Quarterly / Earnings Reports | Second Quarter (2Q) Update

Crew Energy Talks Q2 2019 Results

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   |    Thursday,August 01,2019

Crew Energy Inc. reported its Q2 2019 results.

Q2 Highlights:

• Ultra Condensate-Rich ("UCR") Montney Development Drives 36% Growth in Condensate Production: Q2 condensate volumes averaged 3,127 bbls per day, an increase of 19% over Q1 2019 and 36% over Q2 2018. Total liquids contributed 61% to Crew's total petroleum and natural gas sales for the quarter. 
  
  
• Production of 22,865 boe per day with 31% Liquids: Total liquids increased to 31% of production, compared to 28% in Q1 2019 and 26% in Q2 2018. Greater Septimus production of 19,594 boe per day was in line with the previous quarter and 3% higher than Q2 2018, with significantly higher condensate volumes from newly completed UCR wells. 
  
  
• Stable Adjusted Funds Flow ("AFF"): Q2 AFF totaled $22.5 million or $0.15 per fully diluted share, compared to Q2 2018 AFF of $21.8 million or $0.14 per fully diluted share, reflecting the impact of increased higher-value condensate production. 
  
  
• Continued Strong UCR Results from 15-20 Pad: Crew's four "B" zone wells on the 15-20 pad at Greater Septimus have exceeded projections, generating average sales of 1,021 boe per day with 43% condensate and 11% other natural gas liquids ("ngl") over 120 days. 
  
  
• Positive Contribution from 4-21 Pad in UCR Transition Zone: Crew finalized completing and equipping wells on the 4-21 pad in Q2, which have flowed at restricted rates with average sales over 90 days of 1,042 boe per day, comprised of 28% condensate and 13% ngl. 
  
  
• Low Base Declines at Septimus Supports Sustainability: Production declines at Septimus are approaching 12% generating an operating netback that exceeds maintenance capital for the area. With continued development Crew plans on replicating this success in the UCR area. 
  
  
• UCR Spending Supports Strong Operational Execution: Exploration and development capital expenditures in the quarter totaled $14.0 million, in line with forecast guidance for the period. Net capital expenditures were $10.7 million, including a $3.3 million non-core disposition. Activity in Q2 was directed to finalizing the drilling of one (1.0 net) extended reach horizontal ("ERH") well on the 3-32 pad in the UCR area, and finalizing the completion, equip and tie-in of eight (8.0 net) wells, along with the recompletion of six (6.0 net) heavy oil wells at Lloydminster. 
  
  
• Financial Flexibility Maintained: Quarter end net debt of $353.4 million was 2% lower than Q1 2019 and includes $300 million of term debt due in 2024 which has no financial maintenance covenants. The Company's $235 millioncredit facility was renewed during the quarter and was drawn approximately 21% at the end of the period.

Operations Update

NE BC Montney - Greater Septimus

• During Q2 2019, Crew completed drilling one net ERH well with a lateral length of 3,050 metres on the 3-32 pad in our UCR area at West Septimus.   
  
  
• Results from wells on our 15-20 pad in the UCR area at Greater Septimus have remained strong and offer compelling returns.  The four "B" zone wells produced average sales of 1,021 boe per day comprised of 43% condensate and 11% ngl over 120 days on production.    
• At Crew's 4-21 pad in the UCR transition zone, results have also exceeded internal type well expectations for West Septimus.  The wells are being produced at restricted rates and have produced average sales of 1,042 boe per day over 90 days on production, including 28% condensate and 13% ngl.  
  
  
• As a result of the outperformance of these condensate-rich wells at Greater Septimus, Crew has been able to optimize our commodity mix and during Q2, effectively mitigated the impact of the six-day pipeline shut-down affecting approximately 19,500 boe per day of production along with our continued shut-in of dry gas.  
  
  
• During the pipeline outage, Crew accelerated Septimus facility maintenance work originally planned for 2020 and implemented further debottlenecking measures which are expected to improve the long-term efficiency of our operations. 

Other NE BC Montney

• Tower: Production at Tower averaged 592 boe per day in Q2 2019, reflecting the impact of production being shut-in for offset fracturing during the period. Crew continues to evaluate the relative economics of Tower development as well as reviewing encouraging nearby Lower Montney well results.
  
  
• Monias: Activity at Monias during Q2 was directed to preparing for the completion in Q3 of one horizontal Montneydelineation well that was drilled in Q1, approximately 18 km to the northwest of our West Septimus UCR core area.
  
  
• Attachie: Of Crew's 92 net sections of land in this area, approximately 44 net sections are situated within the liquids-rich hydrocarbon window. Given the positive results generated by offsetting operators, a lease retention well was drilled in January of 2019. 
  
  
• Oak / Flatrock: In this liquids-rich gas area, Crew has over approximately 60 (52 net) sections of land, and the Company plans to continue monitoring industry activity and offsetting well results.

