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) October 17, 2001

                        SOUTHWESTERN ENERGY COMPANY
           (Exact name of registrant as specified in its charter)

               Arkansas             1 - 8246         71-0205415
      (State of incorporation     (Commission      (I.R.S. Employer
         or organization)          File Number)    Identification No.)

          2350 N. Sam Houston Pkwy. E., Suite 300, Houston, Texas 77032
          (Address of principal executive offices, including zip code)

                             (281) 618-4700
           (Registrant's telephone number, including area code)

                                 No Change
     (Former name, former address and former fiscal year; if changed
                            since last report)



Item 7.(c)

Exhibits                                                              Reference

        (99.1)   Conference Call Summary dated October 17, 2001.      p. 3 - 11

Item 9.

Regulation FD Disclosures

         Southwestern  Energy Company is furnishing under Item 9 of this Current
Report on Form 8-K the information included as exhibit 99.1 to this report.

Note:  The  information  in this report  (including  the  exhibit) is  furnished
pursuant  to Item 9 and shall not be deemed to be "filed"  for the  purposes  of
Section 18 of the  Securities  Exchange Act of 1934 or otherwise  subject to the
liabilities  of that section.  This report will not be deemed an admission as to
the  materiality  of any  information  in the  report  that  is  required  to be
disclosed solely by Regulation FD.


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, thereunto duly authorized.

                                               SOUTHWESTERN ENERGY COMPANY

DATE: October 18, 2001                          BY:   /s/ GREG D. KERLEY
     ------------------                        ---------------------------
                                                     Greg D. Kerley
                                                 Executive Vice President
                                               and Chief Financial Officer

                                      - 2 -

Southwestern Energy                                     Conference Call
Company                                                    Summary

                   2001 Third Quarter Results Conference Call
                           Wednesday, October 17, 2001

                                   Chaired by
                                  Harold Korell
                      President and Chief Executive Officer

Korell:  Good morning,  and thank you for joining us today.  With me are Richard
Lane, our Senior Vice President of our E&P Company,  and Greg Kerley,  our Chief
Financial Officer. After some preliminary comments,  I'll turn the floor over to
Richard for an update on our E&P  operations,  and then to Greg for  comments on
our financial results. After that we'll be available for questions.

If you've not received a copy of the press release  announcing our third quarter
results,  you can call Kathy at 501-582-8492  and she'll fax a copy to you. Also
our attorneys have asked that I point out that some of the comments  during this
teleconference may be regarded as forward-looking  statements that involve risks
and uncertainties,  which are detailed in the Company's  Securities and Exchange
Commission filings. While we believe they are reasonable  representations of the
Company's expected performance, actual results could differ materially.

Our  performance  for the quarter and for the nine months of 2001 highlights the
fact that our strategy of adding value through the drill bit is working. Our E&P
program is continuing to deliver production  growth.  This year the Arkoma Basin
will, in fact, exceed our plan and production is showing  significant growth for
the first time in eight  years.  And in east  Texas,  our Overton  drilling  has
delivered  better-than-expected  results.  Richard  will  update  you  on  these
activities in a moment.

As I'm sure you're  aware,  gas prices have been very volatile over the last few
months,  and hit a low point at the end of September,  one we haven't seen since
the first quarter of 1999. Fortunately, we have hedges in place that are serving
us well for the third and fourth  quarters of this year.  In  addition,  we have
hedges in place for 2002 and 2003 that give us a good price for our gas in those
years, and Greg will speak about that later.

Overall,  I'm very pleased with our performance  this year. With the events that
have  occurred in our country over the last month,  we have  recognized  an even
deeper need to discover  new oil and gas  reserves.  We'll  continue to focus on
those projects that have the potential to create the greatest  present value for
our   shareholders.   That  concludes  my  comments,   and  I'll  now  turn  the
teleconference over to Richard for an update on our E&P operations.

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Lane: Thank you Harold, and good morning everyone.  In the third quarter of this
year we  continued  to build on the  success of our  drilling  programs in south
Louisiana,  east Texas and the Arkoma and  Permian  Basins,  and the results are
showing in our production.  Oil and gas production in the third quarter was 10.5
Bcfe, up from 9.0 Bcfe in the third  quarter of last year,  and up from 9.8 Bcfe
in the second quarter of this year.  Through three  quarters,  our  year-to-date
production  is 29.3  Bcfe.  This is a 10%  increase  from 26.6 Bcfe in the first
three quarters of 2000.

