Peyto announces Q1 2020 results
May 12, 20202:00 PM Globe Newswire
CALGARY, Alberta – Peyto Exploration & Development Corp. (“Peyto” or the “Company”) (TSX: PEY) herein presents its operating and financial results for the first quarter of the 2020 fiscal year. The unprecedented global pandemic which disrupted world energy demand, in combination with an untimely market share price war amongst certain OPEC+ members, led to severe commodity price volatility in the quarter. Peyto’s industry leading costs structure allowed it to preserve a 55% Operating Margin(1) however both Profit Margin(2), Return on Capital (0%) and Return on Equity (2%) were eroded due to a further 30% drop in realized commodity prices. Highlights for the quarter included:
Funds from operations of $0.33/share. Generated $55 million in Funds from operations (“FFO”) in Q1 2020, down from $103 million in Q1 2019 due to lower commodity prices and lower production levels. Trailing twelve month FFO ($275 million) exceeded both capital expenditures ($213 million) and dividend payments ($40 million) by $22 million resulting in reduced levels of net debt when compared to a year ago.
Liquids yield increased 24%. Condensate and NGL yields increased from 23 bbl/mmcf in Q1 2019 to 29 bbl/mmcf in Q1 2020, resulting from a focus on development of Peyto’s liquids rich Cardium play. Total liquids production of 11,585 bbl/d in Q1 2020 was the highest in Company history comprised of 6,662 bbls/d of Condensate and Pentanes+, and 4,923 bbls/d of Propane and Butane. Natural gas production was down 13% to 402 mmcf/d as Peyto replaced declining dry gas with significantly higher liquids-rich gas. Total Q1 2020 production of 78,514 boe/d was up slightly from the previous quarter production of 77,457 boe/d but down 10% from 87,703 boe/d recorded in Q1 2019.
Total cash costs of $1.03/Mcfe (or $0.91/Mcfe ($5.46/boe) excluding royalties). Industry leading total cash costs, included $0.12/Mcfe royalties, $0.39/Mcfe operating costs, $0.19/Mcfe transportation, $0.04/Mcfe G&A and $0.29/Mcfe interest, combined with a realized price of $2.30/Mcfe, resulted in a $1.27/Mcfe ($7.63/boe) cash netback, down 42% from $2.18/Mcfe ($13.06/boe) in Q1 2019. Operating costs per unit for Q1 2020 were up 15% from Q1 2019 largely due increased power costs, and stockpiling of chemicals and equipment in preparation for anticipated COVID-19 supply chain disruptions.
Capital investment of $69 million. A total of 17 gross wells (14.3 net) were drilled in the first quarter, 19 gross wells (18 net) were completed, and 20 gross wells (18 net) were brought on production. Over the last 12 months the 64 gross (55.9 net) wells brought on production accounted for approximately 18,000 boe/d at the end of the quarter, which, when combined with a trailing twelve month capital investment of $213 million, equates to an annualized capital efficiency of $11,800/boe/d. Peyto anticipates the 2020 full year capital efficiency will be less than $9,500/boe/d.
Dividends of $0.06/share, Loss of $0.41/share. Dividends of $9.9 million were paid to shareholders during the quarter. This is the first quarterly loss posted since Q4 2004 and is largely due to the confluence of global events occurring in the first quarter of the year resulting in a first ever, non-cash impairment of $80 million.
First Quarter 2020 in Review Preparation for and reaction to the sweeping global pandemic dominated the first quarter of 2020. As Peyto and its hydrocarbon production was deemed an essential and critical provincial service during this time, to provide reliable heat and fuel for electrical generation, all attention was turned to the Company’s business continuity plans in order to ensure the safety and security of Peyto’s employees and field contractors. Peyto’s Working Remotely and Working Alone policies ensured production operations continued without interruption, while at the same time, strategic alliances with select service providers ensured drilling, completion and pipeline operations continued safely throughout the quarter. Drilling and completion operations were focused primarily in the Greater Sundance and Brazeau River areas, on both the Cardium and Spirit River formations. Peyto completed the construction of a 17 km pipeline project in the quarter, connecting a new area called Chambers to Peyto’s Brazeau gas plant. This enabled the existing production that was being processed in third party facilities to be redirected into the Company’s operated gas plant, as well as the connection of several new wells that were drilled in the quarter. As Peyto now controls over 33 prospective sections of land in the Chambers area, this pipeline will be a strategic piece of infrastructure for future opportunities. A lack of winter heating demand in North American natural gas markets caused natural gas prices to weaken throughout the quarter, which combined with the rapid drop in oil and natural gas liquid prices resulted in the lowest realized revenue per Mcfe in the Company’s 21 year history and despite Peyto’s low cash costs, still translated into the lowest ever cash netback at $1.27/mcfe ($7.63/boe). 