Exhibit 99.1

 

QUARTERLY REPORT

for the period ended 30 June 2017 

 

FINANCIAL HIGHLIGHTS

 

-

Average net production for the quarter ended 30 June 2017 was 753 barrels of oil equivalent per day.

 

-

Production from the Foreman Butte acquisition increased slightly from the revised March quarter value of 63,804 barrels of oil (net production) to 64,414 barrels of oil for the June quarter. Following the volatility in the oil price, the decision was made to not return marginally economic wells to production if they went down with a mechanical issue during the quarter.

 

-

Estimated oil and gas revenue was US$2.9 million for the quarter (there is generally a two to three month delay between production and the receipt of funds).

 

-

Oil price differentials in the Williston Basin have improved from $8.00 per barrel 12 months ago to a current estimated differential of between $4.50 and $5.50 per barrel.

 

-

The due date on Samson’s credit facility with Mutual of Omaha bank was extended from October 2017 to October 2018. Estimated operated lease operating expense per barrel was $14.16 for the six months ended 30 June 2017 compared to $17.59 for the six months ended 31 December 2016

 

-

Recent advances in the oil price from a low of $43 per barrel in late June to $49 per barrel currently means that if the current price level is maintained, our realized oil price will increase in the current quarter to levels seen in the March quarter of around $ 45 per barrel.

 

PRODUCTION

 

Production from the Foreman Butte asset increased slightly from the March quarter.

 

Prior 12 month production by quarter:

 

		Q3 2016				Q4 2016				Q1 2017				Q2 2017
OIL, BO			90,818				75,306				64,900				66,015
GAS, MCF			44,379				42,637				30,767	*			10,848	*
BOE			98,215				82,412				70,027				67,823
BOEPD			1,091				915				778				753

 

* Does not include gas produced for which we have not yet received the revenue.

 

Estimated net production and revenue:

 

		OIL Bbls				OIL US$				GAS Mscf				GAS US$				TOTAL US$
March 2017 Quarter			64,900				2,965,195				30,767				82,816				3,040,011
June 2017 Quarter			66,015				2,828,794				10,848				16,272				2,845,066

 

Average commodity prices:

 

		OIL US$/Bbl				GAS US$/Mscf
March 2017 Quarter		$	45.69			$	2.69
June 2017 Quarter		$	42.85			$	1.50

 

In some cases revenue is yet to be received and is therefore an estimate.

 

 

LAND

 

PROJECT	BASIN	STATE	COUNTY	NET ACRES
Hawk Springs	DJ	Wyoming	Goshen	2,291
Roosevelt	Williston	Montana	Roosevelt	2,230
Rainbow	Williston	North Dakota	Williams	294
Foreman Butte	Williston	North Dakota/Montana	Numerous	51,305
South Prairie	Williston	North Dakota	Renville	1,066

 

PROJECTS

  

Rainbow Field: Williams County, North Dakota

Mississippian Bakken Formation, Williston Basin

Gladys 1-20H

Samson 23% Working Interest

Kraken Operating, LLC, the operator of the Gladys 1-20H well, has been producing this well at an average rate of 52 BOPD and 77 MCFPD during the quarter.

 

Cane Creek Project: Grand & San Juan Counties, Utah

Pennsylvanian Paradox Formation, Paradox Basin

Samson 100% Working Interest

Samson can exercise its option to lease 8,080 net acres with SITLA (Utah School and Institutional Trust Lands Administration) at a cost of $75 per acre before November 31, 2017. This acreage is located in the heart of the Cane Creek Clastic Play of the Paradox Formation along the Cane Creek anticline in Grand and San Juan Counties, Utah. The primary drilling objective is the over-pressured and oil saturated Cane Creek Clastic interval. Recent reprocessing of the original Potash 3-D seismic survey has improved the image of the subsurface. New prospects have been mapped and can potentially be drilled in the coming year.

 

Foreman Butte Project: McKenzie & Williams Counties, North Dakota and Richland, Roosevelt, Sheridan Counties, Montana

Mississippian Madison Formation, Williston Basin

Samson 87% Operated Average Working Interest

 

Samson averaged approximately a gross Operated 1,000 BOPD from its Foreman Butte Project this quarter. Samson has started the process of working over some wells with behind-pipe pay zones. These recompletions and some additional well optimizations are scheduled for the upcoming quarter that will continue to increase the overall production of the project.

