UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

ý QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the quarterly period ended March 31, 2016

For the quarterly period ended September 30, 2015

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 No. 000-51926

Ridgewood Energy P Fund, LLC

(Exact name of registrant as specified in its charter)

Delaware

(State or other jurisdiction of

incorporation or organization)

86-1133315

(I.R.S. Employer

Identification No.)

14 Philips Parkway, Montvale, NJ 07645

(Address of principal executive offices) (Zip code)

(800) 942-5550

(Registrant’s telephone number, including area code)

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 o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No o

Indicate by check mark whether the registrant is a large accelerated filer, an 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.

Large accelerated filer	o	Accelerated filer	o
Non-accelerated filer (Do not check if a smaller reporting company)	o	Smaller reporting company	x

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes o No x

As of ~~October~~May 2910, ~~2015~~2016 the Fund had 933.06 shares of LLC Membership Interest outstanding.

Table of Contents

PAGE

			PAGE
PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements		1
		Unaudited Condensed Balance Sheets as of March 31, 2016 and December 31, 2015	1
		Unaudited Condensed Statements of Operations for the three months ended March 31, 2016 and 2015	2
		Unaudited Condensed Statements of Cash Flows for the three months ended March 31, 2016 and 2015	3
		Notes to Unaudited Condensed Financial Statements	4
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		8
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		13
Item 4.	Controls and Procedures		13

PART II - OTHER INFORMATION
Item 1.	Legal Proceedings		13
Item 1A.	Risk Factors		13
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		13
Item 3.	Defaults Upon Senior Securities		13
Item 4.	Mine Safety Disclosures		13
Item 5.	Other Information		13
Item 6.	Exhibits		14

	SIGNATURES		14

			PAGE
PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements		1
		Unaudited Condensed Balance Sheets as of September 30, 2015 and December 31, 2014	1
		Unaudited Condensed Statements of Operations for the three and nine months ended September 30, 2015 and 2014	2
		Unaudited Condensed Statements of Cash Flows for the nine months ended September 30, 2015 and 2014	3
		Notes to Unaudited Condensed Financial Statements	4
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		9
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		14
Item 4.	Controls and Procedures		14
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings		14
Item 1A.	Risk Factors		14
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		14
Item 3.	Defaults Upon Senior Securities		14
Item 4.	Mine Safety Disclosures		14
Item 5.	Other Information		14
Item 6.	Exhibits		15
	SIGNATURES		15

Table of Contents

PART I – FINANCIAL INFORMATION

ITEM 1.

FINANCIAL STATEMENTS

RIDGEWOOD ENERGY P FUND, LLC

UNAUDITED CONDENSED BALANCE SHEETS

(in thousands, except share data)

	September 30, 2015			December 31, 2014
	March 31, 2016			December 31, 2015
Assets
Current assets:
Cash and cash equivalents	$	1,~~644~~454		$	1,~~803~~531
Salvage fund		593			-593
Production receivable		4921			~~174~~44
Other current assets		2			20
Total current assets		2,068			2,168
Total current assets		2,288			1,997
Salvage fund		1,111			1,111
Salvage fund		1,061			1,438
Oil and gas properties:
Proved properties		18,~~273~~271			2218,~~527~~271
Less: accumulated depletion and amortization		(1617,~~638~~824	)		(2017,~~763~~788	)
Total oil and gas properties, net		~~1,635~~447			~~1,764~~483
Total assets	$	43,~~984~~626		$	53,~~199~~762
Liabilities and Members' Capital
Current liabilities:
Due to operators	$	~~101~~108		$	~~241~~92
Accrued expenses		8058			3581
Asset retirement obligations		593			-593
Total current liabilities		~~774~~759			~~276~~766
Asset retirement obligations		1,145			1,~~316~~145
Total liabilities		1,~~919~~904			1,~~592~~911
Commitments and contingencies (Note 4)
Commitments and contingencies (Note 3)
Members' capital:
Manager:
Distributions		(6,765	)		(6,~~734~~765	)
Retained earnings		4,~~243~~207			4,~~206~~221
Manager's total		(2,~~522~~558	)		(2,~~528~~544	)
Shareholders:
Capital contributions (1,335 shares authorized;
933.06 issued and outstanding)		138,344			138,344
Syndication costs		(15,898	)		(15,898	)
Distributions		(39,668	)		(39,~~397~~668	)
Accumulated deficit		(7778,~~191~~498	)		(7678,~~914~~383	)
Shareholders' total		54,~~587~~280			64,~~135~~395
Total members' capital		31,~~065~~722			31,~~607~~851
Total liabilities and members' capital	$	43,~~984~~626		$	53,~~199~~762

The accompanying notes are an integral part of these unaudited condensed financial statements.

Table of Contents

RIDGEWOOD ENERGY P FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF OPERATIONS

(in thousands, except per share data)

	Three months ended September 30,						Nine months ended September 30,
	Three months ended March 31,
	2015			2014			2015			2014
	2016			2015
Revenue
Oil and gas revenue	$	~~201~~48		$	~~915~~220		$	~~740~~		$	~~2,567~~
Expenses
Depletion and amortization		7211			~~261~~63			~~471~~			~~562~~
Management fees to affiliate (Note 3)		-			-			-			272
Impairment of oil and gas properties		25			-
Operating expenses		~~123~~86			~~255~~70			~~346~~			~~893~~
General and administrative expenses		56			5556			~~167~~			~~143~~
Total expenses		~~251~~178			~~571~~189			~~984~~			~~1,870~~
(Loss) gain on sale of oil and gas properties		-			(3	)		-			2,599
(Loss) income from operations		(130	)		31
(Loss) income from operations		(50	)		341			(244	)		3,296
Interest income		1			2
Interest income		-			3			4			8
Net (loss) income	$	(129	)	$	33
Net (loss) income	$	(50	)	$	344		$	(240	)	$	3,304
Manager Interest
Manager Interest
Net (loss) income	$	(14	)	$	14
Net income	$	3		$	89		$	37		$	212
Shareholder Interest
Shareholder Interest
Net (loss) income	$	(115	)	$	19
Net (loss) income	$	(53	)	$	255		$	(277	)	$	3,092
Net (loss) income per share	$	(123	)	$	21
Net (loss) income per share	$	(57	)	$	273		$	(297	)	$	3,314

The accompanying notes are an integral part of these unaudited condensed financial statements.

