U.S. Securities and Exchange Commission

                          Washington, D.C.  20549

                              FORM 10-KSB
                                AMENDED

(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, 1997

[    ]     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  33-95330

                Atlas-Energy for the Nineties-Public #4 Ltd.
                (Name of small business issuer in its charter)

          Pennsylvania                                  25-1772474
(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   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.  $1,094,717

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      No ___

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

     PART I

ITEM 1.      DESCRIPTION OF BUSINESS

Atlas-Energy for the Nineties-Public #4 Ltd. (the "Partnership") 
was formed under the Pennsylvania Revised Uniform Limited Partnership 
Act on July 5, 1995, with Atlas Resources, Inc. ("Atlas") as Managing 
General Partner. The Partnership had its initial and final closing on 
December 27, 1995, and was funded with subscriptions of $6,991,350 to 
drill natural gas development wells.  Also, on December 27, 1995, the 
Managing General Partner was credited with a total capital contribution 
of $1,423,652 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.   Because the initial and final 
closing date was December 27, 1995, the Partnership  did not conduct 
any drilling activities in 1995; however, the Partnership did prepay 
the drilling costs pursuant to the Drilling and Operating Agreement 
with Atlas on December 27, 1995, in an amount equal to $7,230,399 to 
drill 31.5 development wells to the Clinton/Medina geological formation 
in Mercer and Venango Counties, Pennsylvania.  Atlas and its 
affiliates' had sufficient leasehold inventory to provide the prospects 
to be developed by the Partnership.  See  "Properties".
For the next twelve months management believes that the Partnership 
has adequate capital in order to conduct its operations.  The 
Partnership had sufficient capital resources from the closing to drill 
and develop approximately 31.5 net wells.  No other wells will be 
drilled and therefore no additional funds will be required. The payment 
of operating 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 being 
fulfilled through revenues generated from the sale of gas.  During 
producing operations Atlas, as operator, receives 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 are billed 
at the invoice cost of materials purchased or third party services 
performed.  As operator Atlas charges 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 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 is also 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.
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 is 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 100 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 1998, 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 1998.  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 its programs' gas production which includes 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 composed of the President, General Counsel, 
Chief Financial Officer (chairperson) and Director of Marketing, 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 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. 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 May 18, 
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. 

The Partnership does not expect to sell any oil.

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, the 
imposition of new taxes on natural gas and 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 also is 
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.

ITEM 2.     PROPERTIES

DRILLING ACTIVITY.  The Partnership drilled 31.5 net wells, all of 
which were productive.  All the wells were drilled and completed by the 
Partnership as of March 31, 1996.  No further drilling activities will 
be undertaken.
The following table summarizes the Partnership's drilling activity 
since its formation.  All of 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,
                 1995               1996              1997
             GROSS   NET        GROSS   NET        GROSS     NET

Development Wells:
Oil          0       0           0      0            0        0
Gas          0       0           32     31.5         32       31.5
Dry                                   
Total        0       0           32     31.5         32       31.5

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,
                                        1995  1996        1997
Production (1):
Oil (Bbls)                               0     0           0
Natural Gas (Mcf)                        0     523,279     401,575
Total (Equivalent Barrels)  (2)          0     87,214      66,929Average 
Sales Price:
Per Equivalent Barrel (2)(3)             0     $13.44      14.30Average 
Production Cost (lifting cost): 
         Per Equivalent Barrel (2)(4)    0     $1.44        2.05
(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.  Thirty-one of 
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.  One property is subject to a 1/32 (3.125%) overriding 
royalty interest in addition to a 12.5% landowner's royalty and the 
Partnership has an 84.37% 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 $2.29 in 1996 and $2.38 in 1997 after deducting all expenses, 
including transportation expenses.  
(4)     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, 1997.

