OKLAHOMA CITY, Dec. 12, 2016 /PRNewswire/ -- PANHANDLE OIL
AND GAS INC., the "Company," (NYSE: PHX) today reported financial
and operating results for the fiscal year ended Sept. 30, 2016, and for the fiscal fourth
quarter, an update on its bank line-of-credit borrowing base and
provided an operations update.
SIGNIFICANT ITEMS FOR THE PERIODS ENDED SEPT. 30, 2016
- Recorded a fourth quarter 2016 net income of $737,190, $0.05 per
share, compared to a net loss of $887,681, $0.05 per
share, for the 2015 fourth quarter.
- Recorded a fiscal year 2016 net loss of $10,286,884, $0.61
per share, compared to a net income of $9,321,341, $0.56
per share, for fiscal 2015.
- Posted total fiscal 2016 production of 11.5 billion cubic feet
equivalent (Bcfe).
- Generated cash from operating activities of $14.6 million for the year, well in excess of
capital expenditures of $4.0
million.
- Generated lease bonus income of $7.7
million in fiscal 2016, which is not included in cash flow
from operations.
- Reduced debt $20.5 million during
fiscal 2016.
- Incurred non-cash impairment provision for fiscal 2016 of
$12.0 million.
Fiscal Fourth Quarter 2016 Results
For the 2016 fourth quarter, the Company recorded net income of
$737,190, or $0.05 per share. This compared to net loss of
$887,681, or $0.05 per share, for the 2015 fourth quarter. Net
cash provided by operating activities was $1,530,993 for the 2016 fourth quarter versus
$8,223,212 for the 2015 fourth
quarter. Fourth quarter 2016 cash from operating activities again
exceeded costs to drill and equip wells of $626,717. The Company recorded a gain of
$2.4 million on asset sales in the
2016 fourth quarter as small interests in more than 2,000 wells
which were the Company's share of a liquidated partnership were
sold.
Total revenues for the 2016 fourth quarter were $10,151,389, a decrease of 25% from $13,455,001 for the 2015 quarter. Oil, NGL and
gas sales decreased $2,279,094, or
20% in the 2016 quarter, as compared to the 2015 quarter. This
revenue decrease was a result of decreased oil, NGL and natural gas
volumes of 30%, 7% and 14%, respectively, and decreased oil prices
of 6%, slightly offset by increased NGL and natural gas prices of
2% and 5%, respectively. Average sales price per Mcfe of production
during the 2016 fourth quarter was $3.31, a 4% decrease from $3.46 in the 2015 fourth quarter. Oil production
decreased in the 2016 quarter to 78,398 barrels, versus 112,237
barrels in the 2015 quarter, while gas production decreased 14% to
1,940,749 Mcf, and NGL production decreased 7% to 44,598 barrels.
Natural decline and significantly reduced capital expenditures to
drill and complete new wells combined to reduce production volumes.
Additionally, gains on derivative contracts were $0.8 million in the 2016 quarter compared to
$2.1 million in the 2015 quarter.
Fiscal Year 2016 Results
For fiscal 2016, the Company recorded a net loss of $10,286,884, or $0.61 per share. This compared to a net income of
$9,321,341, or $0.56 per share, for fiscal 2015. Net cash
provided by operating activities decreased 68% to $14.6 million for 2016 versus 2015, and was in
excess of capital expenditures in fiscal 2016, which totaled
$4.0 million.
Total revenues for 2016 were $39,063,183, a decrease of 45% from $70,882,093 for 2015. Oil, NGL and natural gas
sales revenues decreased $23,122,561
or 42% in 2016, as compared to 2015. This revenue decrease was a
result of decreased oil, NGL and natural gas prices of 31%, 31% and
30%, respectively, and decreased oil, NGL and natural gas
production volumes of 20%, 19% and 15%, respectively. Overall
results were a 16% decrease in Mcfe production volumes and a 31%
decrease in the average sales price per Mcfe to $2.73, as compared to $3.97 in 2015. Revenue from lease bonuses in 2016
was $7.7 million, compared to
$2.0 million in 2015. Losses on
derivative contracts totaled $0.1
million in 2016 as compared to gains of $13.8 million in 2015. The majority of the
derivative gains in 2015 were for oil contracts put in place in
fiscal 2014 to protect oil prices received for production from the
Eagle Ford Shale properties.