In total, we have  participated in 90 wells so far this year, with 30 being spud
in the third quarter.  Of our third quarter wells,  22 were  successful and five
were in progress at the end of the quarter.  On a year-to-date  basis,  68 wells
have been successful, with six wells still in progress. Our Arkoma Basin program
continues to deliver for us in both Oklahoma and Arkansas.  In the third quarter
we finalized 13 wells,  11 of these were  productive  and two were dry. Our 2001
year-to-date  success  rate in the basin has been 80%.  Our Fairway  area on the
Arkansas  side of the  basin  also  continues  to yield  strong  producers.  Our
Southwestern-operated  Toby #1-7 well,  located in  Franklin  County,  Arkansas,
found  five  well-developed  gas  sands  between  3,000  and  3,800  feet and is
currently producing 3.1 MMcf per day from the Canyon and Orr formations. We hold
a 52.8% working interest in this well.

In Yell County,  Arkansas, we completed the Catlett #1-13, at our thrusted Borum
play  area.  This well is  currently  producing  2.2 MMcf per day from the Upper
Borum.  Southwestern  operates the Catlett well with an 80% working interest. On
the Oklahoma side of the Arkoma Basin,  we have tested our Quaid #2 at a rate of
4.2 MMcf per day, and we hold a 50% working  interest in this well,  which is in
our Robbers'  Cave prospect area of Latimer  County,  Oklahoma.  The Quaid #2 is
currently waiting on pipeline connection.

In the Permian Basin,  we were  successful on 18 of 23 wells drilled through the
first nine months of this year.  In the third  quarter,  we completed  our first
development  well at our Cowden Ranch  discovery  in Crane  County,  Texas,  and
production from those two wells is 250 barrels of oil per day and 200 Mcf of gas
per day from the Devonian  formation at approximately  7,500 feet. Current plans
there call for additional development wells on this discovery next year. We also
have identified two new prospects in the area that we will pursue also.

In our Morrow drilling  program,  we are currently  drilling at a depth of 3,000
feet on our Big Tank prospect in Eddy County, New Mexico. This well is targeting
Morrow pay at  approximately  12,000  feet that has proven to be  productive  in
other offset wells.  Southwestern  operates this  prospect,  located  within our
Phillips joint venture acreage, with a 50% working interest.

At our  Overton  Field in Smith  County,  Texas,  our 2001  development  program
continues to be very  successful.  Since the beginning of the year, we have spud
13 wells of which 11 are on production, and two are currently being drilled. All
of these wells are targeting the Cotton Valley sands at a depth of approximately
11,800 feet. This activity includes the recently-competed  Sally Warren Gas Unit
#1-2 well,  which is an evaluation  well on our 5,800-acre  farm-in  adjacent to
Overton. As a result of the Overton program, gross production from the field has
increased from 1.8 MMcf per day in June of 2000,  when we took over  operations,
to a current rate of 15 MMcf per day.

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Building on our success at Overton,  and to capitalize  on our  continued  plans
there,  we have  acquired  additional  minority  working  interests in the field
during  the  third  quarter.  As a result  of these  acquisitions,  Southwestern
currently operates its Overton wells with an average working interest of 97%. We
expect to keep  developing our Overton  position the remainder of this year, and
have a continued drilling program on into 2002.

In south  Louisiana,  we are continuing to drill ahead on the first  development
well on our North Grosbec discovery.  The Norman Breaux #1 is currently drilling
at 16,000 feet on its way to 18,000 feet. As we have discussed previously,  this
well will test the P-10 sand that is currently  producing in our discovery  well
at a current rate of 16.4 MMcf per day and 600 barrels of condensate per day. In
the third  quarter,  we had to  sidetrack  the Norman  Breaux due to  mechanical
problems in the intermediate  section of the well. We anticipate  reaching total
depth on this well by the end of this year.