 

Field operations continue to improve individual pump efficiencies through the use of well bore fluid level monitoring and the modification of pump stroke, pump frequency and when convenient pump change outs.

 

Samson has designed a proposed water flood pilot project for the Home Run Field utilizing an existing wellbore which is located on the flank of the field and which is non-productive. This well, the Mays 1-20H has been tested and readied for injected water once the NDIC has approved the plan. The plan has been submitted to the Commission who is considering the application following a recent Hearing. The water flood is being used to add pressure to the reservoir which should enhance the recovery of oil. The well performance in the offsetting wells will be monitored to establish the viability of the flood. The water being used is produced formation water so that there is no chemical compatibility issue, in essence the water is being returned to the reservoir from which it originated. Initially this water will be trucked to the injector from the existing producing wells but will ultimately be pipelined.

 

The Home Run Field (aka as the Foreman Butte Field) is the largest areal oil field in Samson’s portfolio. It was developed on a 640 acre spacing pattern and our engineering and geologic analyses have determined that only 3.2% of the original oil in place has been recovered to date. Given that oil fields typically recover up to around 20% of their oil in place there would appear to be significant un-developed oil to be recovered from this field.

 

  

This has been confirmed through the use of a 3 dimensional numerical simulation of the reservoir volume, and the expected production curve for these wells has been developed from the resulting numerical model.

 

The current reservoir pressure has also been established using a field wide fluid level study, and the initial development wells will be located in areas of demonstrated higher pressure.

 

This undeveloped oil forms our Proved Undeveloped reserve of around $30 million, and these reserves represent very robust economics, despite the low oil price, because we have designed a drilling technique that would see two 5,000 feet laterals drilled from existing well bores at an estimated cost of around $400,000 each. These laterals will use existing surface facilities and have an estimated net present value of around $1.5 million.

Accordingly Samson is planning to drill its first development well this Summer/early Fall. The first lateral will test the Ratcliffe Formation of the Mississippian Madison Group. The lateral in the Ratcliffe Formation will help define the pressure depletion radius from the existing producing wellbores which will ultimately determine the number of PUD’s (proven undeveloped drilling locations) we can drill in this reservoir. Currently we have 20 Ratcliffe PUD locations identified. The second lateral will test an undeveloped reservoir in the Mission Canyon Formation of the Mississippian Madison Group. This lateral could prove up a new oil field with the potential for many additional well locations (up to 20 vertical wells or 8 drill-out laterals). A 3,500 acre 4-way structural closure has been mapped from an abundance of existing well control in the area. In 2004, the Banks 1-18H well as a dual lateral in both the Ratcliffe and Mission Canyon reservoirs. The Mission Canyon lateral produced hundreds of barrels of oil while the lateral was being drilled. But, the well was completed as just a single lateral in the Ratcliffe zone due to the operator being unable to remove a stuck whipstock that was set above the Mission Canyon lateral in order to drill the Ratcliffe lateral. This stuck whipstock prevented the completion of the Mission Canyon lateral.

 

LIQUIDITY

 

Sources of cash for the next quarter are as follows:

 

		US$(’000’s)
Current cash on hand			645
Cash receipts from June quarter oil and gas sales*			900
Availability in credit facility			450
TOTAL			1,995

 

* Estimate based on realized June quarter production and $44 oil price (indicative of estimated oil pricing), allowing for a one month delay between production and cash receipt.

 

FINANCIAL

 

Mutual of Omaha Credit Facility

Samson paid down $1.2 million against its facility following the sale of its State GC properties in May 2017. This remains available for redraw. The term of the facility was also extended to October 2018.

 

Cash Distribution
Bank of the West	US$56,298
Bank of New York Mellon	US$17,599
Mutual of Omaha	US$553,445
National Australia Bank	A$12,180

  

 

Foreign Exchange Rates

The closing A$:US$ exchange rate on 30 June 2017 was $0.7692 The average A$:US$ exchange rate for the quarter was $0.75.

