PENNVIRGINIA RBC Capital Markets Shale Gas Conference CORPORATION - - PowerPoint PPT Presentation

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PENNVIRGINIA RBC Capital Markets Shale Gas Conference CORPORATION - - PowerPoint PPT Presentation

PENNVIRGINIA RBC Capital Markets Shale Gas Conference CORPORATION Appalachian and Mid-Continent Shale Gas Plays Toronto, Ontario January 31, 2008 NYSE: PVA PENN VIRGINIA Key investment highlights CORPORATION Proved reserves


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PENNVIRGINIA CORPORATION

RBC Capital Markets’ Shale Gas Conference Appalachian and Mid-Continent Shale Gas Plays Toronto, Ontario January 31, 2008 NYSE: PVA

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2 PENN VIRGINIA CORPORATION

273 323 354 376 487 280% 205% 233% 452% 308% 100 200 300 400 500 600 2002 2003 2004 2005 2006

Bcfe

0% 50% 100% 150% 200% 250% 300% 350% 400% 450% 500% Proved reserves Reserve replacement rate

Proved reserves

57.0 65.2 66.8 74.9 85.6 120.6 20 40 60 80 100 120 140 2002 2003 2004 2005 2006 3Q07 MMcfe/d

CAGR: 17.1%

Average daily production

Key investment highlights

  • Impressive reserve and production growth

− Q1-Q3 2007 production growth of 32% − 2007 production growth guidance of 30% to 33% − 2008 organic production growth guidance of 20% to 26% − 2006 increase in proved reserves of 29%

  • Low-risk plays with compelling economics

− Predominantly low-risk unconventional plays − After-tax RORs range between ~25-55% @ $7.50 NYMEX − 2006 3-yr. reserve replacement of 331% @ $2.37 per Mcfe − Q1-Q3 2007 cash operating costs of $1.86 per Mcfe

  • Significant drilling inventory and upside

− “Deep bench” of over 2,500 drilling locations − 250+ wells drilled in 2007 and ~330 wells planned for 2008 − Downspacing in east Texas (Cotton Valley) − Horizontal drilling: Appalachia, Mississippi & Mid-Continent − Emerging shale plays: Devonian, Woodford, Fayetteville, and Lower Bossier − Higher impact exploration: Gulf Coast

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3 PENN VIRGINIA CORPORATION Snapshot of PVOG’s unconventional play types

Oklahoma

Hartshorne Horizontal CBM Horizontal Granite Wash Woodford / Fayetteville Shales Bakken Shale (ND) Hartshorne Horizontal CBM Horizontal Granite Wash Woodford / Fayetteville Shales Bakken Shale (ND)

Mid-Continent

Cotton Valley Sands Lower Bossier Shale Cotton Valley Sands Lower Bossier Shale

Cotton Valley (E. TX/N. LA)

Selma Chalk Shift to Horizontal Drilling Selma Chalk Shift to Horizontal Drilling

Selma Chalk (MS)

Multi-Lateral Horizontal CBM Devonian / Marcellus Shale Unconventional Tight Sands Multi-Lateral Horizontal CBM Devonian / Marcellus Shale Unconventional Tight Sands

Appalachia

Texas North Dakota Arkansas Mississippi Kentucky Virginia West Virginia Pennsylvania Louisiana

Low-Risk, Unconventional Plays Attractive Economics: ATAX RORs ~25-55% Excellent Production Growth and Reserve Replacement Metrics Low-Risk, Unconventional Plays Attractive Economics: ATAX RORs ~25-55% Excellent Production Growth and Reserve Replacement Metrics Penn Virginia Oil & Gas (PVOG)

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4 PENN VIRGINIA CORPORATION Snapshot of PVOG’s reserve & production base

Oklahoma

49 Bcfe Proved (9%) 187 Bcfe 3P (12%) 25.7 MMcfe/d (21%) 49 Bcfe Proved (9%) 187 Bcfe 3P (12%) 25.7 MMcfe/d (21%)

Gulf Coast (S. LA / S. TX)

