Presentation on theme: "CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 1 CEO Roundtable – 2005 IPAA Annual Meeting Houston, Texas October 26, 2005 CEO Roundtable – 2005."— Presentation transcript:
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 1 CEO Roundtable – 2005 IPAA Annual Meeting Houston, Texas October 26, 2005 CEO Roundtable – 2005 IPAA Annual Meeting Houston, Texas October 26, 2005
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 2 CHK Overview 2 nd largest independent producer of U.S. natural gas: (trail only DVN), #5 overall (includes majors, utilities and pipelines) #1 driller in U.S.: 74 operated rigs, 72 non-operated rigs, collector of 10% of all daily drilling info generated in the U.S. Active consolidator in focused areas: $9.9 billion since 98, $2.1 billion in 04, $4.5 billion to date in 05 Increasing production: 1,270 mmcfe/day projected 05 production - 28% YOY increase; 1,543 mmcfe/day projected 06 production - 22% YOY increase Increasing reserves: 7.1 tcfe of proved reserves at 6/30/05, 92% natural gas, 64% proved developed, 13.8 year R/P Upside potential: 6.4 tcfe of non-proved reserve potential in: i) conventional, ii) unconventional gas resource and iii) emerging gas resource plays: 12-year drilling inventory Industry leading leasehold and seismic position: 7.6 mm acres of U.S. onshore leasehold plus 10.9 mm acres of 3-D seismic $19.4 billion EV: $14.2 billion equity value, $5.2 billion long-term debt 2006 estimates: ebitda $3.4 billion; operating cash flow $3.1 billion; net income to common $1.2 billion CHK offers great value to investors: 4.5x operating cash flow, 5.7x ebitda, 12.1x P/E ratio Top stock price performance: CHK up 25x in 12 years as a public company, #2 performer among mid and large-cap E&P companies during that period Data above incorporates: CHKs Outlook as of 10/3/05; Pro forma adjustments for August 2005 acquisitions and pending acquisition of Columbia Natural Resources (CNR); An assumed common stock price of $34.00, NYMEX prices of $8.00/mcf and $50.00/bbl for 2006 and excluding effects of FAS 133 (unrealized hedging gain or loss) and charges incurred in connection with stock based compensation; and The August 2005 $600 mm senior notes issuance, the September 2005 issuance of 9.2 million shares of common stock, the September 2005 issuance of $345 million of convertible preferred stock and the estimated debt and equity financings of the pending acquisition of CNR
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 3 Agreed to acquire Columbia Natural Resources, LLC (CNR) for $2.2 billion in cash and assume approximately $75 million working capital deficit and additional liabilities related to prepaid sales and hedging agreements valued as follows: –Proved reserves: 1.1 tcfe for $1.5 billion = $1.45/mcfe (1) –Probable/possible reserves and unevaluated leasehold: 1.4 tcfe and 4.1 mm net acres (3.6 mm net acres onshore U.S.) for $500 mm –Midstream: 6,500 miles of gathering pipeline and infrastructure for $175 mm All-in cost to develop 2.5 tcfe of 3P reserves = $2.48/mcfe (1) 99% natural gas; 70% proved developed reserves; 125 mmcfe current daily production rate; 23-year R/P ratio (16 years on proved developed); operate 91% of wells with a 93% average working interest Anticipate hedging at least 50% of CNRs estimated base production through 12/08 Price decks used to value CNR were much lower than the price decks on the forward curve; this arbitrage opportunity has significantly expanded over the last four years Review of CNR Acquisition (1)Excludes negative working capital and liabilities associated with assumed prepaid sales and hedging agreements
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 4 Immediate critical mass and scale in a proven gas prone basin –Fourth largest gas producer in Appalachian Basin behind Equitable, Consol and Dominion –Over 46 tcf of cumulative gas production in Appalachia with 9 tcf of proved and 68 tcf of unproved gas remaining (1) Attractive all-in economics –Premium gas price realizations: High btu gas (1,140 btu/mcf); positive basis differentials of $0.25 to $0.50/mmbtu over NYMEX vs. $2.00 to $4.00/mmbtu discounts to NYMEX in various southwestern and western basins –Attractive lease operating and future development costs: $1.35/mcfe and $2.35/mcfe Multiple value creation opportunities: –Fragmented basin that is ripe for consolidation –Drilling acceleration to enhance PV of inventory Plan to triple capex to over $200 mm in 2006 Low-risk gas-farming opportunities of long-lived, low production decline rate