Table of Contents

RIDGEWOOD ENERGY P FUND, LLC

UNAUDITED CONDENSED STATEMENTS OF CASH FLOWS

(in thousands)

	Nine months ended September 30,
	Three months ended March 31,
	2015			2014
	2016			2015
Cash flows from operating activities
Net (loss) income	$	(~~240~~129	)	$	~~3,304~~33
Adjustments to reconcile net (loss) income to net cash
provided by operating activities:
(used in) provided by operating activities:
Depletion and amortization		~~471~~11			~~562~~63
Gain on sale of oil and gas properties		-			(2,599	)
Impairment of oil and gas properties		25			-
Accretion expense		73			-
Changes in assets and liabilities:
Decrease (increase) in production receivable		125			(76	)
Decrease in production receivable		-			145
Decrease in other current assets		20			2
Increase in due from affiliate		-			(80	)
Decrease in due to operators		(124	)		(195	)
Decrease in other current assets		-			9
Increase in accrued expenses		45			14
Increase (decrease) in due to operators		16			(93	)
Net cash provided by operating activities		370			1,012
Net cash (used in) provided by operating activities		(77	)		77
Cash flows from investing activities
Proceeds from sale of oil and gas properties		-			2,745
Credits for capital investment properties		-			4
(Expenditures) credits for capital investment properties		(11	)		57
Investments in salvage fund		-			(1	)
Investments in salvage fund		(216	)		(108	)
Net cash provided by investing activities		-			3
Net cash (used in) provided by investing activities		(227	)		2,694
Cash flows from financing activities
Distributions		~~(302~~-	)		(~~2,582~~200	)
Net cash used in financing activities		~~(302~~-	)		(~~2,582~~200	)
Net (decrease) increase in cash and cash equivalents		(159	)		1,124
Net decrease in cash and cash equivalents		(77	)		(120	)
Cash and cash equivalents, beginning of period		1,~~803~~531			~~894~~1,803
Cash and cash equivalents, end of period	$	1,~~644~~454		$	21,~~018~~683
Supplemental schedule of non-cash investing activities
Advances used for capital expenditures in oil and gas properties reclassified to proved properties	$	-		$	84

The accompanying notes are an integral part of these unaudited condensed financial statements.

Table of Contents

RIDGEWOOD ENERGY P FUND, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

1.	Organization and Summary of Significant Accounting Policies

Organization

The Ridgewood Energy P Fund, LLC (the "Fund”), a Delaware limited liability company, was formed on March 21, 2005 and operates pursuant to a limited liability company agreement (the “LLC Agreement") dated as of May 16, 2005 by and among Ridgewood Energy Corporation (the "Manager") and the shareholders of the Fund, which addresses matters such as the authority and voting rights of the Manager and shareholders, capitalization, transferability of membership interests, participation in costs and revenues, distribution of assets and dissolution and winding up. The Fund was organized to primarily acquire interests in oil and gas properties located in the United States offshore waters of Texas, Louisiana and Alabama in the Gulf of Mexico.

The Manager has direct and exclusive control over the management of the Fund's operations. With respect to project investments, the Manager locates potential projects, conducts due diligence, and negotiates and completes the transactions ~~in which the investments are made~~. The Manager performs, or arranges for the performance of, the management, advisory and administrative services required for Fund operations. Such services include, without limitation, the administration of shareholder accounts, shareholder relations and the preparation, review and dissemination of tax and other financial information. In addition, the Manager provides office space, equipment and facilities and other services necessary for Fund operations. The Manager also engages and manages the contractual relations with unaffiliated custodians, depositories, accountants, attorneys, broker-dealers, corporate fiduciaries, insurers, banks and others as required. See Notes 32 and 43.

Basis of Presentation

These unaudited interim condensed financial statements have been prepared by the Fund’s management in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in the opinion of management, contain all adjustments (consisting of only normal recurring adjustments) necessary to present fairly the Fund’s financial position, results of operations and cash flows for the periods presented. Certain information and note disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted in these unaudited interim condensed financial statements. The results of operations, financial position, and cash flows for the periods presented herein are not necessarily indicative of future financial results. These unaudited interim condensed financial statements should be read in conjunction with the Fund’s December 31, ~~2014~~2015 financial statements and notes thereto included in the Fund’s Annual Report on Form 10-K filed with the Securities and Exchange Commission (“SEC”). The year-end condensed balance sheet data was derived from audited financial statements for the year ended December 31, 2015, but does not include all disclosures required by GAAP.

Use of Estimates

The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenue and expense during the reporting period. On an ongoing basis, the Manager reviews its estimates, including those related to the fair value of financial instruments, property balances, determination of proved reserves, impairments and asset retirement obligations. Actual results may differ from those estimates.

Fair Value Measurements

The fair value measurement guidance provides a hierarchy that prioritizes and defines the types of inputs used to measure fair value. The fair value hierarchy gives the highest priority to Level 1 inputs, which consists of unadjusted quoted prices for identical instruments in active markets. Level 2 inputs consist of quoted prices for similar instruments. Level 3 ~~valuations~~inputs are ~~derived~~unobservable ~~from~~ inputs ~~that~~and ~~are~~include ~~significant~~situations ~~and~~where ~~unobservable~~there is little, if any, market activity for the instrument; hence, these ~~valuations~~inputs have the lowest priority. Cash and cash equivalents approximate fair value based on Level 1 inputs. ~~Mortgage-backed securities are recorded based on Level 2 inputs, as such instruments trade in over-the-counter markets.~~

Cash and Cash Equivalents

All highly liquid investments with maturities, when purchased, of three months or less, are considered cash and cash equivalents. At times, deposits may be in excess of federally insured limits, which are $250 thousand per insured financial institution. At September 30, 2015, the Fund’s bank balances were maintained in uninsured bank accounts at Wells Fargo Bank, N.A.

Table of Contents

Cash and Cash Equivalents

All highly liquid investments with maturities, when purchased, of three months or less, are considered cash and cash equivalents. At times, deposits may be in excess of federally insured limits, which are $250 thousand per insured financial institution. At March 31, 2016, the Fund’s bank balances were maintained in uninsured bank accounts at Wells Fargo Bank, N.A.

Salvage Fund

The Fund deposits in a separate interest-bearing account, or salvage fund, money to provide for the dismantling and removal of production platforms and facilities and plugging and abandoning its wells at the end of their useful lives in accordance with applicable federal and state laws and regulations. Interest Atearned ~~September~~on ~~30, 2015,~~ the ~~Fund~~account ~~had~~will nobecome ~~investments~~part inof ~~federal agency mortgage-backed securities. At December 31, 2014,~~ the ~~Fund had investments in federal agency mortgage-backed securities within its~~ salvage fund ~~that were classified as available-for-sale of $0~~.2 ~~million. In~~There ~~July 2015, the Fund received all contractual principal and interest payments related to the investments and there was no realized gain or loss. Available-for-sale securities~~ are ~~carried in the financial statements at fair value. At December 31, 2014, there was~~ no ~~unrealized~~restrictions ~~gain~~on orwithdrawals ~~loss~~from ~~related to~~ the ~~Fund’s~~salvage ~~available-for-sale investments~~fund.

