Canada Oil Companies is a download list of 500 Oil and Gas companies.
- The Canada Oil Companies on the list operate in Canada and have drilled wells in the last 3 years in the Western Canada Sedimentary Basin (WCSB).
- Included in the list are company names, mailing address, telephone, production, 2021 budget, websites and Linkedin company page.
Download 500 Canadian Oil & Gas Operator Company List
Top 5 Canadian Operators
Canadian Natural Resources Limited (CNRL)
Canadian Natural Resources Limited ranks #2 in wells drilled in 2022 with 421 wells drilled in Western Canada.
Cenovus Energy Inc.
Cenovus Energy Inc. ranks #1 in wells drilled in 2022 with 508 wells drilled in Western Canada.
Tourmaline Oil Corp
Tourmaline Oil Corp ranks #5 in wells drilled in 2022 with 205 wells drilled in Western Canada.
About Canada Oil Companies
Canadian Natural Resources Canada oil companies has exploited Canada’s resources to become one of the country’s largest natural gas producers. The company has large oil holdings (light, medium, and heavy crude assets) in British Columbia and Alberta, as well as in Saskatchewan. It also has holdings in the North Sea and offshore West Africa. In addition, the company has major interests in oil sands production in Canada. In 2010 Canadian Natural Resources reported proved reserves of 3.8 billion barrels of oil, bitumen, and natural gas liquids, (including 1.9 billion barrels of synthetic crude oil), and 4.3 trillion cu. ft. of natural gas, and produced an average of 632,000 barrels of oil equivalent per day.
CNRL Wells Drilled Last 300 Days
CNRL Oilsands Operations
Horizon Oil Sands include a surface oil sands mining and bitumen extraction plant, complemented by on-site bitumen upgrading with associated infrastructure to produce high quality SCO. In late 2017, the Phase 3 expansion was completed at Horizon, the final step in the Company’s transition to a Long Life Low Decline asset base. In 2020, the Company is evaluating opportunities to increase reliability, lower costs and add production growth in the near and long-term.
Albian Sands Energy Inc. is the operator of the Muskeg River Mine and Jack Pine Mine, an oil sands mining project located 75 kilometres (47 mi) north of Fort McMurray, Alberta, Canada. It is a joint venture between Shell Canada (10%), CNRL (70%) and Chevron Canada (20%).
Kirby – Canadian Natural commenced steam injection at the Kirby South Phase 1 project in September 2013. Kirby South operations are located approximately 85 km northeast of Lac La Biche. This is the first project that we have undertaken in the Athabasca Oil Sands area. The project targets the McMurray reservoir and uses Steam Assisted Gravity Drainage (SAGD) technology for the recovery of bitumen from the in situ oil sands resources.
The project includes a central bitumen processing facility with production capacity of 40,000 bbl/d of bitumen.
Canadian Natural began construction of Kirby North, shortly after receiving regulatory approval in May 2014. Kirby North operations target the McMurray reservoir and will employ SAGD technology for the recovery of bitumen. In the first quarter of 2015, the Kirby North project was deferred due to the fall in commodity prices. In 2016, the Company worked through the Kirby North construction process and its targeted drilling plans in order to ensure cost savings identified could be captured. In late 2017, the Company reinitiated the Kirby North project with planned construction and well-pair drilling in 2018 and 2019. A result of top tier execution and strong productivity, the project achieved first oil in Q2/19. The ramp up of Kirby North is ahead of schedule and has been top tier with July 2020 production averaging approximately 43,200 bbl/d, exceeding the nameplate capacity of 40,000 bbl/d.
Primrose & Wolf Lake In the Cold Lake deposits, our Primrose operations currently produce from the Clearwater reservoir using the cyclic steam stimulation (CSS) process. CSS uses a single well bore to inject and produce steam. This technology has been historically applied to reservoirs that have barriers to vertical flow. The production peaks and troughs at Primrose are a reflection of the cyclic steam process – the peaks are associated with production cycles from newer, less mature wells and the troughs are associated with production cycles from the more mature areas in the field.
Cenovus Energy Inc. is a Canada oil companies that is integrated oil and natural gas company. It is committed to maximizing value by sustainably developing its assets in a safe, innovative and cost-efficient manner, integrating environmental, social and governance considerations into its business plans. Operations include oil sands projects in northern Alberta, which use specialized methods to drill and pump the oil to the surface, and established natural gas and oil production in Alberta and British Columbia. The company also has 50% ownership in two U.S. refineries. Cenovus shares trade under the symbol CVE, and are listed on the Toronto and New York stock exchanges.