1. Operating Margin is defined as funds from operations divided by revenue before royalties but including realized hedging gains/losses. 2. Profit Margin is defined as net earnings for the quarter divided by revenue before royalties but including realized hedging gains/losses. Natural gas volumes recorded in thousand cubic feet (mcf) are converted to barrels of oil equivalent (boe) using the ratio of six (6) thousand cubic feet to one (1) barrel of oil (bbl). Natural gas liquids and oil volumes in barrel of oil (bbl) are converted to thousand cubic feet equivalent (Mcfe) using a ratio of one (1) barrel of oil to six (6) thousand cubic feet. This could be misleading, particularly if used in isolation as it is based on an energy equivalency conversion method primarily applied at the burner tip and does not represent a value equivalency at the wellhead. Three Months Ended March 31% 20202019ChangeOperations Production Natural gas (mcf/d) 401,572462,003-13% Oil & NGLs (bbl/d) 11,58510,7038% Thousand cubic feet equivalent (mcfe/d @ 1:6) 471,083526,220-10% Barrels of oil equivalent (boe/d @ 6:1) 78,51487,703-10%Production per million common shares (boe/d) 476532-11%Product prices Natural gas ($/mcf) 1.632.48-34% Oil & NGLs ($/bbl) 36.7350.37-27%Operating expenses ($/mcfe) 0.390.3511%Transportation ($/mcfe) 0.190.19–Field netback ($/mcfe) 1.602.52-37%General & administrative expenses ($/mcfe) 0.040.06-33%Interest expense ($/mcfe) 0.290.284%Financial ($000, except per share) Revenue and realized hedging gains (losses) 1 97,723151,660-36%Royalties 4,9366,673-26%Funds from operations 54,513103,078-47%Funds from operations per share 0.330.63-48%Total dividends 9,8929,892–Total dividends per share 0.060.06– Payout ratio 181080%Earnings (loss) (67,684)24,970-371%Earnings per diluted share (0.41)0.15-373%Capital expenditures 68,58762,39510%Weighted average common shares outstanding 164,874,175164,874,175–As at March 31Net debt1,166,7811,188,810-2%Shareholders’ equity1,640,7071,654,076-1%Total assets3,514,5243,654,039-4%1excludes revenue from sale of third party volumes Three Months Ended March 31($000 except per share) 20202019Cash flows from operating activities 65,84191,511 Change in non-cash working capital (11,328)9,061 Change in provision for performance-based compensation–215 Performance based compensation–2,291Funds from operations 54,513103,078Funds from operations per share 0.330.63(1) Funds from operations (“FFO”) – Management uses FFO to analyze the operating performance of its energy assets. In order to facilitate comparative analysis, FFO is defined throughout this report as earnings before performance-based compensation, non‑cash and non‑recurring expenses. Management believes that FFO is an important parameter to measure the value of an asset when combined with reserve life. FFO is not a measure recognized by Canadian generally accepted accounting principles (“GAAP”) and does not have a standardized meaning prescribed by GAAP. Therefore, FFO, as defined by Peyto, may not be comparable to similar measures presented by other issuers, and investors are cautioned that FFO should not be construed as an alternative to net earnings, cash flow from operating activities or other measures of financial performance calculated in accordance with GAAP. FFO cannot be assured and future dividends may vary. Exploration & Development First quarter 2020 activity was focused exclusively in the Greater Sundance and Brazeau River areas on the Cardium and Spirit River plays as shown in the following table: FieldTotal Wells DrilledZoneSundanceNosehillWildhayAnsellWhitehorseKisku/ KakwaBrazeauBelly RiverCardium36110Notikewin123FalherWilrich224BlueskyTotal5261317Drilling costs for the first quarter of 2020 were slightly higher on a per meter basis due to an increased weighting of deeper formations in the Brazeau area while completion costs continued to fall, despite the longer lateral and increased frac stage count as illustrated in the following table. 20102011201220132014201520162017201820192020 Q1Gross Hz Spuds52708699123140126135706117Measured Depth (m)3,7623,9034,0174,1794,2514,3094,1974,2294,0203,8484,069 Drilling ($MM/well)$2.76$2.82$2.79$2.72$2.66$2.16$1.82$1.90$1.71$1.62$1.75$ per meter$734$723$694$651$626$501$433$450$425$420$430 Completion ($MM/well)$1.36$1.68$1.67$1.63$1.70$1.21$0.86$1.00$1.13$1.01*$975Hz Length (m)1,3351,3031,3581,4091,4601,5311,4601,2411,3481,4841,563$ per Hz Length (m)$1,017$1,286$1,231$1,153$1,166$792$587$803$835$679$624$ ‘000 per Stage$231$246$257$188$168$115$79$81$51$38$38*excluding Peyto’s Wildhay Montney well. Capital Expenditures During the first quarter of 2020, Peyto invested $27.7 million on drilling, $19.4 million on completions, $7 million on wellsite equipment and tie-ins, $10.2 million on facilities and major pipeline projects, and $4.3 million acquiring new lands and seismic, for total capital investments of $68.6 million. The $10.2 million invested