For all investments, interest income is accrued as earned and amortization of premium or discount, if any, is included in interest income. Interest earned on the account will become part of the salvage fund. There are no restrictions on withdrawals from the salvage fund.

Oil and Gas Properties

The Fund invests in oil and gas properties, which are operated by unaffiliated entities that are responsible for drilling, administering and producing activities pursuant to the terms of the applicable operating agreements with working interest owners. The Fund’s portion of exploration, drilling, operating and capital equipment expenditures is billed by operators.

Exploration, development and acquisition costs are accounted for using the successful efforts method. Costs of acquiring unproved and proved oil and natural gas leasehold acreage, including lease bonuses, brokers’ fees and other related costs are capitalized. Costs of drilling and equipping productive wells and related production facilities are capitalized. The ~~Exploratory~~ costs of exploratory wells are capitalized pending determination of whether proved reserves have been found. If proved commercial reserves are not found, exploratory costs are expensed as dry-hole costs. At times, the Fund receives adjustments to certain wells from their respective operators upon review and audit of the wells’ costs. Annual lease rentals and exploration expenses are expensed as incurred. All costs related to production activity and workover efforts are expensed as incurred. Insurance expense related to operating wells of $9 thousand has been reclassified from “General and administrative ~~expense~~expenses” in ~~prior~~the ~~year~~Fund’s statement of operations for the three months ended March 31, 2015 to “Operating ~~expense~~expenses” to correct prior period presentation.

Once a well has been determined to be fully depleted or upon the sale, retirement or abandonment of a property, the cost and related accumulated depletion and amortization, if any, is eliminated from the property accounts, and the resultant gain or loss is recognized.

At ~~September~~March 3031, ~~2015~~2016 and December 31, ~~2014~~2015, amounts recorded in due to operators totaling $13 thousand ~~and $30 thousand, respectively,~~ related to capital expenditures for oil and gas properties.

Advances to Operators for Working Interests and Expenditures

The Fund may be required to advance its share of the estimated succeeding month’s expenditures to the operator for its oil and gas properties. The Fund accounts for such payments as advances to operators for working interests and expenditures. As the costs are incurred, the advances are reclassified to proved properties.

Asset Retirement Obligations

For oil and gas properties, there are obligations to perform removal and remediation activities when the properties are retired. When a project reaches drilling depth and is determined to be either proved or dry, an asset retirement obligation is incurred. Plug and abandonment costs associated with unsuccessful projects are expensed as dry-hole costs. ~~The~~As ~~following~~indicated ~~table~~above, ~~presents changes in asset retirement obligations for~~ the ~~nine~~Fund ~~months~~maintains ~~ended~~a ~~September~~salvage ~~30,~~fund ~~2015~~to ~~and~~provide for the ~~year~~funding ~~ended~~of ~~December~~future ~~31,~~asset ~~2014~~retirement obligations.

	2015		2014
	(in thousands)
Balance, beginning of period	$	1,316	$	1,292
Accretion expense		73		24
Revisions in estimated cash flows		349		-
Balance, end of period	$	1,738	$	1,316

As indicated above, the Fund maintains a salvage fund to provide for the funding of future asset retirement obligations.

Table of Contents

Syndication Costs

Syndication costs are direct costs incurred by the Fund in connection with the offering of the Fund’s shares, including professional fees, selling expenses and administrative costs payable to the Manager, an affiliate of the Manager and unaffiliated broker-dealers, which are reflected on the Fund’s balance sheet as a reduction of shareholders’ capital.

Revenue Recognition and Imbalances

Oil and gas revenues are recognized when oil and gas is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. The Fund uses the sales method of accounting for gas production imbalances. The volumes of gas sold may differ from the volumes to which the Fund is entitled based on its interests in the properties. These differences create imbalances that are recognized as a liability only when the properties’ estimated remaining reserves net to the Fund will not be sufficient to enable the underproduced owner to recoup its entitled share through production. The Fund’s recorded liability, if any, would be reflected in other liabilities. No receivables are recorded for those wells where the Fund has taken less than its share of production.

Table of Contents

Impairment of Long-Lived Assets

The Fund reviews the carrying value of its oil and gas properties ~~whenever~~annually and when management determines that events and circumstances indicate that the recorded carrying value of properties may not be recoverable. Impairments ~~of proved properties~~ are determined by comparing estimated future net undiscounted cash flows to the ~~net~~carrying ~~book~~ value at the time of the review. If the ~~net~~carrying ~~book~~ value exceeds the estimated future net undiscounted cash flows, the carrying value of the ~~property~~asset is written down to fair value, which is determined using estimated future net discounted ~~future~~ cash flows from the ~~property~~asset. The ~~Fund provides for impairments on unproved properties when it determines that the property will not be developed or a permanent impairment in value has occurred. The~~ fair value determinations require considerable judgment and are sensitive to change. Different pricing assumptions, reserve estimates or discount rates could result in a different calculated impairment. Given the volatility of oil and natural gas prices, it is reasonably possible that the Fund’s estimate of discounted future net cash flows from proved oil and natural gas reserves could change in the near term. ~~If oil and natural gas prices decline significantly, even if only for a short period of time, it is possible that write-downs of oil and gas properties could occur.~~

Significant declines in oil and natural gas prices since fourth quarter 2014 have impacted the fair value of the Fund’s oil and gas properties. During the three months ended March 31, 2016, the Fund recorded impairments of oil and gas properties of $25 thousand, which represented the carrying value of the Eugene Island 346/347 Project. The impairment was primarily attributable to declines in future oil and gas prices. There were no impairments of oil and gas properties during the three months ended March 31, 2015. If oil and natural gas prices continue to decline, even if only for a short period of time, it is possible that additional impairments of oil and gas properties will occur.

Depletion and Amortization

Depletion and amortization of the cost of proved oil and gas properties are calculated using the units-of-production method. Proved developed reserves are used as the base for depleting capitalized costs associated with successful exploratory well costs, development costs and related facilities. The sum of proved developed and proved undeveloped reserves is used as the base for depleting or amortizing leasehold acquisition costs. ~~During the nine months ended September 30, 2015, the Fund recorded $0.2 million of depletion expense related to adjustments to asset retirement obligations for fully depleted properties.~~

Income Taxes

No provision is made for income taxes in the financial statements. The Fund is a limited liability company, and as such, the Fund’s income or loss is passed through and included in the tax returns of the Fund’s shareholders. The Fund files U.S. Federal and State tax returns and the 2013 through 2015 tax returns remain open for examination by tax authorities.

Income and Expense Allocation

Profits and losses are allocated to shareholders and the Manager in accordance with the LLC Agreement.

Distributions

Distributions to shareholders are allocated in proportion to the number of shares held. The Manager determines whether available cash from operations, as defined in the LLC Agreement, will be distributed. Such distributions are allocated 85% to the shareholders and 15% to the Manager, as required by the LLC Agreement. Effective April 1, 2015, the Manager reduced its allocation to 1% of available cash from operations.

