public15bform10q.htm

	United States

	Securities and Exchange Commission

	Washington, D.C. 20549

	Form 10 Q

(Mark One)

R	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

	For the quarterly period ended March 31, 2008

o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934


	For the transition period from _____ to _____

	Commission file number 0-52168


	ATLAS AMERICA PUBLIC #15-2006 (B) L.P.
	(Name of small business issuer in its charter)



Delaware		20-3208390
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

Westpointe Corporate Center One
1550 Coraopolis Heights Road 2nd Floor
Moon Township, PA		15108
(Address of principal executive offices)		(zip code)

Issuer’s telephone number, including area code: (412) 262-2830

Indicate by check mark whether the registrant (1) 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 R No o

Indicate by check mark whether the registrant is a large accelerated filer, a non-accelerated filer, or a smaller reporting company.
See the definitions of "large accelerated filer", "accelerated filer", and "smaller reporting company" in Rule 12b-2 of the Exchange
Act (Check One) Large accelerated filer ¨ Accelerated filer ¨ Non-accelerated filer ¨ Smaller reporting company R

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange
Act).Yes o No R

Transitional Small Business Disclosure Format (check one): Yes o No R

ATLAS AMERICA PUBLIC #15-2006 (B) L.P.

(A Delaware Limited Partnership)

INDEX TO QUARTERLY REPORT

ON FORM 10-Q

PART I.	FINANCIAL INFORMATION	PAGE

Item 1:	Financial Statements

	Balance Sheets as of March 31, 2008 and December 31, 2007	3

	Statements of Net Earnings for the Three Months ended March 31, 2008 and 2007	4

	Statement of Changes in Partners’ Capital for the Three Months ended March 31, 2008	5

	Statements of Cash Flows for the Three Months ended March 31, 2008 and 2007	6

	Notes to Financial Statements	7-14

Item 2:	Management’s Discussion and Analysis of Financial Condition and Results of Operations	15-18

Item 4:	Controls and Procedures	19

PART II.	OTHER INFORMATION

Item 1:	Legal Proceedings	19

Item 6:	Exhibits	19

SIGNATURES		20

CERTIFICATIONS		21-24

PART I

ITEM 1. FINANCIAL STATEMENTS

ATLAS AMERICA PUBLIC #15-2006(B) L.P.

BALANCE SHEETS

	March 31,			December 31,
	2008			2007
	(Unaudited)			(Audited)
ASSETS
Current assets:
Cash and cash equivalents	$	2,692,800		$	2,680,200
Accounts receivable-affiliate		7,825,300			8,299,300
Short-term hedge receivable due from affiliate		24,500			2,492,200
Total current assets		10,542,600			13,471,700

Oil and gas properties, net		147,605,400			154,541,600
Long-term hedge receivable due from affiliate		196,400			372,600
	$	158,344,400		$	168,385,900

LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accrued liabilities	$	14,400		$	23,900
Short-term hedge liability due to affiliate		4,725,800			58,900
Total current liabilities		4,740,200			82,800

Asset retirement obligation		4,113,900			4,070,700
Long-term hedge liability due to affiliate		5,254,300			3,744,200

Partners’ capital:
Managing general partner		32,611,300			35,402,400
Limited partners (14,772.60 units)		121,383,900			126,024,100
Accumulated other comprehensive loss		(9,759,200	)		(938,300	)
Total partners' capital		144,236,000			160,488,200
	$	158,344,400		$	168,385,900

The accompanying notes are an integral part of these financial statements

ATLAS AMERICA PUBLIC #15-2006 (B) L.P.

STATEMENTS OF NET EARNINGS

(Unaudited)

	Three Months Ended
	March 31,
	2008		2007
REVENUE
Natural gas and oil	$	8,973,500	$	7,018,500
Interest income		6,400		13,700
Total revenues		8,979,900		7,032,200

COSTS AND EXPENSES
Production		1,947,800		1,250,300
Depletion		5,124,500		4,280,100
Accretion of asset retirement obligation		43,200		61,400
General and administrative		129,000		94,100
Total expenses		7,244,500		5,685,900
Net earnings	$	1,735,400	$	1,346,300

Allocation of net earnings:
Managing general partner	$	1,537,500	$	1,297,900
Limited partners	$	197,900	$	48,400
Net earnings per limited partnership unit	$	13	$	3

The accompanying notes are an integral part of these financial statements

ATLAS AMERICA PUBLIC #15-2006 (B) L.P.