Cenovus Wells Drilled Last 300 Days
Cenovus Oilsands Operations
Crescent Point Energy Corp. (Crescent Point), Canada oil companies was formerly Crescent Point Energy Trust, is engaged in the business of acquiring, developing and holding interests in petroleum and natural gas properties and assets related thereto through a general partnership and wholly owned subsidiaries. On January 15, 2009, Crescent Point acquired Villanova Energy Corp. (Villanova). On July 3, 2009, the Company acquired Gibraltar Exploration Ltd. (Gibraltar). On October 22, 2009, the Company acquired Wave Energy Ltd. (Wave). On December 15, 2009, the Company acquired TriAxon Resources Ltd. (TriAxon). On June 1, 2009, Crescent Point acquired assets from Talisman Energy Canada (Talisman). On June 1, 2009, the Company disposed of a portion of the assets acquired from Talisman (the Bakken Assets). On July 3, 2009, the Company disposed of 25% interest in the Wild River and Gibraltar assets to Shelter Bay Energy Inc. (Shelter Bay). In July 2010, Crescent Point Energy Trust acquired Shelter Bay Energy Inc. Crescent Point Energy Playbook
Crescent Point Energy Corp. 2021 Operational Update
Crescent Point is upwardly revising its 2021 annual average production guidance to 130,000 to 134,000 boe/d, up from 128,000 to 132,000 boe/d. This reflects the Company’s continued operational outperformance and the reactivation of higher cost production that was previously shut-in during a lower commodity price environment. Crescent Point is also narrowing its 2021 development capital expenditures guidance, within its prior range, to approximately $600 to $625 million.
The Company’s development capital expenditures in the second quarter of 2021 were $88.4 million, compared to $72.0 million in the same period in 2020. In the three months ended June 30, 2021, 28 (26.0 net) wells were drilled and $30.5 million was spent on facilities and seismic.
The Company’s development capital expenditures for the six months ended June 30, 2021 were $207.6 million, compared to $392.1 million in the same period in 2020. In the six months ended June 30, 2021, 93 (90.6 net) wells were drilled and $44.1 million was spent on facilities and seismic.
Crescent Point Wells Drilled Last 900 Days
Baytex Energy Corp. Canada oil companies is an oil and gas corporation based in Calgary, Alberta. The company is engaged in the acquisition, development and production of crude oil and natural gas in the Western Canadian Sedimentary Basin and in the Eagle Ford in the United States. Approximately 83% of Baytex’s production is weighted toward crude oil and natural gas liquids. Baytex’s common shares are traded on the Toronto Stock Exchange and the New York Stock Exchange under the symbol BTE. Baytex Energy Playbook
In 2021, we are benefiting from our diversified oil weighted portfolio and our commitment to allocate capital effectively. Based on the forward strip(1), we expect to generate over $350 million of free cash flow in 2021.
As a result Baytex strong operating performance through the first half of 2021, we are increasing our production guidance to 79,000 to 80,000 boe/d, up from 77,000 to 79,000 boe/d, previously. We continue to forecast 2021 exploration and development expenditures of $285 to $315 million.
Baytex Wells Drilled Last 900 Days
Tourmaline, Canada oil companies through a series of strategic acquisitions, farm-ins and land acquisitions combined with its active capital exploration and development program, has assembled an extensive undeveloped land position with a large, multi-year drilling inventory and operating control of important natural gas processing and transportation infrastructure in two core long-term growth areas – the Alberta Deep Basin and the Greater Peace River High. Tourmaline is executing a large-scale, repeatable capital exploration and development program in these two core long-term growth areas. Tourmaline Playbook
Q2 Capital Program
- Second quarter 2021 EP capital spending was $215.9 million.
- Full-year 2021 EP capital spending of $1.27 billion is currently expected.
- Tourmaline drilled 113.75 net wells in 1H 2021 and expects to drill approximately 250 net wells for full-year 2021, completing approximately 220 (net) of those wells by year end.
- Tourmaline is currently operating 12 drilling rigs and will add an additional rig on the former Black Swan lands in September, as originally planned.
- The Company expects to bring approximately 140 (net) wells onstream through the balance of 2021. Improved time and cost performance for drilling and completion operations has largely offset modest inflationary cost pressures.
