Lindbergh Production Establishes New Record in October Averaging 18,350 bbl/d with Five of Eight Infill Wells on Production
CALGARY, Alberta, Nov. 08, 2018 (GLOBE NEWSWIRE) — Pengrowth Energy Corporation (“Pengrowth”) (TSX:PGF, OTCQX:PGHEF), today reported its results for the three and nine months ended September 30, 2018. Unless otherwise indicated, financial figures are expressed in Canadian Dollars.
“As a result of the successful execution of our 2018 infill program, current production levels at Lindbergh now exceed our 2018 exit rate guidance with three more infill wells still to be brought into production. In addition, stronger AECO natural gas pricing has caused us to return Groundbirch to full production. These accomplishments, along with the significant decrease in cash G&A costs expected in the fourth quarter, put the company on track to meet 2018 Guidance,” said Pete Sametz, President and Chief Executive Officer of Pengrowth. “Approximately 17,000 bbl/d of diluted bitumen, representing 72% of our Lindbergh diluted bitumen sales, continues to be protected from apportionment at a fixed differential price of US$16.82 through the physical contracts that we have in place.”
“We paid down debt during the quarter with adjusted funds flow and deferred proceeds collected on previous dispositions. Our 2019 capital plan is structured to maintain current production levels while applying surplus adjusted funds flow to debt reduction. Pengrowth plans to synchronize the expansion of production at Lindbergh with the addition of pipeline take-away capacity in Western Canada. We continue to work toward a third party agreement to provide co-generation of steam and electricity to enable Lindbergh’s long-term production growth.”
Third Quarter at a Glance (Due to 2017 dispositions, comparisons are to the second quarter of 2018):
- Total debt before working capital decreased 4% or $29.3 million to $672.2 million compared with $701.5 million in the second quarter of 2018 (the “prior quarter”) as the result of $20.5 million in repayments and an $8.8 million favourable foreign exchange impact;
- Increased adjusted funds flow for the third quarter by 54% to $15.6 million compared with $10.1 million in the prior quarter despite a 4% decrease in production related to curtailed production at Groundbirch;
- Incurred capital expenditures of $6.8 million in the third quarter. Of the $65 million 2018 capital program, $56.3 million or 87% has been spent year-to-date as planned;
- Royalty expenses decreased 8% to $3.69/boe compared with $3.99/boe in Q2 2018 due to the general decrease in WCS pricing, partially offset by an increase in sliding Crown royalty rates due to rising WTI pricing;
- Achieved adjusted operating expenses of $10.72/boe in the third quarter which was in-line with Guidance;
- Decreased Cash G&A expenses by 7% to $3.99/boe compared with $4.28/boe in Q2 2018; and
- Realized losses on WTI financial hedges of $22.9 million in the third quarter. Pengrowth has no WTI financial hedges in place for 2019.
- Achieved record quarterly production at Lindbergh of 16,408 bbl/d and on track to reach 19,000 bbl/d in Q4;
- The steam-oil ratio (“SOR”) at Lindbergh for the third quarter decreased 4.2% to 2.99 compared with 3.12 in the prior quarter as new infill wells were brought into production;
- Realized an average differential to West Texas Intermediate (“WTI”) of US$(17.10) for diluted Lindbergh bitumen in the third quarter as a result of our apportionment protected fixed differential physical contracts with key U.S. refineries; and
- Realized Lindbergh operating netbacks of $38.88/bbl, an increase of 14% compared with $34.20/bbl in Q2 2018 (before corporate realized commodity risk management).
Summary of Financial & Operating Results
|Three months ended|
|(monetary amounts in millions except per boe and per share amounts)||Sept 30, 2018||Jun 30, 2018||% Change||Sept 30, 2017||% Change (4)|
|As adjusted (1)|
|Average daily production (boe/d)||21,807||22,600||(4||)||35,072||(38||)|
|Oil and gas sales (1)||$147.9||$146.4||1||$125.1||18|
|Cash proceeds from dispositions||$9.6||$3.5||174||$449.8||(98||)|
|Interest and financing charges||$12.3||$12.6||(2||)||$14.7||(16||)|
|Adjusted funds flow (2)||$15.6||$10.1||54||$(0.3||)|
|Weighted average number of shares outstanding (000’s)||556,117||556,117||—||552,246||1|
|Adjusted funds flow per share (2)||$0.03||$0.02||50||$—|
|Produced petroleum revenue per boe (2)||$47.10||$42.59||11||$28.08||68|
|Operating expenses per boe (1)||$11.02||$10.36||6||$15.99||(31||)|
|Adjusted operating expenses per boe (2)||$10.72||$10.11||6||$14.54||(26||)|
|Royalty expenses per boe||$3.69||$3.99||(8||)||$1.89||95|
|Operating netback before realized commodity risk management per boe (2)||$29.85||$25.82||16||$9.91||201|
|Cash G&A expenses per boe (2)||$3.99||$4.28||(7||)||$3.47||15|
|STATEMENT OF INCOME (LOSS)|
|Net income (loss)||$(1.6||)||$(27.5||)||(94||)||$(144.7||)||(99||)|
|Net income (loss) per share||$—||$(0.05||)||(100||)||$(0.26||)||(100||)|
|Total debt before working capital (3)||$672.2||$701.5||(4||)||$956.0||(30||)|
(1) IFRS 15 was early adopted in the fourth quarter of 2017 effective January 1, 2017 using cumulative effect approach without restating prior period comparatives. See Note 2 to the December 31, 2017 audited Consolidated Financial Statements.