STATEMENT OF CHANGES IN PARTNERS’ CAPITAL

FOR THE THREE MONTHS ENDED March 31, 2008

(Unaudited)

							Accumulated
	Managing						Other
	General			Limited			Comprehensive
	Partner			Partners			Loss			Total

Balance at January 1, 2008	$	35,402,400		$	126,024,100		$	(938,300	)	$	160,488,200

Participation in revenues and expenses:
Net production revenues		2,404,200			4,621,500			—			7,025,700
Interest income		2,200			4,200			—			6,400
Depletion		(809,900	)		(4,314,600	)		—			(5,124,500	)
General and administrative		(44,200	)		(84,800	)		—			(129,000	)
Accretion of asset retirement obligation		(14,800	)		(28,400	)		—			(43,200	)
Net earnings		1,537,500			197,900			—			1,735,400

Other comprehensive loss		—			—			(8,820,900	)		(8,820,900	)

MGP asset received		(1,811,700	)		—			—			(1,811,700	)

Distributions to partners		(2,516,900	)		(4,838,100	)		—			(7,355,000	)

Balance at March 31, 2008	$	32,611,300		$	121,383,900		$	(9,759,200	)	$	144,236,000

The accompanying notes are an integral part of these financial statements

ATLAS AMERICA PUBLIC #15-2006(B) L.P.

STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended
	March 31,
	2008			2007

Cash flows from operating activities:
Net earnings	$	1,735,400		$	1,346,300
Adjustments to reconcile net earnings to net cash provided by operating activities:
Depletion		5,124,500			4,280,100
Accretion of asset retirement obligation		43,200			61,400
Decrease (increase) in accounts receivable – affiliate		474,000			(3,650,400	)
(Decrease) increase in accrued liabilities		(9,500	)		10,800
Net cash provided by operating activities		7,367,600			2,048,200


Cash flows from financing activities:
Distributions to partners		(7,355,000	)		(3,340,100	)
Net cash used in financing activities		(7,355,000	)		(3,340,100	)

Net increase (decrease) in cash and cash equivalents		12,600			(1,291,900	)
Cash and cash equivalents at beginning of period		2,680,200			1,305,800
Cash and cash equivalents at end of period	$	2,692,800		$	13,900


Supplemental schedule of non-cash investing and financing activities:

Assets contributed and received by managing general partner:
Tangible equipment	$	196,500		$	4,164,700
Lease costs		—			544,600
Intangible drilling costs		(2,008,200	)		—
	$	(1,811,700	)	$	4,709,300

Asset retirement obligation	$	—		$	647,800

The accompanying notes are an integral part of these financial statements

ATLAS AMERICA PUBLIC #15-2006(B) L.P.

NOTES TO FINANCIAL STATEMENTS

March 31, 2008

(Unaudited)

NOTE 1 - DESCRIPTION OF BUSINESS

Atlas America Public #15-2006 (B) L.P. (the "Partnership") is a Delaware Limited Partnership which includes Atlas Resources, LLC of Pittsburgh, Pennsylvania, as Managing General Partner ("MGP") and Operator, and 4,122 Limited Partners. The Partnership was formed on May 9, 2006 to drill and operate gas wells located primarily in western Pennsylvania, Ohio and Tennessee. The Partnership has no employees and relies on its MGP for management which, in turn, relies on its parent company, Atlas Energy Resources, LLC (NYSE:ATN), ("Atlas Energy"), for administrative services.

The financial statements as of March 31, 2008 and for the three months ended March 31, 2008 and 2007 are unaudited. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted in this Form 10-Q pursuant to the rules and regulations of the Securities and Exchange Commission. However, in the opinion of management, these interim financial statements include all the necessary adjustments to fairly present the results of the interim periods presented. The unaudited interim financial statements should be read in conjunction with the audited financial statements included in the Partnership's Form 10-KSB for the year ended December 31, 2007. The results of operations for the three months ended March 31, 2008 may not necessarily be indicative of the results of operations for the year ended December 31, 2008.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

In addition to matters discussed further in this note, the Partnership’s significant accounting policies are detailed in its audited financial statements and notes thereto in the Partnership’s annual report on Form 10-KSB for the year ended December 31, 2007 filed with the Securities and Exchange Commission.

Use of Estimates

Preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues, costs and expenses during the reporting period. Actual results could differ from these estimates.

Accounts Receivable and Allowance for Possible Losses

In evaluating the need for an allowance for possible losses, the Partnership's MGP performs ongoing credit evaluations of its customers and adjusts credit limits based upon payment history and the customer’s current creditworthiness, as determined by review of its customers' credit information. Credit is extended on an unsecured basis to many of its energy customers. At March 31, 2008 and December 31, 2007, the Partnership's MGP’s credit evaluation indicated that the Partnership has no need for an allowance for possible losses.

Revenue Recognition

Because there are timing differences between the delivery of the Partnership’s natural gas and oil and the receipt of a delivery statement, the Partnership has unbilled revenues. These revenues are accrued based upon volumetric data from the Partnership’s records and estimates of the related transportation and compression fees which are, in turn, based upon applicable product prices. The Partnership had unbilled trade receivables of $5,221,100 at March 31, 2008 and $5,757,100 at December 31, 2007, which are included in Accounts receivable-affiliate on the Partnership's Balance Sheets.