In late-September, we recompleted the discovery well in our Malone prospect, the
State Lease 16626 #1 well,  into the main P-1 sand pay  interval at 14,300 feet.
After this  recompletion,  the two Malone  wells are  currently  producing  at a
combined rate of 25.8 MMcf per day and 536 barrels of oil per day.  Southwestern
operates these wells with a 33% working interest.

Additionally  in south  Louisiana,  we reached total depth of 14,260 feet in the
Mire #1  well  on our  Horeb  prospect  in  Acadia  Parish.  This is the  second
exploration  test within the Eden 3-D project area, where last year we announced
our  successful  Robertson  well. In the Mire well, our primary deep objective -
the Nodosaria sand - was not  productive.  However,  we did penetrate 50 feet of
pay in the Nonion Struma sand at approximately  12,100 feet and we are currently
completing  there. We expect first  production from this discovery by the end of
November. Southwestern operates the Mire well with a 21.5% working interest.

We have also recently spudded a well on our Crowne prospect,  located in Cameron
Parish,  Louisiana.  This is the second  well  within our  Cameron  Prairie  3-D
project.  The  Miami  Corp #1 will  have a total  depth  of  14,500  feet and is
targeting the Planulina sands. We are currently drilling at approximately 10,300
feet  and  expect  to reach  total  depth in  late-November  or early  December.
Southwestern operates this well with a 40% working interest.

And  lastly  in  south  Louisiana,  we  have  finalized  plans  for a new  large
140-square mile  Southwestern-operated 3-D seismic shoot in a highly prospective
area.  We're  currently  applying  for  permits  for  this  3-D  survey  and are
optimistic it will yield exploratory opportunities for us in the future.

In summary,  I'm very pleased with the results of our year-to-date 2001 program.
We continue to make progress in reducing our lease  operating  expenses on a per
Mcfe basis  compared to the first quarter of this year.  Operating  costs in the
third quarter were $.38 per Mcfe compared to $.51 per Mcfe in the first quarter.
Our  production  rate is  continuing  to increase,  and we are  maintaining  and
strengthening  our strong  inventory of  value-adding  opportunities  for future
growth in reserves  and  production.  I will now turn it over to Greg Kerley who
will discuss the Company's financials for the quarter.

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Kerley:  Thank you Richard,  and good morning. As Harold indicated,  we are very
pleased with our financial results for the quarter and year-to-date. We reported
record net income of $5.0 million,  or $.20 cents a share for the third quarter.
This compared to a loss in the same period last year of $800,000,  or $.03 cents
per share.  Net income for the first nine months of the year was $27.9  million,
more than double our  earnings  during the first nine months of 2000.  Cash flow
from operating activities was $22.7 million during the quarter, up 72% from last
year, and cash flow for the first nine months was $86.4 million, up 58% from the
same period in 2000.  Our strong  results  were  mainly  driven by the growth in
production volumes that Richard spoke about and by higher commodity prices.

Operating  income  for the  exploration  and  production  segment  rose to $15.9
million during the quarter, up from $7.2 million for the same period in 2000. We
realized an average gas price of $3.37 per Mcf during the  quarter,  up 17% over
prices a year ago. Our hedges really helped our performance  during the quarter,
and will continue to have a positive impact for us in the fourth quarter. In the
fourth  quarter we have 6.25 Bcf hedged with an average floor price of $4.06 per
Mcf, and an additional .4 Bcf hedged at a fixed price of $3.19 per Mcf.

During the quarter we added to our hedge  position for 2002 and 2003.  For 2002,
we have 3.25 Bcf in each quarter  hedged at an average  fixed price of $2.88 per
Mcf and a collar on an  additional  1.5 Bcf each  quarter  with a floor price of
$4.00 per Mcf. The  combination of these hedges give us a minimum  average NYMEX
price of about $3.23 per Mcf on approximately 19.0 Bcf of our gas production for
next year. And for 2003, we have hedged 2.3 Bcf each quarter at an average NYMEX
price of $3.18 per Mcf.

Operating  expenses for the exploration  and production  segment fell during the
quarter on a unit of  production  basis to $.38 per Mcfe  compared to $.40 cents
per Mcfe in the third quarter of 2000. As Richard  indicated, this compares very
favorably to our lifting cost of $.51 per Mcfe in the first quarter and $.44 per
Mcfe in the second  quarter of this year. Our G&A per Mcfe was also lower during
the quarter,  while our DD&A expense rose during the quarter,  primarily  due to
higher production volumes.

