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                                UNITED STATES
                     SECURITIES AND EXCHANGE COMMISSION
                            WASHINGTON, DC  20549

                                  FORM 10-Q

            [X]		QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
                      OF THE SECURITIES EXCHANGE ACT OF 1934
                     For the quarterly period ended March 31, 1997
                                   
                       Commission File Number 33-83618

                        SELKIRK COGEN PARTNERS, L.P.
     (Exact name of Registrant (Guarantor) as specified in its charter)

                     Delaware			             51-0324332
       (State or other jurisdiction of             (IRS Employer
      incorporation or organization)             Identification No.)
      
          
                      SELKIRK COGEN FUNDING CORPORATION
           (Exact name of Registrant as specified in its charter)

                     Delaware			             51-0354675
       (State or other jurisdiction of             (IRS Employer
      incorporation or organization)             Identification No.)

               One Bowdoin Square, Boston, Massachusetts 02114
        (Address of principal executive offices, including zip code)

                               (617) 227-8080
            (Registrant's telephone number, including area code)

         SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:
                8.65% First Mortgage Bonds Due 2007, Series A
                8.98% First Mortgage Bonds Due 2012, Series A
                              (Title of class)


	Indicate by check mark whether  the  Registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 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 
												   ---	 ---
	
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             This document consists of 19 pages of which this page is page 1.

<PAGE>






                                                  








                              TABLE OF CONTENTS




										                                Page
																		----
                       PART I.  FINANCIAL INFORMATION


Item 1.	Financial Statements (unaudited)

		Condensed Consolidated Balance Sheets as of March 31, 1997 
		and December 31, 1996.........................................	   3

		Condensed Consolidated Statements of Operations for the three 
		months ended March 31, 1997 and March 31, 1996................	   4

		Condensed Consolidated Statements of Cash Flows for the three 
		months ended March 31, 1997 and March 31, 1996................	   5

		Notes to Condensed Consolidated Financial Statements..........	   6

Item 2.	Management's Discussion and Analysis of Financial Condition 
		and Results of Operations

		Results of Operations.........................................	   7


		Liquidity and Capital Resources...............................	   9


                         PART II.  OTHER INFORMATION


Item 6.		Exhibits and Reports on Form 8-K..........................	  13

SIGNATURES............................................................	  14







                                      2
<PAGE>


                        
<TABLE>
                        SELKIRK COGEN PARTNERS, L.P.
                    CONDENSED CONSOLIDATED BALANCE SHEETS
                               (in thousands)
                                 (unaudited)
<CAPTION>							
				   					     			March 31,   December 31, 
						                        	  1997		    1996
												   ----------	------------
<S>													  <C>			<C>
ASSETS		
										
Current assets:									
  Cash............................................ $      791     $    2,591 
  Restricted funds................................	   22,152          6,284 
  Accounts receivable.............................     17,498         19,899 
  Due from affiliates.............................         14             40 
  Fuel inventory and supplies.....................	    4,637          4,401
  Other current assets............................	      318	         449 
  													---------	   ---------
    	Total current assets......................	   45,410         33,664 
										
  Plant and equipment, net........................    331,029        334,229 
  Long-term restricted funds......................     20,677         20,446 
  Deferred financing charges, net.................     12,822         13,115 
							  						---------	   ---------

				Total Assets		 	 	       $  409,938      $ 401,454
   													---------	   ---------
													---------	   ---------
LIABILITIES AND PARTNERS' CAPITAL									
										
Current liabilities:									
  Accounts payable................................ $      317 	  $      588 
  Accrued bond interest payable...................	    9,036 	         385 
  Accrued expenses................................     11,827         16,239 
  Due to affiliates...............................      1,246 	         937 
  Advances from customer..........................        --- 	          17 
  Current portion of long-term bonds..............      2,167 	       2,167 
	  												---------	   ---------
	    Total current liabilities.................	   24,593         20,333 
										