(2) See definition in our MD&A under section “Non-GAAP Financial Measures“.
(3) Includes Credit Facility, current and long term portions of term notes, as applicable, and bank indebtedness. Excludes letters of credit and finance leases.
(4) Percentage changes in excess of 500% are excluded
2018 & 2019 Guidance
We are maintaining the 2018 Guidance that we revised in the prior quarter and are providing 2019 Guidance. The table below provides a summary of actual results for the nine months ended September 30, 2018, full year 2018 Guidance and full year 2019 Guidance:
| Actual Year to date
Sept 30, 2018
|Full Year 2018 Guidance (1)||Full Year 2019 Guidance (1)|
|Lindbergh Average Production (bbl/d)||15,805||16,500||17,750 – 18,250|
|Average production (boe/d)||21,324||22,500 – 23,500||22,500 – 23,500|
|Capital expenditures ($ millions)||56.3||65||45|
|Royalty expenses (% of produced petroleum revenue) (2) (3)||8.1||8.5 (4)||7.0 – 8.0|
|Adjusted operating expenses ($/boe) (2)||10.41||10.50 – 11.50||9.25 – 10.00|
|Cash G&A expenses ($/boe) (2)||4.41||3.50 – 3.85 (4)||2.50 – 2.75|
(1) Per boe estimates based on high and low ends of production Guidance.
(2) See definition under section “Non-GAAP Financial Measures“.
(3) Excludes financial commodity risk management activities.
(4) Guidance revised in the second quarter of 2018.
Year to date 2018 production of 21,324 boe/d is on track to reach full year 2018 Guidance supported by solid base production from Lindbergh and Groundbirch. Lindbergh production averaged 15,805 bbl/d in the first nine months of 2018 incorporating a partial outage to complete planned maintenance activity and initial production from four of the eight infill wells. The remaining four infill wells are targeted to be on production throughout the fourth quarter of 2018. Lindbergh production is now expected to exit the year at approximately 19,000 bbl/d. The previously curtailed gas production at Groundbirch due to low natural gas prices will be brought back on stream in the fourth quarter of 2018 given higher seasonal pricing.
Year to date 2018 cash G&A expenses per boe are higher than full year 2018 Guidance due to inclusion of costs related to the administrative support associated with disposed properties, higher professional fees, and salaries of staff subject to corporate restructuring. Fourth quarter 2018 cash G&A expenses are expected to further decrease and, coupled with strong production in the fourth quarter, drop to a range of $2.50 to $2.80 per boe. Pengrowth therefore anticipates full year 2018 cash G&A expenses per boe to be in line with its revised full year 2018 Guidance as per the table above.
Third Quarter Operational Review
Average daily production for the third quarter decreased 4% to 21,807 boe/d compared with 22,600 boe/d in the second quarter of 2018 primarily as a result of our choice to curtail production at Groundbirch due to natural gas pricing.
|Three months ended|
|PRODUCTION||Sept 30, 2018||Jun 30, 2018||% Change||Sept 30, 2017||% Change|
|Natural gas (Mcf/d)||27,604||34,064||(19)||83,979||(67)|
|Light oil (bbl/d)||663||769||(14)||5,472||(88)|
|Natural gas liquids (NGL) (bbl/d)||135||278||(51)||3,517||(96)|
Lindbergh was responsible for 75% of third quarter total production. Four of the eight infill wells that were completed in the second quarter of 2018 were brought into production in September. This contributed to a 3% increase in average daily production to 16,408 bbl/d compared with 15,876 bbl/d in the prior quarter. The steam-oil ratio (“SOR”) for the third quarter decreased 4.2% to 2.99 compared with 3.12 in the prior quarter as new infills were brought into production. We expect this to drop further as the remaining infill wells are brought on. The cumulative SOR as at September 30, 2018 was 2.66.