Oil, NGL and natural gas sales decreased $23,122,561, or 42%, for 2016, as compared to
2015. The decrease was due to decreased oil, NGL and natural gas
prices, coupled with lower oil, NGL and natural gas production
volumes. The decrease in oil production was primarily the result of
natural production decline in the Eagle Ford Shale, which was not
offset by new production in the play due to significantly reduced
drilling activity. Declining production from various fields in
western Oklahoma, the Texas Panhandle and the Northern Oklahoma
Mississippian contributed to the decrease to a lesser extent. NGL
production volume decreases were largely the result of natural
production decline in the Anadarko Woodford Shale in western and
central Oklahoma and the
Anadarko Basin Granite Wash in
western Oklahoma and the
Texas Panhandle. Natural gas
production volume decreases were primarily the result of naturally
declining production in the Fayetteville Shale. Declining
production from the Anadarko Basin
Granite Wash and the southeastern Oklahoma Woodford Shale also
contributed to the decrease to a lesser extent.
Total costs and expenses for 2016 increased $336,315, or 0.6% over 2015. Lease operating
expenses declined $3.9 million,
principally as a result of operating efficiencies in the Eagle Ford
Shale field. However, provision for impairment increased
$7.0 million in 2016 as a result of
severely depressed oil, NGL and natural gas prices during 2016. The
Company also recorded a $2.6 million
gain on asset sales in 2016, as compared to only $0.4 million in 2015.
Bank Line-of-Credit Update
On December 8, 2016, Panhandle's
bank line-of-credit borrowing base was reaffirmed and remained
unchanged at $80 million. This
compares to a current outstanding balance of $43.7 million. Availability under the line of
$36.3 million is in excess of
projected needs. Based on currently expected product prices, the
Company anticipates funding normal operations and an expanded
drilling capital expenditure program in 2017 from internally
generated cash flow and utilization of borrowing under the bank
line-of-credit.
Management Comments
Michael C. Coffman, President and
CEO, said, "As have all companies in the oil and gas industry,
Panhandle experienced a very difficult year in 2016, brought on by
extremely low product prices. Our average per Mcfe sales price of
$2.73 in 2016 compared to
$3.97 in 2015 and $5.88 in 2014.
"We were able to supplement cash flows from oil and gas sales
during the year by generating $8.0
million of lease bonus proceeds and selling the assets of a
liquidated partnership and other minor assets, thus generating
another $4.5 million. Combined with
our cash flows from operations, this allowed Panhandle to fund
capital expenditures, pay dividends and reduce debt by $20.5 million. This reduced debt level put the
Company in a position to be able to comfortably fund a significant
amount of low-risk drilling just recently proposed on our acreage
in three core areas of shale plays."
Paul Blanchard, Senior Vice
President and COO, said, "We chose not to participate in the
majority of wells proposed to us in 2016 because we did not believe
they would earn reasonable rates of return at the NYMEX futures
pricing at that time. Instead, we focused on leasing out our
mineral acreage in what we considered to be relatively higher risk
areas as compared to our core resource play holdings.
"As product prices climbed later in fiscal 2016 and into the
first quarter of fiscal 2017, we have seen meaningful activity
return to our core resource play holdings. Participation in this
activity is expected to generate solid rates of return at current
NYMEX strip prices.
"Drilling is underway on an eight-well horizontal drilling
program operated by BP America in the Southeastern Oklahoma
Woodford Shale gas play. Panhandle has an average of 20% working
interest and 27.4% net revenue interest in these wells, which
should begin producing in the second fiscal quarter of 2017.
"Panhandle recently received notice from Cimarex Energy of their
plans to drill six wells on Panhandle leasehold in the core of the
STACK/CANA play beginning in December
2016. Panhandle has elected to participate with 17.5%
working interest and a 16.25% net revenue interest in these
Woodford Shale wells. Cimarex plans
to drill the wells with two rigs and projects they will begin
producing early in the third fiscal quarter of 2017.
"Pad drilling is scheduled to resume on our Eagle Ford leasehold
acreage in our second fiscal quarter of 2017. The operator plans to
move in one rig and drill a ten-well program. This activity should
occur over a roughly six- to seven-month period. Panhandle will
have 16% working interest in six of the wells that are entirely
located on our acreage and approximately 8.2% working interest in
the other four that are roughly half on our acreage. The operator
intends to apply techniques used in the completion of the most
recent well on the acreage block, which began producing last
summer. Production from this well was significantly higher than
previous wells on the block, and this new drilling is expected to
yield similar results.