  Other long-term liabilities.....................	   12,058         10,678 
  Long-term bonds, less current portion...........	  389,253        389,253
										
  General partners' capital.......................	     (144) 		    (173) 
  Limited partners' capital.......................    (15,822)       (18,637)
	   												---------	   ---------
	    Total partners' capital...................    (15,966)       (18,810) 
													---------	   ---------

				Total Liabilities and
					 Partners' Capital             $  409,938     $  401,454 
													---------	   ---------
													---------	   ---------
<FN>
See Notes to Condensed Consolidated Financial Statements.									
</TABLE>
                                      3
<PAGE>
				 																							
<TABLE>
                        SELKIRK COGEN PARTNERS, L.P.
               CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
                               (in thousands)
                                 (unaudited)
											
											
											
<CAPTION>																						
							  					  For the Three Months Ended			
												  --------------------------

					 			    			   	March 31,	   March 31,	
													  1997	      	 1996	
												   ----------	  ----------
<S>                                                    <C>            <C>
Operating revenues:								   

    Electric and steam............................ $   42,521     $   37,713 	
	Gas resale....................................	    1,404 	       8,692
													---------	   ---------
	    Total operating revenues..................	   43,925         46,405 	
Cost of revenue...................................     31,291         29,833
													---------	   ---------
Gross Profit......................................	   12,634         16,572 	
						 	 	   			
Other operating expenses:										
	Administrative services - affiliates..........	      609 		     554 	
	Other general and administrative expenses.....	      646 		   1,068 	
																		
	Amortization of deferred financing charges....	      293 		     293 	
													---------	   ---------
		Total other operating expenses............	    1,548          1,915 	
													---------	   ---------

Operating income..................................	   11,086         14,657 	
											
Net interest expense..............................	    8,242          8,382 	
													---------	   ---------
Net income........................................ $    2,844     $    6,275 	
												    ---------	   ---------
													---------	   ---------

Allocated to:										
	General partners.............................. $       29 	  $       63 	
	Limited partners..............................	    2,815 	       6,212 	
                                                    ---------	   ---------
		Total..................................... $    2,844 	  $    6,275 	
												    ---------	   ---------
													---------	   ---------
<FN>
See Notes to Condensed Consolidated Financial Statements.										
</TABLE>
																						
                                      4
<PAGE>




<TABLE>
                        SELKIRK COGEN PARTNERS, L.P.
               CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
                               (in thousands)
                                 (unaudited)
												
<CAPTION>												
												  For the Three Months Ended			
												  --------------------------

					 			    			   	March 31,	   March 31,	
													  1997	      	 1996	
							                       ----------	  ----------

												
												
			
<S>                                                    <C>			  <C>									
Net cash provided by operating activities......... $   14,282     $   15,219	
												
Cash flows provided by (used in)
 investing activities:											
	Plant and equipment additions.................         34	        (441)	
	Restricted funds..............................    (16,099)		 (10,778)
												    ---------	   ---------

		Net cash used in investing activities.....	  (16,065)       (11,219) 	
												
Cash flows used in financing activities:											
	Cash distributions............................        ---         (4,223) 	
	Advances from a customer......................        (17)	        (136) 	
								  					---------	   ---------

		Net cash used in financing activities.....	      (17)        (4,359)
												
Net decrease in cash..............................     (1,800)		    (359)	
Cash at beginning of period.......................      2,591          2,672 	
													---------	   ---------
Cash at end of period.............................  $     791 	  $    2,313 
									 				---------	   ---------
													---------	   ---------

Supplemental disclosures of cash flow information:										

	Cash paid for interest........................  $      17     $      292   
													---------	   ---------
													---------	   ---------

<FN>
See Notes to Condensed Consolidated Financial Statements.										
</TABLE>											
											
																				
                                      5
<PAGE>



                        SELKIRK COGEN PARTNERS, L.P.

            NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
                                 (unaudited)



Note 1. Basis of Presentation

The  accompanying  unaudited   condensed  consolidated  financial  statements
consolidate Selkirk Cogen Partners, L.P.  and  its  wholly-owned  subsidiary,
Selkirk  Cogen  Funding  Corporation,  (collectively the "Partnership").  All
significant intercompany accounts and transactions have been eliminated.

The condensed  consolidated  financial  statements  for  the  interim periods
presented are unaudited and have been prepared  pursuant  to  the  rules  and
regulations  of  the  Securities  and  Exchange  Commission.  The information
furnished in the  condensed  consolidated  financial  statements reflects all
normal recurring  adjustments  which,  in  the  opinion  of  management,  are
necessary  for  a  fair  presentation  of such financial statements.  Certain
information  and  footnote   disclosures   normally   included  in  financial
statements  prepared  in  accordance  with  generally   accepted   accounting
principles  have  been condensed or omitted pursuant to rules and regulations
applicable to interim financial statements.

These  condensed  consolidated  financial  statements  should  be   read   in
conjunction  with  the  audited consolidated financial statements included in
the Partnership's December 31, 1996 Annual Report on Form 10-K.


Note 2. Contingency

In  connection  with  transactions  in   1994  involving  the  investment  by
affiliates of Cogen Technology, Inc. in the Partnership and the  purchase  of
J.  Makowski Company, Inc. by Beale Generating Company, the Partnership filed
New York State real estate transfer  and  gains tax returns with New York tax
authorities.  The New York tax authorities have raised certain questions  and
issues  about  such  tax returns. 

Although the New York tax authorities have assessed no additional tax against
the Partnership or any other transferor  at this time, the issue currently is
under consideration and it is possible that the New York tax authorities will
assert that additional tax is owed by the Partnership or one or more  of  the
other  transferors  in  connection  with these transactions.  The Partnership
presently cannot predict  the  likelihood  of  the  New  York tax authorities
making such an assertion or, if  made,  the  amount  of  tax  that  might  be
asserted.




                                      6
<PAGE>




           
ITEM 2.  MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL 
         -------------------------------------------------
         CONDITION AND RESULTS OF OPERATIONS
		 -----------------------------------

Results of Operations

Three Months Ended March 31, 1997 Compared to the Three Months Ended 
	March 31, 1996:

Net  income  for  the  quarter  ended  March  31, 1997 was approximately $2.8
million as compared to $6.3 million for the corresponding period in the prior
year.  The decrease in net income is primarily due to a $7.3 million decrease
in gas resale revenues offset by a  $4.8 million net increase in electric and
steam revenues as compared to the corresponding period in the prior year.

Total revenues for the quarter ended March 31, 1997 were approximately  $43.9
million  as  compared  to  $46.4  million for the corresponding period in the
prior year.

Electric Revenues (dollars and kWh's in millions):
--------------------------------------------------

							    For the Three Months Ended	
      				    March 31, 1997               March 31, 1996	
			  ------------------------------- -------------------------------
			  Dollars kWh's Capacity Dispatch Dollars kWh's Capacity Dispatch
			  ------- ----- -------- -------- ------- -----	-------- --------	 
Niagara Mohawk   10.0 161.1   90.31%   100.0%	  6.6  46.2   26.48%   42.45%	   
Con Edison	     32.4 485.9   84.88%   98.56%    30.0 446.5	  77.15%  97.53%    

Revenues  from  Niagara  Mohawk  Power Corporation ("Niagara Mohawk") for the
quarter ended  March  31,  1997  increased  approximately  $3.4  million when
compared to the corresponding period in  the  prior  year.   An  increase  in
delivered  energy  as  evidenced by the 63.8% increase in the capacity factor
was the primary contributor to the  increase in revenues.  During the quarter
ended March 31, 1997, Niagara Mohawk dispatched Unit 1 on-line  from  January
through March.  Energy delivered during January and February was sold at full
contract  rates  and  energy  delivered  during  March was sold under special
dispatch arrangements which called  for  the  pricing  of delivered energy at
variable rates less than  full  contract  rates.   Had  the  Partnership  not
entered into the special dispatch arrangements, the Unit would have otherwise
been  dispatched  off-line.  During the quarter ended March 31, 1996, Niagara
Mohawk dispatched  Unit  1  on-line  during  January  and  February,  at full
contract rates for January and the majority of February, and off-line for the
entire month of March.  Revenues for energy  delivered  pursuant  to  special
dispatch  arrangements  with  Niagara  Mohawk for the quarter ended March 31,
1997 were approximately $1.2 million  as  compared  to $29.3 thousand for the
corresponding period in the prior year.

