Announces Second Quarter 2003 Results

DENVER, August 12, 2003 -- Western Gas Resources, Inc. (NYSE:WGR) today announced that, for the quarter ended June 30, 2003, it had net income of $20.9 million or earnings of $0.56 per share of common stock. This compares to net income of $13.8 million or earnings of $0.34 per share of common stock for the same period in 2002. Earnings per share for both periods are on a fully-diluted basis and are after giving effect to preferred stock dividends. Revenues for the quarter ended June 30, 2003 totaled $660.5 million.

For the six months ended June 30, 2003, net income was $44.3 million or earnings of $1.19 per share of common stock. This compares to net income of $21.8 million or earnings of $0.52 per share of common stock for the same period in 2002. Earnings per share for both periods are on a fully-diluted basis and are after giving effect to preferred stock dividends. Revenues for the six months ended June 30, 2003 were $1.55 billion. Net income for the six months ended June 30, 2003 includes the cumulative effect of a one-time after-tax charge for a change in accounting principle of $6.7 million or $0.18 per share.

For the second quarter of 2003, EBITDA (earnings before interest, taxes, depreciation and amortization) was $56.9 million and cash flow before working capital adjustments was $43.4 million.

For the six months ended June 30, 2003, EBITDA (earnings before interest, taxes, depreciation and amortization and the cumulative effect of a change in accounting principle), was $129.7 million and cash flow before working capital adjustments was $115.4 million.

Volumes and prices. Natural gas equity production in the second quarter of 2003 increased sharply compared to the same period a year ago and total gas sales volumes marketed decreased. Prices received for natural gas and natural gas liquids ("NGLs") increased significantly from a year ago.

Natural gas equity production in the second quarter of 2003 increased 24 percent compared to the same period in 2002, averaging 149 million cubic feet equivalent per day ("MMcfed"). All of the Company's production growth was in the Powder River Basin coal bed methane ("CBM") play and the Greater Green River Basin.

Total gas sales volumes marketed, including equity gas production, gas produced at the Company's plants and gas purchased from third parties for resale, were 1.2 billion cubic feet per day ("Bcfd") in the second quarter of 2003 compared to 1.9 Bcfd for the same period in 2002. The decrease is primarily from reduced sales of natural gas purchased from third parties for resale. Average gas prices increased 61 percent to $4.86 per Mcf in the second quarter of 2003 compared to $3.02 per Mcf for the same period in 2002.

Total NGLs sales volumes marketed averaged 1.6 million gallons per day ("MMGald") in the second quarter of 2003 compared to 2.1 MMGald in the same period of 2002. The decrease in sales volumes was largely the result of the Company's sale of its Toca facility in September 2002. Average NGL prices increased 32 percent to $0.54 per gallon in the second quarter of 2003 compared to $0.41 per gallon in the same period in 2002. Operations. The Company's fully integrated operations include exploration, production, gathering, processing, transportation and marketing of natural gas and NGLs.

Exploration and production realized segment-operating profit (EBITDA before general and administrative expenses) of $29.4 million for the second quarter of 2003 compared to $15.9 million for the same period in 2002. This increase was primarily due to substantially higher natural gas prices and significant production volume growth from the Powder River CBM and Pinedale Anticline developments.

Gathering and processing realized segment-operating profit of $27.9 million for the second quarter of 2003 compared to $25.4 million for the second quarter of 2002. This increase is primarily due to higher commodity prices and increased gathering volumes from equity and third-party CBM production and the acquisition of several gathering systems in February 2003.

Gas transportation realized segment-operating profit of $2.9 million for the second quarter of 2003 compared to $3.2 million for the second quarter of 2002. The transportation segment includes the results from the MIGC and MGTC pipelines in the Powder River Basin.

Marketing realized segment-operating profit of $9.2 million for the second quarter of 2003 compared to $13.4 million for the same period in 2002. The results for the marketing business benefited significantly from transactions utilizing the Company's firm transportation capacity and storage positions. The Company's firm transportation allows it to purchase gas in the Rocky Mountain region for resale in the Mid-Continent markets. Operating profit decreased compared to the 2002 period as the price difference between the two regions narrowed as additional transportation capacity out of the Rocky Mountain region became operational in the second quarter of 2003.

Hedging.

The Company's equity-hedging positions decreased operating profit by $6.9 million in the second quarter of 2003 and by $22.3 million in the six months ended June 30, 2003. This compares to an increase in operating profit of $3.3 million in the second quarter of 2002 and to an increase in operating profit of $12.8 million in the six months ended June 30, 2002 resulting from hedge positions in that year. The Company has similar hedging positions in place for the remainder of 2003. The Company has begun hedging its estimated 2004 equity production including 30,000 MMbtus in a costless collar structure with a minimum price of $4.00 per MMbtu and a maximum price of $8.88 per MMbtu on a NYMEX-equivalent basis. These hedging positions are outlined in Table A.

Powder River Basin CBM.

Net CBM production sold increased nine percent to 11.1 Bcf in the second quarter of 2003 as compared to the same period one year ago and averaged 122 MMcfd. The Company has participated in the drilling of 273 CBM wells through July 2003 and plans to participate in a total of 600 to 650 CBM wells in 2003. Completion of the Company's 2003 drilling program will be subject to obtaining the necessary drilling and water discharge permits in a timely fashion.

As of July 2003, gross CBM production from wells in which the Company has an interest in the Big George coal was approximately 32 MMcfd of gas from one development and two pilot areas. Overall, total industry production from the Big George coal has increased approximately 175 percent in the last 12 months to approximately 99 MMcfd in May 2003. The Company expects to participate in 255 Big George wells in 2003 as part of its overall drilling program.

The Bureau of Land Management's ("BLM") Buffalo, Wyoming field office issued the final Record of Decision ("ROD") for the Powder River Basin Oil and Gas Environmental Impact Statement ("EIS") on April 30, 2003. On May 12, 2003, the BLM began accepting new applications to drill CBM wells on federal acreage. To date, 46 of the 86 permits approved since the ROD will benefit the Company.

Western averaged 414 MMcfd of CBM gathering volumes, including third-party gas, during the second quarter of 2003. This represents a 15 percent increase compared to the same period in 2002. Of that volume, approximately 107 MMcfd was transported through the Company's MIGC pipeline. The Company remains the largest gatherer and transporter of coal bed methane in the Powder River Basin.

Greater Green River Basin.

Production sold from the Pinedale Anticline, Jonah Field and Sand Wash Basin development areas in southwest Wyoming and northwest Colorado increased 206 percent to 2.5 Bcfe net in the second quarter of 2003 and averaged 27 MMcfed. The Company has participated in 24 wells drilled or drilling to date in 2003 with a 100 percent success rate. Western plans to participate in a total of approximately 50 wells in 2003.

A third and fourth phase expansion of the Company's 50 percent-owned Rendezvous gathering system into the Pinedale Anticline is under construction. The two phases will increase gathering capacity to 350 MMcfd and are expected to be completed by December 2003 at a net cost of $17.7 million to Western. Volumes on the operational portion of the Rendezvous system averaged 216 MMcfd in June 2003. As part of our expansion process we are implementing a 100 MMcfd processing capacity upgrade at the Company's Granger plant.

Capital Expenditures.

