SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
Quarterly Report Pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934
For the quarter ended Commission File Number
September 30, 1999 0-12052
DYCO OIL AND GAS PROGRAM 1983-1
(A LIMITED PARTNERSHIP)
(Exact Name of Registrant as specified in its charter)
Minnesota 41-1451945
(State or other jurisdiction (I.R.S. Employer Identification
of incorporation or Number)
organization)
Samson Plaza, Two West Second Street, Tulsa, Oklahoma 74103
- ------------------------------------------------------------
(Address of principal executive offices) (Zip Code)
(918) 583-1791
----------------------------------------------------
(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
------ ------
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PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
DYCO OIL AND GAS PROGRAM 1983-1 LIMITED PARTNERSHIP
BALANCE SHEETS
(Unaudited)
ASSETS
September 30, December 31,
1999 1998
------------ ------------
CURRENT ASSETS:
Cash and cash equivalents $147,146 $133,429
Accrued oil and gas sales 85,578 70,919
-------- --------
Total current assets $232,724 $204,348
NET OIL AND GAS PROPERTIES, utilizing
the full cost method 301,162 367,820
DEFERRED CHARGE 36,744 36,744
-------- --------
$570,630 $608,912
======== ========
LIABILITIES AND PARTNERS' CAPITAL
CURRENT LIABILITIES:
Accounts payable $ 8,121 $ 5,774
Gas imbalance payable 7,689 7,689
-------- --------
Total current liabilities $ 15,810 $ 13,463
ACCRUED LIABILITY (Note 1) $124,344 $138,999
PARTNERS' CAPITAL:
General Partner, 76 general
partner units $ 4,305 $ 4,565
Limited Partners, issued and
outstanding, 7,600 Units 426,171 451,885
-------- --------
Total Partners' capital $430,476 $456,450
-------- --------
$570,630 $608,912
======== ========
The accompanying condensed notes are an
integral part of these financial statements.
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DYCO OIL AND GAS PROGRAM 1983-1 LIMITED PARTNERSHIP
STATEMENTS OF OPERATIONS
FOR THE THREE MONTHS ENDED SEPTEMBER 30, 1999 AND 1998
(Unaudited)
1999 1998
-------- --------
REVENUES:
Oil and gas sales $126,371 $194,188
Interest 1,313 3,329
-------- --------
$127,684 $197,517
COSTS AND EXPENSES:
Oil and gas production $ 39,582 $ 44,812
Depreciation, depletion, and
amortization of oil and gas
properties 9,776 69,042
General and administrative
(Note 2) 19,895 19,973
-------- --------
$ 69,253 $133,827
-------- --------
NET INCOME $ 58,431 $ 63,690
======== ========
GENERAL PARTNER (1%) - net income $ 584 $ 637
======== ========
LIMITED PARTNERS (99%) - net income $ 57,847 $ 63,053
======== ========
NET INCOME PER UNIT $ 7.62 $ 8.30
======== ========
UNITS OUTSTANDING 7,676 7,676
======== ========
The accompanying condensed notes are an
integral part of these financial statements.
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DYCO OIL AND GAS PROGRAM 1983-1 LIMITED PARTNERSHIP
STATEMENTS OF OPERATIONS
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1999 AND 1998
(Unaudited)
1999 1998
-------- --------
REVENUES:
Oil and gas sales $322,062 $497,472
Interest 3,380 9,053
-------- --------
$325,442 $506,525
COSTS AND EXPENSES:
Oil and gas production $ 86,686 $132,314
Depreciation, depletion, and
amortization of oil and gas
properties 42,137 137,963
General and administrative
(Note 2) 69,073 69,533
-------- --------
$197,896 $339,810
-------- --------
NET INCOME $127,546 $166,715
======== ========
GENERAL PARTNER (1%) - net income $ 1,275 $ 1,667
======== ========
LIMITED PARTNERS (99%) - net income $126,271 $165,048
======== ========
NET INCOME PER UNIT $ 16.62 $ 21.72
======== ========
UNITS OUTSTANDING 7,676 7,676
======== ========
The accompanying condensed notes are an
integral part of these financial statements.