Tourmaline Wells Drilled Last 900 Days
Whitecap Resources Canada oil companies is a Canadian public oil company based in Calgary, Alberta, with operations in Alberta, Saskatchewan, and British Columbia. Whitecap is an oil weighted growth company that pays a monthly cash dividend to its shareholders while being recognized for storing more CO2 annually than we emit corporately. Whitecap Resources Playbook
Q2 2021 Update
Whitecap’s second quarter results were exceptional across all areas of the business, achieving record production of 116,799 boe/d which was 4% above our forecast of 112,000 boe/d, on capital investments of $39 million, which was approximately 30% below our forecast of $55 – $60 million. The record production in the second quarter includes 153 MMcf/d of natural gas, which is expected to increase as we continue to grow our Montney production in the second half of the year and in 2022. Our second quarter funds flow netback of $25.07/boe was 15% higher than the first quarter and resulted in funds flow of $267 million ($0.43 per share). Funds flow per share increased 126% compared to the prior year quarter and 19% compared to the first quarter of 2021.
Second quarter capital spending was moderate due to break-up conditions and the majority of capital spending was to bring the remaining wells drilled during the first quarter on production. Late in the second quarter we spudded 3 (2.5 net) wells to get a head start on our optimized second half program which includes 57 (42.2 net) wells.
Our second quarter production outperformance is mainly due to accelerated on production timing and higher than forecasted production rates from our first quarter drilling program on our Frobisher conventional assets in Eastern Saskatchewan, our Viking and Lower Shaunavon assets in Western Saskatchewan and our Charlie Lake assets in our Northwest Alberta and B.C. business unit. In addition, the base declines in some of our legacy and waterflood supported areas in Central Alberta and Western Saskatchewan were lower than forecasted.
We highlight the following second quarter financial and operating results:
- Production Momentum Continues. Second quarter production of 116,799 boe/d compared to 70,807 boe/d in the prior year quarter, which represents an increase of 65% on an absolute basis and 9% per share. Compared to first quarter production of 95,828 boe/d, it increased 22% on an absolute basis and 3% per share.
- Significant Funds Flow. Whitecap generated funds flow of $267 million in the second quarter, or $0.43 per share, compared to $0.19 per share in the prior year quarter and $0.36 per share in the first quarter of 2021. After capital investments, we generated $227 million of free funds flow during the second quarter.
- Increasing Returns to Shareholders. As press released on May 17, 2021, the monthly dividend was increased 8% to $0.01625 per share effective with the June dividend payable in July 2021. With increasing funds flow, a strong balance sheet and low decline asset base, return of capital to shareholders remains a priority for Whitecap. During the quarter, Whitecap repurchased 2.0 million common shares under its NCIB to offset share awards at a weighted average price of $5.57 per share.
- Balance Sheet Strength Maintained. Net debt of $1.4 billion on total credit capacity of $2.0 billion results in significant financial flexibility with approximately $0.6 billion of unused capacity. The Company’s credit facilities have two financial covenants being debt to earnings before interest, taxes, depreciation and amortization (“EBITDA”) not exceeding 4.0 times and EBITDA to interest not less than 3.5 times. Whitecap’s second quarter debt to EBITDA ratio was 1.4 times and EBITDA to interest ratio was 20.6 times. For additional details refer to Note 10 “Long-Term Debt” in the unaudited interim consolidated financial statements for the period ending June 30, 2021.
With the NAL, TORC and the Kicking Horse acquisitions closed, Whitecap’s sustainable business model is now even stronger. Disciplined acquisitions that enhance our per share metrics and improve our free funds flow profile are an important part of our strategy and we will continue to evaluate these opportunities.
Whitecap Wells Drilled Last 900 Days
Teine Energy Canada oil companies is the Viking’s largest producer, with thousands of low-risk, repeatable drilling locations identified on our 800,000 net acres of land. This accounts for about one-third of all Viking production. Our activity in Viking – approximately 3,600 horizontal locations – represents over 15 years of drilling at current activity levels and positions Teine to continue expanding profitability through efficiencies in cost structure, increasing well productivity, and improved reservoir recovery.
Teine Energy Wells Drilled Last 900 Days
Q2 2021 Quarterly Release
“Our track record of free cash flow generation continued in the second quarter with another $350 million of free cash, bringing us to a total of $890 million year-to-date,” said Ovintiv CEO, Doug Suttles. “We also expect to reach our original $4.5 billion net debt target before year-end – one year ahead of our original timeline. This achievement will mark almost $3 billion of net debt reduction since the second quarter of 2020. Our business continues to perform exceptionally well with operational efficiency gains and supply chain management more than offsetting cost inflation year-to-date. Ovintiv is positioned to thrive on the road ahead.
Permian production averaged 126 MBOE/d (82% liquids) in the quarter. The Company averaged three gross rigs, drilled 21 net wells, and had 33 net wells turned in line (TIL).