The Company increased its budget capital expenditures for 2003 to $210.1 million. The new 2003 capital budget includes approximately $77.0 million for exploration and production and lease acquisition activities, $83.9 million for midstream activities and $37.1 million for the acquisition of gathering assets in Wyoming. Overall, capital expenditures in the Powder River Basin coal bed methane development and in southwest Wyoming operations represent 28 percent and 51 percent, respectively, of the total 2003 budget.

Balance sheet.

At June 30, 2003, Western had total assets of $1.4 billion, cash and cash equivalents in short-term investments of $40.2 million, total long-term debt outstanding of $333.3 million and a debt to capitalization ratio, net of cash and cash equivalents, of 36 percent.

CEO comments.

Peter Dea, President and Chief Executive Officer, commented, "Our strong performance in the second quarter continues to reflect the benefits of our integrated approach to the natural gas business. We benefited from strong prices, volume growth in our production and midstream businesses and our firm transportation positions to Mid-Continent markets. The Powder River CBM and the Pinedale Anticline developments both experienced significant volume growth from year ago periods. We are particularly encouraged by stellar results from the Big George coal as it nears 100 MMcf per day of total industry production. We feel confident that the recent release of permits from the BLM is an indication of a steady stream of permits to follow in the coming months. This will allow us to develop our dominant position in this emerging, prolific fairway and will drive future growth beginning in the second half of 2004."

Operational performance guidance for the remainder of 2003. Operational performance guidelines for 2003 were provided in a press release by the Company dated February 20, 2003 and updated May 8, 2003. The following information represents modifications to the previous guidance.

Production.

For the full year 2003, production volumes are expected to be 145 MMcfed, an increase of eight percent compared to 2002. Production volumes are expected to average 144 MMcfed net during the second half of 2003. This includes 119 MMcfd of CBM production in the Powder River Basin and 25 MMcfed from the Greater Green River Basin. Gathering and transportation expense is expected to average $0.65 per Mcf for the second half of 2003. Lease operating expense (LOE) for all production is expected to average approximately $0.49 per Mcf for the remainder of the year, which includes production overhead of $0.09 per Mcf. Other miscellaneous expenses, which include land and exploration costs, are expected to be $0.10 per Mcf. The Company follows the successful efforts method of accounting for oil and gas exploration and production activities.

Gathering and Processing.

Throughput volumes for the second half of 2003 are expected to average 1,379 MMcfd. Plant gas sales are expected to average 594 MMcfd and plant NGL sales are expected to average 1,165 MGald for the second half of 2003. Fee revenues are expected to average $0.22 per Mcf of throughput. The gross operating margin (gross revenues less product purchase expenses) for the gathering and processing business is expected to average approximately $0.41 per Mcf of facility throughput for the remainder of 2003. Gross operating margin is dependent on commodity prices, and these estimates are based on an assumption of $5.35 per Mcf for natural gas and $29.10 per barrel for crude oil (NYMEX-equivalent prices.) Plant operating expenses are expected to average $0.17 per Mcf of throughput for the second half of 2003.

Marketing.

Total gas sales volumes marketed (which include production, plant and third-party gas) are expected to range from 1.7 to 1.8 Bcfd for the last six months of 2003. Gas marketing margins are expected to average approximately $0.015 per Mcf. Total NGL sales volumes marketed, including plant and third party volumes, are expected to average 1,750 MGald. NGL marketing margins are expected to average approximately $0.006 per gallon. These assumptions include the impact of mark-to-market accounting for the Company's marketing activities.

Other expenses.

General and administrative expenses are expected to be $18.5 million, depreciation, depletion and amortization expenses are expected to be $41.3 million and interest expenses are estimated to be $12.9 million for the second half of 2003.

Earnings conference call.

Western invites you to participate in its second quarter 2003 earnings conference call today at 9:30 a.m. (Mountain Time) by dialing (719) 457-2625. Please dial in five to ten minutes before the start of the call. A replay of the conference call will be available through midnight, August 18, 2003 by dialing (719) 457-0820 (passcode 523469). The live conference call may also be accessed on the Internet by logging onto Western's Web site at www.westerngas.com .

Select Financial/Investor

Information followed by the Current News option on the menu. Log on at least ten minutes prior to the start of the call to register, download and install any necessary audio software. An audio replay will be available on the web site through August 31, 2003.

Company description.

Western is an independent natural gas explorer, producer, gatherer, processor, transporter and energy marketer. The Company's producing properties are based in Wyoming and Colorado, including the developing Powder River Basin coal bed methane play, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas-producing basins in the Rocky Mountain, Mid-Continent and West Texas regions of the United States, providing a broad range of services to its customers from the wellhead to the sales delivery point. For additional Company information, visit Western's Web site at www.westerngas.com .

This press release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 regarding commodity prices, expenses, sales and operating margins, sales volumes, drilling activity and production volumes for the remainder of 2003. Although the Company believes that its expectations are based on reasonable assumptions, Western can give no assurances that its goals will be achieved. These statements are subject to a number of risks and uncertainties, which may cause actual results to differ materially. These risks and uncertainties include, among other things, changes in natural gas prices, government regulation or action, litigation, environmental risk, weather, rig availability, transportation capacity and other factors as discussed in the Company's 10-K and 10-Q Reports and other filings with the Securities and Exchange Commission.

Announces Second Quarter 2003 Results Conference Call

DENVER, August 5, 2003 -- Western Gas Resources, Inc. (NYSE:WGR) will release its second quarter 2003 earnings results at 7:00 a.m. Eastern time on Tuesday, August 12, 2003. Western invites you to listen to its first quarter conference call via telephone or live Webcast on Tuesday, August 12, 2003 at 11:30 a.m. Eastern, 9:30 a.m. Mountain time. To listen via telephone, dial (719) 457-2625 five to ten minutes before the start of the call. A replay will be available through midnight, August 18, by dialing (719) 457-0820, pass code 523469.

The live conference call may also be accessed on the Internet by logging onto Western's Web site at www.westerngas.com . Select Financial/Investor Information, then the Current News option on the menu. Log on at least ten minutes prior to the start of the call to register, download and install any necessary audio software. An audio replay of the call will also be available on the Web site through August 31, 2003.

Company Description.

Western is an independent natural gas explorer, producer, gatherer, processor, transporter and energy marketer providing a broad range of services to its customers from the wellhead to the sales delivery point. The Company's producing properties are located primarily in Wyoming, including the developing Powder River Basin coal bed methane play, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas-producing basins in the Rocky Mountain, Mid- Continent and West Texas regions of the United States. For additional Company information, visit Western's Web site at www.westerngas.com .

Declares Common and Preferred Dividends

DENVER, June 2, 2003 -- Western Gas Resources, Inc. (NYSE:WGR) announced today that its Board of Directors has declared a quarterly dividend of $0.05 per share of common stock, payable to stockholders of record on June 30, 2003.

In addition, the Board declared quarterly dividends of $0.65625 per share on the $2.625 Cumulative Convertible Preferred Stock (NYSE:WGR pfA). Preferred dividends are payable to stockholders of record on June 30, 2003. The dividends for all securities will be paid on August 14, 2003.

Announces First Quarter 2003 Results

DENVER, May 8, 2003 -- Western Gas Resources, Inc. ("Western") (NYSE:WGR) today announced net income of $23.4 million or $0.63 per share of common stock for the quarter ended March 31, 2003. This compares to net income of $8.0 million or $0.18 per share of common stock for the same period in 2002. Earnings per share are presented on a fully-diluted basis for both periods and are after giving effect to preferred stock dividends.

