Bellatrix Exploration Ltd (Canada) BXEFF

BXE Announces Second Quarter 2014

[uwinsome]

Wednesday, August 06, 2014

Bellatrix Exploration Ltd. Announces Second Quarter 2014 Financial Results

02:05 EDT Wednesday, August 06, 2014

TSX, NYSE MKT: BXE

CALGARY, Aug. 6, 2014 /PRNewswire/ - Bellatrix Exploration Ltd. ("Bellatrix" or the "Company") (TSX, NYSE MKT: BXE) announces its financial and operating results for the three and six months ended June 30, 2014.

Forward-Looking Statements

This press release, including the report to shareholders, contains forward-looking statements. Please refer to our cautionary language on forward-looking statements and the other matters set forth at the beginning of the management's discussion and analysis (the "MD&A") attached to this press release.

HIGHLIGHTS

		Three months ended June 30,			Six months ended June 30,
		2014	2013		2014	2013
FINANCIAL (unaudited)
(CDN$000s except share and per share amounts)
Revenue (before royalties and risk management (1))		152,311	74,564		315,896	140,107
Funds flow from operations (2)		71,014	36,563		148,656	74,108
	Per basic share (5)	$0.40	$0.34		$0.85	$0.69
	Per diluted share (5)	$0.39	$0.31		$0.84	$0.63
Cash flow from operating activities		60,063	29,611		144,363	65,138
	Per basic share (5)	$0.34	$0.27		$0.83	$0.60
	Per diluted share (5)	$0.33	$0.25		$0.81	$0.55
Net profit		38,252	15,466		63,419	20,027
	Per basic share (5)	$0.22	$0.14		$0.36	$0.19
	Per diluted share (5)	$0.21	$0.13		$0.36	$0.18
Exploration and development		131,362	46,172		284,049	137,632
Corporate		3,206	543		6,161	682
Capital expenditures - cash		134,568	46,715		290,210	138,314
Property dispositions - cash		(8,613)	(16)		(8,392)	(1)
Total net capital expenditures - cash		125,955	46,699		281,818	138,313
Other non-cash items		3,602	(1,308)		8,592	(521)
Total capital expenditures - net (4)		129,557	45,391		290,410	137,792
Long-term debt		323,007	194,002		323,007	194,002
Convertible debentures (6)		-	51,536		-	51,536
Adjusted working capital deficiency (3)		40,426	10,927		40,426	10,927
Total net debt (3)		363,433	256,465		363,433	256,465
Total assets		1,837,242	779,648		1,837,242	779,648
Total shareholders' equity		1,141,830	402,904		1,141,830	402,904