70 Bcfe Proved (13%) 181 Bcfe 3P (12%) 13.6 MMcfe/d (11%) 70 Bcfe Proved (13%) 181 Bcfe 3P (12%) 13.6 MMcfe/d (11%)

Mid-Continent

151 Bcfe Proved (28%) 762 Bcfe 3P (51%) 22.7 MMcfe/d (19%) 151 Bcfe Proved (28%) 762 Bcfe 3P (51%) 22.7 MMcfe/d (19%)

Cotton Valley (E. TX/N. LA)

132 Bcfe Proved (25%) 192 Bcfe 3P (13%) 21.9 MMcfe/d (18%) 132 Bcfe Proved (25%) 192 Bcfe 3P (13%) 21.9 MMcfe/d (18%)

Selma Chalk (MS)

134 Bcfe Proved (25%) 188 Bcfe 3P (12%) 36.7 MMcfe/d (30%) 134 Bcfe Proved (25%) 188 Bcfe 3P (12%) 36.7 MMcfe/d (30%)

Appalachia

Texas North Dakota Arkansas Mississippi Kentucky Virginia West Virginia Pennsylvania Louisiana

536 Bcfe Proved Reserves (PF 12/06) 1,510 Bcfe “3P” Reserves (PF 12/06) 120.6 MMcfe/d 3Q07 Production 536 Bcfe Proved Reserves (PF 12/06) 1,510 Bcfe “3P” Reserves (PF 12/06) 120.6 MMcfe/d 3Q07 Production Penn Virginia Oil & Gas (PVOG)

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5 PENN VIRGINIA CORPORATION

10 20 30 40 50 60 70 80 90 $6.00 $6.50 $7.00 $7.50 $8.00 $8.50 $9.00

NYMEX Gas Price (Flat) - $/MMBtu After-tax Rate of Return %

Economic sensitivities for PVOG by major play

  • PVOG’s plays generate attractive after-tax returns even at prices below current

levels (current 12-month NYMEX strip $8.26 per MMBtu)

  • Hedges protect the downside economics of certain plays with floors between

$7.25 and $8.50 per MMBtu

1/25/08 Avg. NYMEX 12-Month Strip Price

  • S. LA Prospect (risked)

A p p a l a c h i a M u l t i

  • L

a t e r a l H C B M Mississippi Selma Chalk (horizontal) Mid-Con. Hartshorne CBM

  • E. Texas Cotton Valley

M i d

  • C
  • n

. G r a n i t e W a s h ( h

  • r

i z

  • n

t a l )

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6 PENN VIRGINIA CORPORATION E&P capital expenditures

  • 2007E1 - $493 MM: development (63%), acquisitions (28%) and exploration (9%)
  • 2008B2 - $475 MM: development (87%) and exploration (13%)

Breakout of 2007 & 2008 E&P Capital Expenditures

$0 $100 $200 $300 $400 $500 $600

2007E 2008B 2007E 2008B

1 2 1 2 Acquis. Explor. Facil./Other Devel. Explor. Facil./Other Devel. Appalachia Selma Chalk Mid- Continent Cotton Valley Gulf Coast Appalachia Selma Chalk Mid- Continent Cotton Valley Gulf Coast

By Major Category By Geographic Region

$MM

28% 9% 7% 56% 13% 8% 79% 12% 12% 23% 47% 6% 11% 11% 21% 51% 6%

1 Mid-point of updated guidance announced 12/13/07 2 Budget data announced 12/13/07; excludes acquisitions

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7 PENN VIRGINIA CORPORATION 2008 guidance table

2008 Budget/ Capital Expenditures - $MM Guidance Development drilling $377.3 Exploratory drilling 50.6 Pipeline, gathering, facilities 27.8 Lease acquisition, field projects, other 19.1 Proved property acquisitions

  • Total PVOG capital expenditures

$474.8 Drilling Program – gross (net) wells

  • E. Texas Cotton Valley verticals (40-ac. and 20-ac.)