The Company also reported EBITDA (earnings before interest, taxes, depreciation and amortization and the cumulative effect of a change in accounting principle) for the first quarter of 2003 of $72.8 million and cash flow before working capital adjustments of $72.1 million. Revenues totaled $888.1 million.

Cumulative Effect of a Change in Accounting Principle. In June 2001, the Financial Accounting Standards Board, issued SFAS No. 143, "Accounting for Asset Retirement Obligations" ("SFAS No. 143"). SFAS No. 143 establishes accounting standards for recognition and measurement of a liability for an asset retirement obligation and the associated asset retirement cost. The Company adopted SFAS No. 143 on January 1, 2003. The adoption of SFAS No. 143 resulted in a one-time after-tax charge to earnings of $6.7 million or $0.18 per share of common stock on a fully diluted basis in the first quarter of 2003 for the cumulative effect of the change in accounting principle. Net income before the cumulative effect of the change in accounting principle was $30.1 million, or $0.81 per share of common stock on a fully diluted basis for the first quarter of 2003.

Volumes and prices. Natural gas production and total gas sales volumes marketed in the first quarter of 2003 increased sharply compared to the same period a year ago.

Natural gas equity production increased 21 percent to 13.2 billion cubic feet equivalent ("Bcfe") compared to the first quarter of 2002 and averaged 147 million cubic feet equivalent per day ("MMcfed"). All of the Company's production was achieved in the Powder River Basin coal bed methane ("CBM") play and the Greater Green River Basin.

Total gas sales volumes marketed, including equity gas production, gas purchased under contracts at the Company's plants and gas purchased from third parties for resale, averaged 1.6 billion cubic feet per day ("Bcfd") in the first quarter of 2003. This represents a decrease of 35 percent as compared to 2002 due to a reduction of third-party gas sales. Average gas prices for marketed volumes increased 120 percent to $5.44 per Mcf compared to $2.47 per Mcf for the same period in 2002.

Total natural gas liquids ("NGLs") sales volumes marketed averaged 1.7 million gallons per day in the first quarter of 2003. This represents a decrease of 15 percent as compared to the same period in 2002, which was largely the result of the Company's sale of its Toca facility in September 2002. Average NGL prices for marketed volumes increased 68 percent to $0.62 per gallon compared to $0.37 per gallon in the same period in 2002.

Operations. The Company's fully integrated operations include exploration, production, gathering, processing, transportation and marketing of natural gas and NGLs.

Exploration and production realized operating profit (EBITDA before general and administrative expenses) of $33.3 million for the first quarter of 2003 compared to $14.9 million for the first quarter of 2002. This increase was primarily due to substantially higher natural gas prices, significant volume growth from the CBM development and the benefit of firm transportation capacity, which allows the Company to sell gas to more favorable Mid-Continent markets.

Gathering and processing operations realized operating profit of $31.8 million for the first quarter of 2003 compared to $18.8 million for the first quarter of 2002. The increase is primarily due to higher commodity prices and increased gathering volumes from equity and third-party CBM production and the acquisition of several gathering systems in January 2003.

Gas transportation realized operating profit of $4.0 million for the first quarter of 2003 compared to $4.3 million for the first quarter of 2002. The transportation segment includes the results from the MIGC and MGTC pipelines in the Powder River Basin.

Marketing realized operating profit of $15.0 million for the first quarter of 2003 compared to $8.0 million for the same period in 2002. The results for the marketing business benefited significantly from transactions utilizing the Company's firm transportation and storage capacity.

Hedging. The Company's equity hedging positions decreased operating profit by $15.5 million for the first quarter of 2003, including losses of $2.8 million from the discontinuance of certain equity hedges and increased operating profit by $9.5 million in the first quarter of 2002.

Powder River Basin CBM. Net CBM production volumes increased 17 percent to 11.2 Bcf in the first quarter of 2003 as compared to the same period in 2002 and averaged 124 MMcfd. The Company, with its partner, continues to be the largest producer of methane in the basin. Western currently plans to participate in over 800 wells in the Powder River Basin in 2003, of which 101 wells were drilled in the first quarter. Completion of the Company's 2003 drilling program will be subject to obtaining the necessary drilling and water discharge permits in a timely fashion.

On April 30, 2003, gross CBM production from wells in which the Company has an interest in the Big George coal was approximately 30 MMcfd from one development and two pilot areas. In total, approximately 440 Big George wells have been drilled through March 31, 2003. The Company expects to drill approximately 400 gross wells in various pilots in the Big George coal during 2003. Industry, including Western, was producing over 80 MMcfd in February 2003 from the Big George in eight pilots over a 40-mile area.

Western averaged 416 MMcfd of CBM gathering volumes, including third-party gas, during the first quarter of 2003. This represents a 20 percent increase compared to the same period in 2002. Of that volume, approximately 128 MMcfd was transported through the Company's MIGC pipeline. The Company remains the largest gatherer and transporter of CBM in the Powder River Basin.

The Bureau of Land Management's Buffalo, Wyoming field office issued the final Record of Decision ("ROD") for the Powder River Basin Oil and Gas Environmental Impact Statement ("EIS") on April 30, 2003. The Company is currently in the process of reviewing the ROD to determine its impact on its operations in this area. Based on Western's preliminary review of the final EIS, water discharge and air quality guidelines are, for the most part consistent with recent industry practices. More planning will be required for permitting related to certain plant and animal species and cultural surveys and noxious weed mitigation.

Greater Green River Basin. Production from the Pinedale Anticline and Jonah Field development areas of southwest Wyoming and the Sand Wash Basin development area in northwest Colorado increased 50 percent to 2.0 Bcfe net in the first quarter of 2003 compared to the same period of 2002. In 2003, Western plans to participate in approximately 60 wells on the Pinedale Anticline, of which five were drilled in the first quarter, and six wells in the Sand Wash Basin, of which one was drilled in the first quarter. The Company has exposure to participate in up to 500 gross (55 net) potential drilling locations on the Pinedale Anticline based on 40-acre spacing in this area.

Balance sheet. At March 31, 2003, Western had total assets of $1.5 billion, total debt outstanding of $309.8 million and a debt to capitalization ratio of 38 percent.

CEO comments. Peter Dea, Chief Executive Officer and President, commented, "The first quarter of 2003 was extremely profitable, particularly as a result of strong commodity prices, continued growth in production and gathering volumes and benefits of our firm transportation position to the Mid- Continent markets. The issuance of the final Record of Decision for drilling on federal lands in the Powder River Basin is a tremendous step towards the full develop of this play and we will begin to realize its enormous potential during the next several years."

Revisions to operational performance guidance for the remainder of 2003. The Company provided operational performance guidelines for 2003 in a press release dated February 20, 2003. The following information represents modifications to the previous guidance.

In connection with the adoption of SFAS No. 143, the Company completed a review of its operating assets and reevaluated the operating life and salvage values of the associated equipment. As a result, depreciation, depletion and amortization was $2.5 million less than our original guidance. The Company expects the decreased rate of depreciation, depletion and amortization to continue in future quarters and will total approximately $57.4 million for the remaining nine months of 2003 as follows: 53 percent for gathering and processing, 39 percent for exploration and production, one percent for transportation and seven percent for marketing and corporate. Selling and administrative expense for the remaining nine months of 2003 is expected to be approximately $26.5 million. Interest expense is expected to be approximately $20 million for the remainder of 2003.