ATLAS AMERICA PUBLIC #15-2006(B) L.P.

NOTES TO FINANCIAL STATEMENTS (Continued)

March 31, 2008

(Unaudited)

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Property, Plant and Equipment

Property, plant and equipment are stated at cost. Depletion is based on cost less estimated salvage value primarily using the unit-of-production method over the assets’ estimated useful lives. Maintenance and repairs are expensed as incurred. Major renewals and improvements that extend the useful lives of property are capitalized.

Oil and gas properties consist of the following at the dates indicated:	March 31,			December 31,
	2008			2007
Natural gas and oil properties:
Proved properties:
Leasehold interests	$	4,222,100		$	4,222,100
Wells and related equipment		182,501,600			184,313,300
		186,723,700			188,535,400

Accumulated depletion of oil and gas properties		(39,118,300	)		(33,993,800	)
	$	147,605,400		$	154,541,600

Recently Issued Financial Accounting Standards

In March 2008, the Financial Accounting Standards Board, (“FASB”) issued Statement of Financial Accounting Standards No. 161, “Disclosures about Derivative Instruments and Hedging Activities”, (“SFAS 161”), an amendment of FASB Statement No. 133, “Accounting for Derivative Instruments and Hedging Activities”, (“SFAS 133”). SFAS 161 requires entities to provide qualitative disclosures about the objectives and strategies for using derivatives, quantitative data about the fair value of and gains and losses on derivative contracts, and details of credit-risk-related contingent features in their hedged positions. The standard is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008, with early application encouraged, but not required. SFAS 161 also requires entities to disclose more information about the location and amounts of derivative instruments in financial statements; how derivatives and related hedges are accounted for under SFAS 133 and how the hedges affect the entity’s financial position, financial performance, and cash flows. The Partnership is currently evaluating whether the adoption of SFAS 161 will have an impact on its financial position or results of operations.

In April 2007, the FASB issued FASB Staff Position FIN 39-1 amendment of FASB Interpretation No. 39, “Offsetting of Amounts Related to Certain Contracts” (“FSP FIN 39-1”). FSP FIN 39-1 amends FIN 39, which allows an entity to offset fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. FSP FIN 39-1 was effective for the Partnership on January 1, 2008. The adoption of FSP FIN 39-1 did not have a material impact on the Partnership’s financial position or results of operations.

ATLAS AMERICA PUBLIC #15-2006(B) L.P.

NOTES TO FINANCIAL STATEMENTS (Continued)

March 31, 2008

(Unaudited)

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Recently Issued Financial Accounting Standards (Continued)

In February 2007, the FASB issued Statement of Financial Accounting Standards No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities” (“SFAS 159”). SFAS 159 permits entities to choose to measure eligible financial instruments and certain other items at fair value. The objective is to improve financial reporting by providing entities with the opportunity to mitigate volatility in reported earnings caused by measuring related assets and liabilities differently without having to apply complex hedge accounting provisions. The statement was effective for the Partnership as of January 1, 2008. The adoption of SFAS 159 did not have a material impact on the Partnership’s financial position or results of operations.

In September 2006, the FASB issued Statement of Financial Accounting Standards No. 157, “Fair Value Measurement” (“SFAS 157”). SFAS 157 addresses the need for increased consistency in fair value measurements, defining fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. It also establishes a framework for measuring fair value and expands disclosure requirements. In February 2008, the FASB issued Final FASB Staff Position, (“FSP FAS 157-2”). FSP FAS 157-2, which was effective upon issuance, delays the effective date of SFAS 157 for nonfinancial assets and nonfinancial liabilities, except for items that are recognized or disclosed at fair value at least once a year, to fiscal years beginning after November 15, 2008. FSP FAS 157-2 also covers interim periods within the fiscal years for items within its scope. The delay is intended to allow the FASB and its constituents the time to consider the various implementation issues associated with SFAS 157. SFAS 157 was effective for the Partnership as of January 1, 2008. The adoption of SFAS 157 did not have a material impact on the Partnership’s financial position or results of operations.

NOTE 3 - TRANSACTIONS WITH ATLAS RESOURCES, LLC AND ITS AFFILIATES

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

·	Administrative costs which are included in general and administrative expenses in the Partnership’s Statements of Net Earnings are payable at $75 per well per month. Administrative costs incurred for the three months ended March 31, 2008 and 2007 were $110,400 and $75,200, respectively.

Monthly well supervision fees which are included in production expenses in the Partnership’s Statements of Net Earnings are payable at $296 and $285 per well per month in 2008 and 2007 respectively, for operating and maintaining the wells. Well supervision fees incurred for the three months ended March 31, 2008 and 2007 were $436,500 and $285,700, respectively.