141 (102.2)

  • E. Texas Cotton Valley horizontal Lower Bossier

1 (1.0) Appalachia multi-lateral HCBM 27 (13.7) Appalachia Devonian Shale 4 (3.0) Selma Chalk horizontals 18 (16.4) Selma Chalk verticals 14 (13.4) Mid-Continent Hartshorne HCBM 49 (34.0) Mid-Continent horizontal Granite Wash 16 (5.8) Mid-Continent horizontal Fayetteville Shale 12 (4.7) Mid-Continent horizontal Woodford Shale 4 (1.0) Mid-Continent (Williston Basin) horizontal Bakken Shale 2 (1.3) Gulf Coast 11 (6.0) Other 30 (13.9) Total PVOG drilling program 329 (216.4) Other Guidance Natural gas production (Bcf) 43.2 – 45.1 Crude oil and natural gas liquids production (MMBbls) 1.0 – 1.1 Natural gas equivalent production (Bcfe) 49.2 – 51.7 Natural gas equivalent daily production (MMcfe/d) 134.4 – 141.3 Cash operating expenses (LOE, TOTI, G&A)($MM) $100.0 – $110.0 Exploration expense ($MM) $30.0 – $40.0 Depreciation, depletion and amortization expense ($/Mcfe) $2.20 – $2.25

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8 PENN VIRGINIA CORPORATION Penn Virginia Oil & Gas

Overview of Shale Plays

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9 PENN VIRGINIA CORPORATION Summary of PVOG’s major shale plays

  • Devonian / Marcellus Shale

− Lower Huron and Marcellus effort in WV and Marcellus in PA − Approximately 87,500 net acres with net unrisked reserve potential in excess of 250 Bcfe − Effort underway to add Marcellus acreage via leasing and partnering arrangements − Currently completing and testing Lower Huron wells in West Virginia; Marcellus timing of drilling TBD

  • Woodford / Caney Shale

− Located in the Arkoma and Anadarko Basins in Oklahoma − Approximately 40,000 net acres with net unrisked reserve potential of ~ 200 Bcfe − Plans to drill up to 4 exploratory wells in 2008

  • Fayetteville Shale

− Located in the Arkoma Basin primarily in Pope County, Arkansas − Approximately 14,500 net acres − Currently testing acreage through drilling to determine whether to proceed in the play – results have improved over the last few wells

  • Bakken Shale

− Oil play located in the Williston Basin in Dunn County, North Dakota − Approximately 65,000 (39,000 net) acres with net unrisked reserve potential in excess of 100 Bcfe − Plans to drill up to 2 exploratory wells in 2008

  • Lower Bossier Shale

− Located in Harrison and Panola Counties in east Texas − Approximately 46,000 (40,000 net) acres with net unrisked reserve potential of ~ 800 Bcfe − Vertical completions have confirmed stabilized flow rates up to 300 Mcf/d − Plans to spud first exploratory horizontal well in first quarter of 2008

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10 PENN VIRGINIA CORPORATION

Marcellus Shale Rhinestreet Shale Lower Huron Shale Upper Huron Shale Sunbury Shale Cleveland Shale Marcellus Shale Rhinestreet Shale Lower Huron Shale Upper Huron Shale Sunbury Shale Cleveland Shale

Industry: Devonian / Marcellus Shale

  • Technically recoverable resource: 24 Tcf

− Production primarily due to natural fractures − Primary producing interval is organically rich Lower Huron (Devonian) – 30 to 200 net feet − Annual Devonian Shale production ~ 120 Bcf with cumulative production ~ 3Tcf − Historically exploited with vertical wells − Horizontal drilling has increased potential − Mature areas may benefit from downspacing and horizontal drilling

  • Marcellus is the “new” Appalachian shale play

− Deepest section of the Devonian Shale − Generally thickest from SW to NE PA but also deeper with the right TOC’s especially in NE PA − Proximity to thrust belt is probably important − Significant competition for acreage

  • Exploratory opportunities exist in both

shallower and deeper organic shales (i.e. Utica and Sunbury)

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11 PENN VIRGINIA CORPORATION PVOG: Devonian / Marcellus Shale

  • Three primary areas of activity with nearly

85,000 net acres in West Virginia

− Primary targets include Lower Huron and Marcellus − Drilled first horizontal well in Mason County with 1,640’ of lateral - natural flow of 760 Mcf/d decreasing to 150 Mcf/d - waiting on completion − Second horizontal well in Mason County has been drilled with lateral of 2,629’ and natural flow of ~ 100 Mcf/d − First well in Boone County drilled vertically and completed in Marcellus & Lower Huron - testing − Second horizontal well in Boone County drilled with 2,260’ of lateral - testing − Wyoming County horizontal well – second quarter of 2008