in new facilities and major pipeline projects in the quarter included the $7 million, 17 km, 8 inch pipeline connecting the Chambers (South Brazeau) area to the Brazeau River gas plant. Other facility capital included wellsite conversions to reduce emissions and reduce operating costs as well as upgrades to wellsite automation and monitoring systems. Only one new section of land was purchased in the quarter and after the quarter end, all new land sales were suspended by the Crown due to the deteriorated Alberta business environment. Commodity Prices Peyto actively marketed all components of its production stream in the quarter including natural gas, condensate, pentane, butane and propane. Peyto’s market diversification activity resulted in natural gas being sold at various hubs including AECO, Dawn, Ventura, Emerson 2 and Henry Hub using both physical fixed price and temporary basis transactions to access those locations. Natural gas prices were left to float on daily pricing or locked in using fixed price swaps at those hubs and Peyto’s realized price was benchmarked against those local prices, then adjusted for transportation (either physical or short term synthetic) to those markets. The Company’s liquids were also actively marketed with condensate being sold on a monthly index differential linked to West Texas Intermediate (“WTI”) oil prices. Peyto’s NGLs (a blend of pentanes plus, butane and propane) are fractionated by a third party in Fort Saskatchewan, Alberta but Peyto markets each product separately. Pentanes Plus were sold on a monthly index differential linked to WTI, with some volumes forward sold on fixed differentials to WTI. Butane was sold as a percent of WTI or a fixed differential to the Mount Belvieu, Texas market. Propane was sold on a fixed differential to the Conway, Kansas market. While some products were sold pursuant to annual term contracts to ensure delivery paths remain open, others were marketed on the daily spot market. During Q1 2020 Peyto sold 63% of its natural gas at AECO, 9% at Emerson, 5% at Ventura, and 23% at Henry Hub. Benchmark prices, Peyto realized prices, and aggregate gas marketing diversification costs are shown below. Benchmark Commodity Prices Three Months ended March 3120202019AECO 7A monthly ($/GJ)2.031.84AECO 5A daily ($/GJ)1.932.49Empress daily (US$/MMBTU)1.762.95NYMEX (US$/MMbtu)1.882.89Ventura daily (US$/MMbtu)1.723.14Dawn daily (US$/MMbtu)1.762.92Canadian WTI ($/bbl)61.6572.98Conway C3 (US$/bbl)14.3324.32Q1 2020 average CND/USD exchange rate of 1.3449. Peyto Realized Commodity Prices by Component Three Months ended March 3120202019Natural gas ($/mcf)2.592.48Gas marketing diversification activities ($/mcf)(0.88)(0.12)Gas hedging ($/mcf)(0.08)0.12 Oil, condensate and C5+ ($/bbl)57.3464.28Oil hedging ($/bbl)2.773.52Butane and propane ($/bbl)5.0921.58Liquids prices are Peyto realized prices in Canadian dollars adjusted for fractionation, transportation and market differentials. Peyto natural gas has an average heating value of approximately 1.15 GJ/mcf Details of Peyto’s ongoing marketing and diversification efforts are available on Peyto’s website at: http://www.peyto.com/Files/Operations/Marketing/hedges.pdf Financial Results Approximately 36%, or $0.84/Mcfe, of Peyto’s unhedged revenue came from its associated natural gas liquids sales while 64%, or $1.46/Mcfe, is attributable to natural gas sales. Natural gas and liquid hedging activity did not contribute to a material change in total revenue of $2.30/Mcfe. Cash costs of $1.03/Mcfe, included royalties of $0.12/Mcfe, operating costs of $0.39/Mcfe, transportation costs of $0.19/Mcfe, G&A of $0.04/Mcfe and interest costs of $0.29/Mcfe. Cash costs per unit of production were similar to Q1 2019 despite the increase in operating costs that resulted from a stockpiling of chemicals and maintenance equipment. For the balance of the year, Peyto expects lower per unit operating costs from optimized road use, lower water disposal costs, lower chemical and lubricating oil prices, optimized power consumption as well as lower municipal tax and AER fees. When the total cash costs of $1.03/Mcfe were deducted from realized revenues of $2.30/Mcfe, it resulted in a cash netback of $1.27/Mcfe or a 55% operating margin. Historical cash costs and operating margins are shown in the following table. 