"The drilling detailed above will be on some of the lowest-risk
acreage in the Company's portfolio, as it is in the cores of
well-developed and understood resource plays. These investments
should materially increase Panhandle's daily oil, NGL and natural
gas production when the wells come online. The Company also has two
exciting higher-risk plays being tested in the Permian Basin.
"Element Petroleum has commenced testing the economic viability
of drilling horizontal San Andres oil wells on our Cochran County, Texas, mineral block. Prior to
December 2016, Element drilled and
cored two pilot holes on our mineral acreage. In December 2016 and January
2017 they plan to drill and core three additional pilot
wells on and adjacent to our block. Element has also completed a
salt water disposal (SWD) well and has an additional SWD well
planned on the block. Their intent is to use the technical data
from these five pilot wells to determine the optimum placement of
the lateral in the San Andres. Once that has been determined,
Element plans to drill and complete 1.5-mile-long laterals in the
five pilot wells to test the productivity of the San Andres on and
adjacent to our mineral acreage. Panhandle owns 4,053 net mineral
acres on the gross 34.5-square-mile block, which were leased to
Element Petroleum in December 2015.
The lease terms provide Panhandle a 25%, proportionately reduced,
royalty and the right to buy back up to a 10% working interest in
each drilling unit on the lease, as initial unit wells are
proposed. Where Panhandle exercises this right, we will own a 10%
working interest and a 12.1% net revenue interest in those drilling
units. These terms allow Panhandle to not risk capital in the
concept testing phase, but to begin participation with a working
interest position once economic viability has been established. If
successful, there is potential to develop this acreage with
multiple San Andres oil wells per unit.
"QEP Resources is testing the economic viability of a
Woodford Shale resource play on a
block of mineral acreage we own in Andrews and Winkler Counties, Texas. The initial Woodford Shale test well, which began producing
in early 2015, was a productive oil well, but it was uneconomic.
QEP has proposed to drill a second Woodford well with a
two-mile-long lateral in early 2017. The second well will optimize
the fracture stimulation and completion design, utilizing data
acquired from the first well completion. Panhandle's mineral block
consists of 2,439 net acres covering 43.6 square miles. Our lease
to QEP provides Panhandle a 25%, proportionately reduced, royalty
and the right to buy back up to 10% working interest in each
drilling unit on the lease as initial unit wells are proposed.
Where Panhandle exercises this right, we will own an average 7.0%
working interest and a 7.5% net revenue interest in those drilling
units. This allows Panhandle to not risk capital in the concept
testing phase, but to begin participation with a working interest
position once economic viability has been established. If
successful, there is potential to develop this acreage with
multiple Woodford Shale oil wells
per unit."
FINANCIAL
HIGHLIGHTS
Statements of
Operations
|
|
|
|
Three Months Ended
Sept. 30,
|
|
|
Year Ended Sept.
30,
|
|
|
|
2016
|
|
|
2015
|
|
|
2016
|
|
|
2015
|
|
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil, NGL and natural
gas sales
|
|
$
|
8,853,981
|
|
|
$
|
11,133,075
|
|
|
$
|
