CALGARY, Alberta, March 08, 2018 (GLOBE NEWSWIRE) — Chinook Energy Inc. (“our”, “we”, or “us”) (TSX:CKE) is pleased to announce its fourth quarter and 2017 financial and operating results.
Our operational and financial highlights for the three months and year ended December 31, 2017 are noted below and should be read in conjunction with our consolidated financial statements for the years ended December 31, 2017 and 2016 and our related management’s discussion and analysis which have been posted on the SEDAR website (www.sedar.com) and our website (www.chinookenergyinc.com).
Fourth Quarter and 2017 Financial and Operating Highlights
|Three months ended
|Natural gas liquids (boe/d)||551||613||470||637|
|Natural gas (mcf/d)||19,240||21,548||17,602||24,631|
|Crude oil (bbl/d)||21||451||22||768|
|Average daily production (boe/d) (1)||3,779||4,655||3,425||5,510|
|Average natural gas liquids price ($/boe)||$||51.87||$||40.70||$||47.89||$||26.35|
|Average natural gas price ($/mcf)||$||0.99||$||3.31||$||1.95||$||2.06|
|Average oil price ($/bbl)||$||76.96||$||71.98||$||62.27||$||52.01|
|Average commodity pricing ($/boe)||$||13.02||$||27.67||$||16.97||$||19.51|
|Royalty (expense) recovery ($/boe)||$||(0.08||)||$||(2.84||)||$||0.05||$||(1.19||)|
|Realized gain (loss) on commodity price contracts ($/boe)||$||3.83||$||(0.35||)||$||3.02||$||0.50|
|Net production expense ($/boe) (2)||$||(11.06||)||$||(11.88||)||$||(11.57||)||$||(13.61||)|
|Operating Netback ($/boe) (1) (2)||$||5.71||$||12.59||$||8.45||$||5.21|
|Wells Drilled (net)|
|Total natural gas wells drilled (net)||–||2.64||3.63||2.64|
|Three months ended||Year ended
|December 31||December 31
|FINANCIAL ($ thousands, except per share amounts)|
|Petroleum & natural gas revenues, net of royalties||$||4,499||$||10,631||$||21,271||$||36,943|
|Adjusted funds flow (outflow) (2)||$||1,100||$||1,713||$||4,978||$||(1,004||)|
|Per share – basic and diluted ($/share)||$||0.01||$||0.01||$||0.02||$||(0.00||)|
|Net (loss) income||$||(21,160||)||$||6,427||$||(16,914||)||$||(54,773||)|
|Per share – basic and diluted ($/share)||$||(0.10||)||$||0.03||$||(0.08||)||$||(0.25||)|
|Net (debt) surplus (2)||$||(711||)||$||15,138||$||(711||)||$||15,138|
|Common Shares (thousands)|
|Weighted average during period|
|Outstanding at period end||223,565||216,443||223,565||216,443|
(1) Amounts may not be additive due to rounding.
(2) Adjusted funds flow (outflow), adjusted funds flow (outflow) per share, net surplus (debt), operating netback, and net production expense are non-GAAP measures. These terms do not have any standardized meanings as prescribed by IFRS and, therefore, may not be comparable with the calculations of similar measures presented by other companies. See headings entitled “Adjusted Funds Flow (Outflow)”, “Net (Debt) Surplus”, “Operational Netback” and “Net Production Expense” in the Reader Advisory below for further information on such terms.
- During 2017, we completed the sale of non-core properties in the Knopcik/Pipestone and Gold Creek areas of Alberta for net consideration of approximately $17.8 million after customary closing adjustments. These dispositions marked the completion of our transition to a Montney focused company.
- During 2017, we negotiated and secured a demand credit facility as amended with a Canadian chartered bank to increase the availability to $18.0 million which provides us with further financial flexibility.
- Our total proved producing reserves increased by 47% from 2016 to 2017.
- Our total proved (“1P”) reserves increased by 26% from 2016 to 2017 with record low finding and development (“F&D”) costs of $6.04/Boe (1P additions replaced 412% of production).
