Aug 1, 2013
CALGARY, Aug. 1, 2013 /CNW/ - (ARX - TSX) ARC Resources Ltd. ("ARC") is pleased to report its second quarter 2013 operating and financial results. Second quarter production was 93,436 boe per day and funds from operations were $201.2 million ($0.65 per share). ARC's Condensed Interim Consolidated Financial Statements and Notes, as well as ARC's Management's Discussion and Analysis ("MD&A") for three and six months ended June 30, 2013 and 2012, are available on ARC's website at www.arcresources.com and on SEDAR at www.sedar.com.
Three Months Ended June 30
Six Months Ended June 30
2013
2012
2013
2012
FINANCIAL
(Cdn$ millions, except per share and boe amounts)
Funds from operations (1)
201.2
165.8
403.6
346.5
Per share (2)
0.65
0.57
1.30
1.19
Net income
93.3
38.1
140.2
79.0
Per share (2)
0.30
0.13
0.45
0.27
Operating income (3)
53.9
30.5
101.6
77.4
Per share (2)
0.17
0.10
0.33
0.27
Dividends
93.4
87.3
186.3
174.3
Per share (2)
0.30
0.30
0.60
0.60
Capital expenditures
171.4
97.9
403.8
284.8
Net debt outstanding (4)
883.7
996.0
883.7
996.0
Shares outstanding, weighted average diluted
311.2
290.8
310.6
290.1
Shares outstanding, end of period
311.5
291.5
311.5
291.5
OPERATING
Production
Crude oil (bbl/d)
31,635
30,831
32,067
31,068
Condensate (bbl/d)
2,150
2,381
2,091
2,390
Natural gas (mmcf/d)
340.8
347.2
344.7
350.1
NGLs (bbl/d)
2,859
2,913
2,845
2,673
Total (boe/d) (5)
93,436
93,997
94,449
94,484
Average realized prices, prior to hedging
Crude oil ($/bbl)
89.18
78.98
86.07
83.14
Condensate ($/bbl)
91.08
94.60
96.13
97.29
Natural gas ($/mcf)
3.89
2.03
3.63
2.36
NGLs ($/bbl)
29.25
41.17
33.32
42.67
Oil equivalent ($/boe) (5)
47.36
37.09
45.59
39.73
Operating Netback ($/boe)
Commodity and other sales
47.45
37.15
45.74
39.78
Transportation expenses
(2.04)
(1.23)
(1.72)
(1.20)
Royalties
(7.01)
(5.58)
(6.31)
(6.12)
Operating expenses
(10.29)
(9.48)
(9.49)
(9.11)
Netback before hedging
28.11
20.86
28.22
23.35
Realized hedging gain (6)
0.16
3.54
0.33
1.75
Netback after hedging
28.27
24.40
28.55
25.10
TRADING STATISTICS (7)
High price
28.90
23.28
28.90
25.72
Low price
25.73
18.36
23.12
18.36
Close price
27.53
22.90
27.53
22.90
Average daily volume (thousands)
1,074
1,704
1,112
1,529
(1)
Funds from operations does not have a standardized meaning under Canadian Generally Accepted Accounting Principles ("GAAP"). See "Additional GAAP Measures" in the MD&A for the three and six months ended June 30, 2013 and 2012.
(2)
Per share amounts (with the exception of dividends) are based on weighted average diluted shares.
(3)
Operating income does not have a standardized meaning under GAAP. See "Non-GAAP Measures" in the MD&A for the three and six months ended June 30, 2013 and 2012.
(4)
Net debt does not have a standardized meaning under GAAP. See "Additional GAAP Measures" in the MD&A for the three and six months ended June 30, 2013 and 2012.
(5)
In accordance with NI 51-101, a boe conversion ratio of 6 Mcf: 1 bbl has been used, which is based on an energy equivalency conversion method primarily applicable at the burner tip. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different than the energy equivalency of the conversion ratio, utilizing the 6:1 conversion ratio may be misleading as an indication of value.
(6)
Realized hedging gain includes realized cash gains and losses on risk management contracts and unrealized loss on risk management contracts related to current production periods. Hedging gains and losses on foreign exchange contracts are excluded from the netback calculation.
(7)
Trading prices are stated in Canadian dollars and based on intra-day trading.
