derivation of this measure is discussed in the Management’s Discussion and Analysis (“MD&A”). |
(2) | Funds flow from operations is a non-GAAP measure that the Company considers key as it demonstrates the Company’s ability to fund capital reinvestment and debt repayment. The derivation of this measure is discussed in the MD&A. |
(3) | For additional information and details, refer to the net capital expenditures table in the Company's MD&A. |
(4) | A barrel of oil equivalent (“BOE”) is derived by converting six thousand cubic feet (“Mcf”) of natural gas to one barrel (“bbl”) of crude oil (6 Mcf:1 bbl). This conversion may be misleading, particularly if used in isolation, since the 6 Mcf:1 bbl ratio is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. In comparing the value ratio using current crude oil prices relative to natural gas prices, the 6 Mcf:1 bbl conversion ratio may be misleading as an indication of value. |
• Net earnings of $982 million were realized in Q2/18, an increase of 68% over Q1/18 levels, and adjusted net earnings of $1,279 million were achieved, a 45% increase over Q1/18 levels.
• Canadian Natural generated record quarterly funds flow from operations of $2,706 million in Q2/18, increases of $383 million and $980 million from Q1/18 and Q2/17 levels respectively. The increase over Q1/18 and Q2/17 primarily reflects higher realized prices from the Company's liquids production together with higher liquids production volumes when compared to Q2/17.
• In Q2/18, Canadian Natural delivered funds flow from operations in excess of capital expenditures of approximately $1,730 million, an increase of approximately $510 million and $890 million from Q1/18 and Q2/17 levels respectively.
• In the first half of 2018, after dividend requirements, free cash flow totaled approximately $2,200 million.
• The Company maintained balance in the allocation of its funds flow from operations, consistent with the Company's four pillar strategy:
• The Company's production volumes in Q2/18 averaged 1,050,376 BOE/d, an increase of 15% from Q2/17 levels, mainly due to the Horizon Phase 3 expansion and acquisitions in 2017. Production decreased from Q1/18 levels by 7%, primarily as a result of major planned turnaround activities at the Company's Oil Sands Mining and Upgrading and thermal in situ operations as well as proactive and strategic actions taken to maximize value.
• Canadian Natural’s corporate crude oil and NGL production volumes averaged 793,899 bbl/d, a decrease of 7% from Q1/18 levels and a 25% increase from Q2/17 levels. The decrease from Q1/18 was primarily as a result of proactive turnaround activities at our Oil Sands Mining and Upgrading and thermal in situ operations as well as curtailments in Q2/18. The increase from Q2/17 was primarily as a result of production from the Horizon Phase 3 expansion, as well as high reliability and strong production from acquisitions completed in 2017.
• At the Company's world class Oil Sands Mining and Upgrading assets, operations were as expected in Q2/18 with quarterly production of 407,704 bbl/d of Synthetic Crude Oil ("SCO"), a decrease of 11% from Q1/18 levels, as planned turnaround and pit stop activities at all three of the Company's oil sands mines, as well as a major 62 day turnaround at the Scotford Upgrader were successfully completed in the quarter.
• At Kirby North, top tier execution and strong productivity has resulted in the project progressing ahead of schedule, advancing targeted first oil by three months into Q4/19, one quarter earlier than originally planned. Cost performance remains on budget with 95% of the Central Processing Facility equipment delivered to site and Steam Assisted Gravity Drainage ("SAGD") drilling nearing 45% completion. Kirby North targets to add 40,000 bbl/d of SAGD production.
• Balance sheet strength continues to be a focus of the Company and strong financial performance was demonstrated in Q2/18 through reduced long term debt and extensions of select credit facilities.
• In Q2/18 Canadian Natural published its 2017 Stewardship Report to Stakeholders, now available on the Company's website at https://www.cnrl.com/corporate-responsibility/stewardship-report/#2017. The report displays how Canadian Natural continues to focus on safe, reliable, effective and efficient operations while minimizing the Company's environmental footprint.