31,411,353
|
|
|
$
|
54,533,914
|
|
Lease bonuses and
rentals
|
|
|
547,633
|
|
|
|
64,652
|
|
|
|
7,735,785
|
|
|
|
2,010,395
|
|
Gains (losses) on
derivative contracts
|
|
|
756,371
|
|
|
|
2,115,551
|
|
|
|
(86,355)
|
|
|
|
13,822,506
|
|
Income from
partnerships
|
|
|
(6,596)
|
|
|
|
141,723
|
|
|
|
2,400
|
|
|
|
515,278
|
|
|
|
|
10,151,389
|
|
|
|
13,455,001
|
|
|
|
39,063,183
|
|
|
|
70,882,093
|
|
Costs and
expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating
expenses
|
|
|
3,316,004
|
|
|
|
4,238,428
|
|
|
|
13,590,089
|
|
|
|
17,472,408
|
|
Production
taxes
|
|
|
323,918
|
|
|
|
318,085
|
|
|
|
1,071,632
|
|
|
|
1,702,302
|
|
Exploration
costs
|
|
|
1,483
|
|
|
|
36
|
|
|
|
31,589
|
|
|
|
48,404
|
|
Depreciation,
depletion and amortization
|
|
|
5,524,548
|
|
|
|
6,141,070
|
|
|
|
24,487,565
|
|
|
|
23,821,139
|
|
Provision for
impairment
|
|
|
152,207
|
|
|
|
1,476,431
|
|
|
|
12,001,271
|
|
|
|
5,009,191
|
|
Loss (gain) on asset
sales and other
|
|
|
(2,396,624)
|
|
|
|
(371,408)
|
|
|
|
(2,624,642)
|
|
|
|
(398,994)
|
|
Interest
expense
|
|
|
310,592
|
|
|
|
355,427
|
|
|
|
1,344,619
|
|
|
|
1,550,483
|
|
General and
administrative
|
|
|
2,006,071
|
|
|
|
1,965,114
|
|
|
|
7,139,728
|
|
|
|
7,339,320
|
|
Bad debt expense
(recovery)
|
|
|
-
|
|
|
|
180,499
|
|
|
|
19,216
|
|
|
|
180,499
|
|
|
|
|
9,238,199
|
|
|
|
14,303,682
|
|
|
|
57,061,067
|
|
|
|
56,724,752
|
|
Income (loss) before
provision (benefit)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
for income
taxes
|
|
|
913,190
|
|
|
|
(848,681)
|
|
|
|
(17,997,884)
|
|
|
|
14,157,341
|
|
Provision (benefit)
for income taxes
|
|
|
176,000
|
|
|
|
39,000
|
|
|
|
(7,711,000)
|
|
|
|
4,836,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
(loss)
|
|
$
|
737,190
|
|
|
$
|
(887,681)
|
|
|
$
|
(10,286,884)
|
|
|
$
|
9,321,341
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted
earnings per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
(loss)
|
|
$
|
0.05
|
|
|
$
|
(0.05)
|
|
|
$
|
(0.61)
|
|
|
$
|
0.56
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average
shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common
shares
|
|
|
16,402,172
|
|
|
|
16,546,528
|
|
|
|
16,577,799
|
|
|
|
16,522,462
|
|
Unissued, vested
directors' shares
|
|
|
269,461
|
|
|
|
251,005
|
|
|
|
263,057
|
|
|
|
246,442
|
|
|
|
|
16,671,633
|
|
|
|
16,797,533
|
|
|
|
16,840,856
|
|
|
|
16,768,904
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Dividends declared
per share of
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
common stock and paid
in period
|
|
$
|
0.04
|
|
|
$
|
0.04
|
|
|
$
|
0.16
|
|
|
$
|
0.16
|
|
Balance
Sheets
|
|
|
|
Sept. 30,
2016
|
|
|
Sept. 30,
2015
|
|
Assets
|
|
|
|
|
|
|
|
|
Current
Assets:
|
|
|
|
|
|
|
|
|
Cash and cash
equivalents
|
|
$
|
471,213
|
|
|
$
|
603,915
|
|
Oil, NGL and natural
gas sales receivables,
|
|
|
|
|
|
|
|
|
net of allowance for
uncollectable accounts
|
|
|
5,287,229
|
|
|
|
7,895,591
|
|
Refundable income
taxes
|
|
|
83,874
|
|
|
|
345,897
|
|
Refundable production
taxes
|
|
|
-
|
|
|
|
476,001
|
|
Deferred income
taxes
|
|
|
310,900
|
|
|
|
-
|
|
Derivative contracts,
net
|
|
|
-
|
|
|
|
4,210,764
|
|
Other
|
|
|
419,037
|
|
|
|
252,016
|
|
Total current
assets
|
|
|
6,572,253
|
|
|
|
13,784,184
|
|
|
|
|
|
|
|
|
|
|
Properties and
equipment at cost, based on successful
|
|
|
|
|
|
|
|
|
efforts
accounting:
|
|
|
|
|
|
|
|
|
Producing oil and
natural gas properties
|
|
|