AB / SK Heavy Oil - Lloydminster

• During Q2, activity at Lloydminster included the recompletion of six (6.0 net) heavy crude oil wells which contributed to average production of 1,722 bbls per day of heavy crude oil, a 7% increase over the prior quarter. Relative to Q2 2018, heavy crude oil volumes were approximately 11% lower due to limited capital investment in the area. 
  
  
• WCS pricing differentials continued to improve through Q2 and contributed to operating netbacks at Lloydminsterwhich averaged $24.93 per boe. To maximize profitability, Crew will continue to evaluate forward pricing for WCS for the purposes of optimizing the execution timing of a three (3.0 net) multilateral horizontal drilling program.

Outlook

Condensate and Liquids Trending Higher

• The ongoing evolution of Crew's drilling and completion design has improved efficiencies and contributed to condensate ratios trending higher while overall volumes remain stable. 
  
  
• The Company's emphasis on UCR drilling along with our goal of improving margins is meeting with success. Condensate volumes in Q2 increased 36% year-over-year while Crew's average condensate price of $68.96 per bbl was materially higher than the average corporate realized price per boe of $24.77.

Low Base Declines at Septimus Supports Sustainability

• At Septimus, Crew is successfully generating an operating netback that exceeds maintenance capital requirements for the area. As a result of Crew's investment in the area, production declines for Septimus are approaching 12%, representing similar performance attributes to a tight conventional reservoir rather than an unconventional reservoir. Crew plans to replicate the development success and free cash flow generation realized at Septimus within our UCR area, which has over 135 potential drilling opportunities¹, representing over ten years of highly economic future growth at Crew's current pace of development.

Financial Overview

Positive Impacts from Increased Condensate and Total Liquids Weighting

• Production of 22,865 boe per day for the quarter was 3% lower than the same period in 2018, and 2% lower than Q1 2019, with the decreases being attributable to voluntary dry gas shut-ins due to weak pricing, a third-party pipeline outage triggering a full shut down of the Septimus and West Septimus ("Greater Septimus") area production of approximately 19,500 boe per day for six days, and natural declines on Lloydminster production. 
  
  
• Condensate production averaged 3,127 bbls per day, an increase of 36% over Q2 2018 and 19% over Q1 2019, with total liquids production increasing to 31% of total volumes, higher than the 26% weighting in Q2 2018 and 28% in Q1 2019. Condensate contributed 38% to Crew's total sales in Q2 2019, compared with 32% in Q2 2018 and 26% in Q1 2019. 
  
  
• Greater Septimus production averaged 19,564 boe per day in Q2 2019, an increase of 3% over 18,953 boe per day in Q2 2018 and on par with Q1 2019 volume, despite the pipeline outage and related shut down.

AFF per Share Driven by Liquids and Condensate Production

• AFF in Q2 2019 was $22.5 million ($0.15 per diluted share), 7% higher on a per share basis than the same period in 2018, primarily due to higher condensate production and a lower realized hedging loss. For the first half of 2019, Crew's AFF of $48.3 million or $0.32 per diluted share was in line with the same period in 2018. 
  
  
• Quarter-over-quarter, AFF was 13% lower than Q1 2019, primarily attributable to weaker natural gas and ngl prices and higher transportation costs. These inputs were partially offset by lower net operating costs.

Quarter-over-Quarter Improvement in Liquids Volumes and Pricing

• Q2 2019 petroleum and natural gas sales decreased 7% compared to Q1 2019 primarily the result of a substantial drop in natural gas prices quarter-over-quarter. This was partially offset by increased condensate production and improved pricing for condensate and heavy crude oil.
  
  
• Petroleum and natural gas sales during Q2 2019 and for the first half of the year decreased 5% and 6%, respectively, relative to the same periods in 2018, mainly as a result of the lower production combined with lower realized light crude oil, condensate, and ngl prices in 2019 relative to the same periods in 2018.
  
  
• Quarter-over-quarter, Crew's realized light crude oil and condensate price increased 8% and 11%, respectively, approximating the 10% increase in the Canadian dollar denominated West Texas Intermediate ("WTI") benchmark price. WTI prices were bolstered by geo-political concerns arising over Iran's nuclear sanctions and military activity in the strategic Strait of Hormuz oil shipping channel. 
  
  
• Crew's heavy crude oil realized price increased 36% compared to Q1 2019, primarily in response to the Alberta Government's oil curtailment program. The realized price for ngl decreased 31% compared to Q1 2019, primarily due to price declines for propane and butane at Conway, the primary U.S. pricing market for the majority of Crew's ngl production.
  
  
• Crew's realized natural gas price for Q2 2019 was 32% lower than Q1 2019, as natural gas prices across North America declined as a result of continued production growth and reduced weather-related demand. Crew's diversified natural gas marketing portfolio partially offset the market weakness with 66% of the Company's sales exposed to U.S. pricing points. This resulted in a corporate wellhead price of $2.34 per mcf, compared to the Canadian benchmark AECO 5A price of $1.03 per mcf.
  