OPERATIONS REVIEW AND CAPITAL ALLOCATION
Canadian Natural has a balanced and diverse portfolio of assets, primarily Canadian-based, with international exposure in the UK section of the North Sea and Offshore Africa. Canadian Natural’s production is well balanced between light and medium crude oil, primary heavy crude oil, Pelican Lake heavy crude oil, bitumen and SCO (herein collectively referred to as “crude oil”), natural gas and NGLs. This balance provides optionality for capital investments, facilitating improved value for the Company’s shareholders.
Underpinning this asset base is long life low decline production from the Company's Oil Sands Mining and Upgrading, thermal in situ oil sands and Pelican Lake heavy crude oil assets. The combination of low decline, low reserves replacement costs, and effective and efficient operations means these assets provide substantial and sustainable funds flow throughout the commodity price cycle.
Augmenting this, Canadian Natural maintains a substantial inventory of low capital exposure projects within its conventional asset base. These projects can be executed quickly and with the right economic conditions, can provide excellent returns and maximize value for shareholders. Supporting these projects is the Company’s undeveloped land base which enables large, repeatable drilling programs which can be optimized over time. Additionally, by owning and operating most of the related infrastructure, Canadian Natural is able to control a major component of its operating cost and minimize production commitments. Low capital exposure projects can be quickly stopped or started depending upon success, market conditions, or corporate needs.
Canadian Natural’s balanced portfolio, built with both long life low decline assets and low capital exposure assets, enables effective capital allocation, production growth and value creation.
Drilling Activity
Six Months Ended Jun 30 | ||||||||||||||||||||
2018 | 2017 | |||||||||||||||||||
(number of wells) | Gross | Net | Gross | Net | ||||||||||||||||
Crude oil | 210 | 203 | 236 | 216 | ||||||||||||||||
Natural gas | 13 | 9 | 16 | 16 | ||||||||||||||||
Dry | 2 | 2 | 3 | 3 | ||||||||||||||||
Subtotal | 225 | 214 | 255 | 235 | ||||||||||||||||
Stratigraphic test / service wells | 555 | 477 | 232 | 232 | ||||||||||||||||
Total | 780 | 691 | 487 | 467 | ||||||||||||||||
Success rate (excluding stratigraphic test / service wells) | 99 | % | 99 | % |
North America Exploration and Production
Crude oil and NGLs – excluding Thermal In Situ Oil Sands | ||||||||||||||||||||||||||||
| Three Months Ended | Six Months Ended | ||||||||||||||||||||||||||
June 30 2018 | March 31 2018 | June 30 2017 | June 30 2018 | June 30 2017 | ||||||||||||||||||||||||
Crude oil and NGLs production (bbl/d) | 238,631 | 245,609 | 227,083 | 242,101 | 229,325 | |||||||||||||||||||||||
Net wells targeting crude oil | 58 | 101 | 57 | 159 | 204 | |||||||||||||||||||||||
Net successful wells drilled | 58 | 99 | 55 | 157 | 202 | |||||||||||||||||||||||
Success rate | 100 | % | 98 | % | 96 | % | 99 | % | 99 | % |
• North America crude oil and NGLs averaged 238,631 bbl/d in Q2/18, within quarterly corporate guidance, representing a 3% decrease from Q1/18 levels and a 5% increase from Q2/17 levels. The volume decrease in Q2/18 compared to Q1/18 levels was primarily as a result of production curtailments and shut-in volumes of approximately 10,350 bbl/d as well as reduced drilling activity and delayed completion and ramp up of certain primary heavy crude oil wells drilled in Q1/18 and Q2/18.