Western's equity hedges and the associated basis positions for its equity volumes of natural gas and NGLs are outlined under Table A. For the remainder of 2003, Western has hedged approximately 51 percent of its projected equity natural gas volumes and approximately 77 percent of its estimated equity volumes of crude and NGLs. In order to determine the hedged gas price to the particular operating region, adjust the NYMEX -- equivalent price for the basis differential. The NYMEX or Mt. Belvieu -- equivalent prices for NGLs do not include the cost of the hedges of approximately $698,000. There is no associated cost for the natural gas hedges. The natural gas equity hedges associated with the Permian differential and all NGL equity hedges are related to the gathering and processing business. The remaining natural gas hedges are related to the exploration and production business.

Earnings conference call. Western invites you to participate in its first quarter 2003 earnings conference call today at 8:00 AM Mountain Time by dialing (913) 981-5532. A replay of the conference call will be available through midnight, May 15, by dialing (719) 457-0820 (passcode 667947). An audio playback will also be available on Western's Web site after 10:00 AM Mountain Time today at www.westerngas.com. This call can be accessed by selecting Financial/Investor Information then the Current News option on the menu. The audio replay will be available on the web site through May 31, 2003.

Company Description. Western is an independent natural gas explorer, producer, gatherer, processor, transporter and energy marketer providing a broad range of services to its customers from the wellhead to the sales delivery point. The Company's producing properties are located primarily in Wyoming, including the developing Powder River Basin coal bed methane play, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas-producing basins in the Rocky Mountain, Mid- Continent and West Texas regions of the United States.

This press release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 regarding future drilling activity, capital expenditures and production and sales volumes. Although the Company believes that its expectations are based on reasonable assumptions, Western can give no assurances that its goals will be achieved. These statements are subject to a number of risks and uncertainties, which may cause actual results to differ materially. These risks and uncertainties include, among other things, changes in natural gas and NGL prices, government regulation or action, geological risk, environmental risk, weather, rig availability, transportation capacity, the ability of Western's partners to fund the necessary capital expenditures and the progress of ongoing litigation and related disputes with its co-developer in the Powder River Basin of Wyoming, and other factors as discussed in the Company's 10-K and 10-Q Reports and other filings with the Securities and Exchange Commission.

Announces First Quarter 2003 Results Conference Call

DENVER, May 7, 2003 -- Western Gas Resources, Inc. (NYSE: WGR) will release its first quarter 2003 earnings results at 7:00 a.m. Eastern time on Thursday, May 8, 2003. Western invites you to listen to its first quarter conference call via telephone or live Webcast on Thursday, May 8, 2003 at 10:00 a.m. Eastern, 8:00 a.m. Mountain time.

To listen via telephone, dial (913) 981-5532 five to ten minutes before the start of the call. A replay will be available through midnight, May 15, by dialing (719) 457-0820, pass code 667947.

The live conference call may also be accessed on the Internet by logging onto Western's Web site at www.westerngas.com. Select Financial/Investor Information, then the Current News option on the menu. Log on at least ten minutes prior to the start of the call to register, download and install any necessary audio software. An audio replay of the call will also be available on the Web site through May 31, 2003.

Company Description. Western is an independent natural gas explorer, producer, gatherer, processor, transporter and energy marketer providing a broad range of services to its customers from the wellhead to the sales delivery point. The Company's producing properties are located primarily in Wyoming, including the developing Powder River Basin coal bed methane play, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas-producing basins in the Rocky Mountain, Mid- Continent and West Texas regions of the United States.

Announces First Quarter 2003 Results Conference Call

DENVER, May 1, 2003 -- Western Gas Resources, Inc. (NYSE: WGR) will release its first quarter 2003 earnings results at 7:00 a.m. Eastern time on Thursday, May 8, 2003. Western invites you to listen to its first quarter conference call via telephone or live Webcast on Thursday, May 8, 2003 at 10:00 a.m. Eastern, 8:00 a.m. Mountain time.

To listen via telephone, dial (913) 981-5532 five to ten minutes before the start of the call. A replay will be available through midnight, May 15, by dialing (719) 457-0820, pass code 667947.

The live conference call may also be accessed on the Internet by logging onto Western's Web site at www.westerngas.com. Select Financial/Investor Information, then the Current News option on the menu. Log on at least ten minutes prior to the start of the call to register, download and install any necessary audio software. An audio replay of the call will also be available on the Web site through May 31, 2003.

Company Description. Western is an independent natural gas explorer, producer, gatherer, processor, transporter and energy marketer providing a broad range of services to its customers from the wellhead to the sales delivery point. The Company's producing properties are located primarily in Wyoming, including the developing Powder River Basin coal bed methane play, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas-producing basins in the Rocky Mountain, Mid- Continent and West Texas regions of the United States.

Declares Common and Preferred Dividends

DENVER, March 4, 2003 -- Western Gas Resources, Inc. (NYSE:WGR) announced today that its Board of Directors has declared a quarterly dividend of $0.05 per share of common stock, payable to stockholders of record on March 28, 2003.

In addition, the Board declared quarterly dividends $0.65625 per share on the $2.625 Cumulative Convertible Preferred Stock (NYSE:WGR pfA). Preferred dividends are payable to stockholders of record on March 28, 2003. The dividends for all securities will be paid on May 14, 2003.

Provides Operational Projections for 2003

DENVER, February 20, 2003 -- Western Gas Resources, Inc. ("Western" or the "Company") (NYSE:WGR) today provided projections related to its expected operational performance in 2003. These estimates have been prepared based on the Company's current expectations for natural gas and natural gas liquids (NGL) volumes, commodity pricing differentials, expenses, debt balances and other items resulting from the Company's 2003 capital budget. These projections are forward-looking and subject to various factors, including but not limited to those factors outlined in this release. These estimates do not include possible acquisitions or divestitures or other unforeseen events that may occur after this release.

Modeling Assumptions Relating to the Company's Upstream Operations:
Production. Total net natural gas production in 2003 is expected to increase to an average of approximately 146 million cubic feet of gas equivalent per day (MMcfed) or approximately 10 percent from 2002 levels with the majority of the increase to occur in the second half of the year. Natural gas production from the Powder River Basin coal bed methane ("CBM") development is expected to average approximately 126 MMcfd net in 2003. Natural gas production volumes from activities in the Greater Green River Basin are expected to average approximately 20 MMcfed net in 2003.

In December 2002, net CBM production averaged 126 MMcfd, excluding prior period revisions for third party operated production, but declined during January 2003 to an average of 122 MMcfd. Average net production during the first two quarters is expected to be similar to December 2002. We expect net production increases over the two remaining quarters with an exit rate of 132 MMcfd. Several factors account for the recent hiatus in otherwise steep production growth, including operational and permitting delays, Hoe Creek underperformance and the timing of the EIS.

Approximately 70 percent of the Company's gas production is sold primarily into the Mid-Continent market and the remainder is sold in the Rocky Mountain area. The Company expects to have virtually no net exposure to Rockies prices in 2003 for its equity production due to the Company's transportation contracts, equity hedges and derivative contracts for regional basis differences. The production business will realize the effect of the Company's equity natural gas hedging positions for 2003, as detailed in Table A, except those related to the Permian Basin. However, since the results of equity hedges is reported separately, gas price realizations must be adjusted for the appropriate regional price differences from the Henry Hub Index and further reduced by approximately 15 percent for fuel and shrink.