Available cash from dispositions, as defined in the LLC Agreement, will be paid 99% to shareholders and 1% to the Manager until the shareholders have received total distributions equal to their capital contributions. After shareholders have received distributions equal to their capital contributions, 85% of available cash from dispositions will be distributed to shareholders and 15% to the Manager. During the nine months ended September 30, 2014, the Fund made distributions of available cash from dispositions related to the sale of the Raven Project totaling $1.3 million. There were no such distributions during the three months ended September 30, 2014 and during the three and nine months ended September 30, 2015.

Table of Contents

Recent Accounting Pronouncements

The Fund has considered recent accounting pronouncements and believes that these recent pronouncements will not have a material effect on the Fund’s financial statements.

2. ~~Oil~~ ~~and~~Related ~~Gas Properties~~Parties

OnPursuant ~~January~~to ~~17, 2014,~~ the ~~Fund,~~terms ~~along~~of ~~with~~the ~~its~~LLC ~~affiliates~~Agreement, ~~entered~~the ~~into~~Manager arenders ~~purchase~~management, administrative and ~~sale~~advisory ~~agreement~~services to ~~sell~~the ~~its~~Fund. For ~~interest~~such inservices, the ~~Raven~~Manager ~~Project,~~is ~~located~~entitled into ~~the~~an ~~state~~annual ~~waters~~management ~~of Louisiana~~fee, topayable ~~Castex Energy Partners~~monthly, Lof 2.P.5% ~~for~~of ~~cash~~total ~~consideration~~capital ~~totaling~~contributions, ~~$21.7~~net ~~million. The closing~~ of ~~the~~cumulative ~~sale~~dry-hole ~~transaction~~and ~~occurred~~related onwell ~~January~~costs ~~30,~~incurred ~~2014. The~~by ~~Fund~~the ~~had a 6~~Fund.~~25%~~ Effective ~~working~~April ~~interest~~1, in2014, the ~~Raven~~Manager ~~Project~~waived ~~and~~its ~~received~~management ~~$2.7~~fee ~~million~~for inthe ~~cash~~remaining ~~proceeds~~life ~~from~~of the ~~sale~~Fund. ~~The~~Upon ~~net~~the ~~carrying~~waiver ~~value~~of ~~for~~ the ~~Raven~~management ~~Project~~fee, on the ~~date~~Fund ofbegan ~~the~~recording ~~sale~~costs, ~~was~~totaling $~~0.1~~20 ~~million,~~thousand ~~thereby~~per ~~resulting~~quarter, inrepresenting areimbursements ~~gain~~ to the ~~Fund of $2.6 million~~Manager, ~~which~~related ~~was~~to ~~recognized~~services ~~during~~provided by the ~~nine~~Manager ~~months~~for ~~ended~~accounting ~~September~~and ~~30,~~investor ~~2014~~relations. ~~There~~Such ~~was~~costs noare ~~such~~included ~~amount~~within ~~recorded~~general and administrative expenses. Management reimbursement costs during each of the three ~~and nine~~ months ended ~~September~~March 3031, 2016 and 2015 were $20 thousand.

~~3. Related Parties~~6

~~Pursuant~~Table ~~to the terms~~ of the LLC Agreement, the Manager renders management, administrative and advisory services to the Fund. For such services, the Manager is entitled to an annual management fee, payable monthly, of 2.5% of total capital contributions, net of cumulative dry-hole and related well costs incurred by the Fund. Management fees for the nine months ended September 30, 2014 were $0.3 million. Effective April 1, 2014, the Manager waived its management fee for the remaining life of the Fund. Upon the waiver of the management fee, the Fund began recording costs, totaling $20 thousand per quarter, representing reimbursements to the Manager, related to services provided by the Manager for accounting and investor relations. Such costs are included within general and administrative expenses. Management reimbursement costs during the three and nine months ended September 30, 2015 were $20 thousand and $60 thousand, respectively. Management reimbursement costs during the three and nine months ended September 30, 2014 were $20 thousand and $40 thousand, respectively.Contents

The Manager is entitled to receive a 15% interest in cash distributions from operations made by the Fund. Effective April 1, 2015, the Manager reduced its allocation to 1% of available cash from operations. ~~Distributions~~The ~~from~~Fund ~~operations~~did ~~paid~~not topay ~~the Manager for the nine months ended September 30, 2015 were $31 thousand. There were no such~~ distributions ~~paid~~ during the three months ended ~~September~~March 3031, ~~2015~~2016. Distributions ~~from operations~~ paid to the Manager for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2014~~2015 were $0.1 million and $0.2 million, respectively. In addition, the Manager is entitled to receive a 1% interest in cash distributions from dispositions. Distributions from the sale of the Raven project paid to the Manager during the nine months ended September 30, ~~2014 were $13~~ thousand. ~~There were no such distributions paid during the three months ended September 30, 2014 and during the three and nine months ended September 30, 2015.~~

At times, short-term payables and receivables, which do not bear interest, arise from transactions with affiliates in the ordinary course of business.

None of the amounts paid to the Manager have been derived as a result of arm’s length negotiations.

~~The~~3. ~~Fund~~Commitments ~~has working interest ownership in certain projects to acquire~~ and ~~develop oil and natural gas projects with other entities that are likewise managed by the Manager.~~Contingencies

4. Commitments and Contingencies

Capital Commitments

The Fund has entered into multiple agreements for the acquisition, drilling and development of its oil and gas properties. ~~The estimated capital expenditures associated with these agreements vary depending on the stage of development on a property-by-property basis.~~ As of ~~September~~March 3031, ~~2015~~2016, the Fund’s estimated capital commitments related to its oil and gas properties were $32.10 million, ~~(which~~related ~~include~~to ~~asset~~expected ~~retirement~~recompletions ~~obligations~~of ~~for~~$0.1 ~~the~~million ~~Fund’s~~and ~~projects~~asset retirement obligations of $1.9 million), of which $0.76 million is expected to be spent during the next twelve months.

Based upon its current cash position and its current reserve estimates, the Fund expects cash flow from operations to be sufficient to cover its commitments, as well as ongoing operations. Reserve estimates are projections based on engineering data that cannot be measured with precision, require substantial judgment, and are subject to frequent revision.

Table of Contents

Environmental Considerations

The exploration for and development of oil and natural gas involves the extraction, production and transportation of materials which, under certain conditions, can be hazardous or cause environmental pollution problems. The Manager and operators of the Fund’s properties are continually taking action they believe appropriate to satisfy applicable federal, state and local environmental regulations and do not currently anticipate that compliance with federal, state and local environmental regulations will have a material adverse effect upon capital expenditures, results of operations or the competitive position of the Fund in the oil and gas industry. However, due to the significant public and governmental interest in environmental matters related to those activities, the Manager cannot predict the effects of possible future legislation, rule changes, or governmental or private claims. At ~~September~~March 3031, ~~2015~~2016 and December 31, ~~2014~~2015, there were no known environmental contingencies that required the Fund to record a liability.