 

The Company’s cash position at 30 June 2017 was as follows:

 

		US$(‘000’s)
Cash at bank on deposit			645

 

Hedging – to update

 

Product		Start Date		End Date		Volume (BO/Mmbtu)				Floor $				Ceiling $
WTI		1 April 2017		30 Apr 2018			43,485				41.50				63.00
WTI		1 May 2018		31 Dec 2018			107,800				45.00				56.00
Henry Hub		1 Feb 2017		31 Mar 2017			25,842				2.60				3.35
Henry Hub		1 May 2017		31 Oct 2017			61,456				2.40				2.91
Henry Hub		1 Nov 2017		30 Apr 2018			64,774				2.80				3.60
Henry Hub		1 May 2018		31 Dec 2018			80,850				2.65				2.90

 

Product

Start Date

End Date

Volume (BO)

Swap Price $

WTI

1 April 2017

31 Dec 2017

106,425

44.09

WTI

1 Jan 2018

30 Apr 2018

39,720

45.55

 

As at 30 June 2017, the value of Samson’s hedging program was ($0.3 million). At 25^th July 2017, the value of Samson’s hedging program was ($0.5 million).

 

 

For further information please contact Denis Rakich, Director/Company Secretary, on 08 9220 9882

 

For and on behalf of the Board of

SAMSON OIL & GAS LIMITED

TERRY BARR Managing Director

Information contained in this report relating to hydrocarbon reserves was compiled by the Managing Director of Samson Oil & Gas Ltd., T M Barr a Geologist who holds an Associateship in Applied Geology and is a fellow of the Australian Institute of Mining and Metallurgy who has 30 years relevant experience in the oil & gas industry.

 

31 July 2017

 

 

Rule 5.3

Appendix 5B

 

Mining exploration entity and oil and gas exploration entity quarterly report

 

Introduced 01/07/96 Origin Appendix 8 Amended 01/07/97, 01/07/98, 30/09/01, 01/06/10, 17/12/10, 01/05/13, 01/09/16

 

Name of entity
Samson Oil and Gas Limited
ABN	Quarter ended (“current quarter”)
25 009 069 005	30 June 2017

 

Consolidated statement of cash flows				Current quarter $US’000				Year to date (12 months) $US’000
1.	Cash flows from operating activities
1.1	Receipts from customers				3,040				14,105
1.2	Payments for
	(a)	exploration & evaluation			(22	)			(109	)
	(b)	development			(536	)			(2,807	)
	(c)	production			(2,989	)			(9,609	)
	(d)	staff costs			(507	)			(2,043	)
	(e)	administration and corporate costs			(285	)			(2,085	)
1.3	Dividends received (see note 3)				-				-
1.4	Interest received				-				-
1.5	Interest and other costs of finance paid				(477	)			(1,878	)
1.6	Income taxes paid				-				-
1.7	Research and development refunds				-				-
1.8	Other (provide details if material) Hedging				(240	)			(1,342	)
	Abandonment costs				-				(134	)
1.9	Net cash from / (used in) operating activities				(2,016	)			(5,902	)
2.	Cash flows from investing activities
2.1	Payments to acquire:				(11	)			(116	)
	(a)	property, plant and equipment
	(b)	tenements (see item 10)			-				-
	(c)	investments			-				-
	(d)	other non-current assets			-				-
2.2	Proceeds from the disposal of:
	(a)	property, plant and equipment			1,042				15,150
	(b)	tenements (see item 10)			-				-
	(c)	investments			-				-
	(d)	other non-current assets			-				-
2.3	Cash flows from loans to other entities				-				-
2.4	Dividends received (see note 3)				-				-
2.5	Other (provide details if material)				-				-
2.6	Net cash from / (used in) investing activities				1,031				15,034
3.	Cash flows from financing activities				-				-
3.1	Proceeds from issues of shares
3.2	Proceeds from issue of convertible notes				-				-
3.3	Proceeds from exercise of share options				-				5
3.4	Transaction costs related to issues of shares, convertible notes or options				-				(5	)
3.5	Proceeds from borrowings				-				-
3.6	Repayment of borrowings				(450	)			(11,046	)
3.7	Transaction costs related to loans and borrowings				(40	)			(90	)
3.8	Dividends paid				-				-
3.9	Other (provide details if material)				-				-
3.10	Net cash from / (used in) financing activities				(490	)			(11,136	)
4.	Net increase / (decrease) in cash and cash equivalents for the period
4.1	Cash and cash equivalents at beginning of period				2,120				2,655
4.2	Net cash from / (used in) operating activities (item 1.9 above)				(2,016	)			(5,902	)
4.3	Net cash from / (used in) investing activities (item 2.6 above)				1,031				15,034
4.4	Net cash from / (used in) financing activities (item 3.10 above)				(490	)			(11,136	)
4.5	Effect of movement in exchange rates on cash held				-				(6	)
4.6	Cash and cash equivalents at end of period				645				645