·	Transportation fees which are included in production expenses in the Partnership’s Statements of Net Earnings are generally at 13% of the natural gas sales price. Transportation fees incurred for the three months ended March 31, 2008 and 2007 were $1,196,300 and $783,000, respectively.

ATLAS AMERICA PUBLIC #15-2006(B) L.P.

NOTES TO FINANCIAL STATEMENTS (Continued)

March 31, 2008

(Unaudited)

NOTE 3 - TRANSACTIONS WITH ATLAS RESOURCES, LLC AND ITS AFFILIATES (Continued)

Assets received by the MGP which are disclosed on the Partnership's Statements of Cash Flows as a non-cash activity for the three months ended March 31, 2008 were $1,811,700. Assets contributed from the MGP which are disclosed on the Partnership's Statements of Cash Flows as a non-cash activity of the three months ended March 31, 2007 were $4,709,300.

The MGP and its affiliates perform all administrative and management functions for the Partnership including billing revenues and paying expenses. Accounts receivable-affiliate on the Partnership's Balance Sheets represents the net production revenues due from the MGP.

Subordination by Managing General Partner

Under the terms of the Partnership agreement, the MGP may be required to subordinate up to 50% of its share of net production revenues of the Partnership to provide a distribution to the limited partners equal to at least 10% of their agreed subscriptions. Subordination is determined on a cumulative basis, in each of the first five years of Partnership operations, commencing with the first distribution of revenues to the investor partners (March 2007). Since inception of the program, the MGP has not been required to subordinate any of its revenues to its limited partners.

NOTE 4 – COMPREHENSIVE LOSS

Comprehensive loss includes net income and all other changes in equity of a business during a period from transactions and other events and circumstances from non-owner sources. These changes, other than net income, are referred to as "other comprehensive income (loss)" and, for the Partnership, include changes in the fair value of unrealized hedging contracts related to commodity derivatives. Comprehensive loss for the Partnership is as follows for the periods indicated:

	Three Months Ended
	March 31,
	2008			2007

Net earnings	$	1,735,400		$	1,346,300
Other comprehensive loss:
Unrealized holding loss on hedging contracts		(7,946,500	)		(2,840,900	)
Less: reclassification adjustment for gains realized in net earnings		(874,400	)		(728,900	)
Total other comprehensive loss		(8,820,900	)		(3,569,800	)
Comprehensive loss	$	(7,085,500	)	$	(2,223,500	)

NOTE 5 – DERIVATIVE INSTRUMENTS

The Partnership applies the provisions of SFAS 133, which requires each derivative instrument to be recorded in the balance sheet as either an asset or liability measured at fair value. Changes in a derivative instrument’s fair value are recognized currently in earnings unless specific hedge accounting criteria are met.

ATLAS AMERICA PUBLIC #15-2006(B) L.P.

NOTES TO FINANCIAL STATEMENTS (Continued)

March 31, 2008

(Unaudited)

NOTE 5 – DERIVATIVE INSTRUMENTS (Continued)

Atlas Energy on behalf of the Partnership from time to time enters into natural gas and oil futures option and collar contracts to hedge exposure to changes in natural gas and oil prices. At any point in time, such contracts may include regulated New York Mercantile Exchange (“NYMEX”) futures and options contracts and non-regulated over-the-counter futures contracts with qualified counterparties. NYMEX contracts are generally settled with offsetting positions, but may be settled by the delivery of natural gas and oil. Oil contracts are based on a West Texas Intermediate ("WTI") index. These contracts have qualified and been designated as cash flow hedges and recorded at their fair values.

At March 31, 2008, Atlas Energy had allocated natural gas futures contracts to the Partnership related to natural gas sales covering 9,020,300 dekatherms (“Dth”) of gas, maturing through March 31, 2013, at an average settlement price of $8.29 per Dth. In addition, Atlas Energy had allocated oil futures contracts to the Partnership related to oil sales covering 41,800 barrels (“Bbls”) of oil, maturing through March 31, 2013 at an average settlement price of $99.43 per Bbl. At March 31, 2008, the Partnership reflected a net hedge liability on its Balance Sheets of $9,759,200. Of the $9,759,200 net loss in accumulated other comprehensive loss at March 31, 2008, if the fair values of the instruments remain at current market values, the Partnership will reclassify $4,701,300 of net losses to its Statements of Net Earnings over the next twelve month period as these contracts expire, and $5,057,900 of net losses in later periods. Actual amounts that will be reclassified will vary as a result of future price changes. The Partnership realized gains of $874,400 and $728,900 for the three month periods ended March 31, 2008 and 2007, respectively in oil and gas revenues within its Statements of Net Earnings related to the settlement of qualifying hedge instruments. Ineffective hedge gains or losses are recorded within the Statements of Net Earnings while the hedge contract is open and may increase or decrease until settlement of the contract. The Partnership recognized no gains or losses during the three months ended March 31, 2008 and 2007 for hedge ineffectiveness or as a result of the discontinuance of cash flow hedges.

