U.S. Securities and Exchange Commission

Washington, D.C.  20549

Form 10-KSB

(Mark One)

[ X ]     ANNUAL REPORT UNDER SECTION 13 OR 15(d) OF THE
     SECURITIES EXCHANGE ACT OF 1934 [Fee Required]
     For the fiscal year ended December 31, 1998

[    ]     TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE
     SECURITIES EXCHANGE ACT OF 1934 [No Fee Required]
For the transition period from  to 

Commission file number  333-31681

Atlas-Energy for the Nineties-Public #6 Ltd.
(Name of small business issuer in its charter)

Pennsylvania     23-2888337

(State or other jurisdiction of     (I.R.S. Employer
   incorporation or organization)                Identification No.)

311 Rouser Road, Moon Township, Pennsylvania  15108
(Address of principal executive offices)   (Zip Code)

Issuer's telephone number (412) 262-2830
Securities registered under Section 12(b) of the Exchange Act

                Title of each class          Name of each exchange on 
which registered     

                          None                         None

Securities registered under Section 12(g) of the Exchange Act

None
(Title of Class)

Check whether the issuer (1) filed all reports required to be filed by 
Section 13 or 15(d) of the Exchange Act during the past 12 months (or 
for such shorter period that the registrant was required to file such 
reports), and (2) has been subject to such filing requirements for the 
past 90 days.  Yes    X     No 

Check if there is no disclosure of delinquent filers in response to 
Item 405 of Regulation S-B contained in this form, and no disclosure 
will be contained, to the best of registrant's knowledge, in definitive 
proxy or information statements incorporated by reference in Part III 
of this Form 10-KSB or any amendment to this Form 10-KSB.  [ X ]


State issuer's revenues for its most recent fiscal year. $1,721,899

State the aggregate market value of the voting stock held by non-
affiliates of the Registrant.  Not Applicable.

Transitional Small Business Disclosure Format (check one):

Yes     X        No     
================================================================
PART I

ITEM 1.     DESCRIPTION OF BUSINESS

Atlas-Energy for the Nineties-Public #6 Ltd. (the "Partnership") 
was formed under the Pennsylvania Revised Uniform Limited Partnership 
Act on July 1, 1997, with Atlas Resources, Inc. ("Atlas") as Managing 
General Partner.  The Partnership had its final closing on December 31, 
1997, and was funded with total subscriptions of $9,901,025 to drill 
natural gas development wells.  Also, the Managing General Partner was 
credited with a total capital contribution of $1,968,637 because of 
certain expenditures it made on behalf of the Partnership and certain 
prospects it contributed to the Partnership. 
The Partnership has not filed bankruptcy nor has the Partnership been 
involved in any material reclassification, merger, consolidation, 
receivership or similar proceeding or purchase or sale of a significant 
amount of assets not in the ordinary course of business.

The Partnership was funded to drill natural gas development wells 
with the objective being the discovery and production of natural gas in 
commercially marketable quantities.  The initial closing date was 
December 1, 1997, and the Partnership began its drilling activities 
pursuant to the drilling and operating agreement.  Additionally, the 
Partnership prepaid drilling costs pursuant to the drilling and 
operating agreement on December 31, 1997, in an amount equal to 
$7,918,110, in order to claim a 1997 deduction for intangible drilling 
and development costs of wells to be drilled in 1998.  The drilling and 
operating agreement provided that a total of 44.45 development wells 
would be drilled to the Clinton/Medina geological formation in Mercer 
and Lawrence Counties, Pennsylvania.  Atlas and its affiliates had 
sufficient leasehold inventory to provide the prospects to be developed 
by the Partnership.  See  "Description of Property."

For the next 12 months management believes that the Partnership 
has adequate capital in order to conduct its operations.  The 
Partnership had sufficient capital resources from the closings to drill 
and develop approximately 44.45 net wells.  No other wells will be 
drilled and therefore no additional funds will be required.  The 
payment of operation and maintenance costs did not begin until the 
Partnership wells began to generate revenue.  Although management does 
not anticipate that the Partnership will have to do so, any additional 
funds which may be required will be obtained from production revenues 
from Partnership wells or from borrowings by the Partnership from Atlas 
or its affiliates.  Atlas, however, is not contractually committed to 
make such a loan.  The amount that may be borrowed by the Partnership 
from Atlas and its affiliates, if any amounts are borrowed, may not at 
any time exceed 5% of the Partnership subscription.  No borrowings will 
be obtained from third parties.

With respect to operating and maintenance costs, the Partnership's 
commitments pursuant to the drilling and operating agreement are 
expected to be fulfilled through revenues generated from the sale of 
gas and oil. During producing operations Atlas, as operator, will 
receive a monthly well supervision fee of $275 (proportionately reduced 
to the extent less than 100% of the working interest was acquired) for 
each producing well for which it has responsibility under the drilling 
and operating agreement.  The well supervision fee covers all normal 
and regularly recurring operating expenses for the production, delivery 
and sale of gas, such as well tending, routine maintenance and 
adjustment, reading meters, recording production, pumping, maintaining 
appropriate books and records, preparing reports to the Partnership and 
to government agencies, and collecting and disbursing revenues.  The 
well supervision fees do not include costs and expenses related to the 
production and sale of oil, purchase of equipment, materials or third 
party services, brine disposal, and rebuilding of access roads, all of 
which will be billed at the invoice cost of materials purchased or 
third party services performed.  As operator Atlas will charge the 
Partnership at cost for third party services and materials provided for 
each well which has been placed in operation, and a reasonable charge 
for services performed directly by Atlas or its affiliates.  The 
drilling and operating agreement also gives the operator the right at 
any time after three years from the date a Partnership well has been 
placed into production to retain $200 per month to cover future 
plugging and abandonment of such well.

Natural gas and any oil produced by the wells developed by the 
Partnership must be marketed in order for the Partnership to realize 
revenues from such production.  The Partnership did not purchase and 
does not anticipate selling any producing wells.  In recent years 
natural gas and oil prices have been volatile.  

The marketing of natural gas and oil production, if any,  will be 
affected by numerous factors beyond the control of the Partnership and 
the effect of which cannot be accurately predicted.  These factors 
include the availability and proximity of adequate pipeline or other 
transportation facilities; the amount of domestic production and 
foreign imports of oil and gas; competition from other energy sources 
such as coal and nuclear energy; local, state and federal regulations 
regarding production and the cost of complying with applicable 
environmental regulations; and fluctuating seasonal supply and demand.  
For example, the demand for natural gas is greater in the winter months 
than in the summer months, which is reflected in a higher spot  market 
price paid for such gas.  Also, increased imports of oil and natural 
gas have occurred and are expected to continue. The free trade 
agreement between Canada and the United States has eased restrictions 
on imports of Canadian gas to the United States.  Additionally, the 
passage in November, 1993, of the North American Free Trade Agreement 
will have some impact on the American gas industry by eliminating trade 
and investment barriers in the United States, Canada and Mexico.  In 
the past the reduced demand for natural gas and/or an excess supply of 
gas has resulted in  a lower price paid for the gas.  It has also 
resulted in  some purchasers curtailing or restricting their purchases 
of natural gas; renegotiating existing contracts to reduce both take-
or-pay levels and the price paid for delivered gas; and other 
difficulties in the marketing of production.

The Clean Air Act Amendments of 1990 contain incentives for the 
future development of "clean alternative fuel," which includes natural 
gas and liquefied petroleum gas for "clean-fuel vehicles."  The 
Partnership believes the amendments ultimately will have a beneficial 
effect on natural gas markets and prices.

The Managing General Partner is responsible for selling the 
Partnership's gas and oil production.  Atlas' policy is to treat all 
wells in a given geographic area equally.  This reduces certain 
potential conflicts of interest among the owners of the various wells, 
including the Partnership, concerning to whom and at what price the gas 
will be sold.  Atlas calculates a weighted average selling price for 
all the gas sold in the geographic area, such as the Mercer County 
area.  To arrive at the average weighted selling price the money 
received from the sale of all the gas sold to its customers in a 
geographic area is divided by the volume of all gas sold from the wells 
in the area.  On occasion, Atlas has reduced the amount of production 
it normally sells on the spot market until the spot market price 
increased.  Atlas, however, has not voluntarily restricted its gas 
production in the past two years.  (See "Properties - Production.")