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DYCO OIL AND GAS PROGRAM 1983-1 LIMITED PARTNERSHIP
STATEMENTS OF CASH FLOWS
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1999 AND 1998
(Unaudited)
1999 1998
--------- ---------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income $127,546 $166,715
Adjustments to reconcile net
income to net cash provided
by operating activities:
Depreciation, depletion, and
amortization of oil and gas
properties 42,137 137,963
(Increase) decrease in accrued
oil and gas sales ( 14,659) 59,984
Increase in accounts payable 2,347 268
Decrease in gas imbalance
payable - ( 20,049)
Decrease in accrued liability ( 14,655) -
-------- --------
Net cash provided by operating
activities $142,716 $344,881
-------- --------
CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from the sale of oil and
gas properties $ 28,104 $ 18,912
Additions to oil and gas properties ( 3,583) -
-------- --------
Net cash provided by investing
activities $ 24,521 $ 18,912
-------- --------
CASH FLOWS FROM FINANCING ACTIVITIES:
Cash distributions ($153,520) ($575,700)
-------- --------
Net cash used by financing
activities ($153,520) ($575,700)
-------- --------
NET INCREASE (DECREASE) IN CASH AND
CASH EQUIVALENTS $ 13,717 ($211,907)
CASH AND CASH EQUIVALENTS AT
BEGINNING OF PERIOD 133,429 256,491
-------- --------
CASH AND CASH EQUIVALENTS AT
END OF PERIOD $147,146 $ 44,584
======== ========
The accompanying condensed notes are an
integral part of these financial statements.
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DYCO OIL AND GAS PROGRAM 1983-1 LIMITED PARTNERSHIP
CONDENSED NOTES TO FINANCIAL STATEMENTS
SEPTEMBER 30, 1999
(Unaudited)
1. ACCOUNTING POLICIES
-------------------
The balance sheet as of September 30, 1999, statements of operations for
the three and nine months ended September 30, 1999 and 1998, and
statements of cash flows for the nine months ended September 30, 1999 and
1998 have been prepared by Dyco Petroleum Corporation ("Dyco"), the
General Partner of the Dyco Oil and Gas Program 1983-1 Limited Partnership
(the "Program"), without audit. In the opinion of management all
adjustments (which include only normal recurring adjustments) necessary to
present fairly the financial position at September 30, 1999, results of
operations for the three and nine months ended September 30, 1999 and
1998, and changes in cash flows for the nine months ended September 30,
1999 and 1998 have been made.
Information and footnote disclosures normally included in financial
statements prepared in accordance with generally accepted accounting
principles have been condensed or omitted. It is suggested that these
financial statements be read in conjunction with the financial statements
and notes thereto included in the Program's Annual Report on Form 10-K for
the year ended December 31, 1998. The results of operations for the period
ended September 30, 1999 are not necessarily indicative of the results to
be expected for the full year.
OIL AND GAS PROPERTIES
----------------------
Oil and gas operations are accounted for using the full cost method of
accounting. All productive and non-productive costs associated with the
acquisition, exploration and development of oil and gas reserves are
capitalized. The Program's calculation of depreciation, depletion, and
amortization includes estimated future expenditures to be incurred in
developing proved reserves and estimated dismantlement and abandonment
costs, net of estimated salvage values. In the event the unamortized cost
of oil and gas properties being amortized exceeds the full cost ceiling
(as defined by the Securities and Exchange Commission), the excess is
charged to expense in the period during which such excess occurs. Sales
and abandonments of
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properties are accounted for as adjustments of capitalized costs with no
gain or loss recognized, unless such adjustments would significantly alter
the relationship between capitalized costs and proved oil and gas
reserves.
The provision for depreciation, depletion, and amortization of oil and gas
properties is calculated by dividing the oil and gas sales dollars during
the period by the estimated future gross income from the oil and gas
properties and applying the resulting rate to the net remaining costs of
oil and gas properties that have been capitalized, plus estimated future
development costs.