Permian drilling and completion (D&C) costs have averaged $480 per foot year-to-date and are 11% lower than the 2020 program average. Both drilling and completion efficiency records were achieved in the quarter, including an average drilling cost of $170 per foot, 17% lower than the 2020 average. Among wells rig released in the quarter, the average lateral length drilled was 12,050 feet, approximately 20% longer than the 2020 average. Underpinned by Simul-frac operations, the Company completed 3,500 lateral feet per day and pumped 9.5 million pounds of sand per day on a single pad, its most efficient well set to date. During the quarter, 30 out of the 33 net wells were completed using Simul-frac. Ovintiv also began sourcing in-basin, wet sand from a Howard County mine during the quarter.
Anadarko production averaged 133 MBOE/d (62% liquids) in the quarter. The Company averaged two gross rigs, drilled 16 net wells, and had 22 net wells TIL, of which 21 were operated by Ovintiv.
STACK D&C costs have averaged $430 per foot year-to-date, and are 10% lower than the 2020 program average. During the quarter, 17 wells were completed in the STACK, with two wells drilled and completed for $3.5 million. All the STACK wells were completed using Simul-frac operations, where the Company pumped an average of 150,000 bbls per day, 40% more than the 2020 program average. Ovintiv also achieved a new spud-to-rig release drill time pacesetter of 5.9 days. The team has now recorded faster average drilling times in the STACK for the third consecutive quarter.
In SCOOP, four net Woodford/Caney oil wells were brought on-line in the quarter with an average D&C cost of $5.3 million.
Montney production averaged 235 MBOE/d (25% liquids) in the quarter. The Company averaged four gross rigs, drilled 18 net wells and had 30 net wells TIL.
Montney year-to-date D&C costs have averaged $410 per foot and are 9% lower than the 2020 program average. All the quarterly wells TIL targeted the volatile oil and liquids-rich condensate fairway of the play with an expected liquids composition of 30-70%. Ovintiv drilled five wells at or below $100 per foot, 20% of the total quarter rig releases. Six wells were drilled faster than the previous pacesetter and all six wells achieved drilling rates greater than 2,050 feet per day.
Bakken production averaged 24 MBOE/d (79% liquids) in the quarter. The company drilled one net well and had two net wells TIL. The two net wells brought online in the quarter exhibited strong production performance, achieving an average 60-day initial production rate of 1,235 bbls of oil per well. D&C costs from 2020 to 2021 have averaged $510 per foot, 14% lower than the 2019 average.
Ovintiv Wells Drilled Last 900 Days
Tamarack Valley Energy Canada oil companies is an oil and gas company involved in the identification, evaluation and operation of resource plays in the Western Canadian sedimentary basin. The Company uses a rigorous, proven modeling process to carefully manage risk and identify growth opportunities. Tamarack’s diversified suite of oil-focused assets provides exposure to the high impact Cardium light oil resource plays in Lochend, Garrington/Harmattan and Buck Lake in Alberta, low cost Viking light oil resource plays in Redwater, Foley Lake and Westlock in Alberta and highly economic heavy oil opportunities southeast of Lloydminster in Saskatchewan.
Tamarck Wells Drilled Last 900 Days
Peyto Exploration & Development.Canada oil companies (formerly PEYTO Energy Trust) invests in long-life gas projects in Alberta’s Central Deep Basin. The company focuses on the Sundance and Smoky/Kakwa areas and has proved reserves of 124.3 million barrels of oil equivalent. It also operates gas plants and more than 200 miles of gas gathering pipeline. It pursues a strategy of developing long-lived reserves requiring low operating costs in order preserve capital. Peyto Exploration & Development converted from a trust structure in early 2011 to secure better financial returns for shareholders.
Peyto Wells Drilled Last 900 Days
ARC Resources Ltd. is the largest pure-play Montney producer and one of Canada’s largest dividendpaying energy companies, featuring low-cost operations and leading ESG performance. ARC’s
investment-grade credit profile is supported by commodity and geographic diversity and robust risk
management practices around all aspects of the business. ARC’s common shares trade on the Toronto
Stock Exchange under the symbol ARX. ARC Resource Playbook
ARC’s leading position in the Montney resource play features a deep inventory of high-return, de-risked
development opportunities. The enhanced commodity and geographic diversity established through the
Business Combination provides significant optionality within ARC’s portfolio and improves the Company’s
ability to reduce development risk and mitigate the impacts of future commodity price volatility.
ARC processes the majority of its production through owned-and-operated infrastructure. This affords the
Company greater control to deliver on its low cost structure and optimal liquids recoveries, as well as the
ability to optimize revenue streams, and supports strong safety and environmental performance.
ARC’s 2021 capital budget of $950 million to $1.0 billion has been designed to maximize free funds flow
and enhance ARC’s returns-focused value proposition. While the primary focus for 2021 will be to
successfully integrate Seven Generations