In the Mercer County area, a portion of the Partnership's gas is 
transported through Atlas' own pipeline system and sold directly to 
industrial end-users in the area where the wells were drilled.  This 
will generally result in the Partnership receiving higher prices for 
the gas than if the gas were transported a farther distance through 
interstate pipelines because of increased transportation charges.  The 
remainder of the Partnership's gas from the Mercer County area will be 
transported through Atlas' and its affiliates' pipelines to the 
interconnection points maintained with Tennessee Gas Transmission Co., 
National Fuel Gas Supply Corporation, National Fuel Gas Distribution 
Company, East Ohio Natural Gas Company and Peoples Natural Gas Company. 
These delivery points are utilized by Atlas Gas Marketing, Inc. to 
service its end-user markets in the northeast United States which 
include in excess of 300 customers.  Atlas is currently delivering an 
average 27,000 MCF of natural gas per day from the Mercer County area 
to all the aforementioned markets and has the capacity of delivering 
33,000 MCF per day from the Mercer County area. Atlas anticipates that 
Wheatland Tube Company and Carbide Graphite each will purchase 
approximately 10% to 15% of the Partnership's gas production in 1999 
pursuant to gas contracts between them and an affiliate of Atlas, and 
it is possible that other purchasers of the Partnership's gas 
production may account for 10% of the Partnership's gas sales revenues 
in 1999.  (See "Financial Statements.")

In order to optimize the price it receives for the sale of natural 
gas, Atlas markets portions of the gas through long term contracts, 
short term contracts, and monthly spot sales.  The marketing of natural 
gas production has been influenced by the availability of certain 
financial instruments, such as gas futures contracts, options and swaps 
which, when properly utilized as hedge instruments, provide producers 
or consumers of gas with the ability to lock in the price which will 
ultimately be paid for the future deliveries of gas.  Atlas is 
utilizing financial instruments to hedge the price risk of a portion of 
all of its programs' gas production which would include the 
Partnership.  To assure that the financial instruments will be used 
solely for hedging price risks and not for speculative purposes, Atlas 
has established an Energy Price Risk Committee, whose responsibility 
will be to ascertain that all financial trading is done in compliance 
with hedging policies and procedures.  Atlas does not intend to 
contract for positions that it cannot offset with actual production.

There are many companies, partnerships and individuals engaged in 
natural gas exploration, development and operations in the areas where 
the Partnership is conducting its activities.  The industry is highly 
competitive in all phases, including the marketing of natural gas and 
oil.  With respect to the marketing of the Partnership's gas and oil 
the Partnership should, through the use of Atlas' distribution system 
and Atlas' experienced marketing staff, be able to sell the 
Partnership's gas, although there can be no assurance of the price to 
be received by the Partnership for the gas.

The Partnership has not and will not devote any funds to research 
and development activities.  There are no new products or services and 
the Partnership does not have any patents, trademarks, licenses, 
franchises, concessions, royalty agreements or labor contracts.

Oil and gas operations are regulated in Pennsylvania by the 
Department of Environmental Resources, Division of Oil and Gas which 
imposes a comprehensive statutory and regulatory scheme with respect to 
oil and gas operations.   Among other things, the regulations involve:  
(i) new well permit and well registration requirements, procedures and 
fees;  (ii) minimum well spacing requirements;  (iii) restrictions on 
well locations and underground gas storage;  (iv) certain well site 
restoration, groundwater protection and safety measures;  (v) landowner 
notification requirements;  (vi) certain bonding or other security 
measures; (vii) various reporting requirements;  (viii) well plugging 
standards and procedures; and  (ix) broad enforcement powers.  
Generally, the regulatory agency in the state where a producing natural 
gas well is located supervises production activities and the 
transportation of natural gas sold intrastate.  Atlas does not expect 
that these regulations will have a material adverse impact upon the 
operations of the Partnership.  The Partnership believes it has 
complied in all material respects with applicable state regulations and 
will continue to do so.

The Federal Energy Regulatory Commission ("FERC") regulates the 
interstate transportation of natural gas and the pricing of natural gas 
sold for resale interstate; and under the Natural Gas Policy Act of 
1978 ("NGPA") the price of intrastate gas.  Price controls for natural 
gas production from new wells, however, were deregulated on December 
31, 1992.   Deregulated gas production may be sold at market prices 
determined by supply, demand, BTU content, pressure, location of the 
wells, and other factors.  The Managing General Partner anticipates 
that all gas produced by the Partnership wells will be price 
decontrolled gas and sold at fair market value.

Although the transportation and sale of gas in interstate commerce 
remains heavily regulated, FERC has sought to promote greater 
competition in natural gas markets by encouraging open access 
transportation by interstate pipelines, with the goal of expanding 
opportunities for producers to contract directly with local 
distribution companies and end-users.  For example, FERC Order 500 
requires interstate pipelines that transport gas for others to provide 
transportation service to producers, distributors, and all other 
shippers of natural gas on a non-discriminatory, "first-come, first-
served" basis so that producers and other shippers can sell natural gas 
directly to end-users.  FERC Order 636, which became effective in 1992, 
requires gas pipeline companies to, among other things,  separate their 
sales services from their transportation services; and provide an open 
access transportation service that is comparable in quality for all gas 
suppliers.  The premise behind FERC Order 636 was that the gas pipeline 
companies had an unfair advantage over other gas suppliers because they 
could bundle their sales and transportation services together.  FERC 
Order 636 is designed to create a regulatory environment in which no 
gas seller has a competitive advantage over another gas seller because 
it also provides transportation services.  It is difficult to assess 
the effect of the order on the Partnership.

From time to time there are a number of proposals being considered 
in Congress and in the legislatures and agencies of various states that 
if enacted would significantly and adversely affect the oil and natural 
gas industry.  Such proposals involve, among other things, limiting the 
disposal of waste water from wells.  At the present time, it is 
impossible to accurately predict what proposals, if any, will be 
enacted by Congress or the legislatures and agencies of various states 
and what effect any proposals which are enacted will have on the 
activities of the Partnership.

Various federal, state and local laws covering the discharge of 
materials into the environment, or otherwise relating to the protection 
of the environment, may affect the Partnership's operations and costs.  
The Partnership may generally be liable for cleanup costs to the United 
States Government under the Federal Clean Water Act for oil or 
hazardous substance pollution and under the Comprehensive Environmental 
Response, Compensation and Liability Act of 1980 ("CERCLA" or 
Superfund) for hazardous substance contamination. The liability is 
unlimited in cases of willful negligence or misconduct.  There is also 
no limit on liability for environmental cleanup costs or damages with 
respect to claims by the state or private persons or entities.  In 
addition, the Environmental Protection Agency will require the 
Partnership to prepare and implement spill prevention control and 
countermeasure plans relating to the possible discharge of oil into 
navigable waters and will further require permits to authorize the 
discharge of pollutants into navigable waters.  State and local permits 
or approvals will also be needed with respect to wastewater discharges 
and air pollutant emissions.  

Violations of environment-related lease conditions or 
environmental permits can result in substantial civil and criminal 
penalties as well as potential court injunctions curtailing operations.  
Compliance with these statutes and regulations may cause delays in 
producing natural gas and oil from the wells and may increase 
substantially the cost of producing such natural gas and oil.  These 
laws and regulations, however, are constantly being revised and 
changed.  The Partnership is unable to predict the ultimate costs of 
complying with present and future environmental laws and regulations, 
although it does not believe such costs will be substantial.  The 
Partnership is unable to obtain insurance to protect against many 
environmental claims.

The "year 2000 issue" is the result of computer programs being 
written using two digits, rather than four digits, to identify the year 
in a date field.  Any computer programs using such a system which have 
date sensitive software will not be able to distinguish between the 
year 2000 and 1900.  This could result in miscalculations or an 
inability to process transactions, send invoices or engage in similar 
normal business activities.  As is the case with most other businesses, 
Atlas is in the process of evaluating and addressing Year 2000 
compliance of both its information technology and non-information 
technology systems (collectively, the "Systems").

     Based on a recent assessment by Atlas, Atlas believes that the 
Systems for its energy operations have completed approximately 85% of 
the necessary remediation processes and that remediation (including 
testing) will be completed by May 1999.  Atlas believes that its 
embedded systems (such as natural gas monitoring systems and 
telephones) are Year 2000 compliant or, if not, are either not date 
dependent or would not materially affect operations.

     To date, Atlas' costs in remediation of its Systems has not been 
material.  Atlas anticipates that its remaining remediation costs will 
not exceed $100,000.

