UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Date of report (Date of earliest event reported): June 28, 2005

SOUTHWESTERN ENERGY COMPANY

(Exact name of registrant as specified in its charter)

Arkansas

(State or other jurisdiction of incorporation)

1-08246	71-0205415
(Commission File Number)	(IRS Employer Identification No.)

2350 N. Sam Houston Pkwy. E., Suite 300, Houston, Texas	77032
(Address of principal executive offices)	(Zip Code)

(281) 618-4700

(Registrant's telephone number, including area code)

Not Applicable

(Former name or former address, if changed since last report)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

       o Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

o Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

o Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

o Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Explanatory Note

The information in this report, including Exhibit 99.1 attached hereto, shall not be deemed to be "filed" for purposes of Section 18 of the Securities and Exchange Act of 1934, as amended (the "Exchange Act"), or otherwise subject to the liabilities of that Section, and shall not be incorporated by reference into any filing under the Securities Act of 1933, as amended, or the Exchange Act, except as shall be expressly set forth by specific reference in such a filing.

SECTION 7.  REGULATION FD.

Item 7.01 Regulation FD Disclosure.

Southwestern Energy Company disclosed that the company will be presenting certain preliminary information and estimates, supported by technical data, regarding wells in two proposed new fields at a public hearing before the Arkansas Oil and Gas Commission (AOGC) on June 28, 2005. The public hearing relates to Southwestern's pending applications for the Gravel Hill and Scotland fields in the company's Fayetteville Shale play. The preliminary information and estimates indicate that vertical wells in both the Gravel Hill and Scotland fields would have a likely drainage area of approximately 20 acres or less per well, based on an estimated expected ultimate recovery (EUR) ranging from approximately 300,000 to 480,000 Mcf per well. The company will also present the following test data and estimates regarding three horizontal wells in its Gravel Hill and Scotland fields:

Well Name	Field	Test Rate (Mcf/d)	Flowing Pressure	EUR (Bcf)	Approx. Drainage Area (Acres)
Stobaugh #2-1-H	Gravel Hill	3,703	551	2.3 (1)	62
McNew #3-2-H	Gravel Hill	2,780	422	1.7 (2)	46
Linkinogger #2-9-H	Scotland	1,392	219	0.9 (2)	18

(1)    Stobaugh EUR from COMET 3 reservoir simulation and history match.

(2)    McNew and Linkinogger EURs estimated by ratio of test rates to Stobaugh EUR.

With respect to the previously established Griffin Mountain Field in Conway county, Arkansas, Southwestern also disclosed that it will inform the AOGC that recent data from the 11 vertical wells with more than 30 days of production indicates a likely drainage area of approximately 20 acres or less per well and EUR per well ranging from approximately 150,000 to 480,000 Mcf per well, as compared to the previously estimated drainage area of approximately 30 acres or less per well and average EUR of 580,000 and 600,000 Mcf per well for the initial two wells. The reduction in the estimated EUR per well at Griffin Mountain is primarily attributed to reduced observed fracture stimulation lengths, which are about half of the estimates used in the original reservoir stimulation models. The company believes that improved EURs for the field may be obtained with longer fracture lengths and/or horizontal wells with transverse fracture stimulation treatments.

Southwestern will also present single well estimated economics, assuming a $6.00 per Mcf Henry Hub natural gas price held constant. The following estimates are based upon interpretation and associated economics that are subject to change as additional production data is obtained:

Well Type	Gross Well Cost ($000)	IP Rate (Mcf/d)	Gross EUR (MMcf)	Pre-tax Return (%)	Pre-tax Present Value Profit (Disc. 10%)
Vertical	$500	350	404	17.0	149
Horizontal (1)	$1,500	2,780	1,700	34.5	1,535

(1)    Estimated based upon the McNew #3-2H, and based on limited production data.

The company expects variability throughout the play area, therefore the drainage area per well, gas-in-place and ultimate recovery estimates discussed above and included in the company's AOGC filings are not necessarily indicative of the estimated ultimate drainage area, gas-in-place or recovery for the fields, the other pilot areas or the entire play area. The foregoing estimates are forward looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Although the company believes the expectations expressed in such forward-looking statements are based on reasonable assumptions, actual results and the amounts of proved reserves that ultimately are recorded may be materially different. Actual results will be affected by commodity prices, operating costs, future well performance and variability within the play area, as well as other factors and risks that are more fully described in the company's Annual Report on Form 10-K for the year ended December 31, 2004.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

	SOUTHWESTERN ENERGY COMPANY
Dated: June 28, 2005	By:	/s/    GREG D. KERLEY
	Name:	Greg D. Kerley
	Title:	Executive Vice President and
		Chief Financial Officer

EXHIBIT INDEX

Exhibit
Number Description