434,469,093
|
|
|
|
441,141,337
|
|
Non-producing oil and
natural gas properties
|
|
|
7,574,649
|
|
|
|
8,293,997
|
|
Furniture and
fixtures
|
|
|
1,069,658
|
|
|
|
1,393,559
|
|
|
|
|
443,113,400
|
|
|
|
450,828,893
|
|
Less accumulated
depreciation, depletion and
|
|
|
|
|
|
|
|
|
amortization
|
|
|
(251,707,749)
|
|
|
|
(228,036,803)
|
|
Net properties and
equipment
|
|
|
191,405,651
|
|
|
|
222,792,090
|
|
|
|
|
|
|
|
|
|
|
Investments
|
|
|
157,322
|
|
|
|
2,248,999
|
|
Total
assets
|
|
$
|
198,135,226
|
|
|
$
|
238,825,273
|
|
|
|
|
|
|
|
|
|
|
Liabilities and
Stockholders' Equity
|
|
|
|
|
|
|
|
|
Current
Liabilities:
|
|
|
|
|
|
|
|
|
Accounts
payable
|
|
$
|
2,351,623
|
|
|
$
|
2,028,746
|
|
Derivative contracts,
net
|
|
|
403,612
|
|
|
|
-
|
|
Deferred income
taxes
|
|
|
-
|
|
|
|
1,517,100
|
|
Accrued liabilities
and other
|
|
|
1,718,558
|
|
|
|
1,330,901
|
|
Total current
liabilities
|
|
|
4,473,793
|
|
|
|
4,876,747
|
|
|
|
|
|
|
|
|
|
|
Long-term
debt
|
|
|
44,500,000
|
|
|
|
65,000,000
|
|
Deferred income
taxes
|
|
|
30,986,907
|
|
|
|
39,118,907
|
|
Asset retirement
obligations
|
|
|
2,958,048
|
|
|
|
2,824,944
|
|
Derivative contracts,
net
|
|
|
24,659
|
|
|
|
-
|
|
|
|
|
|
|
|
|
|
|
Stockholders'
equity:
|
|
|
|
|
|
|
|
|
Class A voting common
stock, $.0166 par value; 24,000,000 shares
|
|
|
|
|
|
|
|
|
authorized; 16,863,004
issued at Sept. 30, 2016 and 2015
|
|
|
280,938
|
|
|
|
280,938
|
|
Capital in excess of
par value
|
|
|
3,191,056
|
|
|
|
2,993,119
|
|
Deferred directors'
compensation
|
|
|
3,403,213
|
|
|
|
3,084,289
|
|
Retained
earnings
|
|
|
112,482,284
|
|
|
|
125,446,473
|
|
|
|
|
119,357,491
|
|
|
|
131,804,819
|
|
Treasury stock, at
cost; 262,708 shares at Sept. 30, 2016,
|
|
|
|
|
|
|
|
|
and 302,623 shares at
Sept. 30, 2015
|
|
|
(4,165,672)
|
|
|
|
(4,800,144)
|
|
Total stockholders'
equity
|
|
|
115,191,819
|
|
|
|
127,004,675
|
|
Total liabilities and
stockholders' equity
|
|
$
|
198,135,226
|
|
|
$
|
238,825,273
|
|
Condensed Statements
of Cash Flows
|
|
|
|
Year ended Sept.
30,
|
|
|
|
2016
|
|
|
2015
|
|
Operating
Activities
|
|
|
|
|
|
|
|
|
Net income
(loss)
|
|
$
|
(10,286,884)
|
|
|
$
|
9,321,341
|
|
Adjustments to
reconcile net income (loss) to net
|
|
|
|
|
|
|
|
|
cash provided by
operating activities:
|
|
|
|
|
|
|
|
|
Depreciation,
depletion and amortization
|
|
|
24,487,565
|
|
|
|
23,821,139
|
|
Impairment
|
|
|
12,001,271
|
|
|
|
5,009,191
|
|
Provision for deferred
income taxes
|
|
|
(9,960,000)
|
|
|
|
2,672,000
|
|
Exploration
costs
|
|
|
31,589
|
|
|
|
48,404
|
|
Gain from leasing of
fee mineral acreage
|
|
|
(7,732,023)
|
|
|
|
(2,007,993)
|
|
Net (gain) loss on
sales of assets
|
|
|
(2,688,408)
|
|
|
|
-
|
|
Income from
partnerships
|
|
|
(2,400)
|
|
|
|
(515,278)
|
|
Distributions received
from partnerships
|
|
|
33,201
|
|
|
|
736,280
|
|
Common stock
contributed to ESOP
|
|
|
200,158
|
|
|
|
185,113
|
|
Common stock
(unissued) to Directors'
|
|
|
|
|
|
|
|
|
Deferred Compensation
Plan
|
|
|
329,465
|
|
|
|
302,353
|
|
Restricted stock
awards
|
|
|
781,479
|
|
|
|
895,127
|
|
Bad debt expense
(recovery)
|
|
|
19,216
|
|
|
|
180,499
|
|
Cash provided (used)
by changes in assets
|
|
|
|
|
|
|
|
|
and
liabilities:
|
|
|
|
|
|
|
|
|
Oil, NGL and natural
gas sales receivables
|
|
|
2,589,146
|
|
|
|
8,151,379
|
|
Fair value of
derivative contracts
|
|
|
4,639,035
|
|
|
|
(2,308,922)
|
|
Refundable income
taxes
|
|
|
262,023
|
|
|
|
(345,897)
|
|