Groundbirch production was intentionally curtailed to 16,199 Mcf/d during the third quarter of 2018 from a peak production of 28,000 Mcf/d in early April due to weaker natural gas prices.
Lindbergh’s third quarter operating netbacks before corporate realized commodity risk management increased 14% to $38.88/bbl compared with $34.20/bbl in Q2 2018 due to increased realized bitumen prices, lower diluent costs, lower energy operating expenses, slightly lower non-energy operating expenses, offset by higher royalties and increased transportation costs on a per barrel basis.
|Three months ended|
|Lindbergh Operating Netbacks ($/bbl) (1)||Sept 30, 2018||Jun 30, 2018||% Change (3)||Sept 30, 2017||% Change (3)|
|Diluted Bitumen Revenue (2)||68.06||65.16||4||37.35||82|
|Diluent Costs (Inc. transportation)||(11.42)||(12.69)||(10)||(5.78)||98|
|Bitumen revenue (2)||56.64||52.47||8||31.57||79|
|Operating expenses – Non-energy||(7.49)||(7.54)||(1)||(10.82)||(31)|
|Operating expenses – Energy||(2.38)||(3.25)||(27)||(3.77)||(37)|
|Operating netbacks before realized commodity risk management||38.88||34.20||14||11.49||238|
(1) See definition in our MD&A under section “Non-GAAP Financial Measures“.
(2) Net of Fixed Differential Physical Contracts
(3) Percentage changes in excess of 500% are excluded
Corporate operating netbacks before realized commodity risk management in the third quarter increased 16% to $29.85/boe compared with $25.82/boe in Q2 2018 due to increased commodity prices, decreased royalties, partially offset by increased adjusted operating expenses and transportation expenses.
|Three months ended|
|Corporate Operating Netbacks ($/boe) (1) (2)||Sept 30, 2018||Jun 30, 2018||% Change (3)||Sept 30, 2017||% Change (3)|
|Produced petroleum revenue (1)||47.10||42.59||11||28.08||68|
|Adjusted operating expenses (1)||(10.72)||(10.11)||6||(14.54)||(26)|
|Operating netbacks before realized commodity risk management||29.85||25.82||16||9.91||201|
|Realized commodity risk management||(11.41)||(9.82)||16||1.15|
|Operating netbacks ($/boe)||18.44||16.00||15||11.06||67|
(1) See definition in our MD&A under section “Non-GAAP Financial Measures“.
(2) Prior year comparative figures changed to conform to presentation in the current year.
(3) Percentage changes in excess of 500% are excluded
During the second half of 2017, to ensure compliance with relaxed covenants on its debt, Pengrowth entered into a series of WTI hedges on 10,000 bbl/d of production at approximately WTI US$50/bbl to the end of 2018. For the third quarter of 2018, these hedges resulted in a 16% increase in realized commodity risk management loss of $11.41/boe compared with $9.82/boe loss in the second quarter of 2018 driven by increased commodity prices. At this time, Pengrowth does not have any WTI crude oil pricing hedges in place for 2019.
Corporate operating netbacks for the third quarter increased 15% to $18.44/boe compared with $16.00 in the second quarter of 2018 on an increase in realized commodity pricing.
Adjusted Funds Flow
Adjusted funds flow for the three months ended September 30, 2018 increased 54% to $15.6 million compared with $10.1 million in the prior quarter due to the variances provided in the table below:
|($ millions)||Q2/18 vs. Q3/18|
|Adjusted funds flow for comparative period (1)||Q2/18||10.1|
|Increase (decrease) due to:|
|Prices including differentials||5.8|
|Realized commodity risk management||(2.7||)|
|Adjusted operating (1)||(0.7||)|
|Cash G&A (1)||0.8|
|Interest & financing||0.3|
|Other – including transportation||0.1|
|Adjusted funds flow (1)||Q3/18||15.6|
1 See definition in our MD&A under section “Non-GAAP Financial Measures“.
Pengrowth reported a net loss in the third quarter of $1.6 million compared with a net loss of $27.5 million in the second quarter of 2018. The improvement from the prior quarter was primarily the result of a $25.3 million positive change in fair value of commodity risk management contracts, a $5.5 million increase in adjusted funds flow, a $4.5 million positive variance in realized and unrealized foreign exchange, offset by a $6.3 million negative variance from other expenses net of the tax effect of the above items.
Market Access a Key Differentiator
Due to the quality of Lindbergh bitumen, Pengrowth has secured term sales agreements at Hardisty with a number of refiners that ensures market access for 17,000 bbl/d of diluted bitumen at an average price of WTI minus US$16.82 (“dilbit”) to the end of 2018.
These physical delivery contracts, which protect against pipeline apportionment, mitigate credit risk and limit exposure to widening WCS differentials, resulted in a higher realized bitumen sales price by CA$6.62/bbl compared to benchmark prices in the third quarter of 2018.
