DGOC Series 18B LP - FORM 10-Q

DGOC Series 18B LP - FORM 10-Q - May 15, 2018

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EX-32.2 - EXHIBIT 32.2 - DGOC Series 18B LP	a2018_1qxser18bxex322.htm
EX-32.1 - EXHIBIT 32.1 - DGOC Series 18B LP	a2018_1qxser18bxex321.htm
EX-31.2 - EXHIBIT 31.2 - DGOC Series 18B LP	a2018_1qxser18bxex312.htm
EX-31.1 - EXHIBIT 31.1 - DGOC Series 18B LP	a2018_1qxser18bxex311.htm

United States

Securities and Exchange Commission

Washington, D.C. 20549

_____________________________________________

Form 10-Q

_____________________________________________

(Mark One)



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

For the quarterly period ended March 31, 2018



☐	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 000-55839

_____________________________________________

DGOC SERIES 18(B), L.P.

(Name of small business issuer in its charter)

_____________________________________________



Delaware	82-2097510
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

1100 Corporate Drive Birmingham, Alabama	35242
(Address of principal executive offices)	(zip code)

_____________________________________________

Issuer’s telephone number, including area code: (412)-489-0006

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 ☐

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 ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See definitions of “large accelerated filer”, “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

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

DGOC SERIES 18(B), L.P.

INDEX TO QUARTERLY REPORT

ON FORM 10-Q



		PAGE
PART I.	FINANCIAL INFORMATION (Unaudited)

Item 1:	Financial Statements (Unaudited)

	Condensed Balance Sheets	3

	Condensed Statements of Operations	4

	Condensed Statement of Changes in Partners' Capital	5

	Condensed Statements of Cash Flows	6

	Notes to Condensed Financial Statements	7

Item 2:	Management’s Discussion and Analysis of Financial Condition and Results of Operations	11

Item 4:	Controls and Procedures	14

PART II.	OTHER INFORMATION

Item 1:	Legal Proceedings	15

Item 6:	Exhibits	15

SIGNATURES		17

CERTIFICATIONS

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DGOC SERIES 18(B), L.P.

CONDENSED BALANCE SHEETS

(Unaudited)



	March 31, 2018		December 31, 2017
ASSETS
Current assets:
Cash	$	—	$	—
Accounts receivable trade–affiliate	515,900		479,600
Total current assets	515,900		479,600
Gas and oil properties, net	4,374,000		4,478,000
Long-term asset retirement receivable-affiliate	356,900		325,100
Total assets	$	5,246,800	$	5,282,700

LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accrued liabilities	8,400		11,300
Total current liabilities	8,400		11,300

Asset retirement obligations	1,519,300		1,501,800

Commitments and contingencies (Note 4)

Partners’ capital:
Managing general partner’s interest	422,400		412,200
Limited partners’ interest (12,278 units)	3,296,700		3,357,400
Total partners’ capital	3,719,100		3,769,600
Total liabilities and partners’ capital	$	5,246,800	$	5,282,700

See accompanying notes to condensed financial statements.

DGOC SERIES 18(B), L.P.

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)



	Three Months Ended March 31,
	2018		2017
REVENUES
Natural gas and oil	$	510,600	$	725,500
Total revenues	510,600		725,500

COSTS AND EXPENSES
Production	249,600		235,000
Depletion	104,000		103,700
Accretion of asset retirement obligations	17,500		16,500
General and administrative	32,300		23,200
Total costs and expenses	403,400		378,400
Net income	$	107,200	$	347,100

Allocation of net income:
Managing general partner	$	54,500	$	115,500
Limited partners	$	52,700	$	231,600
Net income per limited partnership unit	$	4	$	19

See accompanying notes to condensed financial statements.

DGOC SERIES 18(B), L.P.

CONDENSED STATEMENT OF CHANGES IN PARTNERS’ CAPITAL

(Unaudited)



	Managing General Partner			Limited Partners			Total
Balance at December 31, 2017	$	412,200		$	3,357,400		$	3,769,600

Participation in revenues, costs and expenses:
Net production revenues	80,100			180,900			261,000
Depletion	(11,600		)	(92,400		)	(104,000		)
Accretion of asset retirement obligations	(4,900		)	(12,600		)	(17,500		)
General and administrative	(9,100		)	(23,200		)	(32,300		)
Net income	54,500			52,700			107,200

Distributions to partners	(44,300		)	(113,400		)	(157,700		)

Balance at March 31, 2018	$	422,400		$	3,296,700		$	3,719,100

See accompanying notes to condensed financial statements.