In addition, in order to deliver its gas from the wellhead to these markets, the Company incurs gathering, compression and transportation expenses of approximately $0.65 per Mcfe. These costs must be deducted from the gas price realized to arrive at a wellhead gas price. Additional costs to be deducted from the wellhead price are production taxes, lease operating expenses (LOE) and other miscellaneous expenses. Production taxes are expected to average approximately 13 percent of wellhead prices. LOE expenses, which include production overhead, are expected to be approximately $0.46 per Mcfe. Other items, including delay rentals, impairment and unsuccessful well expense (expensed due to successful efforts accounting) are expected to average $0.08 per Mcfe.

Modeling Assumptions Relating to the Company's Midstream Operations:
Gathering, Processing and Treating. Gas throughput volumes at the Company's facilities are expected to average approximately 1.3 Bcfd. Natural gas plant sales are expected to average approximately 560 MMcfd. Price realizations on these sales are dependent upon current basis differentials to the basins in which the Company operates and are generally below the NYMEX Henry Hub Index. The Company estimates that approximately 50 percent of plant gas is sold in the Rocky Mountain area and approximately 25 percent is sold in each of the Mid-Continent and Permian Basin areas. NGL plant sales are expected to be approximately 1,500 MGald. Composite NGL price realizations have historically been about 70 to 75 percent of NYMEX crude oil prices adjusted by approximately $0.04 per gallon for the cost of transportation and fractionation. However, the crude oil to NGL relationship can vary dramatically for short periods based on various market factors.

The revenues from the Company's gathering, processing and treating facilities are derived from percent of proceeds, keep-whole and fee-based contracts. Gross operating margin (gross revenues less product purchase expenses) is dependent on commodity prices and is expected to average approximately $0.40 per Mcf of facility throughput. This estimate is based on an assumption of $4.00 per MMbtu for natural gas and $25.00 per barrel for crude oil (NYMEX-equivalent prices). Assuming higher commodity prices of $5.00 per MMbtu and $28.00 per barrel, gross operating margin would be estimated to be approximately $0.43 per Mcf of throughput. Assuming lower commodity prices of $3.00 per MMbtu and $20.00 per barrel, gross operating margin would be estimated to be approximately $0.35 per Mcf of throughput. The gross operating margins exclude the effect of equity hedges related to the gathering and processing business, which are currently in place for 2003. These hedging positions include the equity natural gas hedges related to the Permian Basin and all oil and NGL equity hedges, as detailed in Table A. Of the average gross operating margin, approximately $0.22 per Mcf is comprised of fee revenues and is not subject to changes in commodity prices.

Plant operating expenses are projected to be approximately $0.18 to $0.19 per Mcf of throughput volumes and should be deducted from the gross operating margin to arrive at a net operating margin per Mcf of throughput volumes. The cost of gathering gas from the wellhead to the plant is included in plant operating expense rather than product purchase expense beginning in 2003.

In addition to the above guidance information, the gathering and processing segment will realize income from its equity investments in the Fort Union Gas Gathering, L.L.C. and Rendezvous Gas Services, L.L.C. joint ventures, which should approximate $8 to $9 million for 2003. This amount will be included under income from equity investments on the income statement.

Transportation. Gas transportation and sales volumes are expected to be approximately 180 MMcfd and revenues are projected to be approximately $23 million for 2003. Operating income, after deducting pipeline operating expenses and product purchase expenses, is expected to be approximately $13 million.

Marketing. Marketed natural gas volumes (which include equity and third-party gas) are expected to be approximately 2.0 Bcfd. Gas marketing margins are projected to be approximately $0.015 to $0.02 per Mcf. Volatility of commodity prices and changes in regional price differences (basis) between market areas could affect the gas marketing margin either positively or negatively. Marketed NGL volumes, including plant and third-party NGLs, are expected to be approximately 2,000 MGald. NGL marketing margins and fees are projected to be approximately $0.004 per gallon. These margin assumptions include the impact of mark-to-market accounting for the Company's marketing activities, which is reflected on the income statement under non-cash change in fair value of derivatives.

Other Modeling Assumptions:
Other Revenues. Miscellaneous income in the corporate segment, including corporate interest income, is expected to approximate $2.0 million in 2003. These revenues will be included in other, net on the income statement.

Other Expenses. General and administrative expenses are projected to be approximately $37 million for 2003. These expenses are estimated to be related to the segments as follows: 31 percent for exploration and production, 41 percent for gathering and processing, 8 percent for transportation and 20 percent for marketing. Depreciation, depletion and amortization expense is expected to approximate $85.4 million as follows: $28.1 million for exploration and production, $51.0 million for gathering and processing, $1.1 million for transportation, $0.2 million for marketing and $5.0 million for corporate. Interest expense is projected to be approximately $29.3 million for 2003.

Adoption of SFAS-143 -- Accounting for Asset Retirement Obligations. Income for 2003 will be reduced by a one-time entry in the first quarter for the cumulative effect of a change in accounting principle due to the adoption of SFAS No. 143 -- "Accounting for Asset Retirement Obligations." This accounting principle requires the accrual for estimated asset retirement obligations. The amount of the entry is yet to be determined.

Income Tax. The corporate income tax rate is projected to be 37 percent. Approximately 70 to 75 percent of current year income taxes are expected to be deferred.

Common shares outstanding and preferred dividends. As of December 31, 2002, there were 33,063,611 common shares outstanding. Preferred dividends, assuming preferred shares outstanding at December 31, 2002 remain outstanding for all of 2003, would be $7.2 million in 2003.

Product Prices. Prices for natural gas and NGLs are subject to fluctuations in response to changes in supply, demand, market uncertainty and a variety of additional factors that are beyond the Company's control. To an extent the Company can manage this price risk through hedges of its equity production and as a result, from time to time, the Company enters into hedges. Table A outlines the Company's equity hedge positions currently outstanding. For 2003, Western has hedged approximately 53 percent of its projected equity natural gas volumes and approximately 78 percent of its estimated equity volumes of crude, condensate and NGLs. The Company cannot predict the price that it will receive for its unhedged products or for products beyond the term of the hedges.

Table A -- Outstanding Equity Hedges and the Associated Basis for 2003. In order to determine the hedged gas price to the particular operating region, adjust the NYMEX -- equivalent price for the basis differential. The NYMEX or Mt. Belvieu -- equivalent prices for NGLs do not include the cost of the hedges of approximately $930,000. There is no associated cost for the natural gas hedges. The natural gas equity hedges associated with the Permian differential and all NGL equity hedges are related to the gathering and processing business. The remaining natural gas hedges are related to the exploration and production business.

Updates. This document will be maintained on Western's web site and is included in a Form 8-K filed with the SEC and the NYSE on February 20, 2003. Although the Company is not undertaking any duty or requirement to update the information contained in this report, if the Company decides to provide to any third party updated information that the Company believes may be material, the Company first will include that information in a Form 8-K filed with the SEC and the NYSE. That information will then be posted on Western's web site. Revisions that may be material could include the addition of information for a new financial reporting period or changes of five percent or more in the Company's production quantities, earnings or cash flow estimates, exclusive of commodity price changes. Minor revisions or updates to this information that the Company does not believe are material may be made directly to the document maintained on the web site without announcement.