ACCRUED LIABILITY
-----------------
The Accrued Liability at September 30, 1999 and December 31, 1998
represents charges accrued for lease operating expenses incurred in
connection with the Program's overproduced gas imbalance positions. The
rate used in calculating the accrued liability is the average of the
annual production costs per Mcf at December 31, 1998. At September 30,
1999, cumulative total gas sales volumes for overproduced wells exceeded
the Program's pro-rata share of total gas production from these wells by
367,446 Mcf, resulting in accrued lease operating expenses of $124,344. At
December 31, 1998, cumulative total gas sales volumes for overproduced
wells exceeded the Program's pro-rata share of total gas production from
these wells by 410,754 Mcf, resulting in accrued lease operating expenses
of $138,999.
2. TRANSACTIONS WITH RELATED PARTIES
---------------------------------
Under the terms of the Program's partnership agreement, Dyco is entitled
to receive a reimbursement for all direct expenses and general and
administrative, geological and engineering expenses it incurs on behalf of
the Program. During the three months ended September 30, 1999 and 1998 the
Program incurred such expenses totaling $19,895 and $19,973, respectively,
of which $17,820 was paid each period to Dyco and its affiliates. During
the nine months ended September 30, 1999 and 1998 the Program incurred
such expenses totaling $69,073 and $69,533, respectively, of which $53,460
was paid each period to Dyco and its affiliates.
Affiliates of the Program operate certain of the Program's properties.
Their policy is to bill the Program for all customary charges and cost
reimbursements associated with these activities.
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<PAGE>
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
USE OF FORWARD-LOOKING STATEMENTS AND ESTIMATES
- -----------------------------------------------
This Quarterly Report contains certain forward-looking statements. The
words "anticipate", "believe", "expect", "plan", "intend", "estimate",
"project", "could", "may" and similar expressions are intended to identify
forward-looking statements. Such statements reflect management's current
views with respect to future events and financial performance. This
Quarterly Report also includes certain information, which is, or is based
upon, estimates and assumptions. Such estimates and assumptions are
management's efforts to accurately reflect the condition and operation of
the Program.
Use of forward-looking statements and estimates and assumptions involve
risks and uncertainties which include, but are not limited to, the
volatility of oil and gas prices, the uncertainty of reserve information,
the operating risk associated with oil and gas properties (including the
risk of personal injury, death, property damage, damage to the well or
producing reservoir, environmental contamination, and other operating
risks), the prospect of changing tax and regulatory laws, the availability
and capacity of processing and transportation facilities, the general
economic climate, the supply and price of foreign imports of oil and gas,
the level of consumer product demand, and the price and availability of
alternative fuels. Should one or more of these risks or uncertainties
occur or should estimates or underlying assumptions prove incorrect,
actual conditions or results may vary materially and adversely from those
stated, anticipated, believed, estimated, and otherwise indicated.
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
Net proceeds from the Program's operations less necessary operating
capital are distributed to investors on a quarterly basis. The net
proceeds from production are not reinvested in productive assets, except
to the extent that producing wells are improved or where methods are
employed to permit more efficient recovery of the Program's reserves which
would result in a positive economic impact.
The Program's available capital from subscriptions has been spent on oil
and gas drilling activities. There should not be any further material
capital resource commitments in the future. The Program has no debt
commitments. Cash for operational purposes will be provided by current oil
and gas production.
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<PAGE>
The Programs Statement of Cash Flows for the nine months ended September
30, 1999 includes proceeds from the sale of oil and gas properties during
the second quarter of 1999. These proceeds will be included in the 1983-1
Program's future cash distributions.
RESULTS OF OPERATIONS
- ---------------------
GENERAL DISCUSSION
The following general discussion should be read in conjunction with the
analysis of results of operations provided below. The most important
variable affecting the Program's revenues is the prices received for the
sale of oil and gas. Due to the volatility of oil and gas prices,
forecasting future prices is subject to great uncertainty and inaccuracy.
Substantially all of the Program's gas reserves are being sold on the
"spot market". Prices on the spot market are subject to wide seasonal and
regional pricing fluctuations due to the highly competitive nature of the
spot market. Such spot market sales are generally short-term in nature and
are dependent upon the obtaining of transportation services provided by
pipelines. In addition, crude oil prices in 1998 and early 1999 were at or
near their lowest level in the past decade due primarily to the global
surplus of crude oil. Oil prices have since rebounded primarily due to a
decrease in the global oil surplus as a result of production curtailments
by several major oil producing nations. Management is unable to predict
whether future oil and gas prices will (i) stabilize, (ii) increase, or
(iii) decrease.