                                      7

<PAGE>

Revenues  from  Consolidated  Edison Company of New York, Inc. ("Con Edison")
for the quarter ended  March  31,  1997  increased approximately $2.4 million
when compared to the corresponding period in the prior year.  An increase  in
delivered energy as evidenced by the 7.7% increase in the capacity factor and
higher contract energy rates resulting from higher index fuel prices were the
contributing factors to the increase in revenues.

Pursuant  to  the  Steam  Sales  Agreement  General  Electric  may  implement
productivity  or  energy  efficiency projects in its manufacturing processes,
including projects  involving  the  production  of  steam  within the General
Electric plant  commencing  in  1996.   General  Electric  has  informed  the
Partnership  of  its intent to implement an energy efficiency project in 1997
that would reduce the  quantity  of  steam  required  by the General Electric
plant.  Under the energy efficiency  project,  General  Electric  anticipates
managing  its  annual  average steam demand at 160,000lbs/hr.  Steam revenues
for the quarters ended March 31, 1997  and  March 31, 1996 were reduced by an
annual true-up of $0.9  million  and  $0.3  million,  respectively,  so  that
General  Electric  would  be  charged  a  nominal  amount which is the annual
equivalent of 160,000lbs/hr.  Steam revenues  for the quarter ended March 31,
1997 were approximately $92.3 thousand on 506.343  million  pounds  of  steam
delivered as compared to approximately $1.1 million on 585.991 million pounds
of  steam  delivered  for  the  corresponding  period in the prior year.  The
decrease in steam  revenues  during  the  quarter  ended  March  31, 1997 was
primarily due to lower steam demand.

Gas resale revenues for the quarter ended March 31, 1997  were  approximately
$1.4  million  on  sales  of approximately 0.5 million MMBtu's as compared to
$8.7  million  on  sales  of   approximately  1.8  million  MMBtu's  for  the
corresponding period in the prior year.  The decrease in gas resale  revenues
was  primarily  due to lower natural gas resale prices and higher dispatch of
Unit 1, which resulted in lower volumes of natural gas becoming available for
resale at lower prices.  The decrease in natural gas resale prices during the
quarter  ended  March  31,   1997   generally  resulted  from  more  moderate
temperatures in the Northeast region as compared to the  colder  than  normal
temperatures,  which  caused  an  increase  in the demand for natural gas and
resulted in lower than  normal  gas  storage  levels during the corresponding
period in the prior year.  The Partnership enters  into  gas  resales  during
periods when Units 1 and 2 are not operating at full capacity.

Cost  of  revenues  for  the  quarter ended March 31, 1997 were approximately
$31.3 million on  purchases  of  6.9  million  MMBtu's  as  compared to $29.8
million on purchases of 7.2 million MMBtu's for the corresponding  period  in
the  prior year.  The largest component of the increase for the quarter ended
March 31, 1996 was fuel  costs,  which  increased $1.2 million from the prior
year.  The increase in the cost of fuel was primarily due to higher  contract
firm  fuel  rates  from higher index fuel prices and rate increases under the
firm transportation contracts.  The 0.3  million MMBtu decrease in total fuel
volumes purchased for the  quarter  ended  March  31,  1997  as  compared  to
corresponding  period  in  the  prior year is primarily due to a reduction in
firm fuel purchases from suppliers.

