Our Assets

South West Saskatchewan

Rock has focused on building a production platform in South West Saskatchewan for these reasons:

  1. Lighter Oil: As one moves south toward the U.S. border, the oil density generally gets lighter (changing from 10°-12° API to 14°-16° API) which requires less diluent and attracts a higher price.
  2. Lower Viscosity: Lower viscosity = higher recovery factors = lower decline rates. In addition to becoming lighter, the oil also becomes significantly less viscous. Let’s use this analogy. If the oil in Lloydminster has the viscosity of molasses, the oil in Mantario is more like corn syrup, and Viking oil at Onward is even lighter - like milk. Since it is easier to produce oil that is less viscous, the recovery factors are higher. As our recovery factors improve, decline rates also improve.
  3. Lower Operating Cost: Lower operating cost = higher netbacks. The production practices in South West Saskatchewan are much more conventional, since we do not need to deal with high sand production. This in turn leads to better economics.
  4. Running Room: Unlike the Lloydminster area where most the mineral rights are held by a few major oil companies, in the Southwest Saskatchewan core area the rights are held mainly by the Crown. As a result, there is ample opportunity to acquire the drilling rights on new pools that we discover.
  5. Shallow Targets: Shallow targets mean a company like rock can afford to explore here. Rock has identified numerous exploration targets in this area. The prospective formations are generally 800-1,000 metres deep so it only costs about $500,000 to test each lead. A $5 million drilling budget means Rock can test 10 ideas. We expect to achieve a one in five chance of success so with a little luck we should be able to discover a new pool or two.
  6. Sizable Prizes: Though the targets are generally shallow, the size of the prize is still significant. At Mantario, for example, we believe our pool may contain 40-45 million barrels of oil on only 1.5 sections of land.


Mantario is the foundation block of Rock’s production base. Currently the pool produces over 3,300 boe per day from 38 vertical and 2 horizontal wells. In 2014 the Company plans to spend another $47 milllion at Mantario to drill 10 vertical and 9 horizontal oil wells, and construct a major production battery and water injection facility. This activity will move the development of the field from primary production (producing oil wells) to secondary development involving a water flood/pressure maintenance scheme. Early in 2015 the Company will begin the injection of chemicals (polymer) to further increase the recovery factor. On primary production, the pool is expected to recover 9-10 percent of the oil-in-place; under water flood it is forecast to recover 15 percent and under polymer flood (tertiary) the recovery factor is expected to be 25 percent. Though the recovery factor, recoverable reserves and value of the pool are increasing significantly, the Company is not forecasting a significant increase in production, but rather a flat production profile. This pool is forecast to produce flat for four to five years, generating over $60 million per year of cash flow, before starting to decline at 15-20 percent per year.

In addition to the development project at the main Mantario pool, Rock has identified 6-10 exploration leads in the area, similar in nature to the main pool, that will be tested in the next 12 months.

Mantario Battery 1 Mantario Battery 2 Mantario Battery 3 Mantario Battery 4 Mantario Battery 5 Mantario Future Battery Site


Viking: Rock began to explore the Viking play in early 2013 by testing for oil production in 3 vertical wells in the Onward area. With these successful tests the Company assembled over 38 net sections of lands in an area we believed to be oil-charged. Once the land was tied up, the Company drilled its first two horizontal wells (September 2013) to confirm the production capabilities. These two wells came on at an average rate of 40 barrels of oil per day which verified the potential for commercial production. By the end of the first quarter of 2014, the Company has drilled a total of 18 wells (including the first 2) in the play and achieved average initial production rates (30-day IP) of 50 barrels of oil per day, with total production from the Viking exceeding 500 barrels of oil per day. This activity has de-risked 15.5 sections of land, and generated up to 230 new development locations. For the remainder of 2014 Rock will focus on testing the remaining lands to determine the full extent of this resource. In 2015 the Company will consider the development of a significant Viking light oil production platform.

Mannville: Rock entered the Onward area in 2012 through the acquisition of a producing Mannville pool. At the time of the acquisition the pool was producing 200 barrels of oil per day from the Lloydminster Formation. Once acquired, the Company proceeded to optimize the production practices, by drilling new oil producers and re-configuring the injection patterns, and grew production to 325-350 barrels of oil per day. Further optimization is being completed on this pool and we expect production to continue to climb before entering a period of very shallow decline (10 percent per year).

During 2013 Rock was actively exploring for other Mannville targets in this area. A new pool discovery well was drilled in the fourth quarter and is currently producing over 100 barrels of oil per day from the Lloydminster Formation. This discovery was followed up by three or four development locations in the second quarter. Rock has identified numerous other exploration targets in this area and we expect to test four to six of them in the next 12 months

Onward Lightoil Battery 1 Onward Lightoil Battery 2 Onward Lightoil Battery 3