  • 2-3 additional exploratory / confirmation

horizontal wells will be drilled in 2008

  • Effort underway to expand PVOG’s

Marcellus acreage via leasing and partnering arrangements

70,000 acres 8,000 acres 12,000 acres

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12 PENN VIRGINIA CORPORATION Industry: Woodford / Caney Shale

  • Technically recoverable resource: 4 Tcf

− Woodford Shale typically 100-200 feet in thickness − Gets shallower south to north − Caney Shale is a shallower and thicker formation that has been less explored − 250+ horizontal wells drilled in the latest 12 months (9/07) with ~90 horizontal wells drilled in the previous 12 months − Daily production of 250+ MMcf/d and growing − Longer laterals (3,000’+), improvements in completion techniques and use of 3-D seismic will drive improved success − Less explored, but showing similar promise to both the Barnett and Fayetteville Shales

  • Shallower producing zones exist

− Hartshorne Coal and conventional zones

3000 2626; 2687 1270 1423 471 2576 3875; 2133 3720; 3265 1152 882 836 462 4350 11200 2248; 4887 5004 1714 3270 5295 703 640 1034 1424; 2818

LEGEND

Woodford vertical Woodford horizontal 2000 IP in MCFPD 3000 2626; 2687 1270 1423 471 2576 3875; 2133 3720; 3265 1152 882 836 462 4350 11200 2248; 4887 5004 1714 3270 5295 703 640 1034 1424; 2818

LEGEND

Woodford vertical Woodford horizontal 2000 IP in MCFPD

LEGEND

Woodford vertical Woodford horizontal 2000 IP in MCFPD

PVOG Acreage Is Depicted In Yellow PVOG Acreage Is Depicted In Yellow

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13 PENN VIRGINIA CORPORATION PVOG: Woodford / Caney Shale

  • Primary area of activity in Arkoma Basin in

Oklahoma with about 20,000 net acres

− Primary targets include Woodford and Caney Shales − Plans to drill up to 4 (1.0 net) horizontal exploratory wells in 2008 − Industry drilling has occurred in vicinity of PVOG’s Arkoma acreage with most activity to date just to the south

  • Successful exploration in 2008 would likely

lead to development drilling in 2009 and beyond

  • Additional 20,000+ net acres in the

Anadarko Basin holds potential for PVA

− Geologically similar with characteristics necessary for success − May hold similar upside as Arkoma Basin

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14 PENN VIRGINIA CORPORATION Industry: Fayetteville Shale

  • Technically recoverable resource: 15 Tcf

− Primary producing interval is 100 to 300 net feet in thickness − 600+ wells drilled to date, with 350+ wells drilled in 2007 and 115+ wells drilled in 2006 − Daily production of 300+ MMcf/d and growing − Less recoverable resource than the Barnett Shale (~40 Tcf), but has a similar development history − Longer laterals and improvements in and refinements of completion techniques have enhanced production performance and economics since 2005 − Exploration in non-core areas to west and east continues with mixed success thus far

Source: RBC Capital Markets’ Fayetteville Shale Weekly (1/22/08)

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15 PENN VIRGINIA CORPORATION PVOG: Fayetteville Shale

  • Sole area of activity is Pope County,

Arkansas with nearly 15,000 net acres

− Plan to drill up to 12 (4.8 net) exploratory wells in 2008 − Bulk of PVOG acreage is west and adjacent to core area counties in the play (Conway and Van Buren) − PVOG has participated in 9 wells to date (4

  • perated / 5 outside operated) with IP’s that

range from 212 Mcf/d - 1,508 Mcf/d; mean of 805 Mcf/d

  • 2008 will be the “make-or-break” year for

PVOG with respect to the Fayetteville Shale

− Results of the next 5-6 wells will determine whether PVOG exits play

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16 PENN VIRGINIA CORPORATION Other Shale Plays: Bakken & Lower Bossier