As of March 31, 2008, Atlas Energy had allocated to the Partnership the following natural gas and oil hedge contracts:

Natural Gas Fixed Price Swaps

Production			Average		Fair Value
Period Ending	Volumes		Fixed Price		Asset/
December 31,	(MMbtu) (1)		(per MMbtu)		(Liability) (2)

2008		2,033,300	$	8.81	$	(2,924,900	)
2009		2,513,900		8.42		(3,124,200	)
2010		1,478,700		7.80		(1,698,200	)
2011		739,400		7.51		(825,800	)
2012		492,900		8.65		(14,200	)
2013		123,200		8.73		(9,700	)
					$	(8,597,000	)

ATLAS AMERICA PUBLIC #15-2006(B) L.P.

NOTES TO FINANCIAL STATEMENTS (Continued)

March 31, 2008

(Unaudited)

NOTE 5 – DERIVATIVE INSTRUMENTS (Continued)

Natural Gas Costless Collars

Production				Average		Fair Value
Period Ending	Option	Volumes		Floor & Cap		Asset/
December 31,	Type	(MMbtu) (1)		(per MMbtu)		(Liability) (2)

2008	Puts purchased		160,200	$	7.50	$	—
2008	Calls sold		160,200		9.40		(194,800	)
2010	Puts purchased		394,300		7.75		—
2010	Calls sold		394,300		8.75		(281,300	)
2011	Puts purchased		985,800		7.50		—
2011	Calls sold		985,800		8.45		(680,200	)
2012	Puts purchased		98,600		7.00		—
2012	Calls sold		98,600		8.37		(86,800	)
						$	(1,243,100	)

Crude Oil Fixed Price Swaps

Production			Average		Fair Value
Period Ending	Volumes		Fixed Price		Asset/
December 31,	(Bbl)		(per Bbl)		(Liability) (2)

2008		4,500	$	103.25	$	17,100
2009		4,900		99.03		16,000
2010		4,300		96.52		10,500
2011		3,400		95.79		7,100
2012		3,000		95.35		4,800
2013		800		95.35		1,300
					$	56,800

ATLAS AMERICA PUBLIC #15-2006(B) L.P.

NOTES TO FINANCIAL STATEMENTS (Continued)

March 31, 2008

(Unaudited)

NOTE 5 – DERIVATIVE INSTRUMENTS (Continued)

Crude Oil Costless Collars

Production				Average		Fair Value
Period Ending	Option	Volumes		Floor & Cap		Asset/
December 31,	Type	(Bbl)		(per Bbl)		(Liability) (2)

2008	Puts purchased		4,200	$	85.00	$	2,200
2008	Calls sold		4,200		127.13		—
2009	Puts purchased		5,000		85.00		6,800
2009	Calls sold		5,000		118.63		—
2010	Puts purchased		4,300		85.00		6,000
2010	Calls sold		4,300		112.92		—
2011	Puts purchased		3,700		85.00		4,700
2011	Calls sold		3,700		110.81		—
2012	Puts purchased		2,900		85.00		3,500
2012	Calls sold		2,900		110.06		—
2013	Puts purchased		800		85.00		900
2013	Calls sold		800		110.09		—
						$	24,100

				Total Net Liability		$	(9,759,200	)

____________

(1)	MMBTU represents million British Thermal Units.

(2)	Fair value based on forward NYMEX natural gas and oil prices.

The following table sets forth the book and estimated fair values of derivative instruments at the dates indicated:

	March 31, 2008						December 31, 2007
	Book Value			Fair Value			Book Value			Fair Value
Assets
Derivative instruments	$	220,900		$	220,900		$	2,864,800		$	2,864,800
	$	220,900		$	220,900		$	2,864,800		$	2,864,800
Liabilities
Derivative instruments	$	(9,980,100	)	$	(9,980,100	)	$	(3,803,100	)	$	(3,803,100	)
	$	(9,759,200	)	$	(9,759,200	)	$	(938,300	)	$	(938,300	)

Fair Value of Financial Instruments

The Partnership adopted the provisions of SFAS 157 at January 1, 2008. SFAS 157 establishes a fair value hierarchy which requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. SFAS 157’s hierarchy defines three levels of inputs that may be used to measure fair value:

Level 1– Quoted prices in active markets for identical assets and liabilities that the reporting entity has the ability to access at the measurement date.

ATLAS AMERICA PUBLIC #15-2006(B) L.P.

NOTES TO FINANCIAL STATEMENTS (Continued)

March 31, 2008

(Unaudited)

NOTE 5 – DERIVATIVE INSTRUMENTS (Continued)

Fair Value of Financial Instruments (Continued)

Level 2– Inputs other than quoted prices included within Level 1 that are observable for the asset and liability or can be corroborated with observable market data for substantially the entire contractual term of the asset or liability.