• Due to current market conditions the Company has exercised its capital flexibility by shifting capital from primary heavy crude oil to light crude oil in 2018, resulting in an additional 7 net light crude oil wells targeted to be drilled in the second half of the year. Primary heavy crude oil drilling was reduced by 24 net primary heavy crude oil wells in Q2/18, with an additional 35 primary heavy crude oil well reduction targeted for the second half of the year.
• Canadian Natural's primary heavy crude oil production averaged 84,811 bbl/d in Q2/18, a 5% decrease from Q1/18 levels. In order to maximize value from the Company’s primary heavy crude oil assets, Canadian Natural implemented and executed on proactive decisions and strategic actions in the first half of 2018, such as:
• Controlling costs remains a focus with operating costs of $17.02/bbl in Q2/18, comparable to Q1/18 levels, strong results given the lower production volumes that were primarily as a result of proactive curtailments.
• At the Company's Smith primary heavy crude oil play, initial results have been strong from the 6 net multilateral wells drilled year to date and are currently producing approximately 340 bbl/d per well. There is significant potential at Smith for future development as Canadian Natural has 19 net sections in the fairway with the potential to add approximately 125 net horizontal multilateral primary heavy crude oil wells. Smith is an example of Canadian Natural's large, high quality primary heavy crude oil asset base.
• North America light crude oil and NGL quarterly production averaged 89,906 bbl/d, a decrease of 3% from Q1/18 levels and comparable to Q2/17 levels. Production from additional capital allocated to light crude oil assets is targeted to begin to be added in Q3/18.
• Pelican Lake quarterly production averaged 63,914 bbl/d, comparable with Q1/18 levels and an increase of 36% from Q2/17 levels. The increase from Q2/17 was as a result of the Company's successful integration of the acquired assets in 2017.
• The Company’s 2018 North America E&P crude oil and NGL annual production guidance remains unchanged and is targeted to range from 253,000 bbl/d - 263,000 bbl/d.
Thermal In Situ Oil Sands | ||||||||||||||||||||||||||||
| Three Months Ended | Six Months Ended | ||||||||||||||||||||||||||
Jun 30 2018 | Mar 31 2018 | Jun 30 2017 | Jun 30 2018 | Jun 30 2017 | ||||||||||||||||||||||||
Bitumen production (bbl/d) | 104,907 | 111,851 | 105,719 | 108,359 | 116,983 | |||||||||||||||||||||||
Net wells targeting bitumen | 21 | 22 | 4 | 43 | 12 | |||||||||||||||||||||||
Net successful wells drilled | 21 | 22 | 4 | 43 | 12 | |||||||||||||||||||||||
Success rate | 100 | % | 100 | % | 100 | % | 100 | % | 100 | % | ||||||||||||||||||
• Thermal in situ quarterly production volumes averaged 104,907 bbl/d, within Q2/18 guidance and a decrease of 6% as expected from Q1/18 levels primarily as the Company advanced and completed turnaround activities in the quarter. Production curtailments impacted Q2/18 by approximately 700 bbl/d, mainly at Kirby South.
• The Company’s 2018 thermal in situ annual production guidance remains unchanged and is targeted to range between 107,000 bbl/d - 127,000 bbl/d.
North America Natural Gas | ||||||||||||||||||||||||||||
| Three Months Ended | Six Months Ended | ||||||||||||||||||||||||||
Jun 30 2018 | Mar 31 2018 | Jun 30 2017 | Jun 30 2018 | Jun 30 2017 | ||||||||||||||||||||||||
Natural gas production (MMcf/d) | 1,485 | 1,547 | 1,603 | 1,515 | 1,607 | |||||||||||||||||||||||
Net wells targeting natural gas | 4 | 5 | 5 | 9 | 17 | |||||||||||||||||||||||
Net successful wells drilled | 4 | 5 | 5 | 9 | 16 | |||||||||||||||||||||||
Success rate | 100 | % | 100 | % | 100 | % | 100 | % | 94 | % |
• North America natural gas production was as expected at 1,485 MMcf/d in Q2/18, representing decreases of 4% and 7% from Q1/18 and Q2/17 levels respectively.
