Panhandle Oil and Gas Inc. Reports Fiscal Second Quarter and Six Months 2017 Results, Mid-Year Reserve Update and Operations Update

FISCAL SECOND QUARTER 2017 RESULTS

For the 2017 second quarter, the Company recorded net income of $3,470,433, or $0.21 per diluted share. This compared to a net loss of $7,438,161, or $0.44 per diluted share, for the 2016 second quarter. Net cash provided by operating activities increased 66% to $5,664,914 for the 2017 second quarter, versus $3,416,395 for the 2016 second quarter. Capital expenditures for the 2017 fiscal quarter totaled $5,546,731. In addition, the Company recorded a $10,788 non-cash provision for impairment in the 2017 quarter, as compared to an $8.1 million provision in the 2016 quarter.

Total revenues for the 2017 second quarter were $13,964,288, an 84% increase from $7,592,852 for the 2016 quarter. Oil, NGL and natural gas sales increased $2,754,716 or 45% in the 2017 quarter, compared to the 2016 quarter, as a result of a 72% increase in the average per Mcfe sales price somewhat offset by a 16% decrease in Mcfe production. The average sales price per Mcfe of production during the 2017 second quarter was $3.78, compared to $2.20 for the 2016 second quarter. The 2017 quarter included a $2.7 million gain on derivative contracts, as compared to a $1.0 million gain for the 2016 quarter.

Oil production decreased 27% in the 2017 quarter to 66,547 barrels, versus 90,760 barrels in the 2016 quarter, while gas production decreased 13% to 1,748,909 Mcf for the 2017 quarter, compared to the 2016 quarter. In addition, 33,836 barrels of NGL were sold in the 2017 quarter, as compared to 37,934 barrels in the 2016 quarter.

SIX MONTHS 2017 RESULTS

For the 2017 six months, the Company recorded net income of $1,232,041, or $0.07 per diluted share. This compared to a net loss of $10,237,279, or $0.61 per diluted share, for the 2016 six months. Net cash provided by operating activities decreased 32% year over year to $9,348,565 for the 2017 six months, versus the 2016 six months, but fully funded costs to drill and equip wells. Capital expenditures for the 2017 six months totaled $7,721,254. The Company recorded a $10,788 non-cash provision for impairment in the 2017 six months, as compared to an $11.8 million provision in the 2016 period.

Total revenues for the 2017 six months were $21,000,931, a 10% increase from $19,038,708 for the 2016 six months. Oil, NGL and natural gas sales increased $2,598,646 or 17% in the 2017 six months, compared to the 2016 six months, as a result of a 43% increase in the average per Mcfe sales price somewhat offset by an 18% decrease in Mcfe production. The average sales price per Mcfe of production during the 2017 six months was $3.65, compared to $2.56 for the 2016 six months. The 2017 six months included a $38,650 gain on derivative contracts as compared to a $940,177 gain for the 2016 period.

Oil production decreased 28% in the 2017 six months to 142,183 barrels from 197,122 barrels in the 2016 six months, while gas production decreased 632,460 Mcf, or 15%, compared to the 2016 six months. In addition, 69,487 barrels of NGL were sold in the 2017 six months, which was a 19% decrease compared to 2016 NGL volumes.

RESERVES UPDATE

March 31, 2017, mid-year proved reserves were 140.4 Bcfe, as calculated by the Company's independent consulting petroleum engineering firm, DeGolyer and MacNaughton. This was an increase of 13%, compared to the 124.0 Bcfe of proved reserves at Sept. 30, 2016. SEC prices used for the March 31, 2017, report averaged $2.45 per Mcf for natural gas, $43.10 per barrel for oil and $15.84 per barrel for NGL, compared to $1.97 per Mcf for natural gas, $36.77 per barrel for oil and $12.22 per barrel for NGL at the Sept. 30, 2016, report. The above prices reflect the net prices received at the wellhead. Total proved developed reserves increased 15% to 93.9 Bcfe, as compared to Sept. 30, 2016, reserve volumes.

OPERATIONS UPDATE

Drilling and completion activities continue on five significant projects. Three are in the cores of lower risk resource plays and two are higher risk plays in the Permian Basin.