THREE MONTHS ENDED SEPTEMBER 30, 1999 COMPARED TO THE THREE MONTHS ENDED
SEPTEMBER 30, 1998.
Three Months Ended September 30,
--------------------------------
1999 1998
-------- --------
Oil and gas sales $126,371 $194,188
Oil and gas production expenses $ 39,582 $ 44,812
Barrels produced 76 53
Mcf produced 54,792 95,960
Average price/Bbl $ 20.13 $ 15.08
Average price/Mcf $ 2.28 $ 2.02
As shown in the table above, total oil and gas sales decreased $67,817
(34.9%) for the three months ended September 30, 1999 as compared to the
three months ended September 30, 1998. Of this decrease, approximately
$83,000 was related to a decrease in volumes of gas sold, which decrease
was partially offset by an increase of approximately $14,000 related to an
increase in the average
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price of gas sold. Volumes of oil sold increased 23 barrels, while volumes
of gas sold decreased 41,168 Mcf for the three months ended September 30,
1999 as compared to the three months ended September 30, 1998. The
decrease in volumes of gas sold was primarily due to the curtailment of
sales during the three months ended September 30, 1999 on two wells due to
the Program's overproduced gas balancing position in those wells, which
decreases were partially offset by a negative prior period volume
adjustment made by the operator on one well during the three months ended
September 30, 1998. Average oil and gas prices increased to $20.13 per
barrel and $2.28 per Mcf, respectively, for the three months ended
September 30, 1999 from $15.08 per barrel and $2.02 per Mcf, respectively,
for the three months ended September 30, 1998.
Oil and gas production expenses (including lease operating expenses and
production taxes) decreased $5,230 (11.7%) for the three months ended
September 30, 1999 as compared to the three months ended September 30,
1998. This decrease was primarily due to (i) a decrease in production
taxes associated with the decrease in oil and gas sales and (ii) a
decrease in lease operating expenses associated with the decrease in
volumes of gas sold, which decreases were partially offset by an increase
in compression expenses on one well during the three months ended
September 30, 1999. As a percentage of oil and gas sales, these expenses
increased to 31.3% for the three months ended September 30, 1999 from
23.1% for the three months ended September 30, 1998. This percentage
increase was primarily due to the increased compression expenses.
Depreciation, depletion, and amortization of oil and gas properties
decreased $59,266 (85.8%) for the three months ended September 30, 1999 as
compared to the three months ended September 30, 1998. This decrease was
primarily due to (i) an upward revision in the estimate of remaining gas
reserves at December 31, 1998, (ii) an increase in the gas price used in
the valuation of reserves at September 30, 1999 as compared to September
30, 1998, and (iii) the decrease in volumes of gas sold. As a percentage
of oil and gas sales, this expense decreased to 7.7% for the three months
ended September 30, 1999 from 35.6% for the three months ended September
30, 1998. This percentage decrease was primarily due to the dollar
decrease in depreciation, depletion, and amortization.
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General and administrative expenses remained relatively constant for the
three months ended September 30, 1999 as compared to the three months
ended September 30, 1998. As a percentage of oil and gas sales, these
expenses increased to 15.7% for the three months ended September 30, 1999
from 10.3% for the three months ended September 30, 1998. This percentage
increase was primarily due to the decrease in oil and gas sales.
NINE MONTHS ENDED SEPTEMBER 30, 1999 COMPARED TO THE NINE MONTHS ENDED
SEPTEMBER 30, 1998.
Nine Months Ended September 30,
-------------------------------
1999 1998
-------- --------
Oil and gas sales $322,062 $497,472
Oil and gas production expenses $ 86,686 $132,314
Barrels produced 304 259
Mcf produced 172,832 251,916
Average price/Bbl $ 15.24 $ 13.65
Average price/Mcf $ 1.84 $ 1.96
As shown in the table above, total oil and gas sales decreased $175,410
(35.3%) for the nine months ended September 30, 1999 as compared to the
nine months ended September 30, 1998. Of this decrease, approximately
$155,000 was related to a decrease in volumes of gas sold and
approximately $21,000 was related to a decrease in the average price of
gas sold. Volumes of oil sold increased 45 barrels, while volumes of gas
sold decreased 79,084 Mcf for the nine months ended September 30, 1999 as
compared to the nine months ended September 30, 1998. The decrease in
volumes of gas sold was primarily due to the curtailment of sales during
the nine months ended September 30, 1999 on two wells due to the Program's
overproduced gas balancing position in those wells, which decreases were
partially offset by a negative prior period volume adjustment made by the
operator on one well during the nine months ended September 30, 1998.