• Operating costs of $1.28/Mcf were realized in Q2/18, a decrease of 2% from Q1/18 levels, strong results given lower natural gas volumes due to the Company's proactive decision to shut-in volumes and delay activity on certain natural gas assets.
• In Q2/18 the Company has made the following proactive and strategic actions to maximize value in the Company's natural gas assets, including:
• Additionally, the Company's natural gas production was reduced by approximately 65 MMcf/d in Q2/18 due to restrictions at the Pine River plant, operated by a third party. In Q2/18 Canadian Natural, subject to regulatory approval, agreed to acquire the facility from the third party, which needs to complete a meter upgrade that will take approximately four weeks, at which time the Company targets to complete maintenance work on the facility and will assess increasing plant throughput and reliability to match field capacity of approximately 145 MMcf/d.
• As a result of the items listed above and proactive actions going forward, the Company’s 2018 corporate natural gas annual production guidance has been revised and is targeted to range from 1,550 MMcf/d - 1,600 MMcf/d.
• The Company uses natural gas in its operations representing approximately 35% of its total equivalent gas production providing a natural hedge from the challenging Western Canadian natural gas price environment. Approximately 32% of the natural gas production is exported to other North American markets or sold internationally, with the remaining 33% of the Company's production being exposed to AECO/Station 2 pricing.
International Exploration and Production
| Three Months Ended | Six Months Ended | ||||||||||||||||||||
Jun 30 2018 | Mar 31 2018 | Jun 30 2017 | Jun 30 2018 | Jun 30 2017 | ||||||||||||||||||
Crude oil production (bbl/d) | ||||||||||||||||||||||
North Sea | 24,456 | 21,584 | 26,304 | 23,028 | 24,682 | |||||||||||||||||
Offshore Africa | 18,201 | 19,438 | 20,480 | 18,816 | 21,542 | |||||||||||||||||
Natural gas production (MMcf/d) | ||||||||||||||||||||||
North Sea | 30 | 37 | 37 | 34 | 37 | |||||||||||||||||
Offshore Africa | 24 | 30 | 16 | 27 | 20 | |||||||||||||||||
Net wells targeting crude oil | 1.9 | 1.0 | 1.8 | 2.9 | 1.8 | |||||||||||||||||
Net successful wells drilled | 1.9 | 1.0 | 1.8 | 2.9 | 1.8 | |||||||||||||||||
Success rate | 100 | % | 100 | % | 100 | % | 100 | % | 100 | % | ||||||||||||
• International E&P quarterly production volumes were within quarterly production guidance and reached 42,657 bbl/d in Q2/18, an increase of 4% from Q1/18 levels.
• The Company's 2018 International annual production guidance remains unchanged and is targeted to range from 40,000 bbl/d - 45,000 bbl/d.
North America Oil Sands Mining and Upgrading
| Three Months Ended | Three Months Ended | ||||||||||||||||||||
Jun 30 2018 | Mar 31 2018 | Jun 30 2017 | Jun 30 2018 | Jun 30 2017 | ||||||||||||||||||
Synthetic crude oil production (bbl/d) (1) (2) | 407,704 | 456,076 | 257,541 | 431,756 | 225,196 |
• | Q2/18 SCO production before royalties excludes 3,026 bbl/d of SCO consumed internally as diesel (Q1/18 – 3,224 bbl/d; Q2/17 – 438 bbl/d). |
(3) | Consists of heavy and light synthetic crude oil products. |
• At the Company's world class Oil Sands Mining and Upgrading assets, operations were as expected in Q2/18 with quarterly production of 407,704 bbl/d of SCO, a decrease of 11% from Q1/18 levels as planned turnaround and pit stop activities at all three of the Company's oil sands mines as well as a major 62 day turnaround at the Scotford Upgrader were successfully completed in the quarter.