As Harold  indicated,  at the end of  September  we saw the lowest gas prices we
have seen in over 2 1/2 years,  when the index price for  October  Henry Hub was
$1.86 per Mcf.  As a result of the low prices at  September  30,  the  Company's
unamortized   cost  of  oil  and  gas  properties   exceeded  the  ceiling  test
standardized  measure of our proved oil and gas  reserves by  approximately  $55
million.  However,  due to the  recovery  over the last few weeks in the  market
prices for natural  gas,  the Company was not  required to record a ceiling test

On the utility side of our business, we experienced a seasonal operating loss of
$2.4 million during the third quarter of 2001,  compared to an operating loss of
$1.7 million in the same period last year. For the first nine months,  we posted
operating income of $6.3 million compared to $6.8 million for the same period in
2000, when you exclude the income from our Company's  Missouri assets which were
sold in May of last year.

The Company's marketing group also added $2.2 million in operating income during
the first nine months of this year, compared to $2.0 million for the same period
last year. For the first

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nine months of 2001, our capital  expenditures  totaled  $77 million,  including
$74 million  invested in our  exploration and production operations.

Our total debt decreased  slightly  during the quarter from our level at June 30
and is  currently  at $356  million.  We  expect to pay down an  additional  $10
million during the fourth quarter,  which should bring our debt-to-total capital
ratio down to around 66% by the end of the year.

That  concludes  my  comments;  we'll  now turn back to the  operator,  who will
explain the procedure for asking questions.

                             Questions and Answers

1.       Regarding  production,  what  could  you give us as far as guidance for
next quarter and  next year,  given the  performance  you  had so far  in  third

Kerley:  We had real  strong  production  in the third  quarter,  and we're real
pleased with that. And with 10.5 Bcf equivalent this quarter,  I think we expect
to be up some from that in the fourth quarter. As you might recall, our original
target for the year was about 38 Bcf equivalent of production. And right now, it
looks like we're on target to be somewhere between 39 and 40 Bcf equivalent, and
closer to 40.

For next year,  we're currently in our planning  process and we build our budget
from the ground up there.  But looking  forward we're  targeting 10%  production
growth,  just like we targeted this year. This year, I think, we'll end the year
a little  ahead of that.  And we look like  we'll  start  the next  year  pretty

2.       Specifically  on the Crowne  prospect,  have you talked about the size?
What are you looking for, in reserve  size,  on that prospect?

Lane:    The Crowne Prospect is currently drilling, as I mentioned, and it is in
the 75 to 90 Bcfe potential range.

3.       You've done a good  job  of driving down F&D costs. This year,  though,
you're going  to  have  higher  drilling  costs.  Maybe  they'll  be  offset  by
larger discoveries. What's your feel for the direction you're going to be at the
end of the year?

Korell:  There  are a  couple  of  things  going on  there,  of  course.  As you
mentioned,  the costs of services are up. We've continued to be able to leverage
our ability to generate our ideas and  prospects in a way that has allowed us to
pay lower  disproportionate  shares of the drilling on some of these  prospects.
And  therefore,  I don't  think  we'll see as large an  impact as we might  have
otherwise seen on the finding and development costs.

So, I expect  that when the year ends,  I think we'll be pretty  happy.  I don't
want to put out numbers now,  because you never know quite how your reserves are
going to come down because

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of what we might have on  our drilling  activities  in the next  quarter.  But I
think  we'll be  pretty happy with our finding  and development costs this year.

4.       Could  you  take  us  area  by  area  and tell us whether or not you're
slowing activity in any of the areas you're currently in?

Korell:  Well, I think I can answer that for the company as a whole.  We are not
slowing activity.  When you look at it by area, we've been very active this year
in the Arkoma.  We have an inventory of things to drill there.  Given the prices
for our product and our low operating costs there,  those prospects are economic
down to very low price levels, in fact.