     Atlas has initiated communications with all of its significant 
business partners through a Vendor Readiness Survey to determine their 
Year 2000 compliance.  Responses are evaluated as they are received to 
determine if additional action is required to ensure compliance of the 
business partner.  As of December 31, 1998, all of Atlas; principal 
business partners have advised Atlas that they are Year 2000 compliant 
or have initiated programs that will render them Year 2000 compliant in 
a timely fashion.

     As a result of its internal assessment and survey of its business 
partners, Atlas currently does not believe that Year 2000 matters will 
have a material impact on its business, financial condition or results 
of operations.  To the extent that any of its business partners are 
materially affected by year 2000 problems, Atlas intends to seek 
alternative firms providing the same services that are Year 2000 
compliant.  In view of the responses from its current business 
partners, Atlas will identify alternative firms on an as-needed basis.  
There can be no assurance, however, that Atlas would be able to make 
appropriate arrangements should the need arise and, accordingly, it is 
uncertain whether or to what extent Atlas may be affected if problems 
with its business partners arise.

     Atlas is aware of the potential for claims against it and other 
companies for damages for products and services that were not Year 2000 
compliant.  Since Atlas is neither a hardware manufacturer nor a 
software developer, Atlas believes that it does not have significant 
exposure to liability for such claims.

ITEM 2.     PROPERTIES

Drilling Activity.   The Partnership drilled 44.45 net wells, of 
which 44.45 net wells were productive. All the wells were drilled and 
completed by the Partnership as of June 29, 1998.  No further drilling 
activities will be undertaken.

The following table summarizes the Partnership's drilling activity 
since its formation.  All the wells drilled were development wells 
which means a well drilled within the proved area of an oil or gas 
reservoir to the depth of a stratigraphic horizon known to be 
productive.  A "dry hole" is an exploratory or a development well found 
to be incapable of producing either oil or gas in sufficient quantities 
to justify completion as an oil or gas well.  A "productive well" is an 
exploratory or a development well that is not a dry well.

Year Ended December 31, 1997  1998 

                         Gross      Net
Development Wells:  Oil     0         0     
                    Gas     55       44.45  
                    Dry     0        0      
                    Total   55       44.45  

     A "gross" well is a well in which the Partnership has a working 
interest.  A "net" well is deemed to exist when the sum of the 
fractional ownership working interests owned by the Partnership in 
gross wells equals one. The number of net wells is the sum of the 
fractional working interests owned in gross wells expressed as whole 
numbers and fractions thereof.

The Partnership has not participated, and will not participate, in 
any exploratory wells which means a well drilled to find commercially 
productive hydrocarbons in an unproved area, to find a new commercially 
productive horizon in a field previously found to be productive of 
hydrocarbons at another horizon, or to significantly extend a known 
prospect.  

Production.   The following table shows the Partnership's net 
production in barrels ("Bbls") of crude oil and in thousands of cubic 
feet ("Mcf") of natural gas and the costs and weighted average selling 
prices thereof, for the periods indicated.

Year Ended December 31, 

                                      1997   1998
Production (1):
Oil (Bbls)                            0          
Natural Gas (Mcf)                     0     816,375          
Total (Equivalent Barrels)  (2)       0     136,063
Average Sales Price:
Per Equivalent Barrel (2)(3)          0     $12.66     
Average Production Cost (lifting cost): 
         Per Equivalent Barrel (2)(4) 0     $1.60

                                                                     
(1)     The production shown in the table is determined by multiplying 
the gross production of properties in which the Partnership has an 
interest by the percentage of the leasehold interest owned by the 
Partnership less the royalty interests of others.  The properties owned 
by the Partnership are subject to a 12.5% landowner's royalty and the 
Partnership has an 87.5% net revenue interest.
(2)     The ratio of energy content of oil and gas (six Mcf of gas 
equals one barrel of oil) was used to convert natural gas production 
into equivalent barrels of oil.
(3)     The average sales price per Mcf of gas sold by the Partnership 
was $2.22 in 1998, after deducting all expenses, including 
transportation expenses.
Production costs represent oil and gas operating expenses as reflected 
in the financial statements of the Partnership plus depreciation of 
support equipment and facilities. 

Summary of Productive Wells.  The table below gives the number of the 
Partnership's productive gross and net wells at December 31, 1998.
Gross     Net     
 55     44.45  All Wells Located in Pennsylvania 

"Productive wells" are producing wells and wells capable of production. 
Oil and Gas Reserves.  All of the Partnership's oil and gas reserves 
are located in the United States. Estimates of the Partnership's net 
proved developed and undeveloped oil and gas reserves as of December 
31, 1998, and the present value (discounted at 10%) of estimated future 
net revenue before income tax from those reserves are set forth in the 
following table.  This information is derived from the engineering 
report dated  January 1, 1999.


                    As of December 31, 1998            Present Value of
                      Net Proved Reserves            Future Net Revenues
                     Oil     Gas     Total
                   (Bbls)   (McF)    (BOE)              (in thousands)
Proved Developed     0      $5,631   5,631                939
Proved Undeveloped   0         0       0
Total                0      $5,631   5,631                $939          

Estimated future net revenues represent estimated future gross 
revenues from the production of proved reserves, net of estimated 
production and future development costs, using prices and costs in 
effect as of December 31, 1998.  These prices were held constant 
throughout the life of the properties except where different prices 
were fixed and determinable from applicable contracts.  These price 
assumptions resulted in a weighted average price of $2.33 per Mcf for 
gas over the life of the properties.  The amounts shown do not reflect 
non-property related costs, such as general and administrative 
expenses, and future income tax expense, or depreciation, depletion and 
amortization.  The present value of estimated future net revenues is 
calculated by discounting estimated future net revenues by 10% 
annually. Prices used in calculating the estimated future net revenues 
attributable to proved reserves do not necessarily reflect market 
prices for oil and gas production subsequent to December 31, 1998.  
There can be no assurance that all of the proved reserves will be 
produced and sold within the periods assumed, that the assumed prices 
will actually be realized for such production, or that existing 
contracts will be honored.  The values expressed are estimates only, 
and may not reflect realizable values or fair market values of the oil 
and gas ultimately extracted and recovered.  The standardized measure 
of discounted future net cash flows may not accurately reflect proceeds 
of production to be received in the future from the sale of oil and gas 
currently owned and does not necessarily reflect the actual costs that 
would be incurred to acquire equivalent oil and gas reserves. For 
additional information concerning oil and gas reserves and activities, 
see Note 9 to the Financial Statements.

"Proved reserves" means the estimated quantities of crude oil, 
natural gas, and natural gas liquids which geological and engineering 
data demonstrate with reasonable certainty to be recoverable in future 
years from known reservoirs under existing economic and operating 
conditions, i.e., prices and costs as of the date the estimate is made.  
Prices include consideration of changes in existing prices provided 
only by contractual arrangements, but not on escalations based upon 
future conditions.
(i)     Reservoirs are considered proved if economic producibility is 
supported by either actual production or conclusive formation test.  
The area of a reservoir considered proved includes (a) that portion 
delineated by drilling and defined by gas-oil and/or oil-water 
contacts, if any; and (b) the immediately adjoining portions not yet 
drilled, but which can be reasonably judged as economically productive 
on the basis of available geological and engineering data.  In the 
absence of information on fluid contacts, the lowest known structural 
occurrence of hydrocarbons controls the lower proved limit of the 
reservoir.
(ii)     Reserves which can be produced economically through 
application of improved recovery techniques (such as fluid injection) 
are included in the "proved" classification when successful testing by 
a pilot project, or the operation of an installed program in the 
reservoir, provides support for the engineering analysis on which the 
project or program was based.
(iii)     Estimates of proved reserves do not include the following: 
(a) oil that may become available from known reservoirs but is 
classified separately as "indicated additional reserves"; (b) crude 
oil, natural gas, and natural gas liquids, the recovery of which is 
subject to reasonable doubt because of uncertainty as to geology, 
reservoir characteristics, or economic factors; (c) crude oil, natural 
gas, and natural gas liquids, that may occur in undrilled prospects; 
and (d) crude oil, natural gas, and natural gas liquids, that may be 
recovered from oil shales, coal, gilsonite and other such sources.

"Proved developed oil and gas reserves" means reserves that can be 
expected to be recovered through existing wells with existing equipment 
and operating methods.  Additional oil and gas expected to be obtained 
through the application of fluid injection or other improved recovery 
techniques for supplementing the natural forces and mechanisms of 
primary recovery should be included as "proved developed reserves" only 
after testing by a pilot project or after the operation of an installed 
program has confirmed through production response that increased 
recovery will be achieved.