                  GAS WELLS             OIL WELLS          TOTAL WELLS   
               GROSS     NET          GROSS      NET     GROSS    NET
Pennsylvania     32     31.5            0         0       32     31.5      
Total            32     31.5            0         0       32     31.5

"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, 1997, 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

                          AS OF DECEMBER 31, 1997

                        Oil      Gas           Total     PRESENT VALUE
                       (BBLS)   (MCF)          (BOE)     OF FUTURE NET
                                                         REVENUES
                                                         (in thousands)
Proved Developed         0      2,321,941      386,990     $1,867
Proved Undeveloped       0              0            0          0
Total                    0      2,321,941      386,990     $1,867

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, 1997.  These prices were held constant 
throughout the life of the properties except when different prices were 
fixed and determinable from applicable contracts.  These price 
assumptions resulted in a weighted average price of $2.52 per Mcf for 
gas over the life of the properties.  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, 1997.  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.  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, 1997.  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, 1997, 
the acres of developed and undeveloped oil and gas acreage in which the 
Partnership had an interest.
                  DEVELOPED          UNDEVELOPED          TOTAL  
  LOCATION 
Pennsylvania   GROSS       NET         GROSS     NET   GROSS        NET
Total          1,599.52    1,563.62        0       0   1,599.52     1,563.62

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.  Atlas and Atlas Energy are 
wholly owned subsidiaries of AIC, Inc., a corporation formed in July, 
1995, which is a wholly owned subsidiary of The Atlas Group, Inc., 
("Atlas Group") that was formerly known as AEG Holdings, Inc., a 
corporation which was also formed in July, 1995.  
As of December 31, 1997, Atlas and its Affiliates operated 
approximately 1,240 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 1,700 natural gas wells, 
approximately 1,660 of which were capable of production in commercial 
quantities.  Atlas' primary offices are located at 311 Rouser Road, 
Moon Township, Pennsylvania  15108.
Atlas and its affiliates 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.
The other subsidiaries of AIC, Inc. are:  (i) Atlas Gas Marketing, 
Inc., a gas marketing company; (ii) Mercer Gas Gathering, Inc., a gas 
gathering company which gathers gas from Atlas and its affiliates' 
wells in Mercer County, Pennsylvania, and delivers the gas directly to 
industrial end-users or to interstate pipelines and local distribution 
companies; (iii) Pennsylvania Industrial Energy, Inc., which sells 
natural gas to industrial end-users in Pennsylvania; (iv) Transatco, 
Inc., which owns a 50% interest in Topico which operates a pipeline in 
Ohio; (v) Atlas Energy Corporation, which serves as managing general 
partner of exploratory programs and driller and operator; and (vi) 
Anthem Securities, Inc., which is a registered broker-dealer and a 
member firm of the NASD and serves as dealer-manager of Atlas-sponsored 
programs.  In addition, Atlas is the sole owner of ARD Investments, 
Inc., a corporation formed in July, 1995, and Atlas Energy is the sole 
owner of AED Investments, Inc., a corporation formed in July, 1995.  
Prior to July, 1995, all of the Atlas companies were wholly owned by 
Atlas Energy.  The purpose of forming Atlas Group, AIC, Inc., ARD 
Investments, Inc. and AED Investments, Inc. was to achieve more 
efficient concentration of funds of the Atlas group of companies, 
thereby minimizing transaction costs and maximizing returns on 
investment vehicles.

Atlas and its affiliates have constructed for their use over 600 
miles of gas transmission lines and produce in excess of nine billion 
cubic feet of natural gas annually from wells they operate which they 
market directly to end-users or to interstate pipelines and local 
distribution companies.  In addition, Atlas Gas Marketing, Inc. (an 
affiliate) purchases for resale an additional eight billion cubic feet 
of natural gas annually from third party producers locally and in the 
south/southwest United States which is marketed as described in 

                     "Description of Business."

                       ORGANIZATIONAL DIAGRAM

                       The Atlas Group, Inc.
                                 |
-----------------------------AIC, Inc.
|
|-Atlas Resources, Inc. (Managing General Partner of Development 
| Drilling Programs, Driller and Operator in Pennyslvania)
|                                                    |ARD Investments, Inc.
|
|
|-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)
|
|-Atlas Gas Marketing, Inc. (Markets Natural Gas)
|
|-Anthem Securities Inc. (Registered Broker-Dealer)
|
|-Atlas Energy Group, Inc. (Driller and Operator in Ohio)
                                                | AED Investments, Inc.