- Our total proved plus probable (“2P”) reserves increased by 28% from 2016 to 2017 with F&D costs of $5.26/Boe (2P additions replaced 694% of production).
- The net present value (NPV 10%) of our 1P and 2P reserves increased 25% and 21% respectively, notwithstanding an average 22% reduction to forecasted five year BC Plantgate gas prices.
- Reserves have been booked over only 18% of our approximately 53,200 gross acres (44,350 net acres) of Montney rights in the greater Birley/Umbach area.
- During 2017, we drilled four wells (3.63 net) and completed, equipped and tied-in seven wells (6.27 net) at Birley/Umbach.
- Our capital investment was $39.0 million during 2017, including $11.5 million to complete our Birley/Umbach compression facility expansion from 25 mmcf/d to 50 mmcf/d, which was commissioned on-time near the end of December 2017.
- Upon completion of the latest four new Birley/Umbach wells, the final 24 hour test rates per well averaged 1,800 boe/d including 300 bbl/d of condensate. Two of these wells (1.63 net) came on-stream at the beginning of October 2017; however, due to third party restrictions these new wells are currently flowing at restricted rates.
- These four new Birley/Umbach wells were drilled with longer laterals and completed with a new design including more frac stages with less proppant per stage, tighter spacing and using a ‘zipper frac’ technique on parallel well pairs. We anticipate incorporating this new completion design into our future drilling operations. Early production data indicates that these wells have significantly higher free condensate gas ratios which were up 90% compared to the IP30 rates from previously drilled offsetting wells.
- During December 2017, we completed the private placement of 6,450,000 common shares on a flow-through basis at a price of $0.31 per flow-through common share for total gross proceeds of $2.0 million.
2018 Recent Highlights
- During the first quarter of 2018, we drilled two (2.0 net) vertical exploratory wells in the Birley/Umbach area for $2.1 million. These wells delineated 17 undrilled contiguous sections of 100% owned Montney rights which are located eight kilometres from the nearest well drilled into the Montney. The reservoir quality throughout the entire 235 metre thick Montney zone was evaluated with these wells.
- During the first quarter of 2018, we entered into a commodity price contract to fix the Chicago City Gate index price of 6,000 mmbtu/d of natural gas at US$2.68/mmbtu from February 1, 2018 to March 31, 2019.
2017 Financial Results
Our production during the fourth quarter and year ended 2017 averaged 3,779 boe/d and 3,425 boe/d, a decrease of 19% and 38%, respectively, from the same periods of 2016. These production decreases were primarily due to the absence of both the legacy assets of a subsidiary that we acquired late in the second quarter of 2016, and the majority of our Alberta assets that we conveyed to that subsidiary, as a result of the distribution of that subsidiary’s shares to our shareholders late in 2016 (the “Share Distribution”) and various other property dispositions. In addition, an unforeseen pipeline integrity issue on Enbridge’s Oak 16” gathering line (the “Oak Pipeline”) restricted our Birley/Umbach and Martin Creek production in December 2017 through to the date of this news release. Furthermore, for 2017, our volumes were significantly impacted by a longer than scheduled turnaround at the Enbridge McMahon gas plant and other third party restrictions.
Our 2017 operating netback increased 62% to $8.45/boe compared to the same period of 2016. This increase was driven by our lower cash-based cost structure for our Montney assets and the absence of the properties included in the Share Distribution and other property dispositions which had a higher cash-based cost structure. This increase was despite a decrease in our realized commodity pricing. Our realized commodity price decreases generally trended with the decreases in benchmark pricing resulting in a realized price of $16.97/boe for 2017. We realized a record low Station 2 benchmark price during the second half of 2017, not observed in over two decades as attributable to temporary third party pipeline restrictions which are causing an increase in the overall pressure on the BC system and a surplus of natural gas at Station 2. During 2017, we sold approximately 75% of our natural gas production at Station 2 and approximately 25% at the comparably higher Chicago City Gate benchmark compared to selling only 14% of our 2016 natural gas production at Chicago City Gate benchmark. This increase in the 2017 proportion of our sales at the Chicago City Gate benchmark partially offset the decrease in the Station 2 benchmark and we continue to pursue transportation alternatives with more favorable pricing. We realized a recovery of royalties during 2017 of $0.05/boe due to BC Government royalty grants and a gas cost allowance adjustment. Our 2017 net production expense of $11.57/boe decreased from the same period of 2016, despite significantly lower volumes, primarily due to the divestiture of higher cost properties and our lower cost structure Montney properties. However, our net production expense per boe was higher than our expectations due in part to lower production volumes relative to our fixed operating costs.