DGOC SERIES 18(B), L.P.

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)



	Three Months Ended March 31,
	2018			2017
Cash flows from operating activities:
Net income	$	107,200		$	347,100
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion	104,000			103,700
Accretion of asset retirement obligations	17,500			16,500
Changes in operating assets and liabilities:
Increase in accounts receivable trade-affiliate	(36,300		)	(193,900		)
Increase in asset retirement receivable-affiliate	(31,800		)	(31,800		)
Decrease in accrued liabilities	(2,900		)	(5,200		)
Net cash provided by operating activities	157,700			236,400

Cash flows from investing activities:
Net cash provided by investing activities	—			—

Cash flows from financing activities:
Distributions to partners	(157,700		)	(237,000		)
Net cash used in financing activities	(157,700		)	(237,000		)

Net change in cash	—			(600		)
Cash at beginning of period	—			297,300
Cash at end of period	$	—		$	296,700

See accompanying notes to condensed financial statements.

DGOC SERIES 18(B), L.P.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

NOTE 1 - DESCRIPTION OF BUSINESS

DGOC Series 18(B), L.P. (the “Partnership”) is a Delaware limited partnership, formed on July 6, 2017 and includes the Appalachian-based assets that were previously included within Atlas Resources Public #18-2009 (B) L.P. ("Predecessor Partnership") that was formed on April 8, 2008 and was then managed by Atlas Resources, LLC ("Atlas" or "Previous MGP"). DGOC Partnership Holdings, LLC now serves as its Managing General Partner ("DGOC Holdings" or the "MGP") and certain affiliates of the MGP serve as our Operator ("Operator"). DGOC Holdings is an indirect subsidiary of Diversified Gas & Oil, PLC (“Diversified”; AIM: DGOC). Unless the context otherwise requires, references below to “the Partnership,” “we,” “us,” “our” and “our company”, refer to DGOC Series 18(B), L.P.

The Partnership has drilled and currently operates wells located in Pennsylvania and Tennessee. We have no employees and rely on our MGP to staff and manage our operations, which in turn, relied on Atlas Energy Group, Titan’s parent company, for administrative services through a Transition Services Agreement effective through December 31, 2017. Since the expiration of the TSA, staffing is provided by an affiliate of Diversified.

The Partnership’s operating cash flows are generated from its wells, which produce natural gas and oil. Produced natural gas and oil is then delivered to market through third-party gas gathering systems. The Partnership intends to produce its wells until they are sold, depleted or become uneconomical to produce, at which time they will be plugged and abandoned . The Partnership does not expect to drill additional wells and expects no additional funds will be required for drilling.

The economic viability of the Partnership’s production is based on a variety of factors including proved developed reserves that it can expect to recover through existing wells with existing equipment and operating methods or in which the cost of additional required extraction equipment is relatively minor compared to the cost of a new well; and through currently installed extraction equipment and related infrastructure which is operational at the time of the reserves estimate (if the extraction is by means not involving drilling, completing or reworking a well). There are numerous uncertainties inherent in estimating quantities of proven reserves and in projecting future net revenues.

The prices at which the Partnership’s natural gas and oil will be sold are uncertain and the Partnership is not guaranteed a specific price for the sale of its production. Changes in natural gas and oil prices have a significant impact on the Partnership’s cash flow and the value of its reserves. Lower natural gas and oil prices may, in addition to decreasing the Partnership’s revenues, also reduce the amount of natural gas that the Partnership can produce economically.

Liquidity and Capital Resources

The Partnership is generally limited to the amount of funds generated by the cash flow from its operations to fund its obligations and make distributions, if any, to its partners. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and continue to remain low, on a relative basis, in 2018. These lower commodity prices negatively impact the Partnership’s revenues, earnings and cash flows. In addition, low commodity prices place downward pressure on the Partnership’s proved natural gas and oil reserves as some volumes in the later years of the life of the well become uneconomic to produce at the lower prices. The MGP continues to implement various cost saving measures to reduce the Partnership’s operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, and deferring and/or eliminating discretionary costs. The MGP will continue to be strategic in managing the Partnership’s cost structure and, in turn, liquidity to meet its operating needs. To the extent commodity prices remain low or decline further, or the Partnership experiences other disruptions in the industry, the Partnership’s ability to fund its operations and make distributions may be further impacted, and could result in the liquidation of the Partnership’s operations.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

