Trilogy updates Alberta Montney, Duvernay activity

Trilogy Energy Corp., Calgary, has recently finished completing the Trilogy horizontal Kaybob 9-10-64-19w5 stepout well on the western side of the Kaybob Montney oil pool and also plans to participate for its 30% working interest in two four-well pads targeting Duvernay production.

The 9-10 Montney well is averaging 438 b/d of oil, 900 Mcfd of gas, and 104 b/d of water at 2,200 kPa tubing pressure after a 27-stage frac along its 2,018 m of horizontal length. All load fluids are recovered.

Trilogy is encouraged by the early results and believes they support the potential that the pool extends beyond the previously identified boundaries. More work is required to completely evaluate the reserves and to confirm that these results support continued expansion.

Trilogy rig-released the stepout well at 16-29-63-17w5 on Sept. 26 that was drilled to evaluate additional acreage on the eastern margin of the Kaybob Montney oil pool. The 16-29 well is expected to be completed and evaluated through October and November and with a successful completion should be on production in the first quarter of 2014.

In the third quarter, Trilogy completed drilling the Duvernay horizontal well at 1-24-61-22w5 and moved the drilling rig to the next location at 13-33-57-18w5. Both wells were drilled to maintain Trilogy’s Duvernay land position. Following the 13-33 drilling, the rig will move to 16-28-58-18w5 to drill a vertical well that is expected to preserve a 14-section block.

In the same quarter, Trilogy elected to participate for its 30% working interest in a four-well pad operated by a third-party targeting Duvernay. The average cost to drill and complete, net of certain technical expenses, was $12 million/well. The four laterals were each 2,000 m in length and were completed in 100 fracture intervals in 17 stages.

The four wells were production-tested in August at an average per well rate of 3.4 MMcfd of gas and 1,366 b/d of condensate. Each well was flow-tested for 53 hrs with average flowing pressures between 13 and 24 MPa. The four-well pad is expected to be tied in during September and placed on production in late October.

Trilogy also plans to participate for its 30% working interest in a second four-well pad 2 miles west of the first multiwell pad. Drilling is finished, and completion operations are expected to begin in early October with first production in December. The estimated cost to drill, complete, equip, and tie-in this pad is $12 million/well.

These two multiwell pads are on the same joint interest land block on which Trilogy and its partner drilled two wells in 2012. Those two wells were brought on production in August 2013, producing for 28 days before being shut in due to maintenance at the Keyera Simonette gas plant.

The two joint wells were flowing at restricted rates of 500 b/d each of 48-54° gravity condensate with associated gas production. The wells should return to production when plant maintenance is completed at the end of September.

Trilogy has approximately 125 net sections of prospective lands in the volatile oil area and 75 net sections of land in what Trilogy interprets to be the gas-condensate area of the play.

With the added capital spending related to this Duvernay activity and costs associated with previously unbudgeted activity, Trilogy will review its spending plans for the rest of 2013 and provide further guidance when it releases operating and financial results released in November.

Through September, Trilogy’s production has been impacted by various plant outages in the Kaybob and Grande Prairie areas, including the Trilogy-operated Kaybob North gas plant that processes a large portion of Trilogy’s production.

Trilogy had contingency plans to redirect the impacted production to the SemCAMS K3 Plant, but an unexpected outage at that plant necessitated those volumes being curtailed through September. These plant outages will reduce third quarter volumes to 31,000 b/d of oil equivalent.

The company expects to resume normal production levels in the fourth quarter. The added capital projects described here will not have a significant impact on the average annual production rate as the new wells are expected to come on production late in the current year; however, the additional wells are expected to increase the exit rate for the year.

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