For the fourth quarter of 2017 (“fourth quarter”), our operating netback decreased 55% to $5.71/boe compared to the same quarter of 2016. This decrease was driven by lower realized commodity pricing despite improvements in each of the other components of the operating netback. Our realized commodity pricing decreases generally trended with the decreases in benchmark pricing which included the significant decrease in the Station 2 benchmark resulting in an average realized price of $13.02/boe for the fourth quarter. Consistent with 2017, our lower proportion of the comparatively higher priced crude oil sales also negatively impacted our realized pricing in the fourth quarter compared to the same quarter of 2016. We realized lower royalties during the fourth quarter compared to the same quarter of 2016 due to BC Government royalty grants. Our other cost improvements are due to the same reasons previously explained.
For 2017, our adjusted funds flow of $5.0 million increased compared to the adjusted funds outflow of $1.0 million during 2016, as a result of higher natural gas liquids pricing and a lower cash-based cost structure for our Montney focused operations. Despite this favorable cost structure, lower realized natural gas pricing and restricted production volumes resulted in the fourth quarter’s adjusted funds flow of $1.1 million decreasing compared to the $1.7 million in the same quarter of 2016. Despite historically low Station 2 benchmark pricing and restricted production volumes, our fourth quarter adjusted funds flow is the sixth consecutive quarter we have reported positive adjusted funds flow which corresponds to when we started our transition to a Montney focused play.
We reported a net loss for 2017 of $16.9 million compared to a net loss of $54.8 million during the same period of 2016. This improvement reflects a lower cost structure associated with our transition to a Montney focused play in addition to higher gains from the disposition of non-core properties and on commodity price contracts. However, partially offsetting these gains were lower natural gas pricing and restricted production volumes. The comparative period of 2016 was also impacted by net losses from our previous subsidiary’s operations whose shares were included in the Share Distribution. These net losses included $58.1 million of impairment charged against the subsidiary’s assets but as partially offset by $20.6 million of net losses attributable to the non-controlling interest.
2017 Operational Results
With the sale of our non-core assets at Gold Creek and Knopcik/Pipestone during the first quarter of 2017, we have completed our transformation into a Montney play focused company. The capital raised from these dispositions as well as cash on hand and adjusted funds flow were used during 2017 to develop our Birley/Umbach property.
During the first quarter of 2017, we completed and tied-in the three wells (2.64 net) (the a-71-F, d-95-F and c-95-F wells) drilled during the fourth quarter of 2016. Total costs for the first three wells, including the fourth quarter of 2016 drilling costs, totalled an average of $3.7 million per gross well.
During the second and third quarters of 2017, we successfully drilled, completed and tied-in our four (3.63 net) horizontal Montney gas wells at Birley/Umbach (the a-81-F, b-90-G, 02/d-5-K and b-14-K wells), with various downhole locations on our D-93-F pad. On average, each well cost $4.6 million gross to drill and complete. The higher average total cost per well incurred on our most recent drilling program, compared to the previous 2016 three (2.64 net) well program, resulted from each well, on average, having 200 metre longer lateral lengths and eight additional completion stages.