FINANCIAL AND OPERATIONAL HIGHLIGHTS
ARC's execution of its 2013 budget remains on track to meet full year 2013 production guidance of between 93,000 and 97,000 boe per day, and sets the stage for average production in excess of 110,000 boe per day in 2014 with the completion of the Parkland/Tower gas processing and liquids handling facility.
ARC achieved second quarter and first half production of 93,436 boe per day and 94,449 boe per day, respectively, in 2013, relatively consistent with 2012 levels. Strong well performance at Pembina and higher production at Ante Creek contributed to strong production in 2013. ARC expects third quarter 2013 production to decline relative to the second quarter, prior to increasing in the fourth quarter of 2013 as new pad wells are brought on production at Ante Creek. ARC expects 2013 full year production to average between 93,000 and 97,000 boe per day.
Second quarter and first half 2013 crude oil and liquids production of 36,644 barrels per day and 37,003 barrels per day increased slightly relative to 2012 levels. Higher 2013 liquids production is the result of ARC's focus on opportunities that generate the highest rates of return and cash flows.
Second quarter and first half 2013 commodity sales revenues of $403.4 million and $781.9 million were up 27 per cent and 14 per cent, respectively, relative to 2012 levels due to higher realized crude oil and natural gas prices. Crude oil and liquids production contributed approximately 70 per cent of second quarter and first half sales revenues due to the strength of crude prices relative to natural gas prices, despite accounting for 39 per cent of production.
Second quarter funds from operations were $201.2 million ($0.65 per share), up 21 per cent from the second quarter of 2012. First half funds from operations were $403.6 million ($1.30 per share), 16 per cent higher than the first half of 2012. The increase in second quarter and first half 2013 funds from operations was primarily due to higher crude oil and natural gas prices in 2013.
Operating incomewas $53.9 million ($0.17 per share) in the second quarter of 2013, 77 per cent higher than the second quarter of 2012. First half operating income of $101.6 million ($0.33 per share) was up 31 per cent relative to the first half of 2012 due primarily to higher crude oil and natural gas prices in 2013.
ARC's second quarter 2013 funds from operations included realized hedging gains of $1.6 million on ARC's commodity, foreign currency and power hedging contracts. First half 2013 funds from operations included realized hedging gains of $6.2 million on ARC's commodity, foreign currency and power hedging contracts. ARC's second quarter and first half realized hedging gains were primarily attributed to gains on crude oil and power contracts.
Second quarter capital expenditures, prior to net property and undeveloped land acquisitions, totaled $171.4 million, resulting in first half capital spending of $403.8 million. ARC's capital program focused primarily on oil and liquids-rich opportunities at Tower, Ante Creek, Pembina, and southeast Saskatchewan. ARC drilled 30 gross operated wells in the second quarter of 2013 (20 oil wells and 10 liquids-rich natural gas wells), resulting in 90 gross operated wells being drilled in the first half of 2013 (73 oil wells, 12 liquids-rich natural gas wells and five natural gas wells). Full year capital expenditures are still targeted at approximately $830 million.
During the second quarter, construction continued on ARC's 60 mmcf per day Parkland/Tower gas processing and liquids handling facility, the first of two 60 mmcf per day phases at Parkland/Tower. Construction is on schedule with the bulk of major equipment having arrived on site and a significant portion of construction completed. The first phase of the plant is expected to be on-stream in early 2014. ARC has completed drilling of all 16 wells on two pads at Tower and completed all wells in the first pad during the second quarter. The wells in the second pad will be completed in the third quarter. With the completion of the Parkland/Tower facilities, 2014 average production is expected to be greater than 110,000 boe per day.
ARC divested certain non-core assets located in southwest Saskatchewan for gross proceeds of approximately $28 million during the second quarter. Through the first half of 2013, ARC has received total gross proceeds of approximately $37 million from non-core assets divestments. The assets divested through the first half produced approximately 300 boe per day (approximately 80 per cent liquids) with associated proved plus probable reserves of 1.5 mmboe. Proceeds will be used to fund ongoing capital development programs, including the development projects at Parkland/Tower and Sunrise. ARC has maintained full year 2013 production guidance as the divestments will not significantly impact 2013 production.
ARC closed the second quarter with a strong balance sheet including total available credit facilities of $2 billion and debt of $796.6 million drawn. ARC had available credit of approximately $1.1 billion after a working capital deficit. Net debt to annualized first half funds from operations ratio was 1.1 times and net debt was approximately nine per cent of ARC's total capitalization at the end of the second quarter; both metrics are well within ARC's target levels.