  • Bakken Shale

− Oil play requiring higher oil prices to generate attractive rates of return − Industry results have been mixed to date but “sweet spots” have been identified, primarily east of the Nesson Anticline − PVOG has ~ 65,000 (39,000 net) acres with net unrisked reserve potential in excess of 15 MM barrels of oil (~100 Bcfe) − Plans to drill 2 (1.3 net) exploratory horizontal wells in 2008

  • Lower Bossier Shale

− Approximately 46,000 (40,000 net) acres with net unrisked reserve potential of roughly 800 Bcfe − Not the typical organic shale − ~11,000’ depth or approximately 500 feet below the lowest of PVOG’s Cotton Valley sands (Taylor sand) − Cotton Valley production is currently PVOG’s largest development and production growth play infrastructure and knowledge of vicinity will help PVOG develop the play if exploration is successful − PVOG has drilled 15 vertical wells to test deeper formations with the Lower Bossier Shale demonstrating the best potential − Plans to drill 1 (1.0 net) exploratory horizontal well in 2008

North Dakota Texas

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17 PENN VIRGINIA CORPORATION Conclusions and summary

  • With the success of the Barnett, Fayetteville and, now, Woodford shales, the

Appalachian Devonian Shale could be the next, new significant “shale” play

  • Horizontal drilling and improvements in frac techniques are making shales

profitable

  • The experience factor of the industry is assisting in the identification of

geological characteristics required to be successful in new shale plays

  • Penn Virginia is active in five shale plays with potential in excess of 1 Tcfe
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18 PENN VIRGINIA CORPORATION

Forward-looking statements

Certain statements contained herein that are not descriptions of historical facts are “forward-looking” statements within the meaning of Section 27A of the Securities Act

  • f 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Because such statements include risks, uncertainties and contingencies,

actual results may differ materially from those expressed or implied by such forward-looking statements. These risks, uncertainties and contingencies include, but are not limited to, the following: the cost of finding and successfully developing oil and gas reserves; our ability to acquire new oil and gas reserves and the price for which such reserves can be acquired; energy prices generally and specifically, the price of crude oil and natural gas; the volatility of commodity prices for crude oil and natural gas; the projected demand for crude oil and natural gas; the projected supply of crude oil and natural gas; our ability to obtain adequate pipeline transportation capacity for our

  • il and gas production; non-performance by third party operators in wells in which we own an interest; competition among producers in the oil and natural gas industry;

the extent to which the amount and quality of actual production of our oil and natural gas differs from estimated recoverable proved oil and gas reserves; hazards or

  • perating risks incidental to our business; unanticipated geological problems; the availability of required drilling rigs, materials and equipment; the occurrence of unusual

weather or operating conditions including force majeure events; the failure of equipment or processes to operate in accordance with specifications or expectations; delays in anticipated start-up dates of our oil and natural gas production; environmental risks affecting the drilling and producing of oil and gas wells; the risks associated with having or not having price risk management programs; labor relations and costs; accidents; changes in governmental regulation or enforcement practices; risks and uncertainties relating to general domestic and international economic (including inflation and interest rates) and political conditions (including the impact of potential terrorist attacks); changes in financial market conditions; and other risks set forth in “Risk Factors,” of our Annual Report on Form 10-K for the year ended December 31, 2006 and subsequently filed interim reports. Many of the factors that will determine our future results are beyond the ability of management to control or predict. Readers should not place undue reliance on forward-looking statements, which reflect management’s views only as of the date hereof. Penn Virginia Corporation (the “Company”

  • r “we”) undertake no obligation to revise or update any forward-looking statements, or to make any other forward-looking statements, whether as a result of new

information, future events or otherwise. The U.S. Securities and Exchange Commission (“SEC”) has generally permitted oil and gas companies, in their filings with the SEC, to disclose only proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating

  • conditions. We use the terms “estimated ultimate recovery,” “EUR,” “probable,” “possible,” and “non-proven” reserves, reserve “potential” or “upside” or other descriptions
  • f volumes of reserves potentially recoverable through additional drilling or recovery techniques that the SEC’s guidelines may prohibit us from including in filings with the
  • SEC. These estimates are by their nature more speculative than estimates of proved reserves and accordingly are subject to substantially greater risk of being actually

realized by us.