Also included in our 2017 capital expenditures was $11.5 million for the expansion of our Birley/Umbach facility to 50 mmcf/d. This expansion was commissioned on-time late in December 2017. The completion of this expansion provides us with the capacity to produce all of our 13 (11.23 net) Birley/Umbach wells, once third party restrictions are resolved, as expected by April 2018.
Gross test results and production from our Birley/Umbach property are as follows(1) (2):
|Well||Working Interest (%)||On Production Date||Total Depth (meters)||Drill Time (days)||Lateral Length (metres)||Ports||Frac’d Stages (gross)||Stage Spacing (meters)||Total Gross Cost ($ thousands)||IP30 Gas (mcf/d)||IP30 CGR (bbl/ mmcf)||IP60 Gas (mcf/d)||IP60 CGR (bbl/ mmcf)||IP90 Gas (mcf/d)||IP90 CGR (bbl/ mmcf)||IP120 Gas (mcf/d)||IP120 CGR (bbl/ mmcf)||IP180 Gas (mcf/d)||IP180 CGR (bbl/ mmcf)||IP365 Gas (mcf/d)||IP365 CGR (bbl/ mmcf)|
(1) Initial production or test rates are not necessarily indicative of long-term performance of the relevant well or fields or of ultimate recovery of hydrocarbons. Well-flow test result data should be considered to be preliminary until a pressure transient analysis and/or well-test interpretation has been carried out. Please see “Initial Productions Rates” under the Reader Advisory section of this news release
(2) IP gas and liquids rates shown in the table above are calculated on an average basis which excludes non-producing days.
The growth potential in our Birley/Umbach area is significant, with approximately 53,200 acres (44,350 net) of Montney rights. There are over 290 (242 net) management identified locations (at four horizontal wells per drill spacing unit) in the upper Montney interval alone, with additional potential to develop the middle Montney over the entire land block and the lower Montney in areas with sufficient reservoirs.
2017 marked a successful year for us as we moved from delineation to exploitation of our Birley/Umbach property. In early 2014, we drilled our first Montney test well at Birley at a time when others were not entirely convinced of its prospectivity. The results of that test well, along with our follow up wells, confirmed the presence of a large Montney resource and established a large drilling inventory for Chinook. Subsequent to our Birley discovery, we began to streamline our business by divesting of our international assets in Tunisia and transacting on all our non-core Alberta assets through either cash dispositions or share transactions.
Today we are a Montney focused company with a healthy balance sheet. During 2017 we were not able to show the full results and benefits of our newly streamlined operations due to low commodity prices and third party restrictions. Currently, we continue to produce at volumes less than our capability due to gathering system maintenance issues on the Oak Pipeline which are expected to be temporarily resolved by April 2018. In anticipation of weaker natural gas prices, we may voluntarily shut-in volumes through the summer months as we do not have large take or pay commitments that would force us to produce at low prices.
However, we believe that our capital program during the last few years which saw us drill and complete 13 (11.23 net) wells on our Birley/Umbach property as well as our on-time completion of our Birley facility expansion to 50 mmcf/d puts us in an excellent position to accelerate activity when commodity prices recover. We have confirmed the resources are there, now our objective will be to extract them efficiently and profitably. To that effect, although we are encouraged about the results of our exploitation program in 2017 and additional delineation work in 2018, we remain cautious on further capital expenditures until such time as commodity prices improve to a more constructive level. The capital program for the balance of 2018 will be minimal and continuously reviewed by management and the board of directors with adjustments made in response to changing market conditions.
We also believe that consolidation is required and would increase efficiencies among producers and streamline operations. We will continue to pursue opportunities that have the potential to generate additional value to our shareholders.
About Chinook Energy Inc.
Chinook is a Calgary-based public oil and natural gas exploration and development company which is focused on realizing per share growth from its large contiguous Montney liquids-rich natural gas position at Birley/Umbach, British Columbia.
For further information please contact:
President and Chief Executive Officer
Chinook Energy Inc.
Telephone: (403) 261-6883
Vice President, Finance and Chief Financial Officer
Chinook Energy Inc.
Telephone: (403) 261-6883