OPERATING			Three months ended June 30,		Six months ended June 30,
			2014	2013	2014	2013
Average daily sales volumes
	Crude oil, condensate and NGLs	(bbls/d)	12,640	6,206	12,524	6,095
	Natural gas	(mcf/d)	142,214	95,376	139,051	87,812
	Total oil equivalent	(boe/d)	36,342	22,102	35,699	20,730
Average prices
	Crude oil and condensate	($/bbl)	103.25	93.48	100.72	91.83
	NGLs (excluding condensate)	($/bbl)	42.70	36.20	49.72	39.05
	Crude oil, condensate and NGLs	($/bbl)	74.73	71.84	77.53	72.70
	Crude oil, condensate and NGLs (including risk management (1))	($/bbl)	67.71	73.10	71.14	73.26
	Natural gas	($/mcf)	5.04	3.85	5.45	3.69
	Natural gas (including risk management (1))	($/mcf)	4.40	3.68	4.64	4.01
	Total oil equivalent	($/boe)	45.72	36.78	48.43	37.01
	Total oil equivalent (including risk management (1))	($/boe)	40.78	36.39	43.01	38.54
Statistics
	Operating netback (4)	($/boe)	28.93	21.06	30.85	21.04
	Operating netback (4) (including risk management (1))	($/boe)	23.98	20.68	25.43	22.58
	Transportation	($/boe)	0.82	0.83	1.20	0.83
	Production expenses	($/boe)	7.80	8.64	7.96	8.65
	General & administrative	($/boe)	1.37	1.24	1.56	1.62
	Royalties as a % of sales after transportation		18%	17%	17%	18%
COMMON SHARES
Common shares outstanding			191,091,741	107,919,329	191,091,741	107,919,329
Share options outstanding			11,576,839	9,173,560	11,576,839	9,173,560
Shares issuable on conversion of convertible debentures (6)			-	9,821,429	-	9,821,429
Fully diluted common shares outstanding			202,668,580	126,914,318	202,668,580	126,914,318
Diluted weighted average shares - net profit (5)			180,975,410	121,265,334	177,408,647	121,038,666
Diluted weighted average shares - funds flow from operations and cash flow from operating activities (2) (5)			180,975,410	121,265,334	177,408,647	121,038,666
SHARE TRADING STATISTICS
TSX and Other (7)
(CDN$, except volumes) based on intra-day trading
High			11.65	6.94	11.65	6.94
Low			8.88	4.70	7.64	4.03
Close			9.26	6.45	9.26	6.45
Average daily volume			3,266,310	1,005,989	2,563,117	844,333
NYSE MKT
(US$, except volumes) based on intra-day trading
High			10.70	6.85	10.70	6.85
Low			8.15	4.55	6.93	4.03
Close			8.71	6.08	8.71	6.08
Average daily volume			371,163	67,541	265,351	70,189

(1)	The Company has entered into various commodity price risk management contracts which are considered to be economic hedges. Per unit metrics after risk management include only the realized portion of gains or losses on commodity contracts.
	The Company does not apply hedge accounting to these contracts. As such, these contracts are revalued to fair value at the end of each reporting date. This results in recognition of unrealized gains or losses over the term of these contracts which is reflected each reporting period until these contracts are settled, at which time realized gains or losses are recorded. These unrealized gains or losses on commodity contracts are not included for purposes of per unit metrics calculations disclosed.
(2)	The highlights section contains the term "funds flow from operations" which should not be considered an alternative to, or more meaningful than cash flow from operating activities as determined in accordance with generally accepted accounting principles ("GAAP") as an indicator of the Company's performance. Therefore reference to the non-GAAP measures of funds flow from operations, or funds flow from operations per share may not be comparable with the calculation of similar measures for other entities. Management uses funds flow from operations to analyze operating performance and leverage and considers funds flow from operations to be a key measure as it demonstrates the Company's ability to generate the cash necessary to fund future capital investments and to repay debt. The reconciliation between cash flow from operating activities and funds flow from operations can be found in the MD&A. Funds flow from operations per share is calculated using the weighted average number of common shares for the period.
(3)	Net debt and total net debt are considered non-GAAP measures. Therefore reference to the non-GAAP measures of net debt or total net debt may not be comparable with the calculation of similar measures for other entities. The Company's 2014 calculation of total net debt excludes deferred lease inducements, long-term commodity contract liabilities, decommissioning liabilities, the long-term finance lease obligation, deferred lease inducements, and the deferred tax liability. Net debt and total net debt include the adjusted working capital deficiency (excess). The adjusted working capital deficiency (excess) is a non-GAAP measure calculated as net working capital deficiency (excess) excluding short-term commodity contract assets and liabilities, current finance lease obligation, and deferred lease inducements. For the comparative 2013 calculation, net debt also excludes the liability component of convertible debentures which were then outstanding. A reconciliation between total liabilities under GAAP and total net debt and net debt as calculated by the Company is found in the MD&A.
(4)	Operating netbacks and total capital expenditures - net are considered non-GAAP measures. Operating netbacks are calculated by subtracting royalties, transportation, and operating costs from revenues before other income. Total capital expenditures - net includes the cash impact of capital expenditures and property dispositions, as well as the non-cash capital impacts of corporate acquisitions, adjustments to the Company's decommissioning liabilities, and share based compensation. The detailed calculations of operating netbacks are found in the MD&A.
(5)	Basic weighted average shares for the three and six months ended June 30, 2014 were 177,847,190 (2013: 107,919,329), and 174,754,132 (2013: 107,900,781), respectively.
	In computing weighted average diluted earnings per share and weighted average diluted cash flow from operating activities and funds flow from operations per share for the three and six months ended June 30, 2014, a total of 3,128,220 (2013: 3,524,576), and 2,654,515 (2013: 3,316,456) common shares were added to the denominator as a consequence of applying the treasury stock method to the Company's outstanding share options and no common shares issuable (three and six months ended June 30, 2013: 9,821,429) on conversion of convertible debentures were added to the denominator as they were dilutive, resulting in diluted weighted average common shares of 180,975,410 (2013: 121,265,334), and 177,408,647 (2013: 121,038,666), respectively. As a consequence, a total of nil (2013: $0.8 million) and nil (2013: $1.6 million) for interest and accretion expense (net of income tax effect) was added to the numerator for the three and six month calculations, respectively
(6)	During the year ended December 31, 2013, the Company announced a notice of redemption of its then outstanding $55.0 million 4.75% convertible debentures, with a redemption date set of October 21, 2013. During September and October 2013, the $55.0 million principal amount of remaining convertible debentures were converted or redeemed in exchange for an aggregate of 9,794,848 common shares of the Company. For the three and six months ended June 30, 2013, shares issuable on conversion of convertible debentures were calculated by dividing the $55.0 million principal amount of the convertible debentures by the conversion price of $5.60 per share.
(7)	TSX and Other includes the trading statistics for the Toronto Stock Exchange and other Canadian trading markets.