 

 

5.	Reconciliation of cash and cash equivalents at the end of the quarter (as shown in the consolidated statement of cash flows) to the related items in the accounts		Current quarter $US’000				Previous quarter $US’000
5.1	Bank balances			645				2120
5.2	Call deposits			-				-
5.3	Bank overdrafts			-				-
5.4	Other (provide details)			-				-
5.5	Cash and cash equivalents at end of quarter (should equal item 4.6 above)			645				2120

 

6.	Payments to directors of the entity and their associates		Current quarter $US'000
6.1	Aggregate amount of payments to these parties included in item 1.2			100
6.2	Aggregate amount of cash flow from loans to these parties included in item 2.3			-
6.3	Include below any explanation necessary to understand the transactions included in items 6.1 and 6.2
Salary

7.	Payments to related entities of the entity and their associates		Current quarter $US'000
7.1	Aggregate amount of payments to these parties included in item 1.2			-
7.2	Aggregate amount of cash flow from loans to these parties included in item 2.3			-
7.3	Include below any explanation necessary to understand the transactions included in items 7.1 and 7.2

 

8.	Financing facilities available Add notes as necessary for an understanding of the position		Total facility amount at quarter end $US’000				Amount drawn at quarter end $US’000
8.1	Loan facilities			24,000				23,452
8.2	Credit standby arrangements			-
8.3	Other (please specify)			-
8.4	Include below a description of each facility above, including the lender, interest rate and whether it is secured or unsecured. If any additional facilities have been entered into or are proposed to be entered into after quarter end, include details of those facilities as well.

 

 

Mutual of Omaha Bank credit facility - $23.4m. The interest rate is 5.25% on the reserve based lending facility and the interest rate is 6.5% on the term loan with a balance of $4.0 million. Both loans mature October 2018 and are fully secured against Samson’s oil and gas assets.

 

  

9.	Estimated cash outflows for next quarter		$US’000
9.1	Exploration and evaluation			-
9.2	Development			1,860
9.3	Production			1,000
9.4	Staff costs			600
9.5	Administration and corporate costs			500
9.6	Other (provide details if material)			-
9.7	Total estimated cash outflows			3,960

 

10.	Changes in tenements (items 2.1(b) and 2.2(b) above)	Tenement reference and location	Nature of interest	Interest at beginning of quarter	Interest at end of quarter
10.1	Interests in mining tenements and petroleum tenements lapsed, relinquished or reduced
10.2	Interests in mining tenements and petroleum tenements acquired or increased

 

 

Compliance statement

1

This statement has been prepared in accordance with accounting standards and policies which comply with Listing Rule 19.11A.

2

This statement gives a true and fair view of the matters disclosed.

 

 

Sign here:		Date: 31 July 2017
	(Director/Company secretary)

 

Print name: DENIS RAKICH

 

 

Notes

1.

The quarterly report provides a basis for informing the market how the entity’s activities have been financed for the past quarter and the effect on its cash position. An entity that wishes to disclose additional information is encouraged to do so, in a note or notes included in or attached to this report.

 

2.

If this quarterly report has been prepared in accordance with Australian Accounting Standards, the definitions in, and provisions of, AASB 6: Exploration for and Evaluation of Mineral Resources and AASB 107: Statement of Cash Flows apply to this report. If this quarterly report has been prepared in accordance with other accounting standards agreed by ASX pursuant to Listing Rule 19.11A, the corresponding equivalent standards apply to this report.

 

3.

Dividends received may be classified either as cash flows from operating activities or cash flows from investing activities, depending on the accounting policy of the entity.