Company Description. Western is an independent natural gas explorer, producer, gatherer, processor, transporter and energy marketer providing a broad range of services to its customers from the wellhead to the sales delivery point. The Company's producing properties are located primarily in Wyoming, including the developing Powder River Basin coal bed methane play, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas-producing basins in the Rocky Mountain, Mid- Continent and West Texas regions of the United States.

This press release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 regarding natural gas and NGL production and sales volumes, commodity pricing and locational differentials, and other revenues and expenses. Although the Company believes that its expectations are based on reasonable assumptions, Western can give no assurances that its projections are accurate. These statements are subject to a number of risks and uncertainties, which may cause actual results to differ materially. These risks and uncertainties include, among other things, changes in natural gas and NGL prices, government regulation or action, geological risk, environmental risk, weather, rig availability, transportation capacity, the ability of Western's partners to fund the necessary capital expenditures and the progress of ongoing litigation and related disputes with its co-developer in the Powder River Basin of Wyoming, and other factors as discussed in the Company's 10-K and 10-Q Reports and other filings with the Securities and Exchange Commission.

Announces 2002 Results

DENVER, February 20, 2003 -- Western Gas Resources, Inc. (NYSE:WGR) today announced net income of $50.6 million, or $1.23 per share of common stock on a fully diluted basis for the year ended December 31, 2002. This compares to net income of $95.6 million for the year ended December 31, 2001, or $2.48 per share of common stock on a fully diluted basis.

The Company also reported EBITDA (earnings before interest, taxes, depreciation and amortization) for 2002 of $184.7 million from revenues of $2.5 billion and cash flow before working capital adjustments of $161.1 million.

For the fourth quarter of 2002, the Company reported net income of $15.4 million, or $.37 per share of common stock on a fully diluted basis. This compares to net income of $10.8 million for the fourth quarter of 2001, or earnings of $.22 per share of common stock on a fully diluted basis. Earnings per share for both annual and quarterly periods give effect to preferred stock dividends.

For the fourth quarter of 2002, EBITDA was $53.4 million from revenues of $645.6 million and cash flow before working capital adjustments was $53.2 million.

Volumes and Prices. Total gas marketed, including equity gas production, gas purchased under contracts at its plants and gas purchased from third-parties for resale, averaged 2.0 billion cubic feet per day ("Bcfd") for the year ended December 31, 2002 and 1.7 Bcfd in the fourth quarter of 2002. Gas volumes marketed increased nominally in 2002 compared to 2001, but were lower in the fourth quarter of 2002 by 25 percent compared to the same period in 2001 due to a reduction in sales of third-party gas. Average gas prices for marketed volumes decreased 26 percent to $2.92 per thousand cubic feet ("Mcf") in 2002 and increased 47 percent to $3.64 per Mcf in the fourth quarter of 2002, as compared to the same periods in 2001.

Natural gas equity production in 2002 increased 34 percent to 48.9 Bcfe net compared to the same period in 2001. Production in 2002 averaged 134 million cubic feet equivalent of gas per day ("MMcfed").

Total natural gas liquids ("NGLs") marketed, including NGLs produced at the company's plants and NGLs purchased from third-parties for resale, averaged 2.0 million gallons per day ("MMGald") for the year ended December 31, 2002 and 1.8 MMGald in the fourth quarter of 2002. NGL volumes marketed decreased by 14 percent in 2002 and by 28 percent in the fourth quarter compared to the comparable periods in 2001 due to a reduction of NGLs purchased from third-parties for resale. Average NGL prices for marketed volumes decreased 14 percent to $0.42 per gallon in 2002 and increased 29 percent to $0.49 per gallon in the fourth quarter of 2002, as compared to the same periods in 2001.

Operations. The Company's fully integrated operations include exploration, production, gathering, processing, transporting and marketing of natural gas and NGLs.

Exploration and production realized operating profit (EBITDA before general and administrative expenses) of $73.7 million for 2002 compared to operating profit of $64.4 million in 2001. This increase was primarily due to significant volume growth from the Powder River Basin coal bed methane ("CBM") development and the benefit of firm transportation capacity, which allows the Company to sell gas to more favorable Mid-Continent markets.

Gathering and processing operations realized operating profit of $92.9 million for 2002 compared to operating profit of $135.8 million in 2001. The decrease in operating profit is primarily due to a reduction in product prices as gas throughput volumes were 1.2 Bcfd in 2002, comparable to 2001. An increase in gas throughput volumes in 2002 from growing gathering volumes of equity and third party CBM production was partially offset by the sale of the Toca facility in September 2002.

Gas transportation realized operating profit of $15.7 million for 2002 compared to operating profit of $16.5 million in 2001. Revenues, primarily transportation fees, in 2002 totaled $24.8 million while product purchase costs and plant operating expenses totaled $9.1 million. Gas transportation volumes on the MIGC and MGTC pipelines averaged 192 MMcfd in 2002.

Marketing realized operating profit of $37.5 million for 2002 compared to operating profit of $50.0 million in 2001. The results for the marketing business for both periods benefited from transactions utilizing the Company's firm transportation capacity and storage positions.

Hedging. Overall, in 2002, the Company's equity-hedging positions increased operating income by $20.2 million for the full year and $1.0 million for the fourth quarter. In 2001, equity hedging positions increased operating income by $11.6 million for the full year and $16.8 million for the fourth quarter.

Powder River Basin CBM. Production from the Company's jointly-owned Powder River Basin CBM development increased 33 percent in 2002 to 43.4 Bcf net. Fourth quarter volume totaled 12.3 Bcf net, including the addition of 628 MMcf for the prior period revision of third-party operated production. The Company, with its partner, continues to be the largest producer of methane in the basin. The Company participated in the drilling of 909 gross wells during 2002 in this basin.

Gas production continues to increase from the Company's Big George coal development in the Powder River Basin. As of February 17, 2002, gross production from the Company's All-Night Creek development area had increased to approximately 24 MMcfd from 88 producing wells. An additional 61 wells are in various stages of dewatering. Gas production from two additional Big George pilots has increased to a combined 3.0 MMcfd. The Company has drilled approximately 425 gross Big George CBM wells as of year-end 2002. An estimated nine industry-wide development and pilot projects in the Big George coal are now producing approximately 68 MMcfd and continue to validate the potential of the Big George coals.

The Company is the largest gatherer and transporter of methane gas in the Powder River Basin. In 2002, Western gathered 381 MMcfd of production, including third-party gas. This represents a 33 percent increase compared to 2001. Approximately 135 MMcfd of that volume was transported through the Company's MIGC pipeline.

Green River Basin. Western participated in 26 gross wells in the Pinedale Anticline during 2002 and drilled two successful wells on its acreage in the Sand Wash Basin development of northwest Colorado. Net production from these areas increased 47 percent to 5.4 Bcfe in 2002 and averaged 20 MMcfed net during the fourth quarter of 2002. Operators of wells on the Pinedale Anticline in which the Company participated during 2002 were 100 percent successful. Western plans to participate in approximately 32 wells on the Pinedale Anticline and 6 wells in the Sand Wash Basin in 2003. The Company has a large inventory of undrilled locations on the Pinedale Anticline resulting from 40-acre down spacing in this area.