REPORT TO SHAREHOLDERS

In spite of the significant production processing wantage experienced in the first half of 2014 the Company continues to demonstrate accelerated growth posting record earnings, revenue, cash flow and production while continuing to drive down operating expenses. The wells drilled in the first half of 2014 are in line with our published type curves, facilitating the Company's ability to meet its published guidance of 2014 average daily production of +/-41,000 boe/d and an exit rate of approximately +/-48,000 boe/d, assuming no future unscheduled production constraints occur. Bellatrix's technical staff were habile in redirecting gas production from plant to plant thereby maximizing throughput in an active plant turnaround season.

Operational highlights for the three and six months ended June 30, 2014 include:

• Record sales of 36,342 boe/d (65% natural gas) up 64% from sales volumes of 22,102 boe/d registered in the second quarter of 2013.
• Funds flow from operations for the six months ending June 30, 2014 was $148.7 million, doubling the same period in 2013 ($74.1 million) and furthermore, exceeds the funds flow for all of 2013 ($143.5 million).
• Earnings for the second quarter 2014 of $38.3 million were 147% higher than the $15.5 million posted in Q2 2013.
• On a year to date basis the Company has posted earnings of $63.4 million up 217% over the same period in 2013 ($20.0 million).
• Operating costs reduced to a record $7.80/boe in the second quarter of 2014.
• During the first six months of 2014, Bellatrix posted a 100% success rate drilling and/or participating in 63 gross (34.56 net) wells, resulting in 47 gross (27.38 net) Cardium oil wells, 14 gross (6.02 net) Notikewin/Falher liquids-rich gas wells, and 2 gross (1.15 net) Cardium gas wells. During the second quarter of 2014, Bellatrix drilled and/or participated in 19 gross (9.00 net) wells, consisting of 11 gross (5.51 net) Cardium oil wells, 7 gross (2.99 net) Notikewin/Falher liquids-rich gas wells, and 1 gross (0.50 net) Cardium gas well.
• During the second quarter of 2014, the Company successfully drilled and completed a two mile Spirit River gas well in the Ferrier area which was placed on restricted production in mid-July at 18 mmcf/d with 2,000 psi of back pressure. As more production space comes available the well rate will be increased.
• On April 2, 2014, Bellatrix announced the completion of a 1.6 km river bore and a 7 km pipeline in conjunction with Blaze Energy Ltd. ("Blaze"), completing a 55 km pipeline to tie-in Bellatrix natural gas for processing in the Blaze gas plant located at 4-31-48-12W5. Bellatrix has secured firm processing capacity of 100 mmcf/d in the plant.
• During the second quarter of 2014, Bellatrix spent $134.6 million on capital projects, compared to $46.7 million in Q2 2013. In the six months ended June 30, 2014, Bellatrix spent $290.2 million on capital projects, compared to $138.3 million in the first six months of 2013.
• As at June 30, 2014, Bellatrix had approximately 395,237 net undeveloped acres of land in Alberta, British Columbia and Saskatchewan.
• To facilitate moving our growing production base to the area third party gas processing plants, Bellatrix has purchased 21 compressors in the field totaling 31,000 hp in the first half of 2014. In addition the Company completed 55km of group pipelines. In the second quarter the Company completed construction of an oil battery at 5-5-46-12W5M with a treating capacity of 2,800 bbl/d.