Refundable production
taxes
|
|
|
476,001
|
|
|
|
149,995
|
|
Other current
assets
|
|
|
(167,021)
|
|
|
|
102,812
|
|
Accounts
payable
|
|
|
(811,749)
|
|
|
|
(343,186)
|
|
Income taxes
payable
|
|
|
-
|
|
|
|
(523,843)
|
|
Accrued
liabilities
|
|
|
388,053
|
|
|
|
40,500
|
|
Total
adjustments
|
|
|
24,876,601
|
|
|
|
36,249,673
|
|
Net cash provided by
operating activities
|
|
|
14,589,717
|
|
|
|
45,571,014
|
|
|
|
|
|
|
|
|
|
|
Investing
Activities
|
|
|
|
|
|
|
|
|
Capital expenditures,
including dry hole costs
|
|
|
(3,986,235)
|
|
|
|
(30,800,625)
|
|
Acquisition of
working interest properties
|
|
|
-
|
|
|
|
(308,180)
|
|
Proceeds from leasing
of fee mineral acreage
|
|
|
8,049,434
|
|
|
|
2,053,900
|
|
Investments in
partnerships
|
|
|
50,126
|
|
|
|
(533,580)
|
|
Proceeds from sales
of assets
|
|
|
4,501,726
|
|
|
|
-
|
|
Net cash used in
investing activities
|
|
|
8,615,051
|
|
|
|
(29,588,485)
|
|
|
|
|
|
|
|
|
|
|
Financing
Activities
|
|
|
|
|
|
|
|
|
Borrowings under debt
agreement
|
|
|
12,339,101
|
|
|
|
25,833,116
|
|
Payments of loan
principal
|
|
|
(32,839,101)
|
|
|
|
(38,833,116)
|
|
Purchases of treasury
stock
|
|
|
(117,165)
|
|
|
|
(242,313)
|
|
Payments of
dividends
|
|
|
(2,677,305)
|
|
|
|
(2,669,056)
|
|
Excess tax benefit on
stock-based compensation
|
|
|
(43,000)
|
|
|
|
23,000
|
|
Net cash provided by
(used in) financing activities
|
|
|
(23,337,470)
|
|
|
|
(15,888,369)
|
|
Increase (decrease)
in cash and cash equivalents
|
|
|
(132,702)
|
|
|
|
94,160
|
|
Cash and cash
equivalents at beginning of year
|
|
|
603,915
|
|
|
|
509,755
|
|
Cash and cash
equivalents at end of year
|
|
$
|
471,213
|
|
|
$
|
603,915
|
|
Condensed Statements
of Cash Flows (continued)
|
|
|
|
Year ended Sept.
30,
|
|
|
|
2016
|
|
|
2015
|
|
Supplemental
Disclosures of Cash Flow
|
|
|
|
|
|
|
|
|
Information
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest paid (net of
capitalized interest)
|
|
$
|
1,365,474
|
|
|
$
|
1,558,885
|
|
Income taxes paid,
net of refunds received
|
|
$
|
2,029,977
|
|
|
$
|
3,009,939
|
|
|
|
|
|
|
|
|
|
|
Supplemental
schedule of noncash
|
|
|
|
|
|
|
|
|
investing and
financing activities:
|
|
|
|
|
|
|
|
|
Additions and
revisions, net, to asset
|
|
|
|
|
|
|
|
|
retirement
obligations
|
|
$
|
14,095
|
|
|
$
|
70,529
|
|
|
|
|
|
|
|
|
|
|
Gross additions to
properties and equipment
|
|
$
|
5,118,733
|
|
|
$
|
26,183,115
|
|
Net (increase)
decrease in accounts payable for
|
|
|
|
|
|
|
|
|
properties and
equipment additions
|
|
|
(1,132,498)
|
|
|
|
4,925,690
|
|
Capital expenditures,
including dry hole costs
|
|
$
|
3,986,235
|
|
|
$
|
31,108,805
|
|
OPERATING
HIGHLIGHTS
|
|
|
Fourth Quarter
Ended
|
|
|
Fourth Quarter
Ended
|
|
|
Year Ended
|
|
|
Year Ended
|
|
|
Sept. 30,
2016
|
|
|
Sept. 30,
2015
|
|
|
Sept. 30,
2016
|
|
|
Sept. 30,
2015
|
|
MCFE Sold
|
|
2,678,725
|
|
|
|
3,221,086
|
|
|
|
11,496,249
|
|
|
|
13,729,733
|
|
Average Sales Price
per MCFE
|
$
|
3.31
|
|
|
$
|
3.46
|
|
|
$
|
2.73
|
|
|
$
|
3.97
|
|
Barrels of Oil
Sold
|
|
78,398
|
|
|
|
112,237
|
|
|
|
364,252
|
|
|
|
453,125
|
|
Average Sales Price
per Barrel
|
$
|
41.62
|
|
|
$
|
44.18
|
|
|
$
|
36.70
|
|
|
$
|
53.12
|
|
MCF of Natural Gas
Sold
|
|
1,940,749
|
|
|
|
2,261,236
|
|
|
|
8,284,377
|
|
|
|
9,745,223
|
|
Average Sales Price
per MCF
|
$
|
2.55
|
|
|
$
|
2.43
|
|
|
$
|
1.92
|
|
|
$
|
2.73
|
|
Barrels of NGL
Sold
|
|
44,598
|
|
|
|
47,738
|
|
|
|
171,060
|
|
|
|
210,960
|
|
Average Sales Price