In our south  Louisiana  area, the primary thing that you'll want to keep an eye
on  there  is  that  you  are  generating  quality  prospects  and  that  you've
appropriately  assessed  risk.  The  size of those  are  large  enough  to where
accurately assessing risk is more important almost than price. The Permian Basin
would be the area that we'd need to keep the closest eye on, because the finding
costs tend to be a little higher there for us and the operating costs are higher
than the Arkoma Basin.

At Overton, the reserves that we're finding there make that a project that we're
excited about  drilling on at these price levels.  So,  overall we're really not
changing our capital plan.

5.       For next year,  would you expect  that your budget's  going to be lower
than it was this year and you'll be forced to reduce activity somewhat?

Korell:  Well,  the activity level for next year will be determined by, in large
part,  where prices  settle.  I don't know if you were on the line when Greg was
describing the hedges that we have in place for next year. But with those hedges
and with reasonable  expectations for where the remaining unhedged volumes would
be priced,  and given what the strip is out there now, we should have an equally
large capital program next year, to what we had this year.

6.       In terms of Overton, can you  remind  us  what  kind of reserves you're
getting per well out there?

Lane:  The  wells  are very  early in their  lives,  but  we're  seeing  that we
anticipate those wells will do something around 2 Bcf per well.

7.       This year at Overton  you've  drilled 13 wells.  How many do you expect
to drill between now and  year-end?  And then how many next year at Overton?

Lane:  Well, we have two more wells  planned that we'll start in November.  That
will bring our total to 15 wells for the year. And then,  next year, like Harold
said,  depending on where prices settle out and how our capital  program settles
out, I would say now we're  anticipating  a program next year that's  similar to
what we have this year.

8.       Previously,  you  had shared with us the kind of reserves  that you had
found  year-to-date.  But  recently,  you  haven't  done  that.  Can you tell us
what kind of reserves you've found year to date?

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Korell:  Well, I might try to respond to that. I think on the reserve  question,
so much is affected by where prices are, at a point in time.  And we'll probably
pass on talking about reserves and finding and development costs right now, on a
quarterly basis. But I expect we're going to have a nice finding and development
cost this year and a reserve replacement ratio that we'll be proud to report on.

9.       What's the expectation for spending in the fourth quarter?

Kerley:  Right now, we are at $77 million in total. If you recall, that includes
about $6.5 million that we've  received  from our partner at Overton.  We expect
the total number to be about another $23 million, but we'll get about $6 million
or $7 million  back from our Overton  partner of that number too.  So, we'll end
the year to where our total capital  investments  will be close to $100 million,
but we'll get probably $13 million back from our partner in Overton.  So, net to
the Company will be $87 - $88  million and the bulk of which  will be in the E&P

10.      That program  with  your partner  at Overton,  wasn't that  just for 14
wells, or so?  How many more wells do you have in that program?  And then, after
that program's over, are you just going to do it on your own?

Kerley:  That's  correct and we're looking at that right now. The last two wells
that  Richard  was  talking  about  will end the  program  for that phase of the
partnership.  And we'll  evaluate that and see if we want to try to do something
there  again.  Either  way,  we are going to go  forward  with our  drilling  at
Overton.  We're very  pleased  with our  results  there,  but we haven't  made a
decision on whether to do that as a partnership.

11.      In  terms  of  Arkoma  Basin,  I know  you were  really  successful  at
Haileyville in particular.  Did you  talk about  what  the rates  are  there, at
Haileyville? Have they come down a  whole lot and do you have any success of the
same magnitude?

Lane: Well, on the project itself,  last quarter we talked about production on a
gross basis of about 40 MMcf per day, for the Haileyville area. And I think that
was about 13 MMcf net to our interest, and we also reported that we thought we'd
probably  developed up the real core productive area of that project.  The wells
going forward,  we anticipated two or three more in the third quarter,  and that
they  would be  getting  out of that  core  area and back to more of the  normal
wells. That's in fact what's happened.

We have drilled  three more in  the third  quarter.  And we've  completed  those
wells,  but they  are not the  prolific  wells  we saw in the core  part of that
project, more typical of what we expect in the basin. So, out there on a project
basis, the production rates are coming down, as expected.  But still, I think we
were  producing  on a gross basis about 29 MMcf a day out there,  still.  So, it
continues to be a really good producing area for us. That's what's  happening in
that region.