The Partnership does not have any proved undeveloped reserves.  
"Proved undeveloped reserves" are reserves that are expected to be 
recovered from new wells on undrilled acreage, or from existing wells 
where a relatively major expenditure is required for recompletion.  
Reserves on undrilled acreage are limited to those drilling units 
offsetting productive units that are reasonably certain of production 
when drilled.  Proved reserves for other undrilled units can be claimed 
only where it can be demonstrated with certainty that there is 
continuity of production from the existing productive formation.  Under 
no circumstances should estimates for proved undeveloped reserves be 
attributable to any acreage for which an application of fluid injection 
or other improved recovery technique is contemplated, unless such 
techniques have been proved effective by actual tests in the area and 
in the same reservoir.

No major discovery or other favorable or adverse event which would 
cause a significant change in estimated reserves is believed by the 
Company to have occurred since December 31, 1998.  Reserves cannot be 
measured exactly as reserve estimates involve subjective judgment.  The 
estimates must be reviewed periodically and adjusted to reflect 
additional information gained from reservoir performance, new 
geological and geophysical data and economic changes.  The Partnership 
has not filed any estimates (on a consolidated basis) of its oil and 
gas reserves with, nor were such estimates included in any reports to, 
any Federal or foreign governmental agency other than the Securities 
and Exchange Commission within the 12 months prior to the date of this 
filing. 

Acreage.  The following table sets forth, as of December 31, 1998, 
the acres of developed and undeveloped oil and gas acreage in which the 
Partnership had an interest.


                  Developed Acreage    Undeveloped Acreage    Total             
Location           Gross     Net        Gross     Net     Gross   Net
Pennsylvania       2,512    2,025        0         0     2,512   2,025
Total              2,512    2,025        0         0     2,512   2,025 

A "gross" acre is an acre in which the Partnership owns a working 
interest.  A "net" acre is deemed to exist when the sum of the 
fractional ownership working interests owned by the Partnership in 
gross acres equals one.  The number of net acres is the sum of the 
fractional working interests owned in gross acres expressed as whole 
numbers and fractions thereof.  "Undeveloped acreage" is those lease 
acres on which wells have not been drilled or completed  to a point 
that would permit the production of commercial quantities of oil and 
gas regardless of whether or not such acreage contains proved reserves.

Delivery Commitments.   The Partnership is not obligated to 
provide any determinable quantity of gas under any existing contracts 
or agreements.  The majority of the Partnership's gas production from 
the wells was sold pursuant to short term contracts, which are term 
contracts for a period of less than one year, with the remainder of the 
Partnership gas production sold on the spot market and long term 
contracts, which are term contracts for a period longer than one year.
===============================================================

ITEM 3.     DIRECTORS, EXECUTIVE OFFICERS AND SIGNIFICANT EMPLOYEES

Responsibilities of Atlas.  The Partnership has no employees and 
relies on Atlas as Managing General Partner of the Partnership.  Atlas 
also serves as driller/operator of the wells.  Atlas has complete and 
exclusive discretion and control over the operations and activities of 
the Partnership and will make all of the Partnership's decisions 
affecting the wells developed by the Partnership.  Atlas will provide 
continuing review and analysis of all wells developed by the 
Partnership and will monitor all expenditures and commitments made on 
behalf of the Partnership.  In addition, Atlas will perform 
administrative services relating to the funding and operation of the 
Partnership, Participant reporting, financial budgeting and 
recordkeeping.

Business of Atlas.  Atlas, a Pennsylvania corporation, was 
incorporated in 1979 and Atlas Energy Group, Inc. ("Atlas Energy"), an 
Ohio corporation, was incorporated in 1973.  As of December 31, 1998, 
Atlas and its affiliates operated approximately 1,399 natural gas wells 
located in Ohio and Pennsylvania.  Atlas and Atlas Energy have acted as 
operator with respect to the drilling of a total of approximately 1,842 
natural gas wells, approximately 1,781 of which were capable of 
production in commercial quantities.  Atlas' primary offices are 
located at 311 Rouser Road, Moon Township, Pennsylvania  15108.
     
On September 29, 1998, Atlas Group, the former parent company of 
Atlas, merged into Atlas America, Inc. ("AAI"), a newly formed wholly-
owned subsidiary of Resource America, Inc. ("RAI").  The merger was 
consummated pursuant to an Agreement and Plan of Merger dated July 13, 
1998, as amended by Amendment No. 1 thereto dated September 29, 1998 by 
and among RAI, AAI, Atlas Group and certain shareholders of Atlas 
Group, (collectively, the "Agreement").  RAI is a publicly-traded 
company principally engaged in real estate finance, equipment leasing 
and energy and energy finance. 
     
AAI will continue the existing business of Atlas Group.  AAI will 
be headquartered in Atlas Group's existing suburban Pittsburgh offices. 
     
There may be changes in the future in the directors and executive 
officers of Atlas.  However, Mr. James R. O'Mara will continue to serve 
Atlas, as well as AAI, as President and Chief Executive Officer 
pursuant to an employment agreement which can be renewed upon the 
expiration of its term.  Additionally, it is anticipated that current 
RAI, AAI and/or Resource Energy, Inc. ("Resource Energy") staff and 
directors of RAI will assume a variety of new operating 
responsibilities in AAI.  Although Resource Energy will maintain its 
separate corporate existence, AAI will manage the employees and assets 
of Resource Energy including sharing common employees.

Atlas and its affiliates under AIC, Inc. employ a total of 
approximately ninety-nine persons, consisting of three geologists  (one 
of whom is an exploration geologist), five landmen, five engineers, 
thirty-three operations staff, eight accounting, one legal, eight gas 
marketing, and eighteen administrative personnel. The balance of the 
personnel are engineering, pipeline and field supervisors.

ORGANIZATIONAL DIAGRAM (1)

Resource America, Inc.Atlas America, Inc.AIC, Inc.Atlas Resources, 
Inc. (Managing General Partner, Driller and Operator in 
Pennsylvania)Mercer Gas Gathering, Inc. (Gas Gathering 
Company)Pennsylvania Industrial Energy, Inc. ("PIE") (Sells Gas to 
Pennsylvania Industry)Atlas Energy Corporation (Managing General 
Partner of Exploratory Drilling Programs and Driller and 
Operator)Transatco, Inc., which owns 50% of Topico (Operates Pipeline 
in Ohio)Anthem Securities Inc. (Registered Broker-Dealer and Dealer-
Manager)Atlas Energy Group, Inc. (Driller and Operator in Ohio)Atlas 
Information Management, L.L.C. (Markets Information and Technology 
Services)ARD Investments, Inc.AED Investments, Inc.

Resource Energy, Inc., a subsidiary of Resource America, Inc., is 
also engaged in the oil and gas business.  As a result of the merger 
there may, in the future, be a consolidation of the existing entities.  
In addition, AAI has agreed to seel its gas marketing subsidiary, Atlas 
Gas Marketing, Inc. to an Affiliate of First Energy (a company listed 
on the New York Stock Exchange).  The Managing General Partner 
anticipates the Partnership's gas would be marketed by First Energy's 
Affiliate, Northeast Ohio Gas Marketing

Directors, Executive Officers and Significant Employees of Atlas.    
The executive officers, directors and significant employees of Atlas 
are as follows:

NAME            AGE       POSITION OR OFFICE     

Charles T. Koval    65     Chairman of the Board and a Director
James R. O'Mara     55     President, Chief Executive Officer and a 
Director
Bruce M. Wolf       50     General Counsel, Secretary and a Director
Donald P. Wagner    56     Vice President-Drilling and Completion  
Frank P. Carolas    38     Vice President of Geology
Tony C. Banks       43     Senior Vice President of Finance and Chief 
Financial Officer
Michael L. Staines  49     Senior Vice President and Chief Operating 
Officer 
Jacqueline B. Poloka47     Controller
John A. Ranieri     38     Director of Gas Marketing
Eric D. Koval       33     President of Anthem Securities, Inc.
Jeffrey C. Simmons  39     Vice President of Production

Charles T. Koval.  Chairman of the Board and a director.  He co-founded 
Atlas Energy.  Mr. Koval is serving and has served as a director of 
Imperial Harbors since 1980.

James R. O'Mara.  President, chief executive officer and a director.  
Mr. O'Mara joined Atlas Energy in 1975.  He is the President of Mercer 
Gas Gathering, Inc. and AAI.

Bruce M. Wolf.   General Counsel, Secretary and a director.  Mr. Wolf 
joined Atlas Energy in January, 1980. Mr. Wolf is the President of 
Atlas Gas Marketing, Inc., AIC, Inc., ARD Investments, Inc. and AED 
Investments, Inc.