ARC paid a dividend of $0.30 per share to shareholders for the second quarter of 2013 and has confirmed a dividend of $0.10 per share to shareholders for July 2013 to be paid on August 15, 2013. ARC has conditionally declared a dividend of $0.10 per share, payable monthly for August, September and October 2013, subject to confirmation by monthly news release and subject to any further resolution of the Board of Directors. ARC has maintained the monthly dividend at $0.10 per share or higher since inception, with payments totaling $29.18 per share since inception through July 15, 2013.
Southern Alberta experienced severe flooding in late June. While there was minimal impact to ARC's field operations, ARC's Calgary corporate office was closed for a week due to flooding in the downtown core which resulted in restricted access and services. During this time, ARC enacted its business continuity plan, enabling employees to continue working remotely. ARC is committed to assisting with the relief efforts for those affected by the flooding and to restore our communities. ARC employees have contributed many volunteer hours to the relief efforts in Calgary and surrounding communities and ARC has donated approximately $250,000 to various organizations and communities to assist with flood relief. Contributions have been made to the Canadian Red Cross, Inn from the Cold, and the Calgary Food Bank. ARC also provided vacuum truck services to residents of High River, fulfilling an immediate need for many homeowners affected by the flooding. For more information on the donations please visit our website at www.arcresources.com.
ARC is pleased to announce two new Officer appointments. After 16 years at ARC, Al Roberts, Vice President, Production, has announced his retirement effective October 2013. During his tenure, Al has had responsibility for ARC's field production operations, seeing production grow from 10,000 boe per day to over 95,000 boe per day at present. Sean Calder will be replacing Al as Vice President, Production effective September 2013. Sean joined ARC in 2005 and currently serves as Manager of Technical Operations. Sean has 18 years of industry experience and a proven track record as a strong and effective leader. ARC wishes Al the best in his retirement and welcomes Sean to his new role.
ARC is pleased to announce the appointment of Karen Nielsen to the position of Vice President, Operations, filling a vacancy created with the appointment of Cam Kramer to the position of Senior Vice President and Chief Operating Officer in January 2013. Karen is an Engineer with 25 years of industry experience and most recently served as Vice President, Engineering at a mid-sized Canadian natural gas producer. ARC is pleased to welcome Karen to the team.
ECONOMIC ENVIRONMENT
During the second quarter of 2013, West Texas Intermediate ("WTI") crude oil traded at an average of US$94 per barrel and Brent crude oil prices averaged US$103 per barrel. Brent prices weakened during the second quarter due to continued economic uncertainty and fears of moderating oil demand in Europe and China. WTI prices remained strong throughout the second quarter due to a reduction in US crude oil imports and the reversal and subsequent expansion of the Seaway pipeline in late 2012 and early 2013. The Seaway expansion served to partially alleviate pipeline bottlenecks between Cushing, Oklahoma and the United States Gulf Coast. As a result, the WTI/Brent differential narrowed to average US$9 per barrel in the second quarter of 2013 as financial markets priced in a narrowing future spread between WTI and Brent crude oil prices.
Crude oil infrastructure constraints in the mid-western United States, which resulted in extreme volatility in crude oil differentials throughout 2012, were partially alleviated in the first half of 2013 with increased refinery utilization and added pipeline and rail capacity. As a result, the WTI/Edmonton Par differential narrowed significantly to an average discount of US$3.64 per barrel during the second quarter of 2013 relative to an average discount of US$10.34 per barrel in the second quarter of 2012. Looking ahead, additional infrastructure projects are being executed or proposed including additional crude oil pipelines and refining capacity. This is expected to mitigate certain bottlenecks; however, due to the long-term nature of these projects, the risk of volatile differentials remains a concern throughout 2013 and into 2014 until remaining infrastructure issues are resolved and additional pipeline capacity becomes available.
Western Canadian natural gas prices (AECO Monthly) averaged $3.59 per mcf in the second quarter of 2013, up 96 per cent from $1.83 per mcf in the second quarter of 2012. The US Henry Hub (NYMEX) natural gas price averaged US$4.09 per mmbtu in the second quarter, 79 per cent higher than the second quarter of 2012. Natural gas inventories increased through the second quarter of 2013 relative to the first quarter of 2013 on sustained high natural gas production in the United States and lower demand attributed to mild weather and reduced power consumption. With the recovery in natural gas prices from the 10-year lows seen in 2012, there has been some reversion to coal-fired power generation, reducing the power consumption of natural gas. Going forward, sustained demand growth from the power sector will be necessary in order to support a stronger natural gas price in the mid-term. Over the long-term, the export of liquefied natural gas and increased usage from the transportation and industrial sectors should lead to an increase in the demand for natural gas.