Korell:  In regard to the broader  question there about the Arkoma Basin, as you
know over the last three years at least,  we've stated that our objective  there
was to maintain  production  in the Arkoma and we've broken that trend this year
by increasing production. We have set, as a target

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for that team that they would become  one of our teams  whose  objective  is  to
grow,  not  just  maintain.  Of  course, we  have  to drill wells to do that and
those wells have to be successful.

12.      At  Haileyville,  some of the prolific wells there were not normal,  as
you say. But, I mean,  are there some trends there that you can follow and maybe
hit some sweet spots in other areas?

Lane:  Well, we have probably  eight or 10 plays that are similar to that on the
Oklahoma  side of the basin,  that we're always  pursuing.  Any of them have the
potential for that to occur and we'll  continue to pursue those through the rest
of this  year and next  year.  As active as we are in the  basin,  it  certainly
increases our chances of finding those kinds of things.

13.      I know your debt level is still,  maybe above  what you're  comfortable
with and you're  trying to pay down the debt.  But,  are you looking  forward to
making acquisitions,  not just in the Arkoma, but elsewhere?  I know that area's
heating  up. You know  Chesapeake  sold their  Canadian  properties  and they're
emphasizing the Mid-Continent. I'd just like to hear your comments about that.

Korell:  Well, our comments on acquisitions  are pretty much the same as they've
always been.  That is, if we see things that we like,  that we think that we can
exploit  and we can take  advantage  of, and that we can fit within our  capital
program or available cash flow,  it's something that will add value.  And again,
we look at things on a PVI basis. So, an acquisition,  in effect, has to compete
with a drilling project. Based upon where our capital availability is right now,
we're not flush with cash like some others  are.  So, we won't be out being very
aggressive.  But when we see something we want,  we'll be  aggressive,  like the
additional  interests that we've bought in the Overton Field, where we know what
we're  doing  and where  that's  working  well for us.  So,  that's  the type of
acquisition  you should  expect to see us do.  They  won't be large;  they'll be
small things. But they have an opportunity to really have an impact.

Remember,  we paid about $6 million for Overton,  back in 2000.  And look at the
activity and value we're generating there.

14.      What  about the other  side?  I think  once you get some  stability  in
the  commodity  price,  then you  maybe  begin to get some  more  matching  with
sellers' and buyers'  expectations.  Are there  properties still - I know you've
talked in the past about things that maybe are higher LOE - that you would still
be looking to divest,  to maybe  apply that to either Cap Ex or debt  reduction?
What's your status on property divestitures.

Korell:  Well,  we've said for a number of quarters that our strategy  about the
Mid-Continent,  the western part of Oklahoma,  I mean, was that we're in harvest
mode.  We've  reduced our costs there and we would either  produce the value out
there at a low cost,  or sell or trade.  And,  we have some work  going on right
now.  Richard has a team of people that right now are looking hard at those.  We
have some upcoming activity there that might have a positive impact.

So, I'd say we're kind of in a hold pattern  relative to selling that,  although
we're  always  looking to improve  our  position  in the areas we think are real
core, like Permian or Arkoma. We're always open to opportunities to do that, and
the option to do that.

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Kerley:   This is Greg Kerley again. Thank you for  joining us  today and please
feel free  to  call me  with any  other  questions  that you  have or  for other
information that you may need.  This concludes our teleconference.

Operator:        Ladies and  gentlemen,  that does conclude your  conference for
today.  You may all  disconnect,  and thank you for participating.

Southwestern Energy Company          2001 Third Quarter Earnings Conference Call
                                       -9-                           www.swn.com

                          Southwestern Energy Company
                          P.O. Box 1408
                          Fayetteville, AR 72702-1408

October 18, 2001

Securities and Exchange Commission
ATTN: Filing Desk, Stop 1-4
450 Fifth Street, N.W.
Washington, DC  20549-1004


Pursuant to  regulations  of the Securities and  Exchange  Commission, submitted
herewith for filing  on behalf of  Southwestern Energy Company is Form 8-K dated
October 17, 2001.

This filing is being  effected by direct  transmission to the Commission's EDGAR

Very truly yours,

Stan Wilson