per Barrel
|
$
|
14.43
|
|
|
$
|
14.10
|
|
|
$
|
12.60
|
|
|
$
|
18.25
|
|
Quarterly Production
Levels
|
|
Quarter
ended
|
|
Oil Bbls
Sold
|
|
|
MCF Sold
|
|
|
NGL Bbls
Sold
|
|
|
MCFE Sold
|
|
9/30/16
|
|
|
78,398
|
|
|
|
1,940,749
|
|
|
|
44,598
|
|
|
|
2,678,725
|
|
6/30/16
|
|
|
88,732
|
|
|
|
2,112,567
|
|
|
|
40,477
|
|
|
|
2,887,821
|
|
3/31/16
|
|
|
90,760
|
|
|
|
2,014,139
|
|
|
|
37,934
|
|
|
|
2,786,303
|
|
12/31/15
|
|
|
106,362
|
|
|
|
2,216,922
|
|
|
|
48,051
|
|
|
|
3,143,400
|
|
9/30/15
|
|
|
112,237
|
|
|
|
2,261,236
|
|
|
|
47,738
|
|
|
|
3,221,086
|
|
6/30/15
|
|
|
109,738
|
|
|
|
2,407,049
|
|
|
|
41,737
|
|
|
|
3,315,899
|
|
3/31/15
|
|
|
114,567
|
|
|
|
2,475,777
|
|
|
|
48,681
|
|
|
|
3,455,265
|
|
12/31/14
|
|
|
116,583
|
|
|
|
2,601,161
|
|
|
|
72,804
|
|
|
|
3,737,483
|
|
Derivative contracts
in place as of Dec. 2, 2016
|
|
|
|
Production
volume
|
|
Indexed
|
|
|
Contract
period
|
|
covered per
month
|
|
pipeline
|
|
Fixed
price
|
Natural gas costless
collars
|
|
|
|
|
|
|
October - December
2016
|
|
70,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$2.75 floor / $3.05 ceiling
|
October - December
2016
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$2.90 floor / $3.40 ceiling
|
November 2016 - March
2017
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$2.25 floor / $3.65 ceiling
|
November 2016 - March
2017
|
|
80,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$2.25 floor / $3.95 ceiling
|
November 2016 - March
2017
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$2.60 floor / $3.25 ceiling
|
January - June
2017
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$2.85 floor / $3.35 ceiling
|
January - December
2017
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$2.80 floor / $3.47 ceiling
|
January - December
2017
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$3.00 floor / $3.35 ceiling
|
April - December
2017
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$2.80
floor / $3.35 ceiling
|
April - December
2017
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$2.75 floor / $3.35 ceiling
|
April - December
2017
|
|
30,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$3.00 floor / $3.65 ceiling
|
May - December
2017
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$3.00 floor / $3.60 ceiling
|
|
|
|
|
|
|
|
Natural gas fixed
price swaps
|
|
|
|
|
|
|
October 2016 - March
2017
|
|
25,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$3.200
|
November 2016 - April
2017
|
|
80,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$2.955
|
January - December
2017
|
|
25,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$3.100
|
April - December
2017
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$3.070
|
April - December
2017
|
|
50,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$3.210
|
April - December
2017
|
|
30,000
Mmbtu
|
|
NYMEX Henry Hub
|
|
$3.300
|
|
|
|
|
|
|
|
Oil costless
collars
|
|
|
|
|
|
|
July - December
2016
|
|
3,000 Bbls
|
|
NYMEX WTI
|
|
$35.00 floor / $49.00 ceiling
|
October - December
2016
|
|
3,000 Bbls
|
|
NYMEX WTI
|
|
$40.00 floor / $47.25 ceiling
|
October 2016 - March
2017
|
|
3,000 Bbls
|
|
NYMEX WTI
|
|
$40.00 floor / $58.50 ceiling
|
October 2016 - March
2017
|
|
3,000 Bbls
|
|
NYMEX WTI
|
|
$45.00 floor / $54.00 ceiling
|
October 2016 - March
2017
|
|
3,000 Bbls
|
|
NYMEX WTI
|
|
$45.00 floor / $55.50 ceiling
|
January - December
2017
|
|
3,000 Bbls
|
|
NYMEX WTI
|
|