assets Proven blanket sand and shale horizons ideal for accelerated drilling program –Future reserve upside? CHK has identified 1,316 PUDs and 8,119 unproved drillsites and initially recognized 2.5 tcfe of 3P reserves vs. 1,611 PUDs and 14,000 unproved locations and 3.9 tcf of 3P reserves determined by sellers third-party engineers –Deeper drilling potential that plays to CHKs expertise in largely under-explored basin <1% of more than 400,000 wells drilled below 7,500 feet –Over 3,000 wells with workover potential at >50% rates of return CNR Acquisition Highlights (1)Source: National Petroleum Council - September 2003 CHK believes the Appalachian Basin is the last frontier for American onshore gas exploration and consolidation
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 5 Anadarko Basin Barnett Shale South Texas Texas Gulf Coast Permian Basin Arkoma Basin Ark-La-Tex Gas Focused Onshore Platform – Now Expanding to Appalachia… CHK/CNR field officesCHK OKC headquarters CHK operated rigs (74)CHK non-operated rigs (72) Counties with CHK leasehold Counties with leasehold CHK is acquiring from Columbia Natural Resources Pro forma for pending acquisition of Columbia Natural Resources Rig activity excludes Appalachian pending rigs Scale: 1 inch = 115 miles Scale: 1 inch = 200 miles Appalachian Basin CNR Charleston headquarters
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 6 …Extending CHKs Long Reserve Life Asset Base (1) (1)As of 6/30/05 - Pro forma for acquisitions announced in August 2005 (2) (2)Includes pending acquisition of Columbia Natural Resources (3) (3)Other includes the Piceance Basin of Colorado and the Williston Basin of North Dakota and Montana. Proved Reserves (bcfe) Proved Reserves % Production (mmcfe/d) Production % R/P (years) Mid- Continent 3,75053%81958%12.5 Appalachia (2) 1,05015%1259%23.0 Ark-La-Tex & Barnett Shale (1) 90013%16912%14.6 Permian (1) 70010%1047%18.4 S. Texas & Gulf Coast 6008%17713%9.3 Other (3) 501% Totals (1)(2)(3) 7,050100%1,402100%13.8
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 7 CHKs Business Strategy Growth through acquisitions Acquire, exploit, expand and explore Growth through the drillbit Onshore domestic U.S. Regional consolidation PIMBY not NIMBY Gas, gas, gas Clean, domestic fuel
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 8 CHKs Successful Business Strategy Following operational failures and oil/gas price collapse in the late 1990s, CHK revamped its business strategy and for the past 7 years has executed a simple and highly effective business strategy: – Balanced growth through acquisitions and the drillbit Focus on long-lived, low-decline, onshore US gas reserves that have become much more valuable over time Rediscover the lost art of deep gas exploration through new investments in people, land and seismic in the right areas – Regional consolidation to generate operating scale, maintain low operating and administrative costs and deliver high returns CHKs scale in its core areas is a real competitive advantage and has created negotiating power, informational advantages and attracted top industry talent – Concentration on gas One of the first companies to recognize and capitalize on tightening supply/demand fundamentals and permanent upward shift in gas prices that began in 99 CHK has benefited from substantial first mover advantages and has built one of the largest U.S. natural gas resource bases
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 9 CHKs Business Strategy Growth through acquisitions Acquire, exploit, expand and explore Growth through the drillbit Onshore domestic U.S. Regional consolidation PIMBY not NIMBY Gas, gas, gas Clean, domestic fuel
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 10 Keys To Being A Successful Acquirer Focus Know what you want to buy, where you want to buy it and how you want to buy it Experience Inexperienced or occasional buyers generally do not succeed. CHK has a consistent approach to acquiring and assimilating acquisitions. CHK is always in the market and has 50 people working full-time on acquisition integration Drillbit Expertise Must be able to accurately assess, accelerate and deliver upside from PUDs, probables, possibles and exploration opportunities Operational Skill Must be able to operate acquired properties more efficiently than sellers. Significant operating scale and attention to detail are the keys to achieving efficiencies CHK has executed more acquisition transactions in the past seven years than any other E&P company – experience helps prevent mistakes!