Donald P. Wagner.  Vice President-Drilling and Completion   Mr. Wagner 
joined Atlas Energy in 1979.

Frank P. Carolas.  Vice President of Geology.  Mr. Carolas joined Atlas 
Energy in 1981.

Tony C. Banks.  Senior Vice President of Finance and Chief Financial 
Officer.  Mr. Banks joined Atlas Group in 1995. Prior to Mr. Banks 
joining Atlas he had been with affiliates of Consolidated Natural Gas 
Company ("CNG") since 1974.  Mr. Banks started as an accounting clerk 
with CNG's parent company in 1974 and progressed through various 
positions with CNG's Appalachian producer, northeast gas marketer and 
southwest producer to his last position as Treasurer of CNG's national 
energy marketing subsidiary.

Michael L. Staines.  Chief Operating Officer.  Senior Vice President 
and Secretary of RAI since 1989 and President, Chief Executive Officer 
and director of Resource Energy, Inc. ("Resource Energy") (a wholly 
owned subsidiary of RAI) since 1997.

Jacqueline B. Poloka.  Controller.  Ms. Poloka joined Atlas Energy in 
1980.  

Eric D. Koval.  President of Anthem Securities, Inc.  Mr. Koval joined 
Atlas in 1993 as a production engineer specializing in acquisitions and 
dispositions. He subsequently moved into the investor relations 
department in 1994.  Mr. Koval is a registered broker-dealer principal, 
and is the son of Charles Koval.

Jeffrey C.  Simmons.  Vice President of Production.   Executive Vice 
President, Chief Operating Officer and director of Resource Energy 
since 1997.  From 1994 to 1997, he was Vice President - Exploration of 
RAI and, from 1988 to 1994, he was Director of Well Services of RAI.

ITEM 4.     REMUNERATION OF DIRECTORS AND OFFICERS

The Partnership, as previously stated, has no employees.  The 
following table, however, sets forth all cash compensation paid by 
Atlas (which has complete and exclusive discretion and control over the 
operations and activities of the Partnership) during the calendar  
years ended  December 31, 1998 and 1997, to the three most highly 
compensated persons who are executive officers or directors and to all 
executive officers and directors of Atlas as a group, for services in 
all capacities while acting as executive officers or directors of 
Atlas:

          (A)             (B)            (C)        (D)        (E)
Name of Individual or
number of persons in
group(3)
                  Capacities in
                  which served (4)
                                        Cash
                                  Compensation (1)
                                              Compensation
                                              pursuant to
                                               Plans (2)
                                                          Aggregate of
                                                          contingent forms
                                                          of remuneration
James R. O'Mara
President, Chief Executive Officer and a Director
                                    $307,450     $21,457      -------
                                    $305,300     $12,066      -------

Charles T. Koval
Chairman of the Board and  a Director
                                    $298,000      $5,000      -------
                                    $296,500      $5,281      -------
Bruce M. Wolf
General Counsel,  Secretary and a Director
                                    $147,560     $14,059      -------
                                    $217,150     $11,735      -------
Donald P. Wagner
Vice President-Drilling and Completion
                                    $147,560     $14,059      -------
                                    $125,604      $5,281      -------
Tony C. Banks
Senior Vice President and Chief Financial Officer
                                    $143,034     $12,269      -------
                                    $124,000      $3,926      -------

Executive Officers as a Group (8 persons)
                                  $1,534,085    $179,189      -------
                                  $1,383,530     $70,703      -------
          
(1)The amounts indicated were composed of salaries and all cash bonuses 
for services rendered to the Managing General Partner and its 
Affiliates during the last fiscal year, including compensation that 
would have been paid in cash but for the fact the payment of the 
compensation was deferred. 
(2)Atlas Group and its Affiliates had an Employee Stock Ownership Plan 
("ESOP") for the benefit of its employees, other than Messrs. Koval and 
Joseph R. Sadowski (a retired founder), to which it contributed 
annually approximately 6% of annual compensation in the form of shares 
of Atlas Group, and a 401(K) plan which allowed employees to contribute 
the lesser of 15% of their compensation or $10,000 for the calendar 
year 1998 and 1997. Atlas Energy contributed an amount equal to 50% of 
each employee's contribution for the calendar years 1998 and 1997. 
(3)During the Managing General Partner's fiscal year ended July 31, 
1998, each director was paid a director's fee of $12,000 for the year. 
There were no other arrangements for remuneration of directors.

ITEM 5.     SECURITY OWNERSHIP OF MANAGEMENT AND CERTAIN SECURITY 
HOLDERS

As of December 31, 1998, the Partnership had issued and 
outstanding  991.615 Units.   No officer or director of Atlas owns any 
Units, and no partner beneficially owns more than 10% of the 
outstanding Units of the Partnership. 

     RAI owns 100% of the common stock of AAI, which owns 100% of the 
common stock of AIC, Inc., which owns 100% of the common stock of the 
Managing General Partner.  See above regarding the stock options in RAI 
to the executive officers.

ITEM 6.     INTEREST OF MANAGEMENT AND OTHERS IN CERTAIN TRANSACTIONS

Oil and Gas Revenues.  The Managing General Partner is allocated 
25% of the oil and gas revenues of the Partnership in return for paying 
organization and offering costs equal to 15% of the Partnership 
Subscription, 14% of tangible costs and contributing all leases to the 
Partnership.   During the calendar year ending December 31, 1998, the 
Managing General Partner received $ 376,170 from the Partnership's oil 
and gas net revenues.

Leases.  The Managing General Partner initially contributed (at 
the lower of fair market value or the Managing General Partner's cost 
of such prospects)  55 undeveloped prospects to the Partnership to 
drill approximately 44.45 net wells.  With respect to the  prospects 
contributed for these wells Atlas received a credit in the amount of 
$156,420.  During 1998, the Managing General Partner did not enter into 
any further lease transactions and none are anticipated.

Administrative Costs.  The Managing General Partner and its 
affiliates will receive an unaccountable, fixed payment reimbursement 
for their administrative costs determined by the Managing General 
Partner to be an amount equal to $75 per well per month, which will be 
proportionately reduced if less than 100% of the working interest in a 
well is acquired.   With respect to the net wells during the calendar 
year ending December 31, 1998, the Managing General Partner received 
$31,691.

Direct Costs.  The Managing General Partner and its affiliates are 
reimbursed for all direct costs expended on behalf of the Partnership.  
With respect to the net wells during the calendar year ending December 
31, 1998, the Managing General Partner received $109,396.

Drilling Contracts.  On December 31, 1997, the Partnership entered 
into a drilling contract with Atlas to drill and complete 44.45  net 
wells.  The Partnership paid Atlas for drilling and completing the 
Partnership wells an amount equal to $37.39 per foot to the depth of 
the well at its deepest penetration, proportionately reduced if less 
than 100% of the working interest in a well is acquired.   With respect 
to the net wells the total amount received by Atlas was $10,228,088.  
During 1998, the Partnership did not enter into any further drilling 
transactions and none are anticipated. 

Per Well Charges.  Atlas, as operator, is reimbursed at actual 
cost for all direct expenses incurred on behalf of the Partnership and 
receives well supervision fees for operating and maintaining the wells 
during producing operations in the amount of $275 per well per month 
subject to an annual adjustment for inflation.  With respect to the net 
wells during the calendar year ending December 31, 1998, the Managing 
General Partner received $107,823.  The well supervision fees are 
proportionately reduced to the extent the Partnership acquires less 
than 100% of the Working Interest in a well.
As operator Atlas charges the Partnership at cost for third party 
services and materials provided for each well which has been placed in 
operation.

Transportation and Marketing Fees.  The Partnership  pays a 
combined transportation and marketing charge at a competitive rate, 
which is currently 29 cents per MCF, to affiliates of Atlas, with 
respect to natural gas produced by the Partnership.

Other Compensation.  Atlas or an affiliate will be reimbursed by 
the Partnership for any loan Atlas or an affiliate may make to or on 
behalf of the Partnership, and Atlas or the affiliate will have the 
right to charge a competitive rate of interest on any such loan.  If 
Atlas provides equipment, supplies and other services to the 
Partnership it may do so at competitive industry rates.  For the 
calendar year ending December 31, 1998, Atlas did not advance any funds 
nor did it provide any equipment, supplies or other services.
================================================================
PART II

ITEM 7.     MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED 
STOCKHOLDER MATTERS

Market Information.    There is no established public trading 
market for the Investor General Partner interests or the Limited 
Partner interests and it is not anticipated that such a market will 
develop.  The Partnership interests may be transferred only in 
accordance with the provisions of Article 6 of the Partnership 
Agreement.  The principal restrictions on transferability are as 
follows:  (i) the consent of the Managing General Partner is required; 
and (ii) no transfer may be made which would result in materially 
adverse tax consequences to the Partnership or the violation of federal 
or state securities laws.