Average oil prices increased to $15.24 per barrel for the nine months
ended September 30, 1999 from $13.65 per barrel for the nine months ended
September 30, 1998. Average gas prices decreased to $1.84 per Mcf for the
nine months ended September 30, 1999 from $1.96 per Mcf for the nine
months ended September 30, 1998.
Oil and gas production expenses (including lease operating expenses and
production taxes) decreased $45,628 (34.5%) for the nine months ended
September 30, 1999 as compared to the nine months ended September 30,
1998. This decrease was primarily due to (i) a decrease in lease operating
expenses associated with the decrease in volumes of gas sold, (ii)
workover expenses incurred on one well during the nine
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months ended September 30, 1998 in order to improve the recovery of
reserves, and (iii) a decrease in production taxes associated with the
decrease in oil and gas sales. These decreases were partially offset by an
increase in compression expenses on one well during the nine months ended
September 30, 1999. As a percentage of oil and gas sales, these expenses
remained relatively constant at 26.9% for the nine months ended September
30, 1999 and 26.6% for the nine months ended September 30, 1998.
Depreciation, depletion, and amortization of oil and gas properties
decreased $95,826 (69.5%) for the nine months ended September 30, 1999 as
compared to the nine months ended September 30, 1998. This decrease was
primarily due to (i) an increase in the gas price used in the valuation of
reserves at September 30, 1999 as compared to September 30, 1998, (ii) an
upward revision in the estimate of remaining gas reserves at December 31,
1998, and (iii) the decrease in volumes of gas sold. As a percentage of
oil and gas sales, this expense decreased to 13.1% for the nine months
ended September 30, 1999 from 27.7% for the nine months ended September
30, 1998. This percentage decrease was primarily due to the dollar
decrease in depreciation, depletion, and amortization.
General and administrative expenses remained relatively constant for the
nine months ended September 30, 1999 as compared to the nine months ended
September 30, 1998. As a percentage of oil and gas sales, these expenses
increased to 21.4% for the nine months ended September 30, 1999 from 14.0%
for the nine months ended September 30, 1998. This percentage increase was
primarily due to the decrease in oil and gas sales.
YEAR 2000 COMPUTER ISSUES
- -------------------------
IN GENERAL
The Year 2000 Issue ("Y2K") refers to the inability of computer and other
information technology systems to properly process date and time
information, stemming from the earlier programming practice of using two
digits rather than four to represent the year in a date. For example,
computer programs and imbedded chips that are date sensitive may recognize
a date using (00) as the year 1900 rather than the year 2000. The
consequence of Y2K is that computer and imbedded processing systems may be
at risk of malfunctioning, particularly during the transition from 1999 to
2000.
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<PAGE>
The effects of Y2K are exacerbated by the interdependence of computer and
telecommunication systems throughout the world. This interdependence also
exists among the Program, Samson Investment Company and its affiliates
("Samson"), and their vendors, customers, and business partners, as well
as with regulators. The potential risks associated with Y2K for an oil and
gas production company fall into three general areas: (i) financial,
leasehold and administrative computer systems, (ii) imbedded systems in
field process control units, and (iii) third party exposures. As discussed
below, Dyco does not believe that these risks will be material to the
Program's operations.
The Program's business is producing oil and gas. The day-to-day production
of the Program's oil and gas is not dependent on computers or equipment
with imbedded chips. As further discussed below, management anticipates
that the Program's daily business activities will not be materially
affected by Y2K.
The Program relies on Samson to provide all of its operational and
administrative services on either a direct or indirect basis. Samson has
addressed each of the three Y2K areas discussed above through a readiness
process that:
1. increased the awareness of the issue among key employees;
2. identified areas of potential risk;
3. assessed the relative impact of these risks and Samson's ability
to manage them; and
4. remediated the risks on a priority basis wherever possible.