Ongoing commodity price volatility may affect ARC's funds from operations and rates of return on its capital programs. As continued volatility is expected in 2013, ARC will take steps to mitigate these risks, optimize its rates of return, and maintain its strong financial position.
FINANCIAL REVIEW
Funds from Operations
ARC's second quarter funds from operations of $201.2 million ($0.65 per share) were up 21 per cent compared to the second quarter of 2012 and first half funds from operations of $403.6 million ($1.30 per share) were up 16 per cent relative to the first half of 2012. Higher second quarter and first half 2013 funds from operations were attributed to higher crude oil and natural gas prices and lower current income taxes offset in part by higher royalties, transportation and operating costs and lower realized hedging gains.
The following table details the change in funds from operations for 2013 relative to 2012.
Three Months Ended June 30
Six Months Ended June 30
$ millions
$/Share (3)
$ millions
$/Share (3)
Funds from operations - 2012 (1)
165.8
0.57
346.5
1.19
Volume variance
Crude oil and liquids
3.5
0.01
9.9
0.03
Natural gas
(1.2)
—
(3.1)
(0.01)
Price variance
Crude oil and liquids
25.7
0.08
11.8
0.04
Natural gas
57.6
0.20
79.2
0.27
Realized gain (loss) on risk management contracts
(34.7)
(0.11)
(38.5)
(0.11)
Unrealized gain (loss) on risk management contracts related to current production periods (2)
6.0
0.02
13.7
0.04
Royalties
(11.8)
(0.04)
(2.6)
(0.01)
Expenses
Transportation
(6.8)
(0.02)
(8.7)
(0.03)
Operating
(6.4)
(0.02)
(5.6)
(0.02)
General and administrative
(0.2)
—
(7.2)
(0.02)
Interest
0.6
—
0.8
—
Current tax
2.9
0.01
7.1
0.02
Realized loss on foreign exchange
0.2
—
0.3
—
Diluted shares
—
(0.05)
—
(0.09)
Funds from operations - 2013 (1)
201.2
0.65
403.6
1.30
(1)
Additional GAAP measure which may not be comparable to similar additional GAAP measures used by other entities. Refer to the section entitled "Additional GAAP Measures" contained in the MD&A for the three and six months ended June 20, 2013 and 2012. Also refer to the "Funds from Operations" section in the MD&A for the three and six months ended June 30, 2013 and 2012 for a reconciliation of ARC's net income to funds from operations and cash flow from operating activities.
(2)
ARC has entered into certain commodity price risk management contracts that pertain to production periods spanning the entire calendar year but that are settled at the end of the year on an annual average benchmark commodity price. The portion of gains or losses associated with these contracts that relate to production periods for the three and six months ended June 30 has been applied to either increase or reduce funds from operations and operating income in order to more appropriately reflect the funds from operations and operating income generated during the period after any effect of contracts used for economic hedging.
(3)
Per share amounts are based on weighted average shares, diluted.
Operating Netbacks
ARC's second quarter 2013 operating netback, before hedging, of $28.11 per boe was 35 per cent higher than the second quarter of 2012. ARC's first half 2013 pre-hedging netback of $28.22 per boe was 21 per cent higher than the first half of 2012. After hedging, ARC's second quarter and first half 2013 netbacks increased to $28.27 per boe and $28.55 per boe, respectively. Higher 2013 netbacks both before and after hedging, relative to 2012, were primarily due to higher crude oil and natural gas prices in the second quarter and first half of 2013.
ARC's second quarter total corporate royalty rate of 14.8 per cent ($7.01 per boe) was relatively unchanged from 15 per cent ($5.58 per boe) in the second quarter of 2012. ARC's first half total corporate royalty rate was 13.8 per cent, a decrease from 15.4 per cent in the first half of 2012. Lower royalty rates in the second quarter and first half of 2013 were due to a greater portion of oil production in Alberta qualifying for a five per cent royalty rate.