An assignee may become a substituted Limited Partner or Investor 
General Partner only upon meeting certain further conditions, which 
include: (i) the assignor gives the assignee such right; (ii) the 
Managing General Partner consents to such substitution, which consent 
shall be in the Managing General Partner's absolute discretion; (iii) 
the assignee pays to the Partnership all costs and expenses incurred in 
connection with such substitution; and (iv) the assignee executes and 
delivers such instruments, in form and substance satisfactory to the 
Managing General Partner, necessary or desirable to effect such 
substitution and to confirm the agreement of the assignee to be bound 
by all terms and provisions of the Partnership Agreement.  A substitute 
Limited Partner or Investor General Partner is entitled to all rights 
attributable to full ownership of the assigned Units, including the 
right to vote.

Holders.    As of December 31, 1998, there were 393 investors.

Dividends.   The Managing General Partner will review the accounts 
of the Partnership at least quarterly to determine whether cash 
distributions are appropriate and the amount to be distributed, if any.  
The Partnership will distribute funds to the Managing General Partner 
and the Participants allocated to their accounts which the Managing 
General Partner deems unnecessary to be retained by the Partnership.  
In no event, however, will funds be advanced or borrowed for purposes 
of distributions, if the amount of such distributions would exceed the 
Partnership's accrued and received revenues for the previous four 
quarters, less paid and accrued operating costs with respect to such 
revenues.  The determination of the revenues and costs will be made in 
accordance with generally accepted accounting principles, consistently 
applied.  Cash distributions from the Partnership to the Managing 
General Partner may only be made in conjunction with distributions to 
Participants and only out of funds properly allocated to the Managing 
General Partner's account.  During the calendar year ending December 
31, 1998, the Partnership distributed $806,289 to the Participants and 
$257,732 to the Managing General Partner.

==================================
ITEM 8.     LEGAL PROCEEDINGS
None.
==================================
ITEM 9.     CHANGES IN AND DISAGREEMENTS ON ACCOUNTING AND FINANCIAL 
DISCLOSURE
None.
==================================
ITEM 10.     SUBMISSION OF MATTERS TO A VOTE OF SECURITIES HOLDERS
None, however, see Item 12 below.
==================================
ITEM 11.     COMPLIANCE WITH SECTION 16(A) OF THE EXCHANGE ACT
There are no equity securities registered pursuant to Section 12 of the 
Exchange Act. 
==================================
ITEM 12.     REPORTS ON FORM 8-K
==================================
The registrant filed one report on  Form 8-K during the last 
quarter of the period covered by this report. In December 1998, the 
Partnership engaged Grant Thornton, L.L.P., as the independent 
certified public accountants to audit the Partnership's financial 
statements for the calendar year ended December 31, 1998.  At that 
time, the Partnership chose not to renew the engagement of McLaughlin & 
Courson, who previously served as the Partnership's independent 
certified public accountants.  The decision to change accountants was 
approved by the Board of Directors of the Managing General Partner, 
Atlas.
     
During the period since the formation of the Partnership on July 
1, 1997, and each subsequent interim period, there were no 
disagreements with the former accountants on any matter of accounting 
principles or practices, financial statement disclosure, or auditing 
scope or procedure, which disagreements, if not resolved to the 
satisfaction of the former accountants would have caused them to make 
reference in connection with their report to the subject matter of the 
disagreements.
     
The reports of the former principal accountants on the financial 
statements of the Partnership since its formation on July 1, 1997, 
contained no adverse opinion or disclaimer of opinion, nor were they 
qualified or modified as to uncertainty, audit scope, or accounting 
principles.
==================================
     PART F/S
ITEM 13.     FINANCIAL STATEMENTS
Atlas-Energy for the Nineties - Public #6 Ltd.                    
(A Pennsylvania Limited Partnership)                    
                    
BALANCE SHEETS                    
                    
December 31                    
                    
                    
                             ASSETS                    
                    
                                      1998          1997
                    
Cash                                  7,960              19,459 
Accounts receivable                 444,226              18,076 

Oil and gas wells and leases 
(Successful Efforts)             10,355,660           10,384,508 
  Less accumulated depletion 
and depreciation                 (1,113,233)                   - 
                                ------------          ----------
                                  9,242,427           10,384,508 
Organizational and syndication
 costs, net of accumulated                    
 amortization o f$159,653
 and $-0-, respectively            1,325,501           1,485,154 
                    
                                 $11,020,114         $11,907,197 
                    
                    
                    
LIABILITIES AND PARTNERS' CAPITAL                                     
                    
                    
Advance from Managing General Partner       -                  15,000 
                    
Accounts payable and accrued liabilities   17,725                   - 

Partners' capital                      11,002,389           11,892,197 
                    
                                      $11,020,114           $11,907,197 
                    
Atlas-Energy for the Nineties - Public #6 Ltd.                    
(A Pennsylvania Limited Partnership)                    
                    
STATEMENTS OF EARNINGS                    
                    
For the periods ended December 31                    
                    
                    
                    
                    JULY 1, 1997
                    (DATE OF FORMATION)
                    TO DECEMBER 31,
                                          1998               1997
Revenues                    
   Natural gas sales                $ 1,721,899                - 
   Interest income                        4,530           22,535 
                                      1,726,429           22,535 

Expenses                    
   Well operating expense               217,219                - 
   Depletion and depreciation of oil and gas                     
       wells and leases               1,113,233                - 
   Amortization of organizational
 and syndication costs                  159,653                - 
   General and administrative fees       43,819                - 
                    
            Total expenses            1,533,924                - 
                    
               NET EARNINGS             192,505           22,535 
                    
Atlas-Energy for the 
Nineties - Public #6 Ltd.                              
(A Pennsylvania Limited Partnership)                              
                              
STATEMENTS OF CHANGES IN PARTNERS' CAPITAL 
For the periods ended December 31, 1998 and 1997 
                              
                              
                              
                              MANAGING                    
                              GENERAL          OTHER          
                              PARTNER          PARTNERS          TOTAL
                              
BALANCE AT JULY 1, 1997          $-            $-                $- 
                              
Participation in revenue and expenses:                              
   Interest income                -             22,535         22,535 
          Net earnings            -             22,535          22,535 
Contributions              1,968,637         9,901,025       11,869,662 
                              
BALANCE AT 
DECEMBER 31, 1997          1,968,637         9,923,560       11,892,197 
                              
Participation in revenue 
and expenses 
   Net production revenues   376,170         1,128,510        1,504,680 
   Interest income             1,132             3,398            4,530 
   Depletion and depreciation:                                         
      Oil and gas wells      (35,513)       (1,077,720)     (1,113,233)
      Amortization          (159,653)            -            (159,653)
   General and 
administrative fees         (10,955)           (32,864)        (43,819)
          Net earnings       171,181            21,324         192,505 
                              
Adjustments to 
assets contributed                              
    by partners             (14,940)            (3,352)        (18,292)
Distributions               (257,732)         (806,289)     (1,064,021)
                              
BALANCE AT 
DECEMBER 31, 1998        $ 1,867,146        $9,135,243    $  11,002,389 
                              
Atlas-Energy for the Nineties - Public #6 Ltd.                    
(A Pennsylvania Limited Partnership)                    
                    
STATEMENTS OF CASH FLOWS                    
                    
For the periods ended December 31                    
                    
                    
                    JULY 1, 1997
                    (DATE OF FORMATION)
                    TO DECEMBER 31,
                                          1998                     1997
Cash flows from operating activities:                    
                    
   Net earnings                         192,505                  22,535 
                    
   Adjustments to reconcile net earnings to net cash provided by 
      operating activities:                    
          Depletion and depreciation   1,113,233                      - 
          Amortization                 159,653                        - 
          Adjustment to oil and 
          gas wells and leases          10,556                        - 
    Increase in accounts receivable   (426,150)                (18,076)
          (Decrease) increase in
 advance from Managing General Partner (15,000)                 15,000 
          Increase in accounts 
payable and accrued liabilities         17,725                       - 
                    
     Net cash provided 
     by operating activities         1,052,522                  19,459 
 