One of Samson Investment Company's Executive Vice Presidents is
responsible for communicating to its Board of Directors Y2K actions and
for the ultimate implementation of its Y2K plan. He has delegated to
Samson Investment Company's Senior Vice President-Technology and
Administrative Services principal responsibility
for ensuring Y2K compliance within Samson.
Samson has been planning for the impact of Y2K on its information
technology systems since 1993. As of November 1, 1999, Samson is in the
final stages of implementation of a Y2K plan, as summarized below:
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FINANCIAL AND ADMINISTRATIVE SYSTEMS
1. Awareness. Samson has alerted its officers, managers and supervisors of
Y2K issues and asked them to have their employees participate in the
identification of potential Y2K risks which might otherwise go unnoticed
by higher level employees and officers. As a result, awareness of the
issue is considered high.
2. Risk Identification. Samson's most significant financial and
administrative systems exposure is the Y2K status of the accounting and
land administration system used to collect and manage data for internal
management decision making and for external revenue and accounts payable
purposes. Other concerns include network hardware and software, desktop
computing hardware and software, telecommunications, and office space
readiness.
3. Risk Assessment. The failure to identify and correct a material Y2K
problem could result in inaccurate or untimely financial information for
management decision-making or cash flow and payment purposes, including
maintaining oil and gas leases.
4. Remediation. Since 1993, Samson has been upgrading its accounting and
land administration software. All of the Y2K upgrades have been completed.
In addition, in 1997 and 1998 Samson replaced or applied software patches
to substantially all of its network and desktop software applications and
believes them to be currently Y2K compliant. The costs of all such risk
assessments and remediation were not material to the Program.
5. Contingency Planning. Notwithstanding the foregoing, should there be
significant unanticipated disruptions in Samson's financial and
administrative systems, all of the accounting processes that are currently
automated will need to be performed manually. Samson has communicated to
its management team the importance of having adequate staff available to
manually perform necessary functions to minimize disruptions.
IMBEDDED SYSTEMS
1. Awareness. Samson's Y2K program has involved all levels of field
personnel from production foremen and higher. Employees at all levels of
the organization have been asked to participate in the identification of
potential Y2K risks, which might otherwise go unnoticed by higher level
employees and officers of Samson, and as a result, awareness of the issue
is considered high.
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<PAGE>
2. Risk Identification. Samson has inventoried all possible exposures to
imbedded chips and systems. Such exposures can be classified as either (i)
oil and gas production and processing equipment or (ii) office machines
such as faxes, copiers, phones, etc.
With respect to oil and gas production and processing equipment, neither
Samson nor the Program operate offshore wells, significant processing
plants, or wells with older electronic monitoring systems. As a result,
Samson's inventory identified less than 10 applications using imbedded
chips. All of these have been tested by the respective vendors and have
been found to be Y2K compliant or have been upgraded or replaced.
Office machines have been tested by Samson and vendors and are believed to
be compliant.
3. Risk Assessment and Remediation. The failure to identify and correct a
material Y2K problem in an imbedded system could result in outcomes
ranging from errors in data reporting to curtailments or shutdowns in
production. As noted above, Samson has identified less than 10 imbedded
system applications all of which have been made compliant or replaced.
None of these applications are believed to be material to Samson or the
Program. Samson believes that sufficient manual processes are available to
minimize any field level risk and that there will be no material impact on
the Program with respect to these applications.
4. Contingency Planning. Should material production disruptions occur as a
result of Y2K failures in field operations, Samson will utilize its
existing field personnel in an attempt to avoid any material impact on
operating cash flow. Samson is not able to quantify any potential exposure
in the event of systems failure or inadequate manual alternatives.
THIRD PARTY EXPOSURES
1. Awareness. Samson has advised management to consider Y2K implications
with its outside vendors, customers, and business partners. Management has
been asked to participate in the identification of potential third party
Y2K risks and, as a result, awareness of the issue is considered high.