Level 3– Unobservable inputs that reflect the entity's own assumptions about the assumptions that market participants would use in the pricing of the asset or liability and are consequently not based on market activity, but rather through particular valuation techniques.

The Partnership uses the fair value methodology outlined in SFAS 157 to value the assets and liabilities for its outstanding derivative contracts. All of the Partnership’s derivatives contracts are defined as Level 2. The Partnership's natural gas and crude oil derivative contracts are valued based on prices quoted on the NYMEX or WTI and adjusted by the respective counterparty using various assumptions including quoted forward prices, time value, volatility factors, and contractual prices for the underlying instruments. In accordance with SFAS 157, the following table represents the Partnership's fair value hierarchy for its financial instruments at March 31, 2008.

	Fair Value Measurements at March 31, 2008 Using
	Quoted prices		Significant other			Significant
	in active		observable			unobservable
	markets		inputs			inputs
	(Level 1)		(Level 2)			(Level 3)

Commodity-based derivatives	$	—	$	(9,759,200	)	$	—

Total	$	—	$	(9,759,200	)	$	—

NOTE 6 – ASSET RETIREMENT OBLIGATION

The Partnership accounts for the estimated plugging and abandonment costs for its oil and gas properties in accordance with Statement of Financial Accounting Standards No. 143 ("SFAS 143"), Accounting for Asset Retirement Obligations and Financial Accounting Standards Board ("FASB"), Interpretation No. 47, Accounting for Conditional Asset Retirement Obligations.

A reconciliation of the Partnership’s liability for plugging and abandonment costs for the periods indicated are as follows:

	Three Months Ended
	March 31,
	2008		2007

Asset retirement obligation at beginning of period	$	4,070,700	$	3,653,400
Liabilities incurred from drilling wells		—		647,800
Accretion expense		43,200		61,400
Asset retirement obligation at end of period	$	4,113,900	$	4,362,600

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION OR PLAN OF OPERATIONS (UNAUDITED)

Forward-Looking Statements

The matters discussed within this report include forward-looking statements. These statements may be identified by the use of forward-looking terminology such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “intend,” “may,” “might,” “plan,” “potential,” “predict,” “should,” or “will,” or the negative thereof or other variations thereon or comparable terminology. In particular, statements about our expectations, beliefs, plans, objectives, assumptions or future events or performance contained in this report are forward-looking statements. We have based these forward-looking statements on our current expectations, assumptions, estimates and projections. While we believe these expectations, assumptions, estimates and projections are reasonable, such forward-looking statements are only predictions and involve known and unknown risks and uncertainties, many of which are beyond our control. These and other important factors may cause our actual results, performance or achievements to differ materially from any future results, performance or achievements expressed or implied by these forward-looking statements.

Management’s Discussion and Analysis should be read in conjunction with our Financial Statements and the Notes to our Financial Statements.

General

We were formed as a Delaware limited partnership on May 9, 2006, with Atlas Resources, LLC as our Managing General Partner, or MGP, to drill natural gas development wells. Atlas Resources, Inc. was merged into a newly-formed limited liability company, Atlas Resources, LLC, which became an indirect subsidiary of Atlas America, Inc. Atlas Resources, LLC now serves as our MGP. We have no employees and rely on our MGP for management which, in turn relies on its parent company, Atlas Energy Resources, LLC (NYSE:ATN), or Atlas Energy, for administrative services.

Our wells are currently producing natural gas and, to a far lesser extent, oil which are our only products. Most of our gas is gathered and delivered to market through Atlas Pipeline Partners, L.P.’s gas gathering system, which is managed by an affiliate of our MGP. We do not plan to sell any of our wells and will continue to produce them until they are depleted or become uneconomical to produce, at which time they will be plugged and abandoned or sold.

Results of Operations

The following table sets forth information relating to our production revenues, volumes, sales prices, production costs and depletion during the periods indicated:

	Three Months Ended
	March 31,
	2008			2007

Production revenues (in thousands):
Gas	$	8,540		$	6,953
Oil	$	434		$	66
Total	$	8,974		$	7,019

Production volumes:
Gas (mcf/day) (2)		10,922			8,965
Oil (bbls/day) (2)		55			14
Total (mcfe/day) (2)		11,252			9,049

Average sales prices:
Gas (per mcf) (1) (2)	$	8.59		$	8.62
Oil (per bbl) (2)	$	86.22		$	53.90

Average production costs:
As a percent of sales		22	%		18	%
Per mcfe (2)	$	1.90		$	1.54

Depletion per mcfe	$	5.00		$	5.26

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(1)	The average sales price per mcf before the effects of hedging was $7.71 for the three months ended March 31, 2008 and 2007.