Rendezvous Gas Services, L.L.C. ("Rendezvous"), a venture in which Western owns 50 percent, expanded its gathering and processing capabilities in the area during 2002. Rendezvous completed two expansion phases, which currently extend to the Jonah field area and provide 275 MMcfd of total gathering capacity. The Company expects to construct an additional 24-mile gathering line expansion northward on the Pinedale Anticline in 2003.

Balance Sheet. At December 31, 2002, Western had total assets of $1.3 billion, cash and cash equivalents in short-term investments of $7.3 million, working capital of $ 37.5 million, total debt outstanding of $359.9 million and a debt to capitalization ratio of 42.7 percent.

Capital Expenditures for 2003. The Company anticipates capital expenditures of approximately $182.3 million in 2003, primarily for growth and expansion projects in its Rocky Mountain upstream and midstream operations. The budget includes the previously announced acquisition of El Paso gathering assets in Wyoming. The 2003 budget represents a 30 percent increase from the $140.6 million expended in 2002. The Rocky Mountain region will utilize 85 percent or $155.2 million of the 2003 budget. Western plans to invest approximately $68.0 million, or 37 percent of its total program, in the Powder River Basin CBM development. Approximately $55.2 million will be spent on drilling 845 gross wells and for lease acquisitions and $12.8 million for gathering and compression. Approximately half of the Powder River CBM budget is dependent on the anticipated first quarter 2003 Record of Decision for the Powder River Basin Environmental Impact Statement (EIS) and the timeliness of subsequent drilling and water discharge permits.

The Greater Green River Basin is another significant area for capital investment. Western expects to invest approximately $82.3 million, or 45 percent of the total program, in this area. The Company will spend approximately $18.4 million to participate in 38 gross wells and 3 workovers, most of which are in the rapidly developing Pinedale Anticline area, $26.9 million to expand gathering and compression services and $37.0 million for the previously announced El Paso acquisition. Exclusive of the Rocky Mountain region, the remaining $27.1 million of Western's 2003 capital spending program is expected to be spent as follows: $15.0 million for well connections, expansions, maintenance and upgrade projects in its other operating areas, $7.8 million for capitalized interest and overhead and $4.3 million for administrative expenditures.

CEO Comments. Peter Dea, Chief Executive Officer and President, stated, "The employees of Western Gas Resources are proud to deliver another strong year of financial and operational performance to our shareholders. Our solid returns and net income in 2002 reflect double-digit volume growth, cost-efficient midstream operations and our systematic price management strategy utilizing hedges and firm transportation. The balanced portfolio that has served our shareholders well these last three years, provides the foundation and catalyst for future shareholder value. The success of 2002 again confirms the quality of our large drilling inventory of low-risk, low-cost, long-lived reserves whose development is internally funded from high margin gathering, processing and marketing business segments."

Earnings Conference Call. Western invites you to participate in its fourth quarter and year-end 2002 earnings conference call today at 8:00 a.m. (Mountain Time) by dialing (719) 457-2665. Please dial in five to ten minutes before the start of the call. A replay of the conference call will be available after 10:00 a.m. (Mountain Time) today for one week following the call by dialing (719) 457-0820 (passcode 584702). The live conference call may also be accessed on the Internet by logging onto Western's Web site at www.westerngas.com . Select Financial/Investor Information followed by the Current News option on the menu. Log on at least ten minutes prior to the start of the call to register, download and install any necessary audio software. An audio replay will be available on the Web site through March 7, 2003.

Company Description. Western is an independent natural gas explorer, producer, gatherer, processor, transporter and energy marketer providing a broad range of services to its customers from the wellhead to the sales delivery point. The Company's producing properties are located primarily in Wyoming, including the developing Powder River Basin coal bed methane play, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas-producing basins in the Rocky Mountain, Mid-Continent and West Texas regions of the United States.

This press release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 regarding future drilling activity, reserves, capital expenditures and production and sales volumes. Although the Company believes that its expectations are based on reasonable assumptions, Western can give no assurances that its goals will be achieved. These statements are subject to a number of risks and uncertainties, which may cause actual results to differ materially. These risks and uncertainties include, among other things, changes in natural gas and NGL prices, government regulation or action, geological risk, environmental risk, weather, rig availability, transportation capacity, the ability of Western's partners to fund the necessary capital expenditures and the progress of ongoing litigation and related disputes with its co-developer in the Powder River Basin of Wyoming, and other factors as discussed in the Company's 10-K and 10-Q Reports and other filings with the Securities and Exchange Commission.

Announces Fourth Quarter and Year End 2002 Results Conference Call

DENVER, February 13, 2003 -- Western Gas Resources, Inc. (NYSE:WGR) will release its fourth quarter and year end 2002 earnings results at approximately 7:00 a.m. Eastern time on Thursday, February 20, 2003. Western invites you to listen to its fourth quarter and year end conference call via telephone or live Webcast on Thursday, February 20, 2003 at 10:00 a.m. Eastern, 8:00 a.m. Mountain time.

To listen via telephone, dial (719) 457-2665 five to ten minutes before the start of the call. A replay will be available through midnight, February 27th, by dialing (719) 457-0820, pass code 584702.

The live conference call may also be accessed on the Internet by logging onto Western's Web site at www.westerngas.com. Select Financial/Investor Information, then the Current News option on the menu. Log on at least ten minutes prior to the start of the call to register, download and install any necessary audio software. An audio replay of the call will also be available on the Web site through March 20, 2003.

Western is an independent natural gas producer, gatherer, processor, transporter and energy marketer providing a broad range of services to its customers from the wellhead to the sales delivery point. The Company's producing properties are based primarily in Wyoming, including the Powder River Basin coal bed methane development, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas- producing basins in the Rocky Mountain, Mid-Continent and West Texas regions of the United States.

Announces 2002 Reserve Additions and Production

DENVER, February 7, 2003 -- Western Gas Resources, Inc. ("Western") (NYSE:WGR) today announced that proved reserves at December 31, 2002 increased 24 percent to 588 billion cubic feet of gas equivalents ("Bcfe"). Additions net of revisions totaled 162 Bcfe and 114 Bcfe net of production. The Company replaced 334 percent of 2002 production of 48.7 Bcfe and net production increased 34 percent in 2002. The drill bit provided all of the reserve and production growth as Rocky Mountain natural gas reserves represent 99 percent of the reserve base. The Company drilled 937 gross wells in 2002 with a 98 percent success rate.

Finding and development costs were approximately $0.43 per Mcfe based on estimated capital expenditures of $70 million for exploration and production operations in 2002. At year-end, the pretax present value of the reserves discounted at 10 percent was $536.6 million, based on year-end NYMEX prices of $4.74 per Mcf of gas and $29.83 per barrel of oil, adjusted for regional pricing differentials and considering existing hedging positions.

Powder River Basin Coal Bed Methane. As of December 31, 2002, the Company controlled approximately 515,000 net acres in the Powder River Basin coal bed methane (CBM) development. Net reserve additions in the Powder River CBM play totaled 64 Bcfe. During 2002, 909 gross CBM wells were drilled with a success rate of 98 percent. Net CBM production increased 33 percent to 43.2 Bcfe in 2002 and averaged 118 MMcfed. In the year ahead, coal bed methane production in the play is expected to see only a modest increase relative to past years, as industry awaits the final Environmental Impact Statement (EIS). The EIS Record of Decision is expected later in the quarter after which drilling and water discharge permits can be issued on federal acreage, followed subsequently by the longer dewatering time of the Big George coals.