These condensed financial statements are unaudited, but in the opinion of management, reflect all adjustments necessary for a fair presentation of results for the interim periods presented. All adjustments are of a normal recurring nature unless disclosed otherwise. Interim period results are not necessarily indicative of results to be expected for the full year. These condensed financial statements have been prepared in accordance with rules of the Securities and Exchange Commission (“SEC”) and do not include all the information and disclosures required by accounting principles generally accepted in the United States (“GAAP”) for complete

financial statements. They should be read in conjunction with the financial statements for the year ended December 31, 2017 and notes thereto included in our 2017 Annual Report on Form 10-K, which include a summary of the significant accounting policies.

Use of Estimates

The preparation of the Partnership’s financial statements in conformity with U.S. GAAP requires the MGP to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities that exist at the date of the Partnership’s condensed financial statements, as well as the reported amounts of revenues and costs and expenses during the reporting periods. The Partnership’s condensed financial statements are based on a number of significant estimates, including the revenue and expense accruals, depletion, impairments and the probability of forecasted transactions. The natural gas industry principally conducts its business by processing actual transactions many as 60 days after the month of delivery. Consequently, the most recent two months’ financial results were recorded using estimated volumes and contract market prices. Actual results could differ from those estimates.

Gas and Oil Properties

The following is a summary of gas and oil properties at the dates indicated:



	March 31,			December 31,			Change
	2018			2017			$			%
Proved properties:
Leasehold interests	$	798,300		$	798,300		$	—		—	%
Wells and related equipment	120,370,300			120,370,300			—			—	%
Total natural gas and oil properties	121,168,600			121,168,600			—			—	%
Accumulated depletion and impairment	(116,794,600		)	(116,690,600		)	(104,000		)	—	%
Gas and oil properties, net	$	4,374,000		$	4,478,000		$	(104,000	)	(2	)%

We review our oil and natural gas producing properties for impairment whenever events or changes in circumstances indicate that the carrying amount of such properties may not be recoverable. The review of the Partnership’s natural gas and oil properties is done on a field-by-field basis by determining if the historical cost of proved properties less the applicable accumulated depletion and impairment is less than the estimated expected undiscounted future cash flows including salvage. If the carrying value exceeds the expected future cash flows, an impairment loss is recognized for the difference between the estimated fair market value and the carrying value of the assets. Events or changes in circumstances that would indicate the need for impairment testing include, among other factors: operating losses; unused capacity; market value declines; technological developments resulting in obsolescence; changes in demand for products manufactured by others utilizing our services or for our products; changes in competition and competitive practices; uncertainties associated with the United States and world economies; changes in the expected level of environmental capital, operating or remediation expenditures; and changes in governmental regulations or actions. There was no triggering event in the first quarter of 2018 that would cause us to believe the value of oil and natural gas producing properties should be impaired.

Recently Adopted Accounting Standards

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). The standard requires an entity to identify all customer contracts and their corresponding performance obligations, determine the transaction price and its allocation, at the entity level, and to recognize revenue upon fulfillment of the performance obligation. ASU 2014-09 replaces most of the existing revenue recognition requirements in GAAP. The Partnership adopted the standard on January 1, 2018 using the modified retrospective method as of the adoption date. The new standard did not have a material impact on the Partnership's Financial Statements other than requiring new disclosures.

Revenue Recognition

The Partnership sells natural gas under multiple purchaser contracts. The Partnership’s performance obligation, to the customer, includes the production and sale of natural gas at multiple delivery points. The sales contracts are based on blended rate pricing provisions with fixed and variable components. The fixed component is well defined, under each purchaser contract, and is tied to base production levels. The variable component is generally tied to a regional market index and is received for anything in excess of the base production levels outlined under each customer contract. Under certain agreements, the Partnership’s natural

gas sales are delivered to midstream processing entities and DGOC Partnership Holdings, LLC is in control of the gas asset at all points of sale to the purchaser(s). The gathering fees charged, by the midstream processing agents, are paid at the gross rate, by the Partnership as production costs which is consistent with prior reporting periods. The Partnership recognizes revenue and related accounts receivable in the month the performance obligation has been met. However; the settlement statements may not be received from the purchaser for 30-90 days after the production is delivered. As a result, DGOC Partnership Holdings, LLC is required to estimate and accrue for the current month’s revenue using well defined processes that have historically demonstrated close proximities to actual payments. The current revenue accruals have existing internal controls and are evaluated, for accuracy, on a regular basis. Revenues from the production of natural gas, in which the Partnership has an interest with other producers, are recognized on the basis of its percentage ownership of working interest and/or overriding royalty. The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses.