201720182019 2020($/Mcfe)Q1Q2Q3Q4Q1Q2Q3Q4Q1Q2Q3Q4Q1Revenue3.443.363.243.503.543.203.273.033.202.602.502.762.30Royalties0.190.170.090.188.8.131.52.120.140.010.030.120.12Op Costs0.290.240.260.280.290.300.310.330.350.340.310.340.39Transportation0.170.180.170.184.108.40.206.220.127.116.11.190.19G&A0.040.050.030.030.080.050.030.040.060.050.050.020.04Interest0.200.210.210.210.240.260.270.270.280.300.310.310.29Cash Costs0.890.850.760.830.910.890.940.951.020.890.890.981.03Netback2.552.512.482.672.632.312.332.082.181.711.611.781.27Operating Margin74%75%76%76%74%72%71%69%68%66%64%65%55%Depletion, depreciation, amortization and impairment charges of $3.28/Mcfe, along with a provision for deferred tax and stock-based compensation payments reduced the cash netback to a loss of $1.58/Mcfe. Dividends of $0.23/Mcfe were paid to shareholders in the quarter. Due to a significantly reduced independent reserve engineer price forecast, attributable to the exceptional commodity price volatility experienced in the first quarter, the carrying value of Peyto’s reserve assets was reduced and a non-cash impairment expense of $80 million was recognized. The impairment has no impact on funds from operations and is expected to reverse in the future should commodity futures recover. Activity Update Peyto currently has 2 rigs drilling on pad sites that utilize existing Company infrastructure in order to limit exposure to third party road bans or restrictions during spring breakup. Both rigs have quickly shifted their focus to leaner natural gas prospects to take advantage of improving gas prices, with one rig operating in the Brazeau area and the other focused in Greater Sundance. The Company continues to work closely with service providers and is taking additional precautions to ensure the health and safety of all workers during the COVID-19 pandemic. Since the end of the quarter, the Company has drilled 6 gross (3.9 net) wells, completed 3 gross (3 net) wells, and brought onstream 4 gross (4 net) new wells. The 6 new wells drilled will be completed later in the quarter after breakup. The most recent wells brought onstream include several Notikewin discoveries in the Chambers and Edson areas that have greatly exceeded Management expectations. Peyto is planning to add two additional drilling rigs in the second half of 2020 as natural gas prices improve. These two rigs will continue focus on leaner natural gas prospects within the Company’s portfolio. At the end of April, the Company installed 80,000 barrels of tank storage capacity in the Sundance and Brazeau areas to serve Peyto’s associated condensate production in the event there are supply disruptions or negative price realizations for this product. This should ensure that Peyto’s natural gas and other associated NGL production will not be shut in if condensate demand is materially impacted by heavy oil curtailments/shut ins. Outlook While the 2020 capital program to date has exceeded expectation for results and costs, Peyto anticipates that an additional 10-15% cost savings will be further realized in the balance of the year due to much reduced industry activity. Peyto will continue to be nimble and flexible, as evidenced by the recently reduced capital program and reduced dividend and may adjust its program for changing commodity prices and in order to match the capital program to forecast funds flow. In order to preserve financial flexibility in the event commodity prices continue to remain weak, Peyto is currently in discussions with its syndicate of lenders and term debt noteholders for temporary relief from its financial covenants as they are defined in its revolving unsecured credit facility and note purchase agreements. Pending results from these discussions, the Company believes it will have sufficient funds from operations and credit capacity to execute the remainder of its revised 2020 capital program of $200 to $250 million. Peyto is also reviewing all government programs which may provide additional relief and liquidity during this highly volatile and challenging period to determine if they may be available to Peyto. Peyto is encouraged by the recent oil supply response that is taking associated gas out of the market and strengthening current and future natural gas prices at both AECO and Henry Hub. While the Company has over 50% of natural gas sales hedged for the next two quarters, all future natural gas production remains extremely exposed to this increasing natural gas price with less than 5% of all producing reserves currently pre-sold. Conference Call and Webcast A conference call will be held with the senior management of Peyto to answer questions with respect to the 2020 first quarter financial results on Wednesday, May 13th, 2020, at 9:00 a.m. Mountain Daylight Time (MDT), or 11:00 a.m. Eastern Daylight Time (EDT). To participate, please call 1-844-492-6041 (North America) or 1-478-219-0837 (International). Shareholders and interested investors are encouraged to ask questions about Peyto and its most recent results. Questions can be submitted prior to the call at firstname.lastname@example.org. The conference call can also be accessed through the internet https://edge.media-server.com/mmc/p/jfmqq7kz. The conference call will be archived on the Peyto Exploration & Development website at www.peyto.com. Management’s Discussion and Analysis/Financial Statements A copy of the first quarter report to shareholders, including the MD&A, unaudited financial statements and related notes, is available at http://www.peyto.com/Files/Financials/2020/Q12020FS.pdf and at http://www.peyto.com/Files/Financials/2020/Q12020MDA.pdf and will be filed at SEDAR, www.sedar.com at a later date. Darren Gee President and CEO May 12, 2020