                                      8

<PAGE>

Total other operating  expenses  for  the  quarter  ended  March 31, 1997 was
approximately $1.5 million as compared to $1.9 million for the  corresponding
period  in  the  prior  year.   The  decrease  in other operating expenses is
primarily due to a decrease in other general and administrative expenses.

Net interest expense for the  quarter  ended  March 31, 1997 of approximately
$8.2 million was comparable to the corresponding period in the prior year.


Liquidity and Capital Resources

Net cash flows provided by operating activities decreased from  approximately
$15.2  million  for the quarter ended March 31, 1996 to $14.3 million for the
quarter ended March 31, 1997.   The  decrease  in  net cash flows provided by
operating activities is due primarily to  the  decrease  in  net  income  and
normally  recurring  cash receipts and disbursements within the Partnership's
operating asset and liability  accounts  during  the  quarter ended March 31,
1997.

Net cash flows used in investing activities for the quarter ended  March  31,
1997  was  approximately  $16.1  million as compared to $11.2 million for the
corresponding period in the  prior  year.   Net  cash flows used in investing
activities primarily represent monies deposited into funds  created  pursuant
to  the  Partnership's Depositary and Disbursement Agreement, administered by
Bankers Trust Company, as  depositary  agent (the "Funds").  Monies deposited
into the Funds for the quarter  ended  March  31,  1997  primarily  represent
monies set aside for interest and principal payments to Bondholders scheduled
for  June  26,  1997.   Monies deposited into the Funds for the quarter ended
March  31,  1996  primarily  represent  monies  set  aside  for  interest and
principal payments to Bondholders scheduled for June 26,  1996  offset  by  a
distribution to the Partners.

Net cash flows used in financing activities decreased from approximately $4.4
million  for  the  quarter  ended  March  31,  1996 to $17.0 thousand for the
quarter ended March 31, 1997.  The  decrease  in cash flows used in financing
activities is primarily due to  a  $4.2  million  cash  distribution  to  the
Partners  during the quarter ended March 31, 1996; whereas there were no cash
distributions to the Partners during the quarter ended March 31, 1997.

                                      9
<PAGE>

Con Edison by a letter dated September 19, 1994 claimed the right to  acquire
that  portion  of Unit 2's firm natural gas supply not used in operating Unit
2, when Unit 2 is dispatched  off-line  or at less than full capability.  The
Con Edison Power Purchase Agreement contains no express language granting Con
Edison any rights with respect to such excess natural gas.  Nevertheless, Con
Edison has argued that, since payments under the contract include fixed  fuel
charges  which  are  payable whether or not Unit 2 is dispatched on-line, Con
Edison  is  entitled  to  take  delivery  of  any  excess  natural  gas.  The
Partnership vigorously disputes the position adopted  by  Con  Edison,  based
notably  on the absence of any contractual provision according Con Edison the
claimed rights but also on the fact that the Partnership has assumed the risk
under the Con Edison Power  Purchase  Agreement that the fuel charges payable
by Con Edison are insufficient to cover the costs actually  incurred  by  the
Partnership.   By  a  letter  dated  May  23,  1995, Con Edison indicated its
intention to pursue the claim asserted  in the September 19, 1994 letter.  In
the May 23, 1995 letter, Con Edison reserved the right to claim 100%  of  the
margins  derived  from the sales of Unit 2's firm natural gas supply not used
in operating Unit 2 (non-plant gas  sales) and requested that the Partnership
reduce the monthly amount invoiced to Con Edison by 50% of a calculated value
of the non-plant gas sales.  The  Partnership  strenuously  objected  to  Con
Edison's  contentions  and,  at  a  meeting  between  the Partnership and Con
Edison, Con Edison agreed to  continue  not to deduct any amount attributable
to non-plant gas sales from payments made upon monthly invoices but stated it
would do so under protest, pending further discussions between  the  parties.
Since  the  commencement  of commercial operations of Unit 2, the Partnership
made and continues to make, from time  to time, excess gas lay-off sales from
Unit 2's gas supply.  The Partnership does not intend to adjust  the  monthly
inv oices issued to Con Edison and continues to assert that Con Edison is not
entitled to any revenues or margins derived from non-plant gas sales.  In the
event  Con  Edison  were  to pursue its asserted claim, the Partnership would
expect to pursue all available legal  remedies, but there can be no certainty
that  the  outcome  of  such  remedial  action  would  be  favorable  to  the
Partnership or, if  favorable,  would  provide  for  the  Partnership's  full
recovery of its damages.