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 11 Acquisition Margins Best Ever Oil and gas price increases have far outpaced acquisition cost increases Margins matter, not per mcfe sticker price Oil and gas price increases have far outpaced acquisition cost increases Margins matter, not per mcfe sticker price Gross margin between cost and gas price $4.37 $3.00 $1.12 $1.79 $3.05 $1.56 $3.78 (to date) 7-year CAGR 11.2% 29.5% 22.5% Acquisition cost – per mcfe Average yearly gas price $8.80 $6.54 (10/05) (1)2006 NYMEX strip as of 10/3/05 (1)
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 12 CHKs Business Strategy Growth through acquisitions Acquire, exploit, expand and explore Growth through the drillbit Onshore domestic U.S. Regional consolidation PIMBY not NIMBY Gas, gas, gas Clean, domestic fuel
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 13 Why Is CHK the #1 Driller in the U.S.? Most active driller in U.S. by a wide margin – 74 operated rigs currently drilling (plus 72 non-operated rigs drilling) – CHK gathers 10% of all the daily drilling information generated in America This is a distinctive competitive advantage. 1/4 of rigs drilling to targets > 15,000; 1/2 between 10-15,000; 1/4 < than 10,000 – Drill more deep onshore wells than anyone in the industry – Also one of the leading horizontal drillers in the industry If properly executed, good drilling easily generates the highest returns on capital: 100%+ vs % acquisitions However, creating value through the drillbit today is difficult – You had to start getting ready 5 years ago – Quality land, people and seismic are scarce resources Over the past 7 years, CHK has differentially invested over $2.4 billion to build the industrys largest inventories of U.S. leasehold (7.6 mm acres) and 3-D seismic (10.9 mm acres) (1) – Amassed a 12-year inventory of over 23,500 drill sites – Now in every major U.S. onshore gas resource play out side of the Rockies CHK is uniquely positioned to transfer and apply technology, data and geoscience knowledgebase across all of its operating regions (1)Pro forma for pending acquisition of Columbia Natural Resources
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 14 Balanced Production Growth 473 mmcfe/day drillbit production growth (51% of growth) 452 mmcfe/day acquisition production growth (49% of growth) 170 mmcfe/day base production 2005 Q2 Average Production CHKs operating performance since January 2001 has been one of the two best performances among the 20 largest E&P companies During this time, our production has more than tripled with over half of this growth coming from the drillbit Through the drillbit only, CHK has created a top 20 U.S. gas producer from scratch in past 5 years CHKs operating performance since January 2001 has been one of the two best performances among the 20 largest E&P companies During this time, our production has more than tripled with over half of this growth coming from the drillbit Through the drillbit only, CHK has created a top 20 U.S. gas producer from scratch in past 5 years Total production has increased 925 mmcfe/day in 18 quarters, or 35% CAGR 149 mmcfe/day drillbit production maintenance 20% initial decline rate 12% current decline rate 22% CAGR through the drillbit 319 mmcfe/day 1,244 mmcfe/day
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 15 Results From Investing in the Future (1) (1)Proved developed and proved undeveloped reserves as of 6/30/05 are internal estimates, as are non-proved reserves as of 2004 and as of 6/30/05 (2) (2)Includes acquisitions announced in August 2005 and pending acquisition of Columbia Natural Resources 1,206 1,355 1,780 2,205 3,169 CHKs deep inventory of projects helps assure repeatable, low risk value creation 4,000 8,902 Non-proved reserve potential Proved undeveloped (PUDs) Proved developed (PDs) # Total proved and non-proved reserves (3P) (1) Bcfe (2) 13,450 (2) 6,400