2. Risk Identification. Samson's most significant third party Y2K exposure
is its dependence on third parties for the receipt of revenues from oil
and gas sales. However, virtually all of these purchasers are very large
and sophisticated companies. Other Y2K concerns include the availability
of electric power to Samson's field operations, the integrity of
telecommunication systems, and the
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readiness of commercial banks to execute electronic fund transfers.
3. Risk Assessment. Because of the high awareness of the Y2K problem in
the U.S., Samson has not undertaken and does not plan to undertake a
formal company wide plan to make inquiries of third parties on the subject
of Y2K readiness. If it did so, Samson has no ability to require responses
to such inquiries or to independently verify their accuracy. Samson has,
however, received oral assurances from its significant oil and gas
purchasers of Y2K compliance. If significant disruptions from major
purchasers were to occur, however, there could be a material and adverse
impact on the Program's results of operations, liquidity, and financial
conditions.
It is important to note that third party oil and gas purchasers have
significant incentives to avoid disruptions arising from a Y2K failure.
For example, most of these parties are under contractual obligations to
purchase oil and gas or disperse revenues to Samson. The failure to do so
will result in contractual and statutory penalties. Therefore, Samson
believes that it is unlikely that there will be material third party
non-compliance with purchase and remittance obligations as a result of Y2K
issues.
4. Remediation. Where Samson perceived a significant risk of Y2K
non-compliance by banks and other significant vendors that would have had
a material impact on Samson's business, Samson undertook joint testing
during 1999, and any identified problems have been resolved.
5. Contingency Planning. In the unlikely event that material production
disruptions occur as a result of Y2K failures of third parties, the
Program's operating cash flow could be impacted. This contingency will be
factored into deliberations on the level of quarterly cash distributions
paid out during any such period of cash flow disruption.
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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET
RISK.
The Program does not hold any market risk sensitive instruments.
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PART II. OTHER INFORMATION
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
27.1 Financial Data Schedule containing summary financial information extracted
from the Dyco Oil and Gas Program 1983-1 Limited Partnership's financial
statements as of September 30, 1999 and for the nine months ended
September 30, 1999, filed herewith.
All other exhibits are omitted as inapplicable.
(b) Reports on Form 8-K.
None.
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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.
DYCO OIL AND GAS PROGRAM 1983-1 LIMITED
PARTNERSHIP
(Registrant)
BY: DYCO PETROLEUM CORPORATION
General Partner
Date: November 3, 1999 By: /s/Dennis R. Neill
-------------------------------
(Signature)
Dennis R. Neill
President
Date: November 3, 1999 By: /s/Patrick M. Hall
-------------------------------
(Signature)
Patrick M. Hall
Chief Financial Officer
-19-
<PAGE>
INDEX TO EXHIBITS
NUMBER DESCRIPTION
- ------ -----------
27.1 Financial Data Schedule containing summary financial information
extracted from the Dyco Oil and Gas Program 1983-1 Limited
Partnership's financial statements as of September 30, 1999 and for
the nine months ended September 30, 1999, filed herewith.
All other exhibits are omitted as inapplicable.
-20-
<TABLE> <S> <C>
<ARTICLE> 5
<CIK> 0000719958
<NAME> DYCO OIL & GAS PROGRAM 1983-1 LTD PSHIP
<S> <C>
<PERIOD-TYPE> 9-MOS
<FISCAL-YEAR-END> DEC-31-1999
<PERIOD-START> JAN-01-1999
<PERIOD-END> SEP-30-1999
<CASH> 147,146
<SECURITIES> 0
<RECEIVABLES> 85,578
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 232,724
<PP&E> 35,503,897
<DEPRECIATION> 35,202,735
<TOTAL-ASSETS> 570,630
<CURRENT-LIABILITIES> 15,810
<BONDS> 0
0
0
<COMMON> 0
<OTHER-SE> 430,476
<TOTAL-LIABILITY-AND-EQUITY> 570,630
<SALES> 322,062
<TOTAL-REVENUES> 325,442
<CGS> 0
<TOTAL-COSTS> 197,896
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 0
<INCOME-PRETAX> 127,546
<INCOME-TAX> 0
<INCOME-CONTINUING> 127,546
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 127,546
<EPS-BASIC> 16.62
<EPS-DILUTED> 0
</TABLE>