Second quarter operating expenses were $10.29 per boe in 2013, compared to $9.48 per boe in the second quarter of 2012. Second quarter operating costs increased relative to the first quarter of 2013 due to maintenance activities which resulted in additional costs and downtime. High electricity rates in the second quarter also contributed to higher operating costs as electricity prices averaged $123 per megawatt hour in the second quarter of 2013, up 207 per cent from $40 per megawatt hour in the second quarter of 2012. ARC expects additional planned turnaround and maintenance activities in the third quarter.
See Tables 16 and 16a in the MD&A for the three and six months ended June 30, 2013 and 2012 for detailed components of netbacks by commodity.
Net Income
ARC recorded net income of $93.3 million ($0.30 per share) for the second quarter of 2013 compared to net income of $38.1 million ($0.13 per share) in the second quarter of 2012. Higher realized crude oil and natural gas prices and a $17 million gain on disposition of producing properties contributed to higher net income in 2013. These gains were partially offset by a foreign exchange loss of $25.2 million (loss of $7.7 million in second quarter of 2012) upon revaluation of US dollar denominated debt balances given the strengthening of the US dollar during the second quarter, and higher deferred income tax expense.
First half 2013 net income of $140.2 million ($0.45 per share) increased 77 per cent relative to the first half of 2012 due to higher realized crude oil and natural gas prices and a $34.4 million gain on disposition of producing properties. These gains were partially offset by a foreign exchange loss of $40.5 million (loss of $0.7 million in first half of 2012) upon revaluation of US dollar denominated debt balances given the strengthening of the US dollar during the first half of 2013, and higher deferred income tax expense.
Operating Income
Second quarter operating income was $53.9 million ($0.17 per share), 77 per cent higher than the second quarter of 2012. First half operating income of $101.6 million ($0.33 per share) was 31 per cent higher than the first half of 2012. Higher operating income in the second quarter and first half of 2013 was attributed primarily to higher realized crude oil and natural gas prices.
See Table 8 in the MD&A for the three and six months ended June 30, 2013 and 2012 for additional information regarding Operating Income.
Risk Management
As part of its overall strategy to protect cash flow and project economics, ARC uses a variety of instruments to hedge crude oil, natural gas, foreign exchange rates, electrical power costs and interest rates.
ARC has hedges in place to protect prices on crude oil volumes through 2014 and natural gas volumes through 2017. Approximately 55 per cent of total production is currently hedged for the remainder of 2013 at prices that will support ARC's business plan. Approximately 50 per cent of crude oil and condensate production is currently hedged for the remainder of 2013 at an average floor/ceiling price of US$95/US$103 per barrel and approximately 60 per cent of natural gas production is currently hedged for the remainder of 2013 at an average floor/ceiling price of US$3.42/US$3.87 per mmbtu. Additional natural gas production is hedged in 2014 through 2017 at floor prices of US$4.00 per mmbtu to support long-term development economics for ARC's significant natural gas resource base. ARC will continue to pursue opportunities to protect funds from operations and will continue to take positions in natural gas and/or crude oil at levels that will provide greater certainty on rates of return.
ARC also has AECO basis swap contracts in place, fixing the AECO price received to approximately 90 per cent of the Henry Hub NYMEX price on a portion of its natural gas volumes throughout the remainder of 2013 and into 2018. As at June 30, the net fair value of these basis swap contracts was an asset of $55.4 million.
The following table summarizes ARC's average crude oil and natural gas hedged volumes for the remainder of 2013 through 2017. For a complete listing and terms of ARC's hedging contracts, see Note 8 "Financial Instruments and Risk Management Contracts" in the Condensed Interim Consolidated Financial Statements for the three and six months ended June 30, 2013 and 2012.