• The Company's 2018 Oil Sands Mining and Upgrading annual production guidance remains unchanged and is targeted to range from 415,000 bbl/d - 450,000 bbl/d of upgraded products.
MARKETING
Three Months Ended | Six Months Ended | ||||||||||||||||||||||||||||||||||||||||||
Jun 30 2018 | Mar 31 2018 | Jun 30 2017 | Jun 30 2018 | Jun 30 2017 | |||||||||||||||||||||||||||||||||||||||
Crude oil and NGLs pricing | |||||||||||||||||||||||||||||||||||||||||||
WTI benchmark price (US$/bbl) (1) | $ | 67.90 | $ | 62.89 | $ | 48.29 | $ | 65.41 | $ | 50.07 | |||||||||||||||||||||||||||||||||
WCS heavy differential as a percentage of WTI (%) (2) | 28 | % | 39 | % | 23 | % | 33 | % | 26 | % | |||||||||||||||||||||||||||||||||
SCO price (US$/bbl) | $ | 67.27 | $ | 61.45 | $ | 49.83 | $ | 64.38 | $ | 50.63 | |||||||||||||||||||||||||||||||||
Condensate benchmark pricing (US$/bbl) | $ | 68.85 | $ | 63.12 | $ | 48.44 | $ | 66.00 | $ | 50.31 | |||||||||||||||||||||||||||||||||
Average realized pricing before risk management (C$/bbl) (3) | $ | 61.14 | $ | 43.06 | $ | 47.12 | $ | 52.32 | $ | 47.08 | |||||||||||||||||||||||||||||||||
Natural gas pricing | |||||||||||||||||||||||||||||||||||||||||||
AECO benchmark price (C$/GJ) | $ | 0.97 | $ | 1.75 | $ | 2.63 | $ | 1.36 | $ | 2.71 | |||||||||||||||||||||||||||||||||
Average realized pricing before risk management (C$/Mcf) | $ | 1.95 | $ | 2.74 | $ | 2.97 | $ | 2.35 | $ | 3.11 |
(1) West Texas Intermediate (“WTI”).
(2) Western Canadian Select (“WCS”).
(3) Average crude oil and NGL pricing excludes SCO. Pricing is net of blending costs and excluding risk management activities.
• In Q2/18, the WCS heavy differential narrowed as heavy crude oil began to be moved to market. The WCS heavy differential widened in Q1/18 as a result of third party pipeline outages backing up heavy crude oil into Western Canada. This resulted in anomalous heavy crude oil pricing as the pipeline operators and rail transport worked to remove the backlog of inventory.
• Canadian Natural and other industry participants, as part of a working committee, are working towards a more effective nomination process that verifies actual production and sales.
• AECO natural gas prices for Q2/18 continued to reflect third party pipeline constraints limiting flow of natural gas to export markets, increased natural gas production in the basin and constraints on export capacity out of Western Canada.
• The North West Redwater ("NWR") refinery, upon completion, will strengthen the Company’s position by providing a competitive return on investment and by creating incremental demand for approximately 80,000 bbl/d of heavy crude oil blends that will not require export pipelines, helping to reduce pricing volatility in all Western Canadian heavy crude oil.
2017 Stewardship Report to Stakeholders
In Q2/18 Canadian Natural published its 2017 Stewardship Report to Stakeholders, now available on the Company's website at https://www.cnrl.com/corporate-responsibility/stewardship-report/#2017. The report displays how Canadian Natural continues to focus on safe, reliable, effective and efficient operations while minimizing its environmental footprint.
FINANCIAL REVIEW
The Company continues to implement proven strategies and its disciplined approach to capital allocation. As a result, the financial position of Canadian Natural remains strong. Canadian Natural’s funds flow generation, credit facilities, US commercial paper program, diverse asset base and related flexible capital expenditure programs all support a flexible financial position and provide the appropriate financial resources for the near-, mid- and long-term.