The  Partnership's  cash  flows  from  the  sale  of electric output would be
materially and adversely affected if Con  Edison were to prevail in its claim
to Unit 2's excess natural gas volumes and the related margins.

On October 6, 1995, Niagara Mohawk filed its "PowerChoice" proposal with  the
New  York  State  Public  Service Commission ("NYPSC").  On October 12, 1995,
Niagara Mohawk filed a Report  on  Form  8-K with the Securities and Exchange
Commission  (the  "Commission")  explaining  the  PowerChoice  proposal  (the
"PowerChoice Statement").   In  the  PowerChoice  Statement,  Niagara  Mohawk
describes  a  number  of  related  proposals  to  restructure  the  utility's
business, including the reorganization of its assets and the renegotiation of
its  contracts with generators which, like the Partnership, are not regulated
as utilities  ("non-utility  generators").   In  connection with PowerChoice,
Niagara Mohawk filed a Report  on  Form  8-K  on  March  10,  1997  with  the
Commission  in which it announced an agreement in principle to restructure or
terminate 44 power purchase contracts.  Among the contracts which is proposed
to be restructured is  the  Niagara  Mohawk  Power Purchase Agreement for the
electric output of Unit 1.  Pursuant to  the  agreement  in  pr  inciple  and
subject to negotiation as described below, the parties propose to restructure
the  Niagara  Mohawk  Power  Purchase  Agreement to provide for payments from
Niagara Mohawk which may be under one  or more pricing arrangements for up to
12 years in lieu of the rates  which  would  be  payable  under  the  current
Niagara Mohawk Power Purchase Agreement.

                                     10

<PAGE>

The  details  of  the  price  arrangements as well as other possible contract
modifications continue  to  be  the  subject  of  extensive  negotiations and
implementation of the agreement in  principle  is  subject  to  a  number  of
significant  conditions,  including  execution  of  binding  agreements;  any
requisite corporate, partnership and stakeholder approvals; NYPSC approval of
the  agreement  in  principle and other related transactions; other state and
federal approvals; the resolution of  all  tax issues; and obtaining required
amendments or  waivers  under  existing  credit  agreements  and  third-party
contracts,  including,  with  respect  to the Partnership, satisfying certain
standards under the Indenture  relating  to  the  absence of material adverse
changes and the maintenance  of  required  projected  debt  service  coverage
ratios  or  receiving  any required approval of holders of the Bonds or other
creditors.

The Partnership, as a party  to  the  agreement in principle, is committed to
negotiate to reach agreement on  a  restructured  power  purchase  agreement;
however,  the Partnership expresses no opinion with respect to the likelihood
that all of the conditions  to  implementation  of the agreement in principle
will be met or that  all  of  the  other  elements  of  PowerChoice  will  be
realized.   Further, the Partnership expresses no opinion with respect to the
viability of Niagara Mohawk's  proposed alternatives should PowerChoice fail,
such as Niagara Mohawk's proposal to take  possession  of  independent  power
projects  through  the  power  of  eminent domain and to thereafter sell such
projects or Niagara Mohawk's position that  it has not ruled out the ultimate
possibility of a filing for  restructuring  under  Chapter  11  of  the  U.S.
Bankruptcy  Code as set forth in the PowerChoice Statement.  Nevertheless, in
the  absence  of  agreement  on  a  definitive  restructured  power  purchase
agreement, the Partnership  continues  to  believe  that  the Nia gara Mohawk
Power Purchase Agreement is a valid and binding contract with Niagara Mohawk.
Until negotiations on  the  restructured  power  purchase  agreement  advance
further,  the  Partnership will not be able to determine what effect, if any,
the restructured power purchase  agreement  or  the PowerChoice proposal will
have on the Partnership, its business or net  operating  revenues.   For  the
quarter  ended March 31, 1997, electric sales to Niagara Mohawk accounted for
approximately 22.8% of total project revenues.