To view Bellatrix's Gas Processing Infrastructure please click here.

Currently when all of the eleven third party plants are in full operation Bellatrix has access to 213 mmcf/d of firm processing capacity to process both the Company's and our joint operator (partner) gas. There is a further 179 mmcf/d of interruptible processing capacity available on a first come first serve basis. This interruptible capacity has recently become congested due to both system constraints and the influx of new reserves and production in the area due to significant drilling with the application of new horizontal drilling and muti-stage fracing technology by all of the area operators. The area plant throughputs are further impacted by fluctuations in the TransCanada system pressures which are forecasted to be high through the summer to accommodate their maintenance programs.

In the second quarter of 2014, Bellatrix processed an average of 142.2 mmcf/d along with approximately 95 mmcf/d of partner gas. In the third quarter following completion of the various plant turnarounds, the Company is forecasting net production of approximately 175 mmcf/d given the area plants have the capacity to process these volumes.

The system tightness is expected to continue until the Bellatrix Plant Phase 1 comes online. All major gas plant equipment has been ordered and is undergoing fabrication. The surface lease has been built to meet the required specifications. Process packages are on schedule for Q3 and Q4 2014 delivery. To date the construction of the gas plant is on budget and on schedule for plant start-up on or before July 1, 2015.

$750.0 Million Short Form Base Shelf Prospectus and $172.6 Million Bought Deal Financing

In May 2014, Bellatrix filed a short form base shelf prospectus (the "$750 million Shelf Prospectus") of up to $750.0 million, with the securities regulatory authorities in each of the provinces of Canada (other than Quebec) and a Registration Statement filed with the United States Securities and Exchange Commission. The $750 million Shelf Prospectus allows Bellatrix to offer and issue common shares, subscription receipts, warrants and units (comprising any combination of the foregoing securities), by way of one or more prospectus supplements at any time during the 25-month period that the $750 million Shelf Prospectus remains in place.

Pursuant to a prospectus supplement to the $750 million Shelf Prospectus, on June 5, 2014, Bellatrix closed a bought deal offering of 18,170,000 common shares of the Company (the "Common Shares") at a price of $9.50 per Common Share for aggregate gross proceeds of $172.6 million (the "Offering"), through a syndicate of underwriters. Net proceeds of $165.5 million received from the Offering were utilized to temporarily reduce outstanding indebtedness under the Company's credit facilities, thereby freeing up borrowing capacity that may be redrawn, from time to time, to fund the Company's ongoing capital expenditure program and for general corporate purposes.