                    
Cash flows used in investing activities:                    
    Payments for oil and 
gas well drilling contracts                -                (9,901,025)
                    
                    
Cash flows from financing activities:                    
    Partners' contributions                -                 9,901,025 
   Capital distributions           (1,064,021)                       - 
                    
  Net cash (used in) provided 
by financing activities            (1,064,021)               9,901,025 
                    
NET (DECREASE) INCREASE IN CASH       (11,499)                  19,459 
                    
Cash at beginning of year              19,459                        - 
                    
Cash at end of year                     7,960                   19,459 
                    
                    
SUPPLEMENTAL SCHEDULE OF NONCASH ACTIVITIES:                    
   Assets contributed
 by Managing General Partner              -                  1,968,637 
                    
   Adjustments to assets 
contributed by partners              (18,292)                        - 
                    
                    
                    
The accompanying notes are an integral part of these financial 
statements.
ATLAS-ENERGY FOR THE NINETIES - PUBLIC #6 LTD.
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL STATEMENTS

December 31, 1998 and 1997


A summary of significant accounting policies consistently applied in 
the preparation of the accompanying financial statements follows:

1. NATURE OF OPERATIONS

Atlas-Energy for the Nineties - Public #6 Ltd. (the "Partnership") 
is a Pennsylvania Limited Partnership which includes Atlas 
Resources, Inc. ("Atlas") of Pittsburgh, Pennsylvania, as Managing 
General Partner and Operator, and 393 other investors as either 
Investor General Partners or Limited Partners.  The Partnership 
was formed on July 1, 1997 to drill and operate gas wells located 
primarily in Mercer County, Pennsylvania.  At December 31, 1998, 
the Partnership has various working interests in 55 wells.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The financial statements are prepared in accordance with generally 
accepted accounting principles.

The Partnership uses the successful efforts method of accounting 
for oil and gas producing activities.  Costs to acquire mineral 
interests in oil and gas properties and to drill and equip wells 
are capitalized.  Depreciation and depletion is computed on a 
field-by-field basis by the unit-of-production method based on 
periodic estimates of oil and gas reserves.

Undeveloped leaseholds and proved properties are assessed 
periodically or whenever events or circumstances indicate that the 
carrying amount of these assets may not be recoverable.  Proved 
properties are assessed based on estimates of future cash flows.

The preparation of financial statements in conformity with 
generally accepted accounting principles requires management to 
make estimates and assumptions that affect the amounts reported in 
the financial statements and accompanying notes.  Actual results 
could differ from those estimates.

In 1998, the AICPA issued Statement of Position 98-5 ("SOP 98-5"), 
Reporting on the Costs of Start-Up Activities.  This statement requires costs of
start-up activities and organization costs, as defined, to be 
expensed as incurred.  The Partnership is required to adopt the 
provisions of SOP 98-5 effective January 1, 1999 and as a result 
will write-off the unamortized organization and syndication costs 
as a charge against Partners' Capital.

3. FEDERAL INCOME TAXES

The Partnership is not treated as a taxable entity for federal 
income tax purposes.  Any item of income, gain, loss, deduction or 
credit flows through to the partners as though each partner had 
incurred such item directly.  As a result, each partner must take 
into account his pro rata share of all items of partnership income 
and deductions in computing his federal income tax liability.
 

ATLAS-ENERGY FOR THE NINETIES - PUBLIC #6 LTD.
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL STATEMENTS - CONTINUED

December 31, 1998 and 1997



4. PARTICIPATION IN REVENUES AND COSTS

Atlas and the other partners generally participate in revenues and 
costs in the following manner:



                                           ATLAS      SUBSCRIBING 
                                                        PARTNERS
Organization and offering costs             100%           0%
Lease costs                                 100%           0%
Revenues                                     25%          75%
Direct operating costs                       25%          75%
Tangible costs                               14%          86%
Tax deductions:
 Intangible drilling and development costs    0%         100%
 Depreciation                                14%          86%
 Depletion allowances                        25%          75%


5. TRANSACTIONS WITH ATLAS AND ITS AFFILIATES

The Partnership has entered into the following significant 
transactions with Atlas and its affiliates as provided under the 
Partnership agreement:

Drilling contracts to drill and complete Partnership wells at 
a
cost of $37.39 per foot on completed wells.  The total amount
paid to Atlas for well drilling contracts was $9,901,025, all 
in 1997. 

Administrative costs at $75 per well per month.  
Administrative
costs totaled $31,691 in 1998.

Well supervision fees initially of $275 per well per month 
plus the
cost of third party materials and services.  Well supervision 
fees
totaled $107,823 in 1998.

Reimbursement of gas transportation and marketing charges.


6. PURCHASE COMMITMENT

Subject to certain conditions, investor partners may present their 
interests beginning in 2001 for purchase by Atlas.  Atlas is not 
obligated to purchase more than 5% of the units in any calendar 
year.



ATLAS-ENERGY FOR THE NINETIES - PUBLIC #6 LTD.
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL STATEMENTS - CONTINUED

December 31, 1998 and 1997



7. SUBORDINATION OF MANAGING GENERAL PARTNER'S
REVENUE SHARE

Atlas will subordinate a part of its partnership revenues in an 
amount up to 10% of production revenues of the Partnership, net of 
related operating costs, administrative costs and well supervision 
fees to the receipt by participants of cash distributions from the 
Partnership equal to at least 10% of their agreed subscriptions of 
$9,901,025, determined on a cumulative basis, in each of the first 
five years of Partnership operations, commencing with the first 
distribution of revenues to the participants.

8. INDEMNIFICATION

In order to limit the potential liability of the investor general 
partners, Atlas and Atlas America, Inc., formerly The Atlas Group, 
Inc. (parent company of Atlas) have agreed to indemnify each 
investor general partner from any liability incurred which exceeds 
such partner's share of Partnership assets.

9. NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED)

The supplementary information summarized below presents the 
results of natural gas and oil activities in accordance with SFAS 
No. 69, "Disclosures About Oil and Gas Producing Activities".

No consideration has been given in the following information to 
the income tax effect of the activities as the Partnership is not 
treated as a taxable entity for income tax purposes.

(1) CAPITALIZED COSTS

The following table presents the capitalized costs related to 
natural gas and oil product activities:



       
                                               1998            1997
Capitalized costs at December 31:
     Proved properties                      $10,355,660    $10,384,508
     Accumulated depreciation 
     and depletion                           (1,113,233)         - 
               NET CAPITALIZED COSTS          $9,242,427    $10,384,508

Costs incurred during the year:
     Development costs                             -        $ 9,901,025

          


ATLAS-ENERGY FOR THE NINETIES - PUBLIC #6 LTD.
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL STATEMENTS - CONTINUED

December 31, 1998 and 1997



9. NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED)
(CONTINUED)

(1) CAPITALIZED COSTS - CONTINUED

Development costs include costs to gain access to and prepare 
development well locations for drilling, to drill and equip 
development wells and to provide facilities to extract, treat, 
gather and store oil and gas.

(2) RESULTS OF OPERATIONS FOR PRODUCING ACTIVITIES

The following table presents the results of operations related to 
natural gas and oil production for the  year  ended  December 31, 
1998 and the period July 1, 1997 (date of formation) to December 
31, 1997:


       
                                             1998   

Natural gas sales                        $1,721,899
Production costs                           (217,219)
Depreciation, depletion and amortization (1,113,233)

Results of operations from 
producing activities                        391,447

Depreciation and depletion of natural gas and oil properties are 
expensed at unit cost rates calculated annually based on the 
estimated volume of recoverable gas and the related costs.

(3) RESERVE INFORMATION

The information presented below represents estimates of proved 
natural gas and oil reserves.  Proved developed reserves represent 
only those reserves expected to be recovered from existing wells 
and support equipment.  All reserves are proved developed reserves 
and are located in Western Pennsylvania.

There are numerous uncertainties inherent in estimating quantities 
of proved reserves and in projecting future net revenues and the 
timing of development expenditures.  The reserve data presented 
represents estimates only and should not be construed as being 
exact.  In addition, the standarized measures of discounted future 
net cash flows may not represent the fair market value of the 
Company's oil and gas reserves or the present value of future cash 
flows of equivalent reserves, due to anticipated future changes in 
oil and gas prices and in production and development costs and 
other factors for which effects have not been provided.