(2)	“Mcf” means thousand cubic feet, “mcfe” means thousand cubic feet equivalent and “bbls” means barrels. Bbls are converted to mcfe using the ratio of six mcfs to one bbl.

Natural Gas Revenues. Our natural gas revenues were $8,540,000 and $6,952,900 for the three months ended March 31, 2008 and 2007, respectively, an increase of $1,587,100 (23%). This increase was due to an increase in production volumes to 10,922 mcf per day for the three months ended March 31, 2008 from 8,965 mcf per day for the three months ended March 31, 2007, an increase of 1,957 mcf per day (22%), partially offset by a decrease in the average sales price we received for our natural gas to $8.59 for the three months ended March 31, 2008 as compared to $8.62 for the three months ended March 31, 2007, a decrease of $.03. The $1,587,100 increase in gas revenue for the three months ended March 31, 2008 as compared to the prior year period was attributable to a $1,612,200 increase in production volumes, partially offset by a $25,100 decrease in natural gas sale prices. The overall increase in gas production volumes for the three months ended March 31, 2008 resulted from a majority of our wells being on-line as compared to the prior year similar period.

Oil Revenues. We drill wells primarily to produce natural gas, rather than oil, but some wells have oil production. Our oil revenues were $433,500 and $65,600 for the three months ended March 31, 2008 and 2007, respectively, an increase of $367,900. This increase was due to an increase in the production volumes to 55 bbl per day for the three months ended March 31, 2008 from 14 bbl per day for the three months ended March 31, 2007, an increase of 41 bbl per day (293%) and an increase in the average sales price we received for our oil to $86.22 for the three months ended March 31, 2008 as compared to $53.90 for the three months ended March 31, 2007, an increase of $32.32 per bbl (60%). The $367,900 increase in oil revenues for the three months ended March 31, 2008 as compared to the prior year similar period was attributable to a $205,400 increase in production volumes and a $162,500 increase in oil prices.

Expenses. Production expenses were $1,947,800 and $1,250,300 for the three months ended March 31, 2008 and 2007, respectively, an increase of $697,500 (56%). This increase was primarily attributable to increases in transportation fees and well supervision fees, which are affected by an increase in production volumes, due to a majority of our wells being on-line for a full year as compared to the prior period.

Depletion of oil and gas properties as a percentage of oil and gas revenues were 57% and 61% for the three months ended March 31, 2008 and 2007, respectively. This percentage change is directly attributable to revenues, oil and gas reserve quantities, product prices, production volumes and changes in the depletable cost basis of oil and gas properties.

General and administrative expenses for the three months ended March 31, 2008 and 2007, were $129,000 and $94,100, respectively, an increase of $34,900 (37%). These expenses include third-party costs for services as well as the monthly administrative fees charged by our MGP. This increase was primarily due to higher administrative fees, due to a majority of our wells being on-line for a full year. In addition to higher audit and tax fees as compared to the prior year period.

Liquidity and Capital Resources

Cash provided by operating activities increased $5,319,400 in the three months ended March 31, 2008 to $7,367,600 as compared to $2,048,200 for the three months ended March 31, 2007. This increase was primarily due to an increase in net earnings before depletion and accretion of $1,215,300 and a decrease in accounts receivable affiliate of $4,124,400 for the current period as compared to the prior year period.

Cash used in financing activities increased $4,014,900 to $7,355,000 during the three months ended March 31, 2008, from $3,340,100 during the three months ended March 31, 2007. This increase was due to higher distributions as a result of an increase in net cash flows.

Our MGP may withhold funds for future plugging and abandonment costs. Any additional funds, if required, will be obtained from production revenues or borrowings from our MGP or its affiliates, which are not contractually committed to make loans to us. The amount that we may borrow may not at any time exceed 5% of our total subscriptions, and we will not borrow from third-parties.

We believe that our future cash flows from operations and amounts available from borrowings from our MGP or its affiliates, if any, will be adequate to fund our operations.

Critical Accounting Policies

The discussion and analysis of our financial condition and results of operations are based upon our financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. On an on-going basis, we evaluate our estimates, including those related to our asset retirement obligations, depletion and certain accrued receivables and liabilities. We base our estimates on historical experience and on various other assumptions that we believe reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions.

For a detailed discussion on the application of our remaining policies critical to our business operations and other accounting policies, see Note 2 of the "Notes to Financial Statements" in our Annual Report on Form 10-KSB.