NOTE 3 - CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS

The Partnership has entered into the following significant transactions with the MGP and its affiliates as provided under its Partnership Agreement. Administrative costs, which are included in general and administrative expenses in the Partnership’s condensed statements of operations, are payable at $75 per well per month. Monthly well supervision fees, which are included in production expense in the Partnership’s condensed statements of operations, are payable at $975 per well per month for Marcellus wells and for all other wells a fee of $392 is charged per well per month for operating and maintaining the wells. Well supervision fees are proportionately reduced to the extent the Partnership does not acquire 100% of the working interest in a well. Transportation fees are included in production expenses in the Partnership’s condensed statements of operations and are generally payable at either 16% of the natural gas sales price or $0.35 per Mcf, whichever is greater. Direct costs, which are included in production and general administrative expenses in the Partnership’s condensed statements of operations, are payable to the MGP and its affiliates as reimbursement for all costs expended on the Partnership’s behalf.

The following table provides information with respect to these costs and the periods incurred:



	Three Months Ended March 31,				Change
	2018		2017*		$			%
Administrative fees	$	6,800	$	6,400	$	400		6	%
Supervision fees	88,600		82,900		5,700			7	%
Transportation fees	82,500		94,100		(11,600		)	(12	)%
Direct costs	104,000		74,800		29,200			39	%
Total	$	281,900	$	258,200	$	23,700		9	%

* Amounts paid to the Previous MGP.

The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses. Accounts receivable trade-affiliate on the Partnership’s balance sheets includes the net production revenues due from the MGP. Accounts payable trade-affiliate on the Partnership’s balance sheets include costs relating to well construction paid by the MGP.

NOTE 4 - COMMITMENTS AND CONTINGENCIES

General Commitments

Subject to certain conditions, investor partners may present their interests for purchase by the MGP. The purchase price is calculated by the MGP in accordance with the terms of the partnership agreement. The MGP is not obligated to purchase more than 5% of the total outstanding units in any calendar year. In the event that the MGP is unable to obtain the necessary funds, it may suspend its purchase obligation.

Beginning one year after each of the Partnership’s wells has been placed into production, the MGP, as Operator, may retain $200 per month per well to cover estimated future plugging and abandonment costs. As of March 31, 2018, the Operator has withheld $356,900 of net production revenue for future plugging and abandonment costs.

Environmental risk is inherent to oil and natural gas operations, and we and our affiliates may be, at times, subject to potential environmental remediation liability. We manage this environmental risk through appropriate environmental policies and practices to minimize any impact our operations may have on the environment. To the extent that we are unable to recover payment

for environmental liabilities from insurance or other potentially responsible parties, we will be responsible for payment of liabilities arising from environmental incidents associated with the operating activities of our oil and natural gas operations.

Legal Proceedings

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


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

Forward-Looking Statements

This Form 10-Q includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 (the “Securities Act”), as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). These statements involve known and unknown risks, uncertainties and other factors that may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by the forward-looking statements. In some cases, you can identify forward-looking statements in this Form 10-Q by words such as “anticipate,” “project,” “intend,” “estimate,” “expect,” “believe,” “predict,” “budget,” “projection,” “goal,” “plan,” “forecast,” “target” or similar expressions. Readers are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly release the results of any revisions to forward-looking statements which we may make to reflect events or circumstances after the date of this Form 10-Q or to reflect the occurrence of unanticipated events.

The Partnership cautions you that the forward-looking statements contained in this Form 10-Q are subject to all of the risks and uncertainties, many of which are beyond its control, incident to the production and sale of natural gas. These risks include, but are not limited to, the risks described in our Annual Report on Form 10-K for the year ended December 31, 2017 (the "2017 Annual Report on Form 10-K"), including under the heading entitled “Forward-Looking Statements,” and all quarterly reports on Form 10-Q filed subsequently thereto. Should one or more of the risks or uncertainties described herein or in our 2017 Annual Report on Form 10-K occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. We specifically disclaim all responsibility to publicly update any information contained in a forward-looking statement or any forward-looking statement in its entirety and therefore disclaim any resulting liability for potentially related damages.

