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40,000 30,000 20,000 10,000

40 30 20 10

02 03 04 05 06 Natural Gas (boe) Oil & NGL (bbls)

Net Debt as a Percentage of Total Capitalization (%) Cash Available for Distribution

Cash Distributions ($/unit)

Total Capitalization ($billions)

For 2006, ARC averaged 63,056 boe per day – well ahead of the 61,000 we had budgeted for the year due to the 20 success of our 6 development program and some minor property acquisitions. This 5 was a 12 per cent increase over 2005 production of 56,254 boe per 15 day. The4 increase in production in 2006 was largely due to the NPCU and 3 Redwater acquisitions completed late in 102005. These two fields contributed approximately 5,500 boe per day of 2 production during 2006, with most of the remaining 1,300 boe 5 increase 1resulting from a successful drilling program that offsets natural declines. The success of the drilling program is evidenced 02 03 04 05 06 02 03 04 05 06 by a seven per cent increase in ARC’s production per unit to 0.31 boe per day per thousand units in 2006 from 0.29 boe per day per thousand units in 2005. With a 2006 exit rate of 64,000 boe per day and approximately 1,000 boe per day of production associated 2.5 800 with 2006 capital spending waiting on tie-in, ARC is well positioned 700 2.0 its production in 2007. to sustain 600 500

400 ARC invested a record $365 million on capital development 1.0 300 activities in 2006, in line with our mid-year forecast of $370 200 million.0.5 The $365 million program delivered approximately 10,000 100 boe per day of production, more than offsetting the natural production 02 decline sustain 03 04 05of06our properties. This ability to 02 03 04 05 06 production is a clear indication of the quality and depth of our Cash Flow asset base as we replaced production volumes in Cash all Distributions of our five core areas in western Canada. Approximately $246 million was spent on drilling and optimization activities including our NGC projects. ARC drilled 294 gross wells (220 net) on operated properties with a 99 per cent success rate. In addition, ARC participated in 441 gross (44 net) wells drilled by other operators.

Approximately $58 million was spent on undeveloped land, seismic and growth oriented exploration activities. The $32 million spent on land was the largest land expenditure in our history and led to a nine per cent increase in our net undeveloped land to 521,000 acres. Significant funds were also devoted to early investment in enhanced oil recovery projects at Midale and Instow, Saskatchewan. While these expenditures did not contribute to production and reserves in 2006, they are expected to add reserves and value in the future. In 2007, ARC is budgeting for a $360 million capital development program that will include the drilling of approximately 275 gross wells (225 net wells) on operated properties and participation in an estimated 150 gross wells to be drilled on non-operated properties. ARC’s 2007 drilling program is expected to add approximately 11,000 boe per day to offset the natural production ANNUAL REPORT REPORTF

1.5 1.0 0.5

700 600 500 400 300 200 100

02 03 04 05 06

02 0

Management Fees Non-Cash G&A Cash G&A

Royalties Operating &Transportation Costs Netback before Hedging ($/boe)




02 03 04 05 06

Cash Flow Earnings

decline and maintaining production volumes stable at 2006 levels. The capital budget is slightly lower than the 2006 expenditures primarily due to anticipated decreases in service 30 costs in 2007. Though ARC is drilling fewer wells in 2007, the 25 average well cost will be higher as we are drilling fewer shallow gas wells and more wells in some of ARC’s northern fields where deeper 20 wells and more complex15drilling and completion techniques are required. ARC is also budgeting $7 million for EOR activities, 10 primarily on preliminary studies for potential CO2 pilot projects. Unit Market Price ($/unit at December 31)




Units Outstanding at Year-end (millions)

Average Selling Price *before hedging




Cash Flow and Earnings ($millions)



G&A and Management Fees ($/boe)



Finding, Development and Acquisition Costs (“FD&A”) During 2006, ARC’s exploitation 02 03 04 and 05 06 development activities replaced approximately 16 mmboe of proved plus probable reserves (including revisions) while 6 mmboe were added through acquisitions (net of minor property dispositions), bringing the total additions to 22 mmboe. This represents 96 per cent of the 23 mmboe produced during 2006. As a result, year-end 2006 reserves of 286 mmboe are effectively unchanged from the 287 mmboe of proved plus probable reserves recorded at year-end 2005. Excluding future development capital (“FDC”), ARC’s proved plus probable FD&A costs for 2006 were $22.41 per boe. On a proved basis, ARC’s FD&A costs were $24.51 per boe. ARC’s finding and development costs (“F&D”) excluding FDC on a proved basis were $22.69 per boe and on a proved plus probable basis were $22.36 per boe. Higher FD&A costs for 2006 reflect the continued increases in the cost of services in 2006 across the oil and gas sector and also include the significant increase by ARC in preinvesting for future reserves adding activities such as buying land and initial funding of ARC’s EOR projects. FD&A costs are high across the sector in 2006 and are expected to come down in 2007 as we have seen a decrease in service costs as industry utilization rates decrease.

Recycle Ratio A measure of capital efficiency is the recycle ratio. The recycle ratio is determined by dividing the netback per boe by the FD&A costs per boe. It is a measure of how effectively an oil and gas company is investing its cash by calculating the dollars received for a barrel sold compared to the cost incurred to find and develop that barrel. Generally a recycle ratio of two or more is considered to be indicative of efficient capital allocation. The proved plus probable recycle ratio for 2006 using ARC’s three year average FD&A of $15.59 per boe and the 2006 netback of $34.68 (prior to hedging gains) was 2.2 times. This recycle ratio is an indication of ARC’s ability to maintain its profitability amidst rising costs.

Review of Operations

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02 0

*** includes exchange


Annual Report


Annual Report