DIRECTORS, EXECUTIVE OFFICERS AND SIGNIFICANT EMPLOYEES OF ATLAS.    
The executive officers, directors and significant employees of Atlas 
who are also officers, directors and significant employees of Atlas 
Group and Atlas Energy are as follows:
          
Charles T. Koval   63     Chairman of the Board and a Director
James R. O'Mara    53     President, Chief Executive Officer and a Director
Bruce M. Wolf      48     General Counsel, Secretary and a Director
James J. Kritzo    62     Vice President of the Land Department
Donald P. Wagner   55     Vice President of Operations
Frank P. Carolas   37     Vice President of Geology
Tony C. Banks      42     Vice President of Finance and CFO
Barbara Krasnicki  52     Vice President of Administration
Jacqueline Poloka  46     Controller
John A. Ranieri    37     Director of Gas Marketing
Eric D. Koval      32     President of Anthem Securities, Inc.
Joseph R. Sadowski 66     Director

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.

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.

JAMES J. KRITZO.  Vice President of the Land Department.  Mr. 
Kritzo joined the Land Department of Atlas Energy in 1979.

DONALD P. WAGNER.  Vice President of Operations.  Mr. Wagner joined 
Atlas Energy in 1979.

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

TONY C. BANKS.  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.

BARBARA J. KRASNICKI.  Vice President of Administration, Ms. 
Krasnicki has been with Atlas Energy since its inception in 1971.

JACQUELINE B. POLOKA.  Controller.  Ms. Poloka joined Atlas Energy 
in 1980.  

JOHN A. RANIERI.  Director of Gas Marketing for Atlas Gas 
Marketing, Inc.  Mr. Ranieri was promoted to Gas Procurement Manager of 
Columbia Gas of Pennsylvania in 1984 and remained with that 
organization until joining Atlas in July, 1990.

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.

JOSEPH R. SADOWSKI.  A director.  He co-founded Atlas Energy.  Mr. 
Sadowski has served as a director of Dixon Ticonderoga since 1987.

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 Atlas' fiscal year 
ended July 31, 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:

    NAME OF INDIVIDUAL                      
    OR IDENTITY OF          CAPACITIES IN WHICH              CASH     
    GROUP(3)                REMUNERATION WAS RECEIVED(4)     COMPENSATION(1,2)

James R. O'Mara         President, Chief Executive Officer     $305,300
                         and a Director
Charles T. Koval        Chairman of the Board                  $296,500
and a Director
Bruce M. Wolf           General Counsel, Secretary             $217,150
                         and a Director
Executive Officers                                             $1,383,530
as a Group (8 persons)

(1)     The amounts indicated were composed of salaries and all cash 
bonuses for services rendered to Atlas and its affiliates during 
the last fiscal year, including compensation that would have been 
paid in cash but for the fact the payment of such compensation was 
deferred.

(2)     Atlas has an "ESOP" retirement plan, described below, and has a 
401(K) plan which allowed employees to contribute the lesser of 15% 
of their compensation or $9,500 for the calendar year 1997 or 
$9,500 for the calendar year 1996.  Atlas contributed an amount 
equal to 50% and 50% of each employee's contribution for the 
calendar years July 31, 1997 and 1996, respectively.

(3)     There were no stock options granted or exercised during the 
fiscal year ended July 31, 1997, to the above individuals.
(4)  During the fiscal year ended July 31, 1997, each director was
paid a director's fee of $12,000 for the 
year. There are no other arrangements for remuneration of directors.

ITEM 5. SECURITY OF MANAGEMENT AND CERTAIN SECURITYHOLDERS

As of December 31, 1997, the Partnership had issued and outstanding 
700 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. 

Atlas Group owns 100% of the common stock of AIC, Inc. which owns 
100% of the common stock of Atlas and Atlas Energy.  The following 
table sets forth, as of December 31, 1997, information as to the 
beneficial ownership of common stock of Atlas Group by each person 
known to Atlas Group to own beneficially 5% or more of the outstanding 
common stock of Atlas Group, by directors and nominees, naming them 
individually, and by all directors and officers of Atlas Group as a 
group:
       
                               SHARES OF COMMON     PERCENT OF CLASS
Charles T. Koval                  109,391                    26.445%
Joseph R. Sadowski.               109,142                    26.384%
James R. O'Mara                    95,164     (1)            23.005%
Bruce M. Wolf                      44,710     (2)            10.808%
   Directors and Officers
 as Group (9 persons)             377,654     (1)(2)         91.344%

(1)     Includes 22,164 shares of Atlas Group issuable upon the 
exercise of stock options held by Mr. O'Mara.