Subordination by Managing General Partner

Recently Issued Financial Accounting Standards

In March 2008, the Financial Accounting Standards Board or FASB issued Statement of Financial Accounting Standards No. 161, Disclosures about Derivative Instruments and Hedging Activities or SFAS 161, an amendment of FASB Statement No. 133, Accounting for Derivative Instruments and Hedging Activities, or SFAS 133. SFAS 161 requires entities to provide qualitative disclosures about the objectives and strategies for using derivatives, quantitative data about the fair value of and gains and losses on derivative contracts, and details of credit-risk-related contingent features in their hedged positions. The standard is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008, with early application encouraged, but not required. SFAS 161 also requires entities to disclose more information about the location and amounts of derivative instruments in financial statements; how derivatives and related hedges are accounted for under SFAS 133 and how the hedges affect the entity’s financial position, financial performance, and cash flows. We are currently evaluating whether the adoption of SFAS 161 will have an impact on our financial position or results of operations.

In April 2007, the FASB issued FASB Staff Position FIN 39-1 amendment of FASB Interpretation No. 39, Offsetting of Amounts Related to Certain Contracts, or FSP FIN 39-1. FSP FIN 39-1 amends FIN 39, which allows an entity to offset fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. FSP FIN 39-1 was effective for us on January 1, 2008. The adoption of FSP FIN 39-1 did not have a material impact on our financial position or results of operations.

In February 2007, the FASB issued Statement of Financial Accounting Standards No. 159, The Fair Value Option for Financial Assets and Financial Liabilities, or SFAS 159. SFAS 159 permits entities to choose to measure eligible financial instruments and certain other items at fair value. The objective is to improve financial reporting by providing entities with the opportunity to mitigate volatility in reported earnings caused by measuring related assets and liabilities differently without having to apply complex hedge accounting provisions. The statement was effective for us as of January 1, 2008. The adoption of SFAS 159 did not have a material impact on our financial position or results of operations.

In September 2006, the FASB issued Statement of Financial Accounting Standards No. 157, Fair Value Measurement, or SFAS 157. SFAS 157 addresses the need for increased consistency in fair value measurements, defining fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. It also establishes a framework for measuring fair value and expands disclosure requirements. In February 2008, the FASB issued Final FASB Staff Position, or FSP FAS 157-2. FSP FAS 157-2, which was effective upon issuance, delays the effective date of SFAS 157 for nonfinancial assets and nonfinancial liabilities, except for items that are recognized or disclosed at fair value at least once a year, to fiscal years beginning after November 15, 2008. FSP FAS 157-2 also covers interim periods within the fiscal years for items within its scope. The delay is intended to allow the FASB and its constituents the time to consider the various implementation issues associated with SFAS 157. SFAS 157 was effective for us as of January 1, 2008. The adoption of SFAS 157 did not have a material impact on our financial position or results of operations.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Under the supervision and with the participation of our MGP’s management, including our MGP’s Chief Executive Officer and Chief Financial Officer, our MGP has evaluated the effectiveness of the design and operation of its disclosure controls and procedures (as defined in the Exchange Act Rule 13a-15(e) and Rule 15d-15(e)) as of the end of the period covered by this report and based on their evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that these disclosure controls and procedures are effective in all material respects, including those to ensure that information required to be disclosed in reports filed or submitted under the Securities Exchange Act is recorded, processed, summarized, and reported, within the time periods specified in the SEC’s rules and forms, and is accumulated and communicated to management, including our MGP’s Chief Executive Officer and Chief Financial Officer, as appropriate to allow for timely disclosure. There have been no changes during our last fiscal quarter that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The Managing General Partner (MGP) is not aware of any legal proceedings filed against the Partnership.

Affiliates to the MGP and their subsidiaries are party to various routine legal proceedings arising in the ordinary course of their collective business. The MGP management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the MGP's financial condition or results of operations.

ITEM 6. EXHIBITS

EXHIBIT INDEX

Exhibit No.		Description

4.0		Amended and Restated Certificate and Agreement of Limited Partnership for Atlas America Public #15-2006 (B) L.P. (1)
10.1		Drilling and Operating Agreement for Atlas America Public #15-2006 (B) L.P. (1)
31.1		Certification Pursuant to Rule 13a-14/15(d)-14
31.2		Certification Pursuant to Rule 13a-14/15(d)-14
32.1		Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2		Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

__________

(1)	Filed on April 17, 2006 in the Form S-1 Registration Statement, dated April 17, 2006, File No. 0-52168.

SIGNATURES

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

Atlas America Public #15-2006 (B) L.P.



		Atlas Resources, LLC, Managing General Partner

Date: May 13, 2008		By:/s/ Freddie M. Kotek
		Freddie M. Kotek, Chairman of the Board of Directors, Chief Executive Officer
		and President


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.



Date: May 13, 2008		By:/s/ Freddie M. Kotek
		Freddie M. Kotek, Chairman of the Board of Directors, Chief Executive
		Officer and President


Date: May 13, 2008		By:/s/ Matthew A. Jones
		Matthew A. Jones, Chief Financial Officer


Date: May 13, 2008		By:/s/ Nancy J. McGurk
		Nancy J. McGurk, Vice President, Chief Accounting Officer