Year-end 2002 proved reserves included 49 Bcfe from the Big George coal, primarily in the All Night Creek Unit. The Company's gross production from the Big George coal has continued to increase and is currently over 24 MMcfd from the All Night Creek Unit and the Pleasantville and Kingsbury Unit pilot areas. Industry Big George production is estimated to be approximately 60 MMcfd currently.

Greater Green River Basin. As of December 31, 2002, the Company controlled approximately 209,000 net acres in the Greater Green River Basin, including 32,000 net acres in the area of the prolific Pinedale Anticline and Jonah Field in southwest Wyoming. In 2002, the Company participated in 26 gross wells in the Pinedale Anticline. The Company also drilled 2 successful wells and spud a third well on its acreage in the Sand Wash Basin in northwest Colorado. The success rate in the Greater Green River Basin was 100 percent. Natural gas production volumes from these areas increased 46 percent from a year ago to 15 MMcfed net in 2002. Total production was 5.4 Bcfe.

Results in 2002 reflect existing 40-acre downspacing and success in the deeper Mesaverde sands in the Pinedale Anticline. Both have added significant proven and probable reserves. The Company estimates it has exposure to 500 additional gross well locations in this prolific low-risk fairway.

CEO Comments. Peter Dea, Chief Executive Officer and President, commented, "We are very pleased to report a 34 percent net production growth in 2002 and solid reserve additions for the fifth straight year, particularly since all of the growth resulted from the drill bit. Our 98 percent drilling success rate, with $0.43 per Mcfe finding and development costs and reserves to production ratio of 12 years, further confirms the low-risk, low-cost and long-lived nature of our leasehold."

Company Description. Western is an independent natural gas explorer, producer, gatherer, processor, transporter and energy marketer providing a broad range of services to its customers from the wellhead to the sales delivery point. The Company's producing properties are located primarily in Wyoming, including the developing Powder River Basin coal bed methane play, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas-producing basins in the Rocky Mountain, Mid-Continent and West Texas regions of the United States.

This press release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 regarding production, new well locations, reserves and capital expenditures. Although the Company believes that its expectations are based on reasonable assumptions, Western can give no assurances that its goals will be achieved. These statements are subject to a number of risks and uncertainties, which may cause actual results to differ materially. These risks and uncertainties include, among other things, changes in natural gas and NGL prices, government regulation or action, geological risk, environmental risk, weather, rig availability, transportation capacity, the ability of Western's partners to fund the necessary capital expenditures and the progress of ongoing litigation and related disputes with its co-developer in the Powder River Basin of Wyoming, and other factors as discussed in the Company's 10-K and 10-Q Reports and other filings with the Securities and Exchange Commission. Reserve estimates are also subject to numerous uncertainties inherent in the estimation of quantities of proved and probable reserves, the projection of future rates of production and the timing of development expenditures. The accuracy of these estimates is a function of the quality of available data and of engineering and geological interpretation and judgment. Reserve estimates are imprecise and should be expected to change as additional information becomes available. Estimates of economically recoverable reserves and of future net cash flows prepared by different engineers or by the same engineers at different times may vary substantially. Results of subsequent drilling, testing and production may cause either upward or downward revisions of previous estimates. In addition, the estimates of future net revenues from proved reserves and the present value of those reserves are based upon certain assumptions about production levels, prices and costs, which may not be correct. Further, the volumes considered to be commercially recoverable fluctuate with changes in prices and operating costs.

Announces Purchase of Wyoming Gathering Assets

DENVER, February 4, 2003 -- Western Gas Resources, Inc. ("Western")(NYSE:WGR) today announced that it has completed the purchase of 18 gathering systems in the Green River, Powder River and Wind River Basins of Wyoming from El Paso Field Services, a business unit of El Paso Corporation (NYSE:EP) for approximately $37.0 million. Closing occurred on January 31, 2003 with an effective date of February 1, 2003. Current gas throughput on the systems totals approximately 139 MMcfd from approximately 450 wells and approximately 550 miles of gathering lines.

Three of the larger systems are located near Western's Red Desert processing facility and gathering system in the Greater Green River Basin in southwest Wyoming. Six of the gathering systems gather coal bed methane in the Powder River Basin and will be integrated with Western's existing systems in that area. The remaining four systems are located in the Wind River Basin in central Wyoming. Over 80 percent of the revenue stream is expected to come from fee-based gathering contracts with the remainder comprised of keep-whole processing arrangements.

Peter Dea, President and Chief Executive Officer of Western, stated, "These assets are an excellent fit with our existing gathering and processing assets in Wyoming. They support our strategy of being a premier producer and gatherer of natural gas in the Rocky Mountain region. The Green River Basin systems allow us to utilize available processing capacity at our Red Desert facility while obtaining long-term gathering agreements with area dedications in a very active drilling area. The Wind River system provides us with an entry point in this active basin."

Company Description. Western is an independent natural gas explorer, producer, gatherer, processor, transporter and energy marketer providing a broad range of services to its customers from the wellhead to the sales delivery point. The Company's producing properties are located primarily in Wyoming, including the developing Powder River Basin coal bed methane play, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas-producing basins in the Rocky Mountain, Mid-Continent and West Texas regions of the United States.

This press release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 regarding future growth potential. Although the Company believes that its expectations are based on reasonable assumptions, Western can give no assurances that its projections are accurate. These statements are subject to a number of risks and uncertainties, which may cause actual results to differ materially. These risks and uncertainties include, among other things, changes in natural gas and NGL prices, government regulation or action, environmental risk, weather, rig availability, transportation capacity, the success of third-party producers drilling near its systems and other factors as discussed in the Company's 10-K and 10-Q Reports and other filings with the Securities and Exchange Commission.

Announces Fourth Quarter and Year End 2002 Results Conference Call

DENVER, January 22, 2003 -- Western Gas Resources, Inc. (NYSE:WGR) will release its fourth quarter and year end 2002 earnings results at approximately 7:00 a.m. Eastern time on Thursday, February 20, 2003. Western invites you to listen to its fourth quarter and year end conference call via telephone or live Webcast on Thursday, February 20, 2003 at 10:00 a.m. Eastern, 8:00 a.m. Mountain time.

To listen via telephone, dial (719) 457-2665 five to ten minutes before the start of the call. A replay will be available through midnight, February 27th, by dialing (719) 457-0820, pass code 584702.

The live conference call may also be accessed on the Internet by logging onto Western's Web site at www.westerngas.com. Select Financial/Investor Information, then the Current News option on the menu. Log on at least ten minutes prior to the start of the call to register, download and install any necessary audio software. An audio replay of the call will also be available on the Web site through March 20, 2003.

Western is an independent natural gas producer, gatherer, processor, transporter and energy marketer providing a broad range of services to its customers from the wellhead to the sales delivery point. The Company's producing properties are based primarily in Wyoming, including the Powder River Basin coal bed methane development, where Western is a leading acreage holder and producer. The Company also designs, constructs, owns and operates natural gas gathering, processing and treating facilities in major gas- producing basins in the Rocky Mountain, Mid-Continent and West Texas regions of the United States.