• The Company’s strategy is to maintain a diverse portfolio balanced across various commodity types. The Company achieved production levels of 1,050,376 BOE/d in Q1/18, with approximately 98% of total production located in G7 countries.
• In Q2/18, Canadian Natural delivered funds flow from operations in excess of capital expenditures of approximately $1,730 million, an increase of approximately $510 million and $890 million from Q1/18 and Q2/17 levels respectively.
• Balance sheet strength continues to be a focus of the Company and strong financial performance was demonstrated in Q2/18 through reduced long term debt and extensions of select credit facilities.
• Returns to shareholders remains a key focus for Canadian Natural as the Company returned approximately $850 million by way of dividend and share buybacks in Q2/18. Share buybacks for cancellation totaled 10,140,127 shares in the quarter at an weighted average share price of $43.52.
• In addition to its strong funds flow, capital flexibility and access to debt capital markets, Canadian Natural has additional financial levers at its disposal to effectively manage its liquidity. As at June 30, 2018, these financial levers include the Company’s third party equity investments of approximately $745 million.
• Subsequent to quarter end, Canadian Natural declared a quarterly cash dividend on common shares of $0.335 per share payable on October 1, 2018.
OUTLOOK
The Company forecasts annual 2018 production levels to average between 815,000 and 885,000 bbl/d of crude oil and NGLs and between 1,550 and 1,600 MMcf/d of natural gas, before royalties. Q3/18 production guidance before royalties is forecast to average between 771,000 and 819,000 bbl/d of crude oil and NGLs and between 1,535 and 1,565 MMcf/d of natural gas. Detailed guidance on production levels, capital allocation and operating costs can be found on the Company’s website at www.cnrl.com.
Canadian Natural's annual 2018 capital expenditures are targeted to be approximately $4.6 billion.
Forward-Looking Statements
Certain statements relating to Canadian Natural Resources Limited (the “Company”) in this document or documents incorporated herein by reference constitute forward-looking statements or information (collectively referred to herein as “forward-looking statements”) within the meaning of applicable securities legislation. Forward-looking statements can be identified by the words “believe”, “anticipate”, “expect”, “plan”, “estimate”, “target”, “continue”, “could”, “intend”, “may”, “potential”, “predict”, “should”, “will”, “objective”, “project”, “forecast”, “goal”, “guidance”, “outlook”, “effort”, “seeks”, “schedule”, “proposed” or expressions of a similar nature suggesting future outcome or statements regarding an outlook. Disclosure related to expected future commodity pricing, forecast or anticipated production volumes, royalties, production expenses, capital expenditures, income tax expenses and other guidance provided throughout this Management’s Discussion and Analysis (“MD&A”) of the financial condition and results of operations of the Company, constitute forward-looking statements. Disclosure of plans relating to and expected results of existing and future developments, including but not limited to the Horizon Oil Sands ("Horizon") operations and future expansions, the Athabasca Oil Sands Project ("AOSP"), Primrose thermal projects, the Pelican Lake water and polymer flood project, the Kirby Thermal Oil Sands Project, the cost and timing of construction and future operations of the North West Redwater bitumen upgrader and refinery, construction by third parties of new or expansion of existing pipeline capacity or other means of transportation of bitumen, crude oil, natural gas or synthetic crude oil (“SCO”) that the Company may be reliant upon to transport its products to market, and the assumption of operations at processing facilities also constitute forward-looking statements. This forward-looking information is based on annual budgets and multi-year forecasts, and is reviewed and revised throughout the year as necessary in the context of targeted financial ratios, project returns, product pricing expectations and balance in project risk and time horizons. These statements are not guarantees of future performance and are subject to certain risks. The reader should not place undue reliance on these forward-looking statements as there can be no assurances that the plans, initiatives or expectations upon which they are based will occur.