$50.00 floor / $55.00 ceiling
|
April - December
2017
|
|
2,000 Bbls
|
|
NYMEX WTI
|
|
$50.00 floor / $57.50 ceiling
|
July - December
2017
|
|
5,000 Bbls
|
|
NYMEX WTI
|
|
$45.00 floor / $56.25 ceiling
|
|
|
|
|
|
|
|
Oil fixed price
swaps
|
|
|
|
|
|
|
January - December
2017
|
|
3,000 Bbls
|
|
NYMEX WTI
|
|
$53.890
|
April - December
2017
|
|
2,000 Bbls
|
|
NYMEX WTI
|
|
$54.200
|
|
|
|
|
|
|
|
Panhandle Oil and Gas Inc. (NYSE: PHX) is
engaged in the exploration for and production of natural gas and
oil. Additional information on the Company can be found at
www.panhandleoilandgas.com.
Forward-Looking Statements and Risk Factors
– This report includes "forward-looking statements," within
the meaning of Section 27A of the Securities Act of 1933 and
Section 21E of the Securities Exchange Act of 1934. Forward-looking
statements include current expectations or forecasts of future
events. They may include estimates of oil and gas reserves,
expected oil and gas production and future expenses, projections of
future oil and gas prices, planned capital expenditures for
drilling, leasehold acquisitions and seismic data, statements
concerning anticipated cash flow and liquidity and Panhandle's
strategy and other plans and objectives for future operations.
Although Panhandle believes the expectations reflected in these and
other forward-looking statements are reasonable, we can give no
assurance they will prove to be correct. They can be affected by
inaccurate assumptions or by known or unknown risks and
uncertainties. Factors that could cause actual results to differ
materially from expected results are described under "Risk Factors"
in Part 1, Item 1 of Panhandle's 2016 Form 10-K filed with the
Securities and Exchange Commission. These "Risk Factors" include
the worldwide economic recession's continuing negative effects on
the natural gas business; Panhandle's hedging activities may reduce
the realized prices received for natural gas sales; the volatility
of oil and gas prices; Panhandle's ability to compete effectively
against strong independent oil and gas companies and majors; the
availability of capital on an economic basis to fund reserve
replacement costs; Panhandle's ability to replace reserves and
sustain production; uncertainties inherent in estimating quantities
of oil and gas reserves and projecting future rates of production
and the amount and timing of development expenditures; unsuccessful
exploration and development drilling; decreases in the values of
Panhandle's oil and gas properties resulting in write-downs; the
negative impact lower oil and gas prices could have on the
Company's ability to borrow; drilling and operating risks; and
Panhandle cannot control activities on its properties as the
Company is a non-operator.
Do not place undue reliance on these forward-looking statements,
which speak only as of the date of this release. Panhandle
undertakes no obligation to update this information. Panhandle
urges you to carefully review and consider the disclosures made in
this presentation and Panhandle's filings with the Securities and
Exchange Commission that attempt to advise interested parties of
the risks and factors that may affect Panhandle's business.
To view the original version on PR Newswire,
visit:http://www.prnewswire.com/news-releases/panhandle-oil-and-gas-inc-reports-fourth-quarter-and-fiscal-2016-financial-results-and-an-operations-update-300376326.html
SOURCE PANHANDLE OIL AND GAS INC.