Hedge Positions Summary (1)
July - December
As at August 1, 2013
2013
2014
2015
2016-2017
Crude Oil (2)
US$/bbl
bbl/day
US$/bbl
bbl/day
US$/bbl
bbl/day
US$/bbl
bbl/day
Ceiling
102.78
18,000
97.61
11,447
—
—
—
—
Floor
95.00
18,000
91.07
11,447
—
—
—
—
Sold Floor
64.00
10,000
70.00
1,240
—
—
—
—
Natural Gas (3)
US$/mmbtu
mmbtu/day
US$/mmbtu
mmbtu/day
US$/mmbtu
mmbtu/day
US$/mmbtu
mmbtu/day
Ceiling
3.86
210,163
4.72
140,000
4.92
90,000
5.00
90,000
Floor
3.43
210,163
4.00
140,000
4.00
90,000
4.00
90,000
Natural Gas - AECO Basis (4)
AECO/
NYMEX %
mmbtu/day
AECO/
NYMEX %
mmbtu/day
AECO/
NYMEX %
mmbtu/day
AECO/
NYMEX %
mmbtu/day
Swap
89.8
170,000
89.8
190,000
90.5
130,000
90.5
130,000
(1)
The prices and volumes noted above represent averages for several contracts representing different periods. The average price for the portfolio of options listed above does not have the same payoff profile as the individual option contracts. Viewing the average price of a group of options is purely for indicative purposes. All positions are financially settled against the benchmark prices disclosed in Note 8 "Financial Instruments and Risk Management Contracts" in the financial statements for the three and six months ended June 30, 2013
(2)
The crude oil prices presented above are referenced to WTI. For 2013, all floor positions settle against the monthly average WTI price, providing protection against monthly volatility. Positions establishing the "ceiling" have been sold against either the annual average WTI price or the six month average WTI price. In the case of settlements on annual or six-month term positions, ARC will only have a negative settlement if prices average above the strike price for an entire year or the six-month period, respectively. These positions provide ARC with greater potential upside price participation for individual months.
(3)
The natural gas prices shown above are referenced to NYMEX at Henry Hub.
(4)
ARC sells the majority of its natural gas production based on AECO pricing; to reduce the risk of weak basis pricing (AECO relative to NYMEX) ARC has hedged a portion of production by tying ARC's price to a percentage of the NYMEX natural gas price.
ARC realized second quarter net losses of $0.8 million on crude oil and natural gas hedging contracts and $2.4 million of net realized cash gains on foreign currency and power hedging contracts. ARC realized net gains of $2.7 million on crude oil and natural gas hedging contracts and $3.5 million of net realized cash gains on foreign currency and power hedging contracts in the first half of 2013.
OPERATIONAL REVIEW
ARC's second quarter and first half production was 93,436 boe per day and 94,449 boe per day, respectively. Strong well performance at Pembina and higher production at Ante Creek, Parkland and Tower contributed to strong production in the first half of 2013. ARC spent $171.4 million in the second quarter of 2013 and drilled 30 gross (29 net) wells on operated lands (20 oil wells and ten liquids-rich gas wells), resulting in 90 gross operated wells drilled in the first half of 2013 (73 oil wells, 12 liquids-rich gas wells and five natural gas wells). ARC's second quarter 2013 capital program focused on oil and liquids development at Ante Creek, Pembina, Parkland and Tower.
ARC's focus on oil and liquids development, which started in 2011, has resulted in crude oil and liquids production reaching 36,644 bbls per day (39 per cent of total production) in the second quarter of 2013 and 37,003 bbls per day in the first half of 2013. Production from new oil and liquids-rich gas wells drilled, predominantly at Pembina, Goodlands, Tower and Ante Creek, contributed to higher liquids production in 2013.
ARC will execute multi-well pad drilling programs in key areas during 2013. The pad drilling programs are expected to decrease overall per well costs to drill, complete and tie-in, but will result in longer lead time from the start of drilling until the wells commence production as all drilling and completion activities must be completed on all wells before they are brought on-stream at one time. ARC expects fourth quarter production to increase as new wells, including pad wells at Ante Creek, are brought on production by year end 2013.
Pembina
Second quarter Pembina production exceeded expectations due to strong well performance. Production increased to approximately 12,400 boe per day in the second quarter, up eight per cent relative to the second quarter of 2012. Pembina second quarter production was comprised of 75 per cent light oil and liquids and 25 per cent natural gas.
ARC drilled seven gross operated (six net) horizontal Cardium oil wells at Pembina in the second quarter. ARC completed the expansion of an existing gas processing plant at Berrymoor to alleviate solution gas processing capacity constraints from oil wells drilled in the Berrymoor, Lindale and Buck Creek areas. The expansion added seven mmcf per day of processing capacity and provides ARC with greater control over operated gas volumes on the east side of the North Saskatchewan River. The plant provides for higher liquids recovery rates, resulting in an increased recovery of up to 50 bbls per mmcf from approximately 30 bbls per mmcf. The higher liquids recovery rate is significant given the liquids-rich solution gas in this area. The expanded plant was successfully brought on-stream during the second quarter of 2013.
During 2013, ARC expects to spend approximately $120 milli