During the past several years, the United States Congress, as well as certain regulatory agencies with jurisdiction over the Fund’s business, have considered or proposed legislation or regulation relating to the upstream oil and gas industry both onshore and offshore. If any such proposals were to be enacted or adopted they could potentially materially impact the Fund’s operations. It is not possible at this time to predict whether such legislation or regulation, if proposed, will be adopted as initially written, if at all, or how legislation or new regulation that may be adopted would impact the Fund’s business. Any such future laws and regulations could result in increased compliance costs or additional operating restrictions, which could have a material adverse effect on the Fund’s operating results and cash flows.

Insurance Coverage

The Fund is subject to all risks inherent in the exploration for and development of oil and natural gas. Insurance coverage as is customary for entities engaged in similar operations is maintained, but losses may occur from uninsurable risks or amounts in excess of existing insurance coverage. The occurrence of an event that is not insured or not fully insured could have a material adverse impact upon earnings and financial position. Moreover, insurance is obtained as a package covering all of the funds managed by the Manager. Claims made by other funds managed by the Manager can reduce or eliminate insurance for the Fund.

Table of Contents

ITEM 2.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Cautionary Statement Regarding Forward-Looking Statements

Certain statements in this Quarterly Report on Form 10-Q (“Quarterly Report”) and the documents Ridgewood Energy P Fund, LLC (the “Fund”) has incorporated by reference into this Quarterly Report, other than purely historical information, including estimates, projections, statements relating to the Fund’s business plans, strategies, objectives and expected operating results, and the assumptions upon which those statements are based, are “forward-looking statements” within the meaning of the US Private Securities Litigation Reform Act of 1995 that are based on current expectations and assumptions and are subject to risks and uncertainties that may cause actual results to differ materially from the forward-looking statements. You are therefore cautioned against relying on any such forward-looking statements. Forward-looking statements can generally be identified by words such as “believe,” “project,” “expect,” “anticipate,” “estimate,” “intend,” “strategy,” “plan,” “target,” “pursue,” “may,” “will,” “will likely result,” and similar expressions and references to future periods. Examples of events that could cause actual results to differ materially from historical results or those anticipated include weather conditions, such as hurricanes, changes in market conditions affecting the pricing and production of oil and natural gas, the cost and availability of equipment, and changes in governmental regulations. Examples of forward-looking statements made herein include statements regarding projects, investments, insurance, capital expenditures and liquidity. Forward-looking statements made in this document speak only as of the date on which they are made. The Fund undertakes no obligation to update or revise publicly any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law.

Critical Accounting Policies and Estimates

The discussion and analysis of the Fund’s financial condition and results of operations are based upon the Fund’s financial statements, which have been prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”). In preparing these financial statements, the Fund is required to make certain estimates, judgments and assumptions. These estimates, judgments and assumptions affect the reported amounts of the Fund’s assets and liabilities, including the disclosure of contingent assets and liabilities, at the date of the financial statements and the reported amounts of its revenues and expenses during the periods presented. The Fund evaluates these estimates and assumptions on an ongoing basis. The Fund bases its estimates and assumptions on historical experience and on various other factors that the Fund believes to be reasonable at the time the estimates and assumptions are made. However, future events and actual results may differ from these estimates and assumptions and such differences may have a material impact on the results of operations, financial position or cash flows. See Note 1 of “Notes to Unaudited Condensed Financial Statements” – “Organization and Summary of Significant Accounting Policies” contained in Item 1. “Financial Statements” within Part I of this Quarterly Report for a ~~presentation~~discussion of the Fund’s significant accounting policies. No changes have been made to the Fund’s critical accounting policies and estimates disclosed in its ~~2014~~2015 Annual Report on Form 10-K.

Overview of the Fund’s Business

The Fund is a Delaware limited liability company formed on March 21, 2005 to primarily acquire interests in oil and natural gas properties located in the United States offshore waters of Texas, Louisiana and Alabama in the Gulf of Mexico. The Fund’s primary investment objective is to generate cash flow for distribution to its shareholders by generating returns across a portfolio of exploratory or development oil and natural gas projects. However, the Fund is not required to make distributions to shareholders except as provided in the Fund’s limited liability company agreement (the “LLC Agreement”). The Fund’s investments in oil and natural gas properties is complete and the balance of the Fund’s capital has been fully allocated to complete such projects. The Fund does not expect in the future to investigate or invest in any additional projects other than those in which it currently has a working interest.

Ridgewood Energy Corporation (the “Manager” or “Ridgewood Energy”) is the Manager, and as such, has direct and exclusive control over the management of the Fund’s operations. The Manager performs ~~certain~~or ~~duties~~arranges onfor the ~~Fund’s~~performance ~~behalf including the evaluation~~ of ~~projects~~, ~~including~~the ~~ongoing~~ management, ~~administrative~~advisory and ~~advisory~~administrative services required for Fund’s operations. ~~For~~As ~~these~~compensation for its services, the Manager is entitled to an annual management fee, payable monthly, equal to 2.5% of the total capital contributions made by the Fund’s shareholders, net of cumulative dry-hole and related well costs incurred by the Fund~~, payable monthly~~. Effective April 1, 2014, the Manager waived its management fee for the remaining life of the Fund. Upon the waiver of the management fee, the Fund began recording costs related to services provided by the Manager for accounting and investor relations. The Fund does not currently, nor is there any plan to, operate any project in which the Fund participates. The Manager enters into operating agreements with third-party operators for the management of all exploration, development and producing operations, as appropriate. The Manager also participates in distributions.

Table of Contents

~~Revenues~~Commodity ~~are~~Price subject to market pricing for oil and natural gas, which has been volatile, and is likely to continue to be volatile in the future. This volatility is caused by numerous factors and market conditions that the Fund cannot control or influence. Therefore, it is impossible to predict the future price of oil and natural gas with any certainty. Low commodity prices could have an adverse effect on the Fund’s future profitability. Factors affecting market pricing for oil and natural gas include:Changes

Changes in commodity prices may significantly affect liquidity and expected operating results. Reductions in oil and gas prices not only reduce revenues and profits, but could also reduce the quantities of reserves that are commercially recoverable. Significant declines in prices could result in non-cash charges to earnings due to impairment.

Since fourth quarter 2014, there has been a significant decline in oil and natural gas prices. See “Results of Operations” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for more information on the average oil and natural gas prices received by the Fund during the three months ended March 31, 2016 and 2015 and the effect of such decreased average prices on the Fund’s results of operations. If oil and natural gas prices continue to decline, even if only for a short period of time, the Fund’s results of operations and liquidity will continue to be adversely impacted.