ATLAS-ENERGY FOR THE NINETIES - PUBLIC #6 LTD.
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL STATEMENTS - CONTINUED

December 31, 1998 and 1997



9. NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED)
(CONTINUED)

(3) RESERVE INFORMATION - CONTINUED


                                              1998

                                          NATURAL GAS
                                               MCF
Proved developed reserves:

   Beginning of period                          -
   Production                               (816,375)   
   Current additions                       6,447,443
   End of period                           5,631,068


(4) STANDARD MEASURE OF DISCOUNTED FUTURE CASH FLOWS

The standardized measure of discounted future net cash flows is 
information provided for the financial statement user as a common 
base for comparing oil and gas reserves of enterprises in the 
industry.  The following schedule presents the standardized 
measure of estimated discounted future net cash flows from the 
Company's proved reserves.  Estimated future cash flows are 
determined by using the weighted average price received for the 
month of December 1998 adjusted only for fixed and determinable 
increases in natural gas prices provided by contractual 
agreements.  The standardized measure of future net cash flows was 
prepared using the prevailing economic conditions existing at 
December 31, 1998 and such conditions continually change.  
Accordingly, such information should not serve as a basis in 
making any judgement on the potential value of recoverable 
reserves or in estimating future results of operations.



       
                                                   1998 
Future cash inflows                           $13,137,280  
Future production costs                        (5,485,285)
     Future net cash flow                       7,651,995
10% annual discount for 
estimated timing of cash flows                 (3,166,039)
 STANDARDIZED MEASURE OF 
 DISCOUNTED FUTURE NET CASH FLOWS            $  4,485,956





ATLAS-ENERGY FOR THE NINETIES - PUBLIC #6 LTD.
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL STATEMENTS - CONTINUED

December 31, 1998 and 1997



9. NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED)
(CONTINUED)

(4) STANDARD MEASURE OF DISCOUNTED FUTURE CASH FLOWS - CONTINUED

Summary of changes in the standardized measure of discounted 
future net cash flows:



                                               1998
Sales of gas and oil produced 
- net of related costs                      $(1,504,680)
Net changes in prices,production and
   development costs                              -
Discoveries and extensions                    5,990,636
Accretion of discount                             -
          Net increase                        4,485,956
Beginning of period                               -
END OF PERIOD                               $ 4,485,956



--------------------------------------------------------------

REPORT OF INDEPENDENT CERTIFIED PUBLIC ACCOUNTANTS





TO THE PARTNERS
ATLAS-ENERGY FOR THE NINETIES - PUBLIC #6 LTD.
A PENNSYLVANIA LIMITED PARTNERSHIP


We have audited the accompanying balance sheet of Atlas-Energy for The 
Nineties - Public #6 Ltd., A Pennsylvania Limited Partnership, as of 
December 31, 1998, and the related statements of earnings, changes in 
partners' capital accounts and cash flows for the year then ended.  
These financial statements are the responsibility of the Partnership's 
management.  Our responsibility is to express an opinion on these 
financial statements based on our audit.
 
We conducted our audit in accordance with generally accepted auditing 
standards.  Those standards require that we plan and perform the audit 
to obtain reasonable assurance about whether the financial statements 
are free of material misstatement.  An audit includes examining, on a 
test basis, evidence supporting the amounts and disclosures in the 
financial statements.  An audit also includes assessing the accounting 
principles used and significant estimates made by management, as well 
as evaluating the overall financial statement presentation.  We believe 
that our audit provides a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present 
fairly, in all material respects, the financial position of Atlas-
Energy for The Nineties - Public #6 Ltd. as of December 31, 1998 and 
the results of its operations and cash flows for the year then ended, 
in conformity with generally accepted accounting principles.


Cleveland, Ohio
March 1, 1999

----------------------------------------------------------------

     PART III
ITEM 14.  EXHIBITS
--------------------------------------------------------------
Description Location
4(a)Certificate of Limited Partnership for 
Atlas-Energy for the Nineties-Public #6 Ltd. 

Previously filed in the Form 10-KSB for the period ending December 31, 
1997.
---------------------------------------------------------------
4(b)Amended and Restated Certificate and Agreement
of Limited Partnership for Atlas-Energy for the
Nineties-Public #6 Ltd. dated December 31, 1997

Previously filed in the Form 10-KSB for the period ending December 31, 
1997.
---------------------------------------------------------------
10(a)Drilling and Operating Agreement updated exhibits
                         March 31, 1999

1998 Fiscal Year Annual Report to Participants
in Atlas-Energy for the Nineties-Public #6 Ltd.
Pursuant to Section 4.03(b)(1) of the Partnership Agreement

(a)     Audited financial statements of the Partnership for the fiscal 
year ending December 31, 1998, are included in this report.
   
(b) The Partnership total fees and compensation including any 
unaccountable, fixed payment reimbursements for Administrative 
Costs and Operating Costs, paid by the Partnership, or indirectly 
on behalf of the Partnership, to the Managing General Partner, the 
Operator and their Affiliates.  $261,039.

Percentage that the annual unaccountable fixed fee reimbursement 
for Administrative Costs bears to annual Partnership revenues.  
2.23%

(c)     The following table describes the Partnership's 55 gross wells 
(44.45 net wells) drilled in 1998.

The following wells were removed from the partnership and wells were 
substituted.
     George #2
     Kaltenbaugh #2
     Kingery #2
     McCartney #1
     Plants #1
     Rick #1
     Roman #1
     Shardy #1
     Sines #4
     Tinney Unit #1
     Wiese #1
     Whyte #4
     Williams #4


(d) Quarterly distributions are made in March, June, September and 
December.  There were three quarterly distributions in 1998 for 
nine months of natural gas production from the partnership's fifty 
five wells located in Lawrence and Mercer, Pennsylvania.

Checks were sent on February 27, 1998 to those partners who earned 
interest while their subscriptions were in the escrow account.  
Checks were sent on September 8, 1998 to each partner for the 
refund of unused drilling funds, prorated according to their 
percentage interest in the partnership.  The total of unused 
drilling funds amounted to $10,556.

(e) There were no farmins and joint ventures in 1998.

(---------------------------------------------------------------



===============================================================
CONSENT OF INDEPENDENT AUDITOR

                          McLAUGHLIN & COURSON
                      CERTIFIED PUBLIC ACCOUNTANTS
                       2002 LAW & FINANCE BUILDING
                         PITTSBURGH, PA 15219

                               412/261-0630
                             FAX 412/261-3582


CONSENT OF INDEPENDENT AUDITOR

ATLAS-ENERGY FOR THE NINETIES-PUBLIC 6 LTD.


The firm, as Independent Certified Public Accountants, hereby consents 
to the use of the audit report dated February 10, 1998, on the balance 
sheet of Atlas-Energy for the Nineties-Public #6 Ltd., a Pennsylvania 
Limited Partnership as of December 31, 1997, and the related statements 
of income, changes in partners, capital accounts and cash flows for the 
year then ended, in the U.S. Securities and Exchange Commission Form 
10-KSB for the year ended December 31, 1998 and any amendments thereto 
for Atlas-Energy for the Nineties-Public #6 Ltd.


                            /s/McLaughlin & Courson
                               Certified Public Accountants


                               April 9, 1999
                               Pittsburgh, Pennsylvania


================================================================

     SIGNATURES


In accordance with Section 13 or 15(d) of the Exchange Act, the 
registrant caused this report to be signed on its behalf by the 
undersigned, thereunto duly authorized.


Atlas-Energy for the Nineties-Public #6 Ltd.

By:  (Signature and Title):      Atlas Resources, Inc., Managing 
General Partner

By   (Signature and Title):     /s/ James R. O'Mara 
James R. O'Mara, President, Chief Executive Officer
and a Director
Date:  April 15,1999


In accordance with the Exchange Act, this report has been signed by the 
following persons on behalf of the registrant and in the capacities and 
on the dates indicated.


By  (Signature and Title):     /s/ Charles T. Koval 
Charles T. Koval, Chairman of the Board and a Director
Date: April 15,1999


By  (Signature and Title):     /s/ James R. O'Mara 
James R. O'Mara, President, Chief Executive Officer and 
  a Director
Date: April 15,1999


By  (Signature and Title):     /s/ Bruce M. Wolf 
Bruce M. Wolf, General Counsel, Secretary and a Director
Date: April 15,1999


By  (Signature and Title):     /s/ Tony  C. Banks 
Tony C. Banks, Vice President of Finance and Chief Financial Officer
Date: April 15,1999


Supplemental information to be Furnished
With Reports Filed Pursuant to Section 15(d)
of the Exchange Act by Non-reporting Issuers

An annual report will be furnished to security holders subsequent to 
the filing of this report.