  
• Marketing income for the quarter was $2.6 million or $1.23 per boe compared to $2.9 million or $1.40 per boe in Q1 2019, and $0.6 million or $0.28 per boe in Q2 2018, reflecting the monetization of the Company's Dawn transport contract and Malin sales contract.

Lower Net Operating Costs Bolster Operating Netbacks

• Corporate operating netbacks in Q2 2019 and first half 2019 averaged $15.06 per boe and $15.88 per boe, respectively, an improvement of 7% and 10% over the same periods in 2018. Compared to Q1 2019, operating net backs decreased 10% as a result of lower commodity prices and higher transportation costs, offset by lower operating costs.
  
  
• Cash costs per boe for Q2 increased 2% relative to Q1 2019, which reflects higher transportation costs per boe, offset by lower royalties and net operating costs per boe. Compared to the same period in 2018, cash costs per boe increased due to higher transportation, financing and G&A costs per boe, offset by lower royalties and net operating costs per boe. 
  
  
• Q2 and first half 2019 net operating costs and net operating costs per boe decreased relative to the same periods in 2018, as a result of a decline in Tower and Lloydminster production, areas which have higher operating costs per boe. Quarter-over-quarter net operating costs were down 4% due to the seasonal decline in field operating costs. 
  
  
• Transportation costs in Q2 2019 and the first half of 2019 increased compared to Q1 2019, and the corresponding periods in 2018, as the Company works to provide further diversified market opportunities for its natural gas production. Further transportation costs were added in April 2018 with the introduction of new service on the NGTL system, and in April 2019 with the addition of fees associated with third party ownership of the sales pipeline between West Septimus and the Saturn meter station.

Q2 Capital Expenditures In-Line with Guidance

• Exploration and development capital expenditures in Q2 were $14.0 million, or $10.7 million net after the impact of a non-core disposition of $3.3 million during the period. Year-to-date in 2019, Crew has invested $50.1 million in net capital expenditures, with the majority directed to drilling and development opportunities within the Company's UCR area. 
  
  
• Approximately $7.8 million of our Q2 capital was allocated to drilling and completion activities in the UCR area, including drilling one (1.0 net) ERH well with a lateral length of 3,050 metres on Crew's 3-32 pad along with finalizing the completion and equipping of eight (8.0 net) wells. Crew directed $3.3 million to Montney well site development, facilities and pipelines and $2.9 million to land, seismic and other miscellaneous expenditures.

Ongoing Focus on Balance Sheet Strength

• Net debt of $353.4 million was 3% lower than at the end of Q1 2019 due to the Company's 2019 capital expenditure program being weighted to higher first quarter spending. 
  
  
• The Company's debt is comprised of $300 million of term debt with no financial maintenance covenants or repayment required until 2024, as well as a $235 million credit facility that was 25% drawn after adjusting for a working capital deficiency of approximately $9.7 million at quarter end. 
  
  
• Crew's credit facility was renewed during Q2, with no changes to the borrowing base of $235 million, no financial maintenance covenants, and access to the full borrowing base value. 
  
  
• Further work on optimizing the asset portfolio in Q2 2019 contributed to the $3.3 million disposition of 2.7 (2.0 net) sections of non-core assets having no production or reserves assigned, with proceeds directed to debt reduction and maintaining a healthy financial position.

Transportation, Marketing & HEDGING

Diversified Market Access Provides Strategic Benefit

• In Q2 and first half 2019, Crew elected to monetize our Dawn and Malin market exposure, realizing marketing income of $2.6 million and $5.5 million, respectively. Crew has further elected to monetize these contracts for Q3 2019, resulting in approximately $1.8 million of marketing income to be realized in the quarter. 
  
  
• For the second half of 2019, our average natural gas sales exposure is currently expected to be approximately 55% to Chicago, 17% to NYMEX, 8% to Alliance ATP, 7% to Dawn, 5% to Malin, 5% to Station 2 and 3% to AECO 5A.

Natural Gas & Liquids Hedging

• Crew's natural gas hedges currently include:
• 25,000 mmbtu per day of Chicago gas at C$3.53 per mmbtu for 2019
• 7,500 mmbtu per day of Dawn gas at C$3.55 per mmbtu for 2019
• 10,000 mmbtu per day of NYMEX gas at US$2.95 per mmbtu for 2019
• 7,500 mmbtu per day of Chicago gas at C$3.40 per mmbtu for 2020
  
  
• For liquids, Crew has the following hedges in place:
• 1,874 bbls per day of WTI at an average price of C$75.99 per bbl for 2019
• 250 bbls per day of WCS for Q4 2019 at C$56.20 per bbl
• 250 bbls per day of differentials at US$17.25 per bbl for Q3 2019
• 500 bbls per day of WCS differential at C$25.23 per bbl for the second half of 2019
• 750 bbls per day of WTI at an average price of C$79.12 per bbl for 2020