Market pricing for oil and natural gas is volatile, and is likely to continue to be volatile in the future. This volatility is caused by numerous factors and market conditions that the Fund cannot control or influence. Therefore, it is impossible to predict the future price of oil and natural gas with any certainty. Factors affecting market pricing for oil and natural gas include:

weather conditions;

economic conditions, including demand for petroleum-based products;

actions by OPEC, the Organization of Petroleum Exporting Countries;

political instability in the Middle East and other major oil and gas producing regions;

governmental regulations, both domestic and foreign;

domestic and foreign tax policy;

the pace adopted by foreign governments for the exploration, development, and production of their national reserves;

the price of foreign imports of oil and gas;

the cost of exploring for, producing and delivering oil and gas;

the discovery rate of new oil and gas reserves;

the rate of decline of existing and new oil and gas reserves;

available pipeline and other oil and gas transportation capacity;

the ability of oil and gas companies to raise capital;

the overall supply and demand for oil and gas; and

the availability of alternate fuel sources.

Business Update

Information regarding the Fund’s current projects, all of which are located in the offshore waters of the Gulf of Mexico, is provided in the following table. See ~~The~~“Liquidity ~~budget~~Needs” under this Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Quarterly Report for ~~each~~information ~~project~~regarding isthe ~~inclusive~~funding of ~~estimated~~the ~~asset~~Fund’s ~~retirement~~capital ~~obligations~~commitments.

				Total Spent		Total
	Working			through		Fund
Project	Interest			September 30, 2015		Budget		Status
				(in thousands)
Producing Properties
Eugene Island 346/347 wells #1 & #2		10.0	%	$	8,395	$	9,053	Production commenced in 2008. Wells are currently shut-in. Recompletion options are under evaluation. A recompletion is currently planned for second quarter 2016.
Eugene Island 354		33.0	%	$	5,092	$	6,364	Production commenced in 2007. Recompletion is planned for 2017.
Liberty Project		2.5	%	$	3,757	$	4,333	Production commenced in 2010. Well is currently shut-in due to pipeline maintenance activities and is expected to resume production in November 2015. Recompletion is planned for 2016.
Fully Depleted Properties
Carrera Project		2.5	%	$	4,058	$	4,639	Production commenced in 2011. Well reached the end of its productive life in fourth quarter 2014.
Sold Properties
Raven Project wells #1 & #2		6.25	%	$	2,863	$	2,863	In January 2014, the Fund sold its interest in the Raven Project. See "Raven Sale" below for additional information.

Table of Contents

Raven Sale

		Total Spent		Total
	Working	through		Fund
Project	Interest	March 31, 2016		Budget		Status
		(in thousands)
Producing Properties
Eugene Island 346/347	10.0%	$	8,395	$	9,053	Eugene Island 346/347 consists of two wells, which commenced production in 2008. Both wells were shut-in periodically throughout 2015 and continue to be shut-in periodically. The wells' current zones are nearing the end of their productive lives, however it is possible that a recompletion will be done in late-2016 at an estimated cost of $50 thousand to recover potential commercial reserves in a new zone. The Fund expects to spend $0.6 million for asset retirement obligations.

Eugene Island 354	33.0%	$	5,092	$	5,209	Eugene Island 354, a single-well project, commenced production in 2007. The Fund expects to spend $0.1 million for asset retirement obligations.

Liberty Project	2.5%	$	3,755	$	4,381	The Liberty Project, a single-well project, commenced production in 2010. After various shut-ins in late-2015 and early-2016, due to third-party facilities' repair and maintenance activities, the well resumed production in late-April 2016. A recompletion is planned for 2017 at an estimated cost of $0.1 million. The Fund expects to spend $0.6 million for asset retirement obligations.

On January 17, 2014, the Fund, along with its affiliates, entered into a purchase and sale agreement to sell its interest in the Raven Project, located in the state waters of Louisiana, to Castex Energy Partners, L.P. for cash consideration totaling $21.7 million. The closing of the sale transaction occurred on January 30, 2014. The Fund had a 6.25% working interest in the Raven Project and received $2.7 million in cash proceeds from the sale. The net carrying value for the Raven Project on the date of the sale was $0.1 million, thereby resulting in a gain to the Fund of $2.6 million, which was recognized during the nine months ended September 30, 2014. There was no such amount recorded during the nine months ended September 30, 2015.

Results of Operations

The following table summarizes the Fund’s results of operations for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2015~~2016 and ~~2014,~~2015 and should be read in conjunction with the Fund’s financial statements and notes thereto included within Item 1. “Financial Statements” in Part I inof this Quarterly Report.

	Three months ended September 30,						Nine months ended September 30,
	Three months ended March 31,
	2015			2014			2015			2014
	2016			2015
	(in thousands)
Revenue
Oil and gas revenue	$	~~201~~48		$	~~915~~220		$	~~740~~		$	~~2,567~~
Expenses
Depletion and amortization		7211			~~261~~63			~~471~~			~~562~~
Management fees to affiliate		-			-			-			272
Impairment of oil and gas properties		25			-
Operating expenses		~~123~~86			~~255~~70			~~346~~			~~893~~
General and administrative expenses		56			5556			~~167~~			~~143~~
Total expenses		~~251~~178			~~571~~189			~~984~~			~~1,870~~
(Loss) gain on sale of oil and gas properties		-			(3	)		-			2,599
(Loss) income from operations		(130	)		31
(Loss) income from operations		(50	)		341			(244	)		3,296
Interest income		1			2
Interest income		-			3			4			8
Net (loss) income	$	(129	)	$	33
Net (loss) income	$	(50	)	$	344		$	(240	)	$	3,304

Overview. The following table provides information related to the Fund’s oil and gas production and oil and gas revenue during the three and nine months ended September 30, 2015 and 2014. Natural gas liquid (“NGL”) sales are included within gas sales.10

	Three months ended September 30,				Nine months ended September 30,
	2015		2014		2015		2014
Number of wells producing		2		5		4		5
Total number of production days		174		352		619		898
Oil sales (in thousands of barrels)		4		8		14		23
Average oil price per barrel	$	44	$	96	$	50	$	99
Gas sales (in thousands of mcfs)		10		19		31		54
Average gas price per mcf	$	2.24	$	4.79	$	2.19	$	4.76

The decreases noted in the overview table were primarily attributable to natural declines in well production, to the Carrera Project, which reached the end of its productive life in fourth quarter 2014 and to Eugene Island 346/347 wells #1 and #2, which were shut-in during third quarter 2015. See additional discussion in “Business Update” section above.