(2)     Includes 14,210 shares of Atlas Group issuable upon the 
exercise of stock options held by Mr. Wolf.

Atlas Group has adopted Atlas Energy's existing Employee Stock 
Ownership Plan ("ESOP") for the benefit of its employees, other than 
Messrs. Koval and Sadowski, to which it will contribute annually 
approximately 6% of annual compensation in the form of shares of Atlas 
Group. Atlas Group anticipates that it will contribute approximately 
3,000 shares of its stock to the ESOP each year.
Pursuant to agreements entered into between Atlas Group and its 
shareholders to accommodate the desire of Messrs. Sadowski and Koval to 
gradually liquidate a majority of their stock ownership in Atlas Group 
in preparation for their respective retirement from Atlas Group it is 
anticipated that by the year 2003 the stock ownership of Atlas Group by 
Messrs. Koval and Sadowski will be reduced through a series of stock 
redemptions to approximately 15% each.  The stock ownership of certain 
of the remaining officers will be increased to approximately 60%, in 
the aggregate; and the stock ownership of the ESOP will be 
approximately 10%.  

The stock redemptions require Atlas Group to execute promissory 
notes, from time to time, in favor of Messrs. Koval and Sadowski, the 
first of which, in the original principal amount of  $4,974,340 each, 
plus interest at 13.5% were executed by Atlas Energy and were assumed 
by Atlas Group.  These promissory notes are totally subordinated to 
Atlas Group's obligations to banks, the ESOP and any and all other 
debts or obligations of Atlas Group, including its indemnification 
obligations and Atlas' drilling obligation to the Partnership.  If 
Atlas Group defaults on a promissory note, Messrs. Koval and Sadowski 
are entitled to purchase up to approximately an additional 1,500,000 
shares of Atlas Group to regain management control.

In 1990, Messrs. Koval and Sadowski entered into five year 
employment agreements with Atlas Energy which agreements have been 
transferred to Atlas Group, renewable for an additional five year term 
and on an annual basis after the first ten years.  Mr. Sadowski, 
however, retired other than as a director in 1996.  The terms and 
provisions of the employment agreements with Mr. Koval are subject to 
negotiation at the time of each renewal and currently do not provide 
for any severance payments.  Also, during the terms of the promissory 
notes Messrs. Koval and Sadowski have the right to serve as directors 
of Atlas Group and as one of the two trustees of the ESOP.
On November 8, 1990, Atlas Energy entered into a Stock Option 
Agreement which established a management employee stock option plan to 
provide incentive compensation for certain of its key employees to 
acquire up to 47,578 shares of common stock of Atlas Energy.  Pursuant 
to the plan, Messrs. O'Mara and Wolf were granted stock options for 
22,164 and 14,210 shares, respectively.  The options are 100% vested 
with an option price of $1.00 per share and may be exercised when the 
promissory notes to Messrs. Koval and Sadowski have been satisfied and 
will terminate on August 15, 2012.  The issuance of future options will 
be determined at a later date.  The shareholders are also subject to  a 
Shareholders Agreement which provides, among other things, that such 
shareholders may not transfer their shares in Atlas Group unless the 
shares have first been offered to Atlas Group and the other 
shareholders.

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, 14.6% of tangible costs and contributing all leases to 
the Partnership.  During the calendar year ending December 31, 1997, 
the Managing General Partner received $205,026 from the Partnership's 
oil and gas 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) 32 undeveloped prospects to the Partnership to drill 
approximately 31.5 net wells.  With respect to the 32 prospects 
contributed for these wells Atlas received a credit in the amount of 
$113,400.  During 1997, 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 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, 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, 1997, the Managing General Partner received 
$27,994.

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, 1997, the Managing General Partner received $34,626.