In addition, statements relating to “reserves” are deemed to be forward-looking statements as they involve the implied assessment based on certain estimates and assumptions that the reserves described can be profitably produced in the future. There are numerous uncertainties inherent in estimating quantities of proved and proved plus probable crude oil, natural gas and natural gas liquids (“NGLs”) reserves and in projecting future rates of production and the timing of development expenditures. The total amount or timing of actual future production may vary significantly from reserve and production estimates.
The forward-looking statements are based on current expectations, estimates and projections about the Company and the industry in which the Company operates, which speak only as of the date such statements were made or as of the date of the report or document in which they are contained, and are subject to known and unknown risks and uncertainties that could cause the actual results, performance or achievements of the Company to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. Such risks and uncertainties include, among others: general economic and business conditions which will, among other things, impact demand for and market prices of the Company’s products; volatility of and assumptions regarding crude oil and natural gas prices; fluctuations in currency and interest rates; assumptions on which the Company’s current guidance is based; economic conditions in the countries and regions in which the Company conducts business; political uncertainty, including actions of or against terrorists, insurgent groups or other conflict including conflict between states; industry capacity; ability of the Company to implement its business strategy, including exploration and development activities; impact of competition; the Company’s defense of lawsuits; availability and cost of seismic, drilling and other equipment; ability of the Company and its subsidiaries to complete capital programs; the Company’s and its subsidiaries’ ability to secure adequate transportation for its products; unexpected disruptions or delays in the resumption of the mining, extracting or upgrading of the Company’s bitumen products; potential delays or changes in plans with respect to exploration or development projects or capital expenditures; ability of the Company to attract the necessary labour required to build its thermal and oil sands mining projects; operating hazards and other difficulties inherent in the exploration for and production and sale of crude oil and natural gas and in mining, extracting or upgrading the Company’s bitumen products; availability and cost of financing; the Company’s and its subsidiaries’ success of exploration and development activities and its ability to replace and expand crude oil and natural gas reserves; timing and success of integrating the business and operations of acquired companies and assets; production levels; imprecision of reserve estimates and estimates of recoverable quantities of crude oil, natural gas and NGLs not currently classified as proved; actions by governmental authorities; government regulations and the expenditures required to comply with them (especially safety and environmental laws and regulations and the impact of climate change initiatives on capital expenditures and production expenses); asset retirement obligations; the adequacy of the Company’s provision for taxes; and other circumstances affecting revenues and expenses.
The Company’s operations have been, and in the future may be, affected by political developments and by national, federal, provincial and local laws and regulations such as restrictions on production, changes in taxes, royalties and other amounts payable to governments or governmental agencies, price or gathering rate controls and environmental protection regulations. Should one or more of these risks or uncertainties materialize, or should any of the Company’s assumptions prove incorrect, actual results may vary in material respects from those projected in the forward-looking statements. The impact of any one factor on a particular forward-looking statement is not determinable with certainty as such factors are dependent upon other factors, and the Company’s course of action would depend upon its assessment of the future considering all information then available.
Readers are cautioned that the foregoing list of factors is not exhaustive. Unpredictable or unknown factors not discussed in this MD&A could also have material adverse effects on forward-looking statements. Although the Company believes that the expectations conveyed by the forward-looking statements are reasonable based on information available to it on the date such forward-looking statements are made, no assurances can be given as to future results, levels of activity and achievements. All subsequent forward-looking statements, whether written or oral, attributable to the Company or persons acting on its behalf are expressly qualified in their entirety by these cautionary statements. Except as required by law, the Company assumes no obligation to update forward-looking statements, whether as a result of new information, future events or other factors, or the foregoing factors affecting this information, should circumstances or the Company’s estimates or opinions change.
Special Note Regarding Currency, Production and Non-GAAP Financial Measures
The Company's MD&A of the financial condition and results of operations of the Company should be read in conjunction with the unaudited interim consolidated financial statements for the six months ended June 30, 2018 and the MD&A and the audited consolidated financial statements for the year ended December 31, 2017.