General

See Note 1 to our condensed financial statements for a description of our business. Comparisons to financial results for periods prior to July 2017 reflect the results of the Predecessor Partnership.

Overview

The following discussion provides information to assist in understanding our financial condition and results of operations. Our operating cash flows are generated from our wells, which produce primarily natural gas, but also some oil. Our produced natural gas is then delivered to market through affiliated and/or third-party gas gathering systems.

Our ongoing operating and maintenance costs have been and are expected to be fulfilled through revenues from the sale of our natural gas production. Our results of operations are dependent upon the difference between prices received for our oil and gas production and the costs to find and produce such oil and gas. Oil and natural gas prices have been volatile and subject to fluctuations based on a number of factors beyond our control.

Beginning in the third quarter of 2014, the global prices for oil and natural gas began a dramatic decline, and while improved, prices remain low on a relative basis. Current prices remain significantly less than they were in the several years prior to mid-2014. A decline in oil and natural gas prices and a sustained period of oil and natural gas prices at depressed levels could have a material adverse effect on our financial condition. We currently do not have any derivative contracts to hedge against declines in commodity prices.

We pay our MGP, as an Operator, a monthly well supervision fee, which covers all normal and regularly recurring operating expenses for the production and sale of natural gas such as:


•	well tending, routine maintenance and adjustment;


•	reading meters, recording production, pumping, maintaining appropriate books and records; and


•	preparation of reports for us and government agencies.

The well supervision fees, however, do not include costs and expenses related to the production and sale of oil, the purchase of certain equipment, materials and brine disposal. If these expenses are incurred, we pay cost for third-party services, materials and a competitive charge for services performed directly by our MGP or its affiliates. Also, beginning one year after each of our wells has been placed into production, our Operators, may retain $200 per month, per well, to cover the estimated future plugging and abandonment costs of the well. As of March 31, 2018, our Operators have withheld $356,900 of net production revenues for this purpose.

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,						Change
	2018			2017			$			%
Production revenues (in thousands):
Gas	$	511		$	726		$	(215	)	(30	)%

Production volumes:
Gas (Mcf/day) (1)	2,443			2,744			(301		)	(11	)%

Average sales prices(2):
Gas (per Mcf) (1)	$	2.32		$	2.94		$	(0.62	)	(21	)%

Production costs:
As a percent of revenues	49		%	32		%	17		%	53	%
Per Mcfe (1)	$	1.14		$	0.95		$	0.19		20	%

Depletion per Mcfe	$	0.47		$	0.42		$	0.05		12	%

___________________


(1)	“Mcf” represents thousand cubic feet, “mcfe” represents thousand cubic feet equivalent.


(2)	Average sales prices represent accrual basis pricing.

Revenues

The following tables reconcile the changes in natural gas revenue for the respective periods presented by reflecting the effect of changes in volume and in the underlying commodity prices.



	Three Months Ended March 31,
	Natural gas
Revenues for the three months ended March 31, 2017	$	725,500
Volume decrease	(79,700		)
Price decrease	(135,200		)
Net decrease	(214,900		)
Revenues for the three months ended March 31, 2018	$	510,600

The natural gas and oil volume variances reflected for the periods presented in the tables above relate to (1) wells being temporarily shut-in, (2) which may result in timing differences associated with the production from those wells depending upon when they are placed back into production, and (3) normal and expected declines inherent in the life of a well.

Costs and expenses



	Three Months Ended March 31,				Change
	2018		2017		$		%
Production	$	249,600	$	235,000	$	14,600	6	%
Depletion	104,000		103,700		300		—	%
Accretion of asset retirement obligations	17,500		16,500		1,000		6	%
General and administrative	32,300		23,200		9,100		39	%
Total costs and expenses	$	403,400	$	378,400	$	25,000	7	%

Production expenses were $249,600 and $235,000 for the three months ended March 31, 2018 and 2017, respectively, an increase of $14,600 (6%). The increase for the three months ended March 31, 2018 when compared to the prior year similar period was primarily due to a combination of higher water hauling and disposal costs and PA Impact Fees.

Depletion expense, which is calculated by taking the total capital invested to develop the producing wells divided by the total estimated reserves of the well and is then recognized for each unit of production during the period. For the three month period ended March 31, 2018 and 2017 the decrease in reserves produced a higher depletion rate which contributed to an increase in depletion expense.