DRILLING CONTRACTS.  On December 27, 1995, the Partnership entered 
into a drilling contract with Atlas to drill and complete 31.5 net 
wells.  The Partnership paid Atlas for drilling and completing the 
Partnership wells an amount equal to $36.36 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 31.5 net wells the total amount received by Atlas was 
$6,991,350.  During 1997, 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, 1997, Atlas received 
$102,575. 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, 1997, Atlas did not advance any funds 
nor did it provide any equipment, supplies or other services.
The following discussion relates solely to certain relationships 
and related transactions with respect to Atlas and does not relate to 
the Partnership.  The following discussion has been included because 
Atlas has been granted by the Partnership Agreement and the drilling 
and operating agreement the exclusive right, power and authority to 
control the operations and activities of the Partnership.

Atlas, its officers, directors and affiliates have in the past 
invested, and may in the future invest, as participants in oil and gas 
programs sponsored by Atlas on the same terms as unrelated investors.  
Atlas, its officers, directors and affiliates have also participated in 
the past, and may in the future participate, as working interest owners 
in wells in which Atlas or its oil and gas programs have an interest.  
Frequently, such participation has been on more favorable terms than 
the terms which were available to unrelated investors and Atlas Group 
has loaned to its officers and directors amounts in excess of $60,000 
from time to time as necessary for participation in such wells or 
programs.  Prior to 1996, such loans were either non-interest bearing 
or accrued interest at variable rates, but since 1995 all new loans for 
such purpose are required to bear interest.  Currently no such loans 
are outstanding.

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, 1997, there were 326 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, 1997, the Partnership distributed $788,542 to the Participants and 
$235,794 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.

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 no reports on  Form 8-K during the last 
quarter of the period covered by this report.

                             PART F/S
ITEM 13.     FINANCIAL STATEMENTS
The Partnership's Financial Statements for the period January 1, 
1997, to December 31, 1997, together with the opinion of the 
accountants thereon, FOLLOW BELOW.

PART III
ITEM 14.     EXHIBITS
(a)     Exhibits
See Exhibit BELOW
           

LOCATION

4(a)
Certificate of Limited Partnership for 
Atlas-Energy for the Nineties-Public #4 Ltd.
Previously filed in the Form 10-KSB for the period ending December 31, 1995, 
and received on April 1, 1996.

4(b)
Amended and Restated Certificate and Agreement
of Limited Partnership for Atlas-Energy for the Nineties-Public #4 Ltd.
dated December 27, 1995 Previously filed in the Form 10-KSB for 
the period ending December 31, 1995, and received on April 1, 1996.

10(a)
Drilling and Operating Agreement with 
exhibits

Previously filed in the Form 10-KSB for the period ending December 31, 1996 
and received on March 31, 1997.

23(a)
Consent of McLaughlin & Courson
BELOW
--------------------------------------------------------------------------

     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 #4 Ltd.

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

By   (Signature and Title):     
/S/James R. O'Mara, President, Chief Executive Officer and a Director
Date:  March __30__, 1998


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, Chairman of the Board and a Director
Date:  March _30___, 1998


By  (Signature and Title):     
/S/James R. O'Mara, President, Chief Executive Officer and a Director
Date:  March _30___, 1998

By  (Signature and Titla
/S/Bruce M. Wolf, General Counsel,Secretary and a Director
Date:  March _30___,1998

By (Signature and Title
/S/Tony C. Banks, Vice President of Finance and CFO
Date:  March _30___,1998


Supplemental Information to be furnished with reports filed pursuant
to Section 15(d) of the Exchange Act by Non-reporting Issures

An annual report will be furnished to securitiy holders subsequent
to the filing of this report.
------------------------------------------------------------------
Exhibit 23(a)
                         McLaughlin & Courson
                      Certified Public Accountants
                      2002 Law & Finance Building
                        Pittsburgh, PA 15219
                         Phone: 412-261-0630


CONSENT OF INDEPENDENT AUDITOR

ATLAS-ENERGY FOR THE NINETIES-PUBLIC #4 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 #4 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 and any amendments thereto for Atlas-Energy for the Nineties-
Public #4 Ltd.



McLaughlin & Courson
Certified Public Accountants



/s/McLaughlin & Courson


March 30, 1998
Pittsburgh, Pennsylvania