All dollar amounts are referenced in millions of Canadian dollars, except where noted otherwise. The Company’s unaudited interim consolidated financial statements for the period ended June 30, 2018 and the Company's MD&A have been prepared in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board. The Company's MD&A includes references to financial measures commonly used in the crude oil and natural gas industry, such as adjusted net earnings from operations, funds flow from operations, adjusted cash production costs and adjusted depreciation, depletion and amortization. These financial measures are not defined by IFRS and therefore are referred to as non-GAAP measures. The non-GAAP measures used by the Company may not be comparable to similar measures presented by other companies. The Company uses these non-GAAP measures to evaluate its performance. The non-GAAP measures should not be considered an alternative to or more meaningful than net earnings and cash flows from operating activities, as determined in accordance with IFRS, as an indication of the Company's performance. The non-GAAP measures adjusted net earnings from operations and funds flow from operations are reconciled to net earnings, as determined in accordance with IFRS, in the “Financial Highlights” section of the Company's MD&A. The non-GAAP measure funds flow from operations is also reconciled to cash flows from operating activities in this section. The derivation of adjusted cash production costs and adjusted depreciation, depletion and amortization are included in the “Operating Highlights - Oil Sands Mining and Upgrading” section of the Company's MD&A. The Company also presents certain non-GAAP financial ratios and their derivation in the “Liquidity and Capital Resources” section of the Company's MD&A.
A Barrel of Oil Equivalent (“BOE”) is derived by converting six thousand cubic feet (“Mcf”) of natural gas to one barrel (“bbl”) of crude oil (6 Mcf:1 bbl). This conversion may be misleading, particularly if used in isolation, since the 6 Mcf:1 bbl ratio is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. In comparing the value ratio using current crude oil prices relative to natural gas prices, the 6 Mcf:1 bbl conversion ratio may be misleading as an indication of value. In addition, for the purposes of the Company's MD&A, crude oil is defined to include the following commodities: light and medium crude oil, primary heavy crude oil, Pelican Lake heavy crude oil, bitumen (thermal oil), and SCO.
Production volumes and per unit statistics are presented throughout the Company's MD&A on a “before royalty” or “gross” basis, and realized prices are net of blending and feedstock costs and exclude the effect of risk management activities. Production on an “after royalty” or “net” basis is also presented for information purposes only.
Additional information relating to the Company, including its Annual Information Form for the year ended December 31, 2017, is available on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov.
CONFERENCE CALL
A conference call will be held at 9:00 a.m. Mountain Time, 11:00 a.m. Eastern Time on Thursday, August 2, 2018.
The North American conference call number is 1-866-521-4909 and the outside North American conference call number is 001-647-427-2311. Please call in 10 minutes prior to the call starting time.
An archive of the broadcast will be available until 6:00 p.m. Mountain Time, Thursday, August 16, 2018. To access the rebroadcast in North America, dial 1-800-585-8367. Those outside of North America, dial 001-416-621-4642. The conference archive ID number is 5289004.
The conference call will also be webcast live and may be accessed on the home page of our website at www.cnrl.com.
Canadian Natural is a senior oil and natural gas production company, with continuing operations in its core areas located in Western Canada, the U.K. portion of the North Sea and Offshore Africa.
CANADIAN NATURAL RESOURCES LIMITED |
2100, 855 - 2nd Street S.W. Calgary, Alberta, T2P4J8 Phone: 403-517-7777 Email: ir@cnrl.com www.cnrl.com |
STEVE W. LAUT Executive Vice-Chairman TIM S. MCKAY President COREY B. BIEBER Chief Financial Officer and Senior Vice-President, Finance MARK A. STAINTHORPE Vice-President, Finance – Capital Markets Trading Symbol - CNQ Toronto Stock Exchange New York Stock Exchange |