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 16 CHKs Substantial U.S. Gas Resource Base Conventional Unconventional gas resource Emerging gas resource Net Acreage (7.6 million acres) Drillsites (23,500 gross wells) Proved Undeveloped Reserves (2,500 bcfe) Non-Proved Reserves (6,400 bcfe) Twelve-year identified inventory of over 23,500 drillsites to develop 2.5 tcfe of proved undeveloped reserves and 6.4 tcfe of non-proved reserves Conventional plays: Much of the Mid-Continent, Permian, Gulf Coast, S. Texas and other areas – Mountain Front Springer: (S. & W. OK); >100,000 net acres; Prolific play initiated by CHK 3-D seismic and leasehold – Zapata County: (S. TX); 100,000 net acres; CHK 3 rd largest producer in the #1 gas producing county in Texas Unconventional gas resource plays: – Sahara (NW OK): >500,000 net acres; Foundational asset; 20-year drilling inventory; 640 acre spacing in 1998, moving down to 40s – Granite, Cherokee/Atoka Washes (West OK/TX Panhandle): 200,000 net acres; Overlooked formations from low gas price days in Anadarko Basin – Barnett Shale (N. TX): 48,000 net acres; Recent expansion in Johnson County sweet spot through acquisition of Hallwoods interest in S. Block AMI – Hartshorne Coal (Oklahoma Arkoma): 100,000 net acres; CHK has drilled over 300 CBM wells – Ark-La-Tex tight sands: >50,000 net acres; CHK rapidly becoming a player in prolific Ark-La-Tex region – Appalachia: (WV, KY, OH, PA, NY) 3.5 mm net acres; 9,435 undrilled locations of primarily shallow, low-risk drilling; > 15-year inventory Emerging gas resource plays: – Fayetteville Shale (Arkansas Arkoma): >200,000 net acres; SWN has been successful to date. CHK plans to drill six operated wells by year-end 2005 – Haley (West TX): 125,000 net acres; Permian Basin deep over-pressured gas play in Loving County, TX with APC as a competitor/partner – Caney/Woodford Shales (Oklahoma Arkoma): 250,000 net acres; age equivalent to Fayetteville, too early to declare success Continue to actively expand all three play types with >500,000 acres acquired in 2Q05 through aggressive land acquisition program utilizing >500 land brokers in the field Were also working on several new potentially significant gas resource plays, details to come... Most recently, CNR acquisition opens up multiple unconventional shale, tight sand and CBM plays Continue to actively expand all three play types with >500,000 acres acquired in 2Q05 through aggressive land acquisition program utilizing >500 land brokers in the field Were also working on several new potentially significant gas resource plays, details to come... Most recently, CNR acquisition opens up multiple unconventional shale, tight sand and CBM plays
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 17 CHKs Business Strategy Growth through acquisitions Acquire, exploit, expand and explore Growth through the drillbit Onshore domestic U.S. Regional consolidation PIMBY not NIMBY Gas, gas, gas Clean, domestic fuel
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 18 Why Regionally Consolidate? Most E&P companies asset bases are too diversified, too spread out Result is often operational mediocrity – sometimes incoherent corporate strategy and resulting investor unease about the future CHK believes top-tier business success can only be achieved by being better at one thing than everyone else – for CHK, thats onshore in the southwest U.S. and now the Appalachian Basin Scale brings many benefits: – –Negotiating power: CHK demands and receives best prices and best services from service industry – –Information advantages: CHK receives > 50% of all drilling information generated in the Mid-Continent. There is tremendous value in this unique and sustainable competitive advantage – –Attracting talent: The best geologists, engineers, and landmen want to work where the action is Our strategy is clear, concise and consistent. What we do has worked, is working and should keep working for the foreseeable future CHKs operating areas are still very fragmented and in the years ahead likely to produce further consolidation opportunities