Oil and Gas Revenue. Oil and gas revenue for the three months ended September 30, 2015 was $0.2 million, a decrease of $0.7 million from the three months ended September 30, 2014. The decrease was attributable to decreased sales volume totaling $0.5 million coupled with the impact of the decrease in oil and gas prices totaling $0.2 million. Oil and gas revenue for the nine months ended September 30, 2015 was $0.7 million, a decrease of $1.8 million from the nine months ended September 30, 2014. The decrease was attributable to decreased sales volume totaling $1.1 million coupled with the impact of the decrease in oil and gas prices totaling $0.7 million. See “Overview” above for additional information.

Table of Contents

~~Depletion and Amortization~~Overview. ~~Depletion~~The ~~and~~following ~~amortization~~table ~~for~~provides ~~the~~information ~~three~~related ~~months~~to ~~ended~~the ~~September~~Fund’s ~~30,~~oil ~~2015~~and ~~was~~gas ~~$0.1~~production ~~million,~~and aoil ~~decrease~~and ofgas ~~$0.2~~revenue ~~from~~during the three months ended ~~September~~March 3031, ~~2014. The~~2016 ~~decrease was attributable to a decrease in production volumes totaling $0.1 million coupled with a decrease in average depletion rates totaling $0.1 million. Depletion~~ and ~~amortization for the nine months ended September 30,~~ 2015 ~~was $0~~.~~5 million, a decrease of $0.1 million from the nine months ended September 30, 2014.~~ ~~The~~Natural ~~decrease~~gas ~~resulted~~liquid from a decrease in production volumes totaling $0.3 million coupled with a decrease in average depletion rates totaling $0.1 million. The decreases during the nine month period were partially offset by an adjustment to asset retirement obligations of $0.2 million, related to the Carrera Project. The decreases in average depletion rates were primarily attributable to the composite of the Fund’s productive wells. See (“~~Overview~~NGL”) ~~above~~sales ~~for~~are ~~additional~~included ~~information~~within ~~regarding~~gas ~~volume variances~~sales.

Management Fees to Affiliate. The Manager is entitled to an annual management fee totaling 2.5% of total capital contributions, net of cumulative dry-hole and related well costs incurred by the Fund, paid monthly. Effective April 1, 2014, the Manager waived its management fee for the remaining life of the Fund. Upon waiver of the management fee, the Fund began recording costs related to services provided by the Manager for accounting and investor relations. Such costs are included within general and administrative expenses. There were no management fees for the three and nine months ended September 30, 2015 and for the three months ended September 30, 2014. Management fees for the nine months ended September 30, 2014 were $0.3 million.

	Three months ended March 31,
	2016		2015
Number of wells producing		4		4
Total number of production days		150		212
Oil sales (in thousands of barrels)		1		4
Average oil price per barrel	$	29	$	46
Gas sales (in thousands of mcfs)		3		10
Average gas price per mcf	$	1.21	$	2.44

The decreases noted in the above table were principally attributable to the Liberty Project, which was shut-in for the majority of first quarter 2016. See additional discussion in “Business Update” section above.

Oil and Gas Revenue. Oil and gas revenue for the three months ended March 31, 2016 was $48 thousand, a decrease of $0.2 million from the three months ended March 31, 2015. The decrease was primarily attributable to decreased sales volume. See “Overview” above for factors that impact the oil and gas revenue volume and rate variances.

Depletion and Amortization. Depletion and amortization for the three months ended March 31, 2016 was $11 thousand, a decrease of $52 thousand from the three months ended March 31, 2015. The decrease was primarily attributable to decreased production volumes. See “Overview” above for certain factors that impact the depletion and amortization volume and rate variances.

Impairment of Oil and Gas Properties. During the three months ended March 31, 2016, the Fund recorded impairments of oil and gas properties of $25 thousand, related to the Eugene Island 346/347 Project, which was primarily attributable to declines in future oil and gas prices. The Fund did not record any impairments of oil and gas properties during the three months ended March 31, 2015.

Operating Expenses. Operating expenses represent costs specifically identifiable or allocable to the Fund’s wells, as detailed in the following table.

	Three months ended September 30,						Nine months ended September 30,
	Three months ended March 31,
	2015			2014			2015			2014
	2016			2015
	(in thousands)
Lease operating expense	$	~~100~~86		$	~~222~~96		$	~~279~~		$	~~524~~
Accretion expense		-			-			73			-
Insurance expense		1			9
Insurance expense		18			5			46			31
Other		(1	)		(35	)
Workover expense and other		5			28			(52	)		338
	$	86		$	70
	$	123		$	255		$	346		$	893

Lease operating expense relates to the Fund’s producing properties ~~during each period as outlined above in “Overview”~~. ~~The~~Insurance ~~average~~expense ~~production~~represents ~~cost~~premiums was $20.25 per barrel of oil equivalent (“BOE”) and $17.12 per BOE during the three and nine months ended September 30, 2015, respectively, compared to $19.03 per barrel of oil equivalent (“BOE”) and $16.36 per BOE during the three and nine months ended September 30, 2014, respectively. Accretion expense related to the ~~asset retirement obligations established for the~~ Fund’s ~~proved~~ properties~~. Insurance expense represents premiums related to producing well and control of well insurance~~, which ~~varies~~vary depending upon the number of wells producing or drilling. Insurance expense related to operating wells has been reclassified from “General and administrative ~~expense~~expenses” in prior year to “Operating ~~expense~~expenses” to correct prior period presentation. ~~Workover expense, which represents costs to restore or stimulate production of existing reserves, related to the Carrera Project and Eugene Island 354.~~

The average production cost, which includes lease operating expense and insurance expense, was $46.05 per barrel of oil equivalent (“BOE”) during the three months ended March 31, 2016, compared to $16.03 per BOE during the three months ended March 31, 2015. The increase was due to ongoing costs for wells that are experiencing natural declines in production.

General and Administrative Expenses. General and administrative expenses represent costs specifically identifiable or allocable to the Fund, such as accounting and professional fees and insurance expenses.

(Loss) Gain on Sale of Oil and Gas Properties. The Fund did not record a loss or gain on sale of oil and gas properties during the three and nine months ended September 30, 2015. During the three months ended September 30, 2014, the Fund recorded a loss on sale of oil and gas properties resulting from post-closing adjustments to the Raven Project sale price. During the nine months ended September 30, 2014, the Fund recorded a gain on sale of oil and gas properties of $2.6 million related to the Raven Project. See “Business Update” for additional information regarding the sale.

Interest Income. Interest income is comprised of interest earned on cash and cash equivalents and salvage fund.