As at September 30, 2018, Pengrowth had physical contracts in place that ensure market access for 10,000 bbl/d of dilbit at an average price of WTI minus US$19.24 for 2019. Subsequent to the quarter Pengrowth secured term sales agreements at Hardisty for an additional 5,000 bbl/d of diluted bitumen for 2019. These barrels are 100% apportionment protected and will be priced monthly as Index barrels plus an apportionment protection fee. Pengrowth now has apportionment protection on 15,000 bbl/d in 2019.
Balance Sheet and Liquidity
Pengrowth’s total debt before working capital (excluding letters of credit) at September 30, 2018 decreased 4% to $672.2 million compared with $701.5 million as at June 30, 2018 as the result of $20.5 million in repayments and an $8.8 million favourable foreign exchange impact. The $20.5 million in debt repayments were the combined result of adjusted funds flow in the third quarter and the collection of $9.6 million in deferred disposition proceeds.
Pengrowth has no scheduled debt maturities in 2018. As at September 30, 2018, Pengrowth had drawings of $158.5 million on its Credit Facility (December 31, 2017 – $109.0), and $79.7 million of outstanding letters of credit (December 31, 2017 – $69.4 million).
Pengrowth’s total debt before working capital is 73 percent denominated in foreign currencies at September 30, 2018. To manage foreign exchange risk, Pengrowth holds a series of swap contracts that fix the foreign exchange rate on 70% of the principal for Pengrowth’s U.S. dollar denominated term debt. At September 30, 2018, Pengrowth held a total of US$255 million in foreign exchange swap contracts at a weighted average rate of US$0.75 per CA$1.00 as follows:
|% of principal swapped||Average fixed rate
(US$ per CA$)
Multi-Year Development Plan: 2019 Capital Plan
Pengrowth’s 2019 Budget calls for a Capital Spending Plan of $45 million, with the vast majority of this capital allocated to Lindbergh. Pengrowth intends to use excess cash from operating activities to continue to pay down debt, and intends to finance all capital spending internally.
Pengrowth’s multi-year development plan remains on track to grow Lindbergh production to 35,000 bbl/d by the end of 2023. Timing to further expand production to 40,000 to 50,000 bbl/d will depend on commodity prices.
Groundbirch maintains a significant inventory of more than 360 locations in some of the most productive Montney horizons in the basin, as demonstrated by recent Pengrowth and industry results. Pengrowth will curtail spending on this asset until AECO natural gas pricing improves.
Updated Continuous Disclosure: Model of Adjusted Funds Flow Less Expenditures on Remediation(1) (“the Model”):
|WTI-WCS Differential $US/bbl||$(27.66)(3)||$(25.00)||$(20.00)|
|US$/CA$ Exchange Rate||US$0.775/CA$1.00(3)||US$0.770/CA$1.00||US$0.770/CA$1.00|
(1) Adjusted funds flow is a non-GAAP measure defined as cash flow from operating activities, less interest and financing charges, and before changes in non-cash operating working capital. Management believes adjusted funds flow less expenditures on remediation is a useful measure of the cash generated by the business that is available to pay down debt and fund capital expenditures. The assumptions for the Model at various WTI are laid out above and also assumes 2018 actuals for nine months ended September 30, 2018.
(2) Incorporates actuals and realized pricing for diluted Lindbergh bitumen at an average differential to WTI of US($16.80)/bbl for the nine months ended September 30, 2018.
(3) Incorporates actual benchmark values for the nine months ended September 30, 2018 and three months of forecasted values.
We have updated the Model to reflect increased WTI-WCS differentials and narrowed the forecast range for WTI based on current market expectations. While the relationship is not linear in an absolute sense, generally, every $1.00 change in pricing has an approximate $8 million change in adjusted funds flow. While our methodology has not changed, we have updated the name of the Model to align with the naming conventions in our Management’s Discussion and Analysis.
Conference Call and Audio Webcast:
Pengrowth will host a conference call and listen-only audio webcast at 9:00 a.m. Mountain Time (“MT”) (11:00 a.m. Eastern Time (“ET”)) today to discuss the quarter. Please note that the format of the webcast will now incorporate a visual presentation for investors and analysts. To listen to the live webcast and watch the presentation please use the following link:
The webcast will remain archived at the above link for one year following the event.
Analysts and institutional investors interested in participating in the question and answer session of the conference call may do so by calling 1-877-648-7976 (toll free) or (617) 826-1698.
Within 24 hours of the event, the webcast will be available for replay at the link above.
An archived recording of the conference call will be available for seven days and can be accessed by dialing 1-800-585-8367 (toll free), Conference ID: 6266467.