PENNVIRGINIA CORPORATION
RBC Capital Markets’ Shale Gas Conference Appalachian and Mid-Continent Shale Gas Plays Toronto, Ontario January 31, 2008 NYSE: PVA
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
RBC Capital Markets’ Shale Gas Conference Appalachian and Mid-Continent Shale Gas Plays Toronto, Ontario January 31, 2008 NYSE: PVA
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
− 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%
− 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
− “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
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)
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)
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 %
1/25/08 Avg. NYMEX 12-Month Strip Price
A p p a l a c h i a M u l t i
a t e r a l H C B M Mississippi Selma Chalk (horizontal) Mid-Con. Hartshorne CBM
M i d
. G r a n i t e W a s h ( h
i z
t a l )
6 PENN VIRGINIA CORPORATION 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
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
$474.8 Drilling Program – gross (net) wells
141 (102.2)
1 (1.0) Appalachia multi-lateral HCBM 27 (13.7) Appalachia Devonian Shale 4 (3.0) Selma Chalk horizontals 18 (16.4) Selma Chalk verticals 14 (13.4) Mid-Continent Hartshorne HCBM 49 (34.0) Mid-Continent horizontal Granite Wash 16 (5.8) Mid-Continent horizontal Fayetteville Shale 12 (4.7) Mid-Continent horizontal Woodford Shale 4 (1.0) Mid-Continent (Williston Basin) horizontal Bakken Shale 2 (1.3) Gulf Coast 11 (6.0) Other 30 (13.9) Total PVOG drilling program 329 (216.4) Other Guidance Natural gas production (Bcf) 43.2 – 45.1 Crude oil and natural gas liquids production (MMBbls) 1.0 – 1.1 Natural gas equivalent production (Bcfe) 49.2 – 51.7 Natural gas equivalent daily production (MMcfe/d) 134.4 – 141.3 Cash operating expenses (LOE, TOTI, G&A)($MM) $100.0 – $110.0 Exploration expense ($MM) $30.0 – $40.0 Depreciation, depletion and amortization expense ($/Mcfe) $2.20 – $2.25
8 PENN VIRGINIA CORPORATION Penn Virginia Oil & Gas
9 PENN VIRGINIA CORPORATION Summary of PVOG’s major shale plays
− 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
− 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
− 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
− 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
− 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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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
− 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
− 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
11 PENN VIRGINIA CORPORATION PVOG: Devonian / Marcellus Shale
− 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
70,000 acres 8,000 acres 12,000 acres
12 PENN VIRGINIA CORPORATION Industry: Woodford / Caney Shale
− 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
− 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
13 PENN VIRGINIA CORPORATION PVOG: Woodford / Caney Shale
− 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
− Geologically similar with characteristics necessary for success − May hold similar upside as Arkoma Basin
14 PENN VIRGINIA CORPORATION Industry: Fayetteville Shale
− 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)
15 PENN VIRGINIA CORPORATION PVOG: Fayetteville Shale
− 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
range from 212 Mcf/d - 1,508 Mcf/d; mean of 805 Mcf/d
− Results of the next 5-6 wells will determine whether PVOG exits play
16 PENN VIRGINIA CORPORATION Other Shale Plays: Bakken & Lower Bossier
− 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
− 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
17 PENN VIRGINIA CORPORATION Conclusions and summary
18 PENN VIRGINIA CORPORATION
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
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
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
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”
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
realized by us.