Table of Contents

Capital Resources and Liquidity

Operating Cash Flows

Cash flows ~~provided~~used byin operating activities for the ~~nine~~three months ended ~~September~~March 3031, ~~2015~~2016 were $0.41 million, primarily related to ~~revenue~~operating ~~received~~expenses of $0.91 million, ~~partially~~and ~~offset~~general byand ~~operating~~administrative expenses ~~paid~~ of $0.41 million, ~~and~~partially ~~general~~offset ~~and~~by ~~administrative~~revenue ~~expenses~~received ~~paid~~ of $0.1 million.

Cash flows provided by operating activities for the ~~nine~~three months ended ~~September~~March 3031, ~~2014~~2015 were $1.0.1 million, primarily related to revenue received of $20.54 million, partially offset by operating expenses ~~paid~~ of $1.0.2 million, ~~management fees of $0.3 million~~ and general and administrative expenses ~~paid~~ of $0.21 million.

Table of Contents

Investing Cash Flows

~~Cash~~There ~~flows~~were ~~used~~no incash flows from investing activities for the ~~nine~~three months ended ~~September~~March 3031, ~~2015 were $0~~2016.~~2 million, primarily related to investments in the salvage fund.~~

Cash flows provided by investing activities for the ~~nine~~three months ended ~~September~~March 3031, ~~2014~~2015 were $~~2.7~~3 ~~million, related to proceeds from the sale of the Raven Project of $2~~thousand.~~7 million and net credits received on oil and gas properties of $0.1 million, partially offset by investments in the salvage fund of $0.1 million.~~

Financing Cash Flows

~~Cash~~There ~~flows~~were ~~used~~no incash flows from financing activities for the ~~nine~~three months ended ~~September~~March 3031, ~~2015 were $0~~2016.~~3 million, related to manager and shareholder distributions.~~

Cash flows used in financing activities for the ~~nine~~three months ended ~~September~~March 3031, ~~2014~~2015 were $20.62 million, related to manager and shareholder distributions~~, of which $1~~.~~3 million was related to the distribution of the proceeds from the sale of the Raven Project.~~

Estimated Capital Expenditures

The Fund has entered into multiple agreements for the acquisition, drilling and development of its oil and gas properties. ~~The~~At March 31, 2016, the Fund’s estimated capital expenditures ~~associated~~related ~~with~~to ~~these~~expected ~~agreements~~recompletions ~~vary~~and ~~depending~~asset onretirement ~~the~~obligations. See ~~stage~~“Business Update” under this Item 2. “Management’s Discussion and Analysis of ~~development~~Financial onCondition aand ~~property-by-property~~Results ~~basis~~of Operations” of this Quarterly Report for information regarding the Fund’s current projects. See “Liquidity Needs” below for additional information.

Capital expenditures for oil and gas properties have been funded with the capital raised by the Fund in its private placement offering~~, which may be all the capital it will obtain~~. The number of projects in which the Fund could invest was limited, and each unsuccessful project the Fund experienced exhausted its capital and reduced its ability to generate revenue.

Liquidity Needs

The Fund’s primary short-term liquidity needs are to fund its operations and capital expenditures for its oil and gas properties. Such needs are funded utilizing operating income, ~~and~~ existing cash on-hand and income earned therefrom.

As of ~~September~~March 3031, ~~2015~~2016, the Fund’s estimated capital commitments related to its oil and gas properties were $32.10 million (which include asset retirement obligations for the Fund’s projects of $1.9 million), of which $0.76 million is expected to be spent during the next twelve months.

Distributions, if any, are funded from available cash from operations, as defined in the LLC Agreement, and the frequency and amount are within the Manager’s discretion.

Off-Balance Sheet Arrangements

The Fund had no off-balance sheet arrangements at ~~September~~March 3031, ~~2015~~2016 and December 31, ~~2014~~2015 and does not anticipate the use of such arrangements in the future.

Table of Contents

Contractual Obligations

The Fund enters into participation and joint operating agreements with operators. On behalf of the Fund, an operator enters into various contractual commitments pertaining to exploration, development and production activities. The Fund does not negotiate such contracts. No contractual obligations exist at ~~September~~March 3031, ~~2015~~2016 and December 31, ~~2014~~2015, other than those discussed in “Estimated Capital Expenditures” above.

Recent Accounting Pronouncements

The Fund has considered recent accounting pronouncements and believes that these recent pronouncements will not have a material effect on the Fund’s financial statements.

Table of Contents

ITEM 3.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Not required.

ITEM 4.

CONTROLS AND PROCEDURES

In accordance with Rules 13a-15 and 15d-15 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), the Fund’s management, including its Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of the Fund’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Fund’s disclosure controls and procedures were effective as of ~~September~~March 3031, ~~2015~~2016.

There has been no change in the Fund’s internal control over financial reporting that occurred during the three months ended ~~September~~March 3031, ~~2015~~2016 that has materially affected, or is reasonably likely to materially affect, the Fund’s internal control over financial reporting.

PART II – OTHER INFORMATION

ITEM 1.

LEGAL PROCEEDINGS

None.

ITEM 1A.

RISK FACTORS

Not required.

ITEM 2.

UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3.

DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4.

MINE SAFETY DISCLOSURES

None.

ITEM 5.

OTHER INFORMATION

None.

1413

Table of Contents

ITEM 6.

EXHIBITS

EXHIBIT NUMBER	TITLE OF EXHIBIT	METHOD OF FILING

31.1	Certification of Robert E. Swanson, Chief Executive Officer of the Fund, pursuant to Exchange Act Rule 13a-14(a)	Filed herewith

31.2	Certification of Kathleen P. McSherry, Executive Vice President and Chief Financial Officer of the Fund, pursuant to Exchange Act Rule 13a-14(a)	Filed herewith

32	Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, signed by Robert E. Swanson, Chief Executive Officer of the Fund and Kathleen P. McSherry, Executive Vice President and Chief Financial Officer of the Fund	Filed herewith

101.INS	XBRL Instance Document	Filed herewith

101.SCH	XBRL Taxonomy Extension Schema	Filed herewith

101.CAL	XBRL Taxonomy Extension Calculation Linkbase	Filed herewith

101.DEF	XBRL Taxonomy Extension Definition Linkbase Document	Filed herewith

101.LAB	XBRL Taxonomy Extension Label Linkbase	Filed herewith

101.PRE	XBRL Taxonomy Extension Presentation Linkbase	Filed herewith

SIGNATURES

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

				RIDGEWOOD ENERGY P FUND, LLC
Dated:	~~October~~May 2910, ~~2015~~2016	By:	/s/	ROBERT E. SWANSON
			Name:	Robert E. Swanson
			Title:	Chief Executive Officer
				(Principal Executive Officer)
Dated:	~~October~~May 2910, ~~2015~~2016	By:	/s/	KATHLEEN P. MCSHERRY
			Name:	Kathleen P. McSherry
			Title:	Executive Vice President and Chief Financial Officer
				(Principal Financial and Accounting Officer)

Filing Compare · Ridgewood Energy P Fund LLC