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 19 Oklahoma: Example of Scale Building Top 20 Oklahoma Gas Producers Gross Operated Oklahoma Gas Production (1) Chesapeake (3) BP Apache Dominion Cimarex Kaiser-Francis (private) Samson (private) Burlington Marathon XTO Newfield St. Mary Questar ChevronTexaco EOG Anadarko ConocoPhillips Unit Chaparral (private) Kerr-McGee Top 20 Producers (excluding CHK) Chesapeake All Others Grand Total ,601 Oklahoma Rigs 10/7/05 (2) (1) In bcfs for 2004 (2) Source: Smith International survey (3) Pro forma for acquisitions (4) Oklahoma is the second largest gas producing state in the U.S. (23%) (38%) (40%) OKC London Houston Richmond Denver Tulsa Houston Ft. Worth Houston Denver Salt Lake City San Francisco Houston Tulsa OKC Headquarters (100%) Production Change, 04 vs. 03 % % % % % (4) Share of Oklahoma Production % % % % % (22%) CHK has increased its gas market share in Oklahoma from 1% to 19% in just six years ( ( ( ( ( ( ( ( ( ( () ) ) ) ) ) ) ) ) ) () )
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 20 CHKs Business Strategy Growth through acquisitions Acquire, exploit, expand and explore Growth through the drillbit Onshore domestic U.S. Regional consolidation PIMBY not NIMBY Gas, gas, gas Clean, domestic fuel
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 21 Why Has CHK Focused on Gas Since 1998? Our operating strategy failure in the mid-90s taught us that: – Significant new reserves of U.S. natural gas are hard to find – Finding costs would accelerate over time – Depletion rates would accelerate over time – Boom in gas fired power plants would cause a train wreck over time We thought that supply/demand fundamentals would steadily improve – Demand trendline would be up 1-3% per year, supply trendline would be down 0-2% per year – In pricing: higher highs, higher lows – the trend would be our friend Volatility is high and likely to increase. We love gas price volatility – why? – Volatility creates opportunity to hedge unusually high prices that generate unusually high returns – Volatility reduces investment in the industry, which dampens supply – Volatility helps unlock the option value embedded in long-life reserves – This option value is a key x factor enhancing the value of long-lived assets and it comes free with acquisitions LNG is a risk to be monitored – But, our view is that U.S. gas prices will need to approximate BTU parity with world oil prices to attract LNG imports in the 2009 and beyond time frame U.S. natural gas production curve today is similar to U.S. oil production curve in the 1970s: a peak, then a steady decline regardless of price increases and technology improvements
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 22 (A) Based on company reports (B) In mmcf per day (C) Independents in green, majors in black, pipelines in red (D) CHKs change calculated on reported 2Q 05 gas production (E) CHKs reported gas production in 2Q 05 was 1,111 mmcf per day - production of 1,144 mmcf per day is pro forma for acquisitions announced in August post CNR, CHK gas production should exceed 1,350 mmcf/day After CNR, CHK Should Become 5 th Largest U.S. Gas Producer The top 20 gas producers (with their royalty 20%) account for 50-55% of U.S. gas production BP ExxonMobil Chevron Devon (1) RoyalDutchShell ConocoPhillips Anadarko (2) Chesapeake (3) EnCana (4) Kerr-McGee (5) XTO (6) Dominion Burlington (7) EOG (8) Apache (9) Williams El Paso Newfield (10) Marathon Pioneer (11) Company2Q 04 Daily U.S. Natural Gas Production (A,B) 1Q 05 2Q 05 vs. 1Q 05 % Change 2Q 05 vs. 2Q 04 % Change 2,790 1,987 2,001 1,652 1,327 1,226 1, ,513 2,648 1,881 1,601 1,610 1,385 1,169 1,183 1,046 1,067 1, , , % (3.8%) 1.2% (6.7%) (2.0%) 2.2% (3.0%) 6.2% (0.6%) 1.4% 10.6% (3.1%) 4.9% 2.5% 6.3% 2.4% 3.0% 2.0% 2.9% 0.9% (2.3%) (9.0%) (19.0%) (9.1%) 2.3% (2.5%) (17.4%) 32.1% 28.8% 57.9% 26.9% 0.2% 5.0% 14.1% (1.7%) 18.2% (12.0%) 12.7% (10.1%) 3.3% 1.1% 2Q 05 2,727 1,809 1,621 1,501 1,357 1,195 1,147 1,111/1,144 1,061 1,023 1, , (C) (E) BP XOM CVX DVN RD COP APC CHK ECA KMG XTO D BR EOG APA WMB EP NFX MRO PXD Ticker (D) US Rigs at 10/7/
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 23 Financial Information
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/ Various Gas Prices $ 4, , ,280 1, $ 1,265 $ x 8.6x 4.3x 5.4x 11.2x $ 3, , ,985 1, $ 1,078 $ x 7.9x 4.7x 5.9x 13.1x ($ in millions; gas price at various NYMEX prices; oil at $50.00 NYMEX) O/G revenue 563 bcfe (1) Hedging effect Marketing and other Production taxes 7%) LOE $0.80/mcfe) G&A $0.11/mcfe) (2) Ebitda (1) Interest Operating cash flow (3) Oil and gas depreciation $2.18/mcfe) Depreciation of other assets $0.11/mcfe) Income taxes (36.5% rate, 95% deferred) Net income to common (1)(2) Net income per fully diluted share Net debt/ebitda (4) Ebitda/fixed charges (including pfd. dividends) (5) MEV/operating cash flow (6) EV/ebitda (7) PE ratio $ 3, , ,838 1, $ 946 $ x 7.6x 5.0x 6.2x 14.4x ) ) ) ) ) ( ( ( ( ( ) ) ) ) ) ( ( ( ( ( $4, , ,427 1, $ 1,358 $ x 9.0x 4.1x 5.2x 10.4x ) ) ) ) ) ( ( ( ( ( )( )()( )( $ 3, , ,133 1, $ 1,172 $ x 8.3x 4.5x 5.7x 12.1x ) ) ) ) ( ( ( ( )( )( ) ) ) ) ( ( ( ( )( )( $4, , ,574 1, $ 1,452 $ x 9.3x 4.0x 5.0x 9.8x ) ) ) ) ) ( ( ( ( ( )( )( )( (as of 10/3/05) (1)Before effects of FAS 133 (unrealized hedging gain or loss) (2)Before charges incurred in connection with issuances of restricted stock (3)Before changes in assets and liabilities (4)Net debt = long-term debt less cash (5)Fixed charges ($414 mm) = interest expense of $346 million plus preferred dividends of $68 million (6)MEV (Market Equity Value) = $14.2 billion ($34.00/share x 417 mm fully diluted shares pro forma for September 2005 equity offerings and estimated equity financing of the pending acquisition of Columbia Natural Resources) (7)EV (Enterprise Value) = $19.4 billion (Market Equity Value, plus $5.2 billion in long-term debt pro forma for the debt offering completed in August and estimated debt financing of the pending acquisition of Columbia Natural Resources) (8)Assuming a common stock price of $34.00/share
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 25 CHK Also Hedges Service Costs Negotiating power through large operating scale – #1 customer of most onshore drilling service providers – We demand best pricing, best equipment, best people Direct rig ownership: Building wholly-owned Nomac Drilling subsidiary to 40 rigs from 15 currently running; estimated current value 100% over CHK cost of$80 mm – Provides operational flexibility – Less turnover and loyalty to operator, not contractor Rig investments: – Own 17% interest in Pioneer Drilling Company (AMEX: PDC) which has 50 rigs and has 7 more on order; $80 mm unrealized gain to date – Recent $15 mm investment for a 45% interest in privately-held DHS Drilling Company that has 6 rigs operating and is expanding to 10 rigs – Recent $25 mm investment for a 49% interest in privately-held Mountain Drilling Company that has secured 4 specialty rigs Third-party rigs: Sponsored the construction of 20 rigs through various drilling contracts with third party rig builders and operators; rates 10%-15% below current market levels CHKs $160 mm of rig investments have appreciated $150 mm and have or will increase the U.S. rig fleet by 60 rigs, or 4%, from 2004 to 2006 HOW?