As a result of the  announcement  of  the  agreement in principle, Standard &
Poor's has placed the Bonds on credit  watch  "with  negative  implications,"
based  in  part  on  its analysis of the Current Reports on Form 8-K recently
filed by Niagara Mohawk  and  the  Partnership,  respectively, and its belief
that the restructuring has the potential to erode cash flow coverage  derived
from  long-term  contracts  supporting  the  Bonds.   As  of the date of this
report, Moody's Investors Service has not  changed its rating or its previous
"negative outlook" on the Bonds as a result of these recent developments.

                                     11

<PAGE>

Future operating results and cash flows from  operations  are  dependent  on,
among  other  things, the performance of equipment and processes as expected,
level of dispatch, fuel deliveries and price as contracted and the receipt of
certain capacity and other fixed  payments.   A  significant change in any of
these factors could have a material adverse effect on  the  results  for  the
Partnership.

The  Partnership  believes that based on current conditions and circumstances
it will have  sufficient  liquidity  available  provided  by  cash flows from
operations to fund existing debt obligations and operating costs.


                                     12

<PAGE>

                         PART II.		OTHER INFORMATION


ITEM 6.  EXHIBITS AND REPORTS ON FORM 8-K

(A)	Exhibits

	Exhibit No.	          Description					         Page No.
	-----------	          -----------					         --------
		10.1	Letter Agreement, dated as of April 18, 1997,	    16
				between Selkirk Cogen Partners, L.P. (the
				"Partnership") and Niagara Mohawk Power
				Corporation ("Niagara Mohawk") which
				restricts the ability of Niagara Mohawk to 
				modify the transmission rate or the transmission
				loss determination methodology from those 
				currently in use under the Transmission Service
				Agreement between Niagara Mohawk and the
				Partnership and the ability of the Partnership
				to seek to challenge those rates or the methodology.

		27		Financial Data Schedule	
				(For electronic filing purposes only)



(B)	Reports on Form 8-K

On  March  14, 1997, the Registrant filed a report on Form 8-K disclosing the
global agreement reached  between  Niagara  Mohawk  Power  Corporation and 19
Independent Power Producers.

Omitted from this Part II are items which are not applicable or to which  the
answer is negative for the periods covered.




                                     13

<PAGE>

                                 SIGNATURES

Pursuant  to  the  requirements  of  Section  13  or  15(d) of the Securities
Exchange Act of 1934, the Registrant has duly caused this report to be signed
on its behalf by the undersigned thereunto duly authorized.



                         			    SELKIRK COGEN PARTNERS, L.P. 

Date:  May 15, 1997			            /s/   JMC SELKIRK, INC.
                                        --------------------------
 	                                    Name: General Partner
						                 
Date:  May 15, 1997			            /s/  JOHN R. COOPER
                                        --------------------------
 	                                    Name:	John R. Cooper
                                  		Title:	Senior Vice President and
		                                     	and Chief Financial Officer
			
















                                     14


<PAGE>

                  
                                 SIGNATURES

Pursuant  to  the  requirements  of  Section  13  or  15(d) of the Securities
Exchange Act of 1934, the Registrant has duly caused this report to be signed
on its behalf by the undersigned thereunto duly authorized.



                         			    SELKIRK COGEN FUNDING 
						                 CORPORATION

Date:  May 15, 1997			            /s/  JOHN R. COOPER
                                        --------------------------
 	                                    Name:	John R. Cooper
                                  		Title:	Senior Vice President and
		                                     	and Chief Financial Officer
			

						





















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