Southeastern Oklahoma Woodford Shale: Panhandle is participating in eight significant wells operated by BP. The first four wells, each with 25% working interest and 31.25% net revenue interest, began producing in late February and early March. After approximately one month of production, the four wells combined were producing 4,000 Mcf per day net to Panhandle. The remaining four wells, each with 15% working interest and 23.6% net revenue interest, are currently being completed and are expected to begin producing in May. Panhandle currently has an additional 1,411 gross undeveloped locations identified in this play with 3P net reserves of 221 Bcfe.

Eagle Ford: Six wells have been drilled on the leasehold during 2017. Panhandle owns an average 16.6% working interest and 12.4% net revenue interest in these wells. The first two wells began producing in late April and are currently making a combined rate of 300 Boe per day net to Panhandle after ten days on production. The remaining four wells are scheduled to be completed in June with initial production expected from those wells in July. An additional four-well pad, with 8.2% working interest and 6.1% net revenue interest, is scheduled to begin drilling this month. These wells should be on production during our fourth quarter, 2017. Panhandle has 97 additional Eagle Ford infill development locations identified on its acreage with 3P net reserves of 6.2 million Boe.

STACK/Cana Play: The Company is participating with a 17.5% working interest and a 16.25% net revenue interest in six Woodford Shale wells operated by Cimarex Energy. All six wells have been drilled, and completion activity is planned to begin mid-May, with initial production from all six wells scheduled for mid-June. Panhandle currently has an additional 1,135 gross undeveloped locations identified in STACK/SCOOP/Cana with 3P net reserves of 166 Bcfe.

Activity in these three low-risk resource plays is anticipated to result in material increases in daily oil, NGL and natural gas production in our 2017 third and fourth quarters. This activity will also result in a material increase in second half 2017 capital expenditures, when compared to the same period in 2016.

Permian Basin: QEP is currently completing a 2-mile lateral Woodford Shale well on the Company's contiguous 43.6-square-mile mineral holdings in Andrews and Winkler Counties, Texas. Panhandle has leased its 2,440 net mineral acres in the block and is entitled to a proportionately reduced 25% royalty. Panhandle also has the right to participate with up to 10% working interest in each unit as initial unit wells are proposed. With full participation, Panhandle would have a 7% working interest and a 7.5% net revenue interest in these new units within the 43.6-square-mile block.

Also in the Permian Basin, Element Petroleum is evaluating the San Andres formation on and around Panhandle's contiguous 34.5-square-mile gross acreage block in Cochran County, Texas. The Company has leased 4,050 net mineral acres to Element and has a proportionately reduced 25% royalty. Panhandle also has the right to participate with 10% working interest in each unit as initial unit wells are proposed. With full participation, Panhandle would have a 10% working interest and a 12.1% net revenue interest in these new units within the 34.5-square-mile block. Thus far, Element has drilled and cored five pilot wells, completed one salt water disposal well, drilled another salt water disposal well and completed two 1.5-mile lateral wells in the San Andres. The two completed San Andres wells are in early stages of completion fluid recovery, but have already started producing oil. Element has scheduled the drilling and completion of eight additional San Andres wells between now and October 2017.

HEDGING UPDATE

As of May 1, 2017, the Company had protected approximately 5.7 Bcf of its gas production from April 2017 through March 2018 at an average floor price of $3.15 per Mcf and an average ceiling price $3.48 per Mcf. The Company has also protected 201,000 barrels of oil production for the same period with an average floor price of $51.32 and an average ceiling price of $55.79. The oil and gas hedges consist of swaps and costless collars.

FINANCIAL HIGHLIGHTS
Statements of Operations
	Three Months Ended March 31,								Six Months Ended March 31,
	2017				2016				2017				2016
Revenues:
Oil, NGL and natural gas sales	$	8,890,902			$	6,136,186			$	17,790,120			$	15,191,474
Lease bonuses and rentals		2,334,203				481,553				3,172,161				2,907,057
Gains (losses) on derivative contracts		2,739,183				975,113				38,650				940,177
		13,964,288				7,592,852				21,000,931				19,038,708
Costs and expenses:
Lease operating expenses		3,105,496				3,187,353				6,154,911				6,753,889
Production taxes		371,553				229,140				739,398				550,981
Depreciation, depletion and amortization		4,105,655				6,045,883				8,939,918				13,003,535
Provision for impairment		10,788				8,115,791				10,788				11,849,064
Loss (gain) on asset sales and other		91,337				34,054				86,998				(204,915)
Interest expense		286,398				342,348				578,767				702,910
General and administrative		1,719,628				1,651,444				3,562,110				3,563,523
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