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 26 (1) NYMEX gas price changes and NYMEX oil price held constant at $ per bbl (2) 7.1 tcfe pro forma for acquisitions announced in August 2005 and pending acquisition of CNR (3) 6.4 tcfe of unproved reserves valued from $ $1.30/mcfe (4) Cash, buildings, drilling rigs, midstream gas assets and investments at estimated fair value (5) Pro forma for the $600 million senior notes issuance in August 2005 and estimated financing related to the pending acquisition of Columbia Natural Resources (6) Pro forma for working capital associated with the the pending acquisition of Columbia Natural Resources (7) Pro forma for September 2005 common and preferred stock offerings and estimated financing related to the pending acquisition of Columbia Natural Resources (8) Based on common stock price of $34.00 per share NYMEX Strip 10/07/05 OilGas 2H yr. avg. $11.09 $11.31 $9.39 $8.28 $7.56 $7.04 $8.93 $62.69 $62.83 $61.87 $60.50 $58.77 $57.89 $61.94 CHKs NAV Exceeds Current Stock Price So, even though stock has roughly doubled YTD, we believe it still has more room to run As of June 30, 2005 various gas prices (1) Proved reserves (2) Unproved reserves (3) Value of CHK hedges Value of CNR hedges assumed Other assets (4) Less: long-term debt (5) Less: preferred stock (when not dilutive) Less: net working capital (6) Shareholder value Fully diluted common shares (7) NAV per share Potential % upside (8) PV PV PV PV PV PV ($ in millions, except per share data) $ 16,109 5, , $ 16, $ % () () $ 17,527 5, , $ 18, $ % () () $ 19,379 6, , $ 21, $ % () () $ 20,869 7, , $ 22, $ % () () $ 22,359 7, , $ 24, $ % () () $ 23,849 8, , $ 26, $ % () () ()()() ()() ()()()()()()
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 27 Why Own CHK ? Performance: #2 mid-to-large cap stock price performer since 1999 and since 1993 Gas: Purest play in U.S. natural gas – all onshore Focus: Uniquely focused business strategy provides high returns Growth: 16 consecutive quarters of organic production growth vs. industrys multi-year decline; 35% production growth in 04, 28% in 05, at least 22% in 06 Sustainability: 6.4 tcfe of unproved reserve potential and 12-year drilling backlog Balance Sheet: Steadily improving, low borrowing costs and long-term maturities Value: Trade at a discount to NAV and discount to closest peers Income: Pay a $0.20 annual common stock dividend Hedging: Best hedging track record among E&Ps during past 5 years Commitment – Two co-founders own 12% of common stock and equivalents, have been active open market acquirers CHK = Value, Growth, Performance
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 28 Gas Market Thoughts
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 29 Drivers of Future Oil and Gas Prices Part 1 Oil and natural gas is increasingly difficult and expensive to find, all across the globe – and we are consuming 31 billion bbls/year World population growth will continue until at least 2050, increasing by approx. 50% – thats 3 billion more energy consumers (10x current USA population) 50% of todays population (mostly Asia) is rapidly industrializing, and rapidly expanding energy consumption Average U.S. oil consumption per capita: 25.3 bbls/year 2003 Average Korean oil consumption per capita: 17.7 bbls/year 2003 Average Japanese oil consumption per capita: 15.6 bbls/year 2003 Average Chinese oil consumption per capita: 1.8 bbls/year 2003 Average Indian oil consumption per capita: 0.9 bbls/year 2003 When urbanized Chinese (40%) and Indians (30%) reach same per capita consumption as Japanese/Koreans average today, the world will consume 42% more oil than today – where will 35 million new bbls/day come from? How quickly will China and India get there? The Great Debate: How close are we to a peak of worldwide crude production?
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 30 Drivers of Future Oil and Gas Prices Part II In addition to Asia, the U.S. and others will also continue to grow – remember, the U.S. adds the equivalent of a new Texas every 7-8 years in population and energy demand Despite the obvious need for massive new resources of oil and natural gas, futures markets and most investors/analysts believe that lower oil and gas prices are inevitable – although this is changing before our eyes Why so much denial of what appear to be easily visible trends? – – Energy has not been expensive for 20 years (almost half of U.S. population has never known anything other than cheap energy) – – Its inconvenient to think about the implications of energy prices – every thing you own and do today is predicated on cheap energy – – Policies favoring cheap energy and a pristine environment are often in conflict – – Technology will save us – maybe, but much higher prices will be needed to drive the needed increases in energy technology investment Bushs inaugural Freedom from Tyranny policy is bullish for energy prices – – If hes right, strong demand increases will overwhelm supply increases – – If hes wrong, supply will be at risk for a long time Hurricane Katrina demonstrates the folly of putting too many of our energy infrastructure eggs in one (very fragile) basket And finally, when will peace, love and harmony break out in oil producing regions of the world?