General and administrative expenses for the three months ended March 31, 2018 and 2017 were $32,300 and $23,200, respectively, an increase of $9,100 (39%). This increase was due to an increase in audit expenses.

Cash Flows Overview

Cash flows from operating activities for the three months ended March 31, 2018 and 2017 were $157,700 and $236,400, respectively, and include cash receipts and disbursements attributable to our normal monthly operating cycle for gas production, lease operating expenses, gathering, processing and transportation expenses, severance taxes, general and administrative expenses. The decrease in cash flows resulted primarily from decreased revenues driven by lower produced volumes.

No cash was provided by investing activities for the three months ended March 31, 2018 and 2017.

Cash used in financing activities decreased $79,300 during the three months ended March 31, 2018 to $157,700 from $237,000 for the three months ended March 31, 2017. This decrease was due to a decrease in cash distributions to partners, which was driven by a (30)% decrease in revenues compounded by a 7% increase in costs and expenses.

Liquidity and Capital Resources

See Note 1 to our condensed financial statements for additional information related to liquidity and capital resources.

Critical Accounting Policies

See Note 2 to our condensed financial statements for additional information related to recently issued accounting standards.

For a more complete discussion of the accounting policies and estimates that we have identified as critical in the preparation of our condensed financial statements, please refer to our Management’s Discussion and Analysis of Financial Condition and Results of Operations in our Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

The MGP maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed in our Securities Exchange Act of 1934 reports is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to the MGP's Chief Executive Officer and Principal Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. In designing and evaluating the disclosure controls and procedures, the MGP recognized that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and our management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

Under the supervision of the MGP's Chief Executive Officer and Principal Financial Officer, the MGP has carried out an evaluation of the effectiveness of its disclosure controls and procedures as of the end of the period covered by this report. Based upon that evaluation, the MGP's Chief Executive Officer and Principal Financial Officer concluded that, as of March 31, 2018, its disclosure controls and procedures were effective.

Changes in Internal Control over Financial Reporting

There have been no changes in the Partnership’s internal control over financial reporting during our most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The Partnership is a party to various routine legal proceedings arising out of the ordinary course of its business. The MGP believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the Partnership’s financial condition or results of operations.

The MGP's affiliates and their subsidiaries are party to various routine legal proceedings arising in the ordinary course of their respective businesses. The MGP 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

3.1		Certificate of Limited Partnership for DGOC Series 18(B), L.P. (incorporated by reference to Exhibit 3.1 to the Company's Form 10-12G Registration Statement filed on September 8, 2017)
3.2		Certificate and Agreement of Limited Partnership for DGOC Series 18(B), L.P. (incorporated by reference to Exhibit 3.2 to the Company's Form 10-12G Registration Statement filed on September 8, 2017)
31.1	(a)	Certification Pursuant to Rule 13a-14/15(d)-14
31.2	(a)	Certification Pursuant to Rule 13a-14/15(d)-14
32.1	(b)	Section 1350 Certification
32.2	(b)	Section 1350 Certification
101	(c)	Interactive Data File

(a)	Filed herewith
(b)	Furnished herewith. Pursuant to SEC Release No. 33-8212, this certification will be treated as "accompanying" this report and not "filed" as part of such report for purposes of Section 18 of the Exchange Act or otherwise subject to the liability of Section 18 of the Exchange Act, and this certification will not be deemed to be incorporated by reference into any filing under the Securities Act of 1933, except to the extent that the registrant specifically incorporates it by reference.
(c)	Pursuant to Rule 406T of Regulation S-T, these interactive data files are being furnished herewith and are not deemed filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, or Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise are not subject to liability.

_______________________________________________

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.

DGOC SERIES 18(B), L.P.



	By:	DGOC Partnership Holdings, LLC, its Managing General Partner

Date: May 15, 2018	By:	/s/ ROBERT R. HUTSON, JR.
		Robert R. Hutson, Jr., Chief Executive Officer (principal executive officer) of the Managing General Partner



Date: May 15, 2018	By:	/s/BRADLEY G. GRAY
		Bradley G. Gray, Chief Operating Officer (principal financial officer) of the Managing General Partner

Large accelerated filer ☐

Accelerated filer ☐

Non-accelerated filer ☐

Smaller reporting company X

Emerging growth company ☐