Properties and equipment and related accumulated DD&A as of June 30, 2020, and September 31, 2019, are as follows:

	June 30, 2020			September 30, 2019
Properties and equipment at cost, based on successful efforts accounting:
Producing oil and natural gas properties		324,913,067			354,718,398
Non-producing oil and natural gas properties		19,081,485			14,599,023
Other property and equipment		777,104			717,121
		344,771,656			370,034,542
Less accumulated depreciation, depletion and amortization		(261,733,655	)		(258,607,521	)
Net properties and equipment		83,038,001			111,427,021

During the second and third quarters of 2020, the Company had no significant divestitures.

During the first quarter of 2020, Panhandle closed on the sale of 530 net mineral acres in Eddy County, New Mexico, for $3.4 million. At the time of sale, the assets were mostly amortized and therefore had minimal net book value. Almost all of the value received was a gain on the sale of assets, $3.3 million, in the first quarter of 2020. The Company utilized a like-kind exchange under Internal Revenue Code Section 1031 to defer income tax on all of the gain by offsetting it with the STACK/SCOOP mineral acreage acquisition that was purchased during the quarter using qualified exchange accommodation agreements.

During the third quarter of 2019, the Company sold 166 net mineral acres and producing oil and natural gas properties located in Martin County, Texas, to private buyers for total net consideration of $4.0 million and recorded a gain on the sale of $4.0 million. The cash from the sale was used to purchase minerals and reduce the Company’s outstanding bank debt.

During the first quarter of 2019, the Company sold 206 net mineral acres and producing oil and natural gas properties located in Lea and Eddy Counties, New Mexico, to a private buyer for total net consideration of $9.1 million and recorded a gain on the sale of $9.1 million. The cash from the sale was used to reduce the Company’s outstanding debt under the Credit Facility.

During the second and third quarters of 2020, the Company had no significant acquisitions.

During the first quarter of 2020, Panhandle closed on the purchase of 700 net mineral acres in Kingfisher, Canadian and Garvin Counties, Oklahoma, for a purchase price of $9.3 million (after customary closing adjustments).

During the third quarter of 2019, the Company acquired 313 net mineral acres (which include producing oil and natural gas properties) in the Bakken/Three Forks play in North Dakota and in the STACK play in Blaine County, Oklahoma, for $3.3 million.

During the second quarter of 2019, the Company acquired 329 net mineral acres (which include producing oil and natural gas properties) in the STACK play in Blaine and Caddo Counties, Oklahoma, for $1.4 million.

During the first quarter of 2019, the Company acquired 45 net mineral acres (which include producing oil and natural gas properties) in the STACK play in Blaine County, Oklahoma, with undeveloped locations identified in both the Woodford and Meramac Shales for $0.4 million.

Management considers the estimation of the Company’s crude oil, NGL and natural gas reserves to be the most significant of its judgments and estimates. Changes in crude oil, NGL and natural gas reserve estimates affect the Company’s calculation of DD&A, provision for retirement of assets and assessment of the need for asset impairments. On an annual basis, with a semi-annual update, the Company’s Independent Consulting Petroleum Engineer, with assistance from Company staff, prepares estimates of crude oil, NGL and natural gas reserves based on available geologic and seismic data, reservoir pressure data, core analysis reports, well logs, analogous reservoir performance history, production data and other available sources of engineering, geologic and geophysical information. Between periods in which reserves would normally be calculated, the Company updates the reserve calculations utilizing appropriate prices for the current period. The estimated oil, NGL and natural gas reserves were computed using the 12-month average price calculated as the unweighted arithmetic average of the first-day-of-the-month oil, NGL and natural gas price for each month within the 12-month period prior to the balance sheet date, held flat over the life of the properties. However, projected future crude oil, NGL and natural gas pricing assumptions are used by management to prepare estimates of crude oil, NGL and natural gas reserves and future net cash flows used in asset impairment assessments and in formulating management’s overall operating decisions. Crude oil, NGL and natural gas prices are volatile and affected by worldwide production and consumption and are outside the control of management (see Item 1A: Risk Factors for a further discussion of price volatility).

All long-lived assets, principally oil and natural gas properties, are monitored for potential impairment when circumstances indicate that the carrying value of the asset may be greater than its estimated future net cash flows. The evaluations involve significant judgment since the results are based on estimated future events, such as: inflation rates; future drilling and completion costs; future sales prices for oil, NGL and natural gas; future production costs; estimates of future oil, NGL and natural gas reserves to be recovered and the timing thereof; the economic and regulatory climates and other factors. The need to test a property for impairment may result from significant declines in sales prices or unfavorable adjustments to oil, NGL and natural gas reserves. Between periods in which reserves would normally be calculated, the Company updates the reserve calculations to reflect any material changes since the prior report was issued and then utilizes updated projected future price decks current with the period. For the nine months ended June 30, 2020, the assessment resulted in an impairment provision on producing properties of $29,315,807, primarily due to the decline in commodity prices caused by the ongoing COVID-19 pandemic and the early March 2020 failure by a group of oil producing nations known as OPEC+ to reach an agreement over proposed oil production cuts (see Item 1A: Risk Factors). During the three and nine months ended June 30, 2020, impairment on wells that were written off totaled $358,826 and $588,721, respectively. For the three and nine months ended June 30, 2019, the assessment resulted in no impairment provisions on producing properties.

During the quarter ended March 31, 2020, impairment of $19.3 million and $7.3 million was recorded on our Fayetteville Shale and Eagle Ford fields, respectively. The remaining $2.7 million of impairment was taken on other producing assets. The discounted cash flows of the properties were prepared using NYMEX strip pricing as of March 31, 2020, using a discount rate of 10% for proved developed and assigning no value to undeveloped locations. The Fayetteville Shale assets are dry-gas assets of which the Company acquired a portion in 2011. Low natural gas prices at March 31, 2020, are the primary reason for impairment in this field. The Company recognized an impairment related to the Eagle Ford at September 30, 2019, of $76.6 million primarily due to the removal of working interest PUDs from the Company’s reserve report. The further impairment of the Eagle Ford assets at March 31, 2020, is due to the decline in commodity prices over fiscal 2020.

A further reduction in oil, NGL and natural gas prices or a decline in reserve volumes may lead to additional impairment in future periods that may be material to the Company.

	June 30, 2020			June 30, 2019
Asset retirement obligations as of beginning of the year	$	2,835,781		$	2,809,378
Wells acquired or drilled		4			27,782
Wells sold or plugged		(61,985	)		(9,669	)
Accretion of discount		97,803			99,996
Asset retirement obligations as of end of period	$	2,871,603		$	2,927,487