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 31 Other Questions to Ponder Can LNG gas supply accretion (from a 2.5 bcf/day base in 05) overcome continuing U.S./Canada gas supply depletion (from a 70 bcf/day current base)? Will all (or enough) spot cargoes of LNG come to the U.S. and at what price? Will LNG importers have financial motivation to undercut U.S. gas prices at the moment of importation? When will we build gas pipeline from McKenzie Delta Alaska? How much of the McKenzie gas gets past Canadian oil sands projects? Should Alaska gas be liquefied instead? What happens if energy demand in India and China (40% of the worlds population) increases by 35 million bbls/day in next 15 years? How will U.S. resolve its public policy conflicts between cheap energy vs. a pristine environment? Will world oil production peak? When? 05, 10, 15? After an oil production peak, how much stranded gas becomes converted to liquids rather than to LNG? How high do oil/natural gas prices have to rise to cut short economic growth/induce conservation/curb demand? How will Iraq and Iran play out and what happens if (or when?) House of Saud falls? At what prices for oil and gas are you willing to change your consumption habits?
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 32 Corporate Information Chesapeake Headquarters 6100 N. Western Avenue Oklahoma City, OK Web site: Contacts: Jeffrey L. Mobley, CFA Vice President – Investor Relations and Research (405) Marcus C. Rowland Executive Vice President and Chief Financial Officer (405) Common Stock – NYSE: CHK Other Publicly Traded SecuritiesCUSIPTicker 6.0% Convertible Preferred Stock# CHKPrA 5.0% Convertible Preferred Stock (2003 Series)# CHKPrB 4.125% Convertible Preferred Stock# n/a 5.0% Convertible Preferred Stock (2005 Series)# pending 4.5% Convertible Preferred Stock# pending 8.375% Senior Notes Due 2008 #165167AV9CHK08 7.5% Senior Notes Due 2013#165167BC0CHK13 7.5% Senior Notes Due 2014#165167BF3CHK14 7.0% Senior Notes Due 2014#165167BJ5CHKA % Senior Notes Due 2015 #165167BA4CHK % Senior Notes Due 2016#165167BE6CHK % Senior Notes Due 2015#165167BL0CHKJ % Senior Notes Due 2016#165167BN6CHKJ % Senior Notes Due 2017#165167BR7pending 6.25% Senior Notes Due 2018#165167BQ9CHK18
CEO Roundtable – 2005 IPAA Annual Meeting – 10/26/05 33 Forward-Looking Statements This report includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of Forward-looking statements give our current expectations or forecasts of future events. They include estimates of oil and gas reserves, expected oil and gas production and future expenses, projections of future oil and gas prices, planned capital expenditures for drilling, leasehold acquisitions and seismic data, and statements concerning anticipated cash flow and liquidity, our business strategy and other plans and objectives for future operations, including our acquisition of Columbia Natural Resources, LLC. and related financings. In addition, statements concerning the fair value of derivative contracts and their estimated contribution to our future results of operations are based upon market information as of a specific date. These market prices are subject to significant volatility. Although we believe the expectations and forecasts reflected in these and other forward-looking statements are reasonable, we can give no assurance they will prove to have been correct. They can be affected by inaccurate assumptions or by known or unknown risks and uncertainties. Factors that could cause actual results to differ materially from expected results are described under Risk Factors beginning on page S-13 of the Prospectus Supplement dated September 8, 2005 for our offering of 4.50% Convertible Preferred Stock we filed with the Securities and Exchange Commission on September 9, They include the volatility of oil and gas prices, adverse effects our substantial indebtedness and preferred stock obligations could have on our operations and future growth and on our ability to make debt service and preferred stock dividend payments as they become due, our ability to compete effectively against strong independent oil and gas companies and majors, the availability of capital on an economic basis to fund reserve replacement costs, uncertainties inherent in estimating quantities of oil and gas reserves and projecting future rates of production and the timing of development expenditures, our ability to replace reserves and sustain production, uncertainties in evaluating oil and gas reserves of acquired properties and associated potential liabilities, unsuccessful exploration and development drilling, declines in the values of our oil and gas properties resulting in ceiling test write-downs, lower prices realized on oil and gas sales and collateral required to secure hedging liabilities resulting from our commodity price risk management activities, drilling and operating risks, and the loss of key personnel. In addition, the CNR acquisition is subject to conditions which must be satisfied before closing. We caution you not to place undue reliance on these forward-looking statements, which speak only as of the date of this presentation, and we undertake no obligation to update this information. We urge you to carefully review and consider the disclosures made in this presentation and our filings with the Securities and Exchange Commission that attempt to advise interested parties of the risks and factors that may affect our business.