As at June 30, 2014, there was $577.4 million available on the $750 million Shelf Prospectus.

Credit Facility Increased 25% to $625 million

Based upon the Company's semi-annual borrowing base review for May 31, 2014, Bellatrix increased its borrowing base and credit facilities to $625 million from $500 million. This 25% increase of $125 million was the result of Bellatrix's strong 2013 drilling results continuing into the first quarter of 2014, combined with benefits derived from the acquisition of Angle Energy Inc. ("Angle") in the fourth quarter of 2013, cumulatively delivering significant reserves and production growth. The increased credit facilities will be available to finance Bellatrix's ongoing capital expenditures, working capital requirements and for general corporate purposes.

The bank syndicate lenders approved the Company's request to change the term of the credit facilities to a 3 year facility, fully revolving until maturity, and extendible annually at the Company's option (subject to lender approval), provided that the term after any extension would not be more than 3 years. Concurrently with such changes, the credit facilities were also amended to include certain ongoing financial covenants that will require quarterly compliance.

Grafton Joint Venture Capital Investment Increase

On April 10, 2014, Bellatrix announced that Grafton elected to exercise an option to increase committed capital investment to the Grafton Joint Venture established during 2013 by an additional $50 million, for a total commitment of $250 million, on the same terms and conditions as the previously announced Grafton Joint Venture. Grafton's increased capital investment will continue to support the accelerated development of a portion of Bellatrix's extensive undeveloped land holdings.

The Grafton Joint Venture properties are located in the Willesden Green and Brazeau areas of West-Central Alberta. After giving effect to the exercise by Grafton of its option, Grafton was committed to contributing 82%, or $250 million, to the $305 million Joint Venture to participate in a Notikewin/Falher and Cardium well program. Under the agreement, Grafton will earn 54% of Bellatrix's working interest ("WI") in each well drilled in the development program until payout (being recovery of Grafton's capital investment plus an 8% return) on the total program, reverting to 33% of Bellatrix's WI after payout. At any time after payout of the entire program, Grafton shall have the option to elect to convert all wells from the 33% WI to a 17.5% Gross Overriding Royalty on Bellatrix's pre-Joint Venture WI. The effective date of the initial agreement for the Joint Venture is July 1, 2013 and had an initial term of 2 years. With the exercise of the $50 million option, Bellatrix shall have until the end of the third anniversary of the effective date to spend the additional capital.

Financial highlights for the three and six months ended June 30, 2014 include:

• Bellatrix's net profit for Q2 2014 was $38.3 million, compared to a net profit of $15.5 million in Q2 2013. For the first half of 2014, Bellatrix recognized a net profit of $63.4 million, compared to a net profit of $20.0 million in the same period of 2013.
• Q2 2014 revenue before royalties and risk management contracts was $152.3 million, 105% higher than the $74.6 million recognized in Q2 2013. The increase in revenues between the periods was primarily due to significantly increased sales volumes for all products, in conjunction with higher realized prices for all commodities in Q2 2014 compared to Q2 2013. Revenue for the first six months of 2014 was $315.9 million, an increase of 125% from $140.1 million in the same period in 2013.
• Funds flow from operations for Q2 2014 was $71.0 million ($0.40 per basic share), up 94% from $36.6 million ($0.34 per basic share) in Q2 2013, and down 9% from $77.6 million ($0.45 per basic share) in Q1 2014. The decrease in funds flow from operations between the first and second quarters of 2014 was due primarily to reduced natural gas and NGL prices impacting revenues and netbacks and higher finance expenses, partially offset by the impact of higher crude oil commodity prices, lower transportation and general and administrative expenses, and a lower net realized loss on commodity contracts. The increase in funds flow from operations between the three months ended June 30, 2014 and the same period in 2013 was principally attributable to higher overall funds from operating netbacks, partially offset by a greater net loss on realized commodity contracts in the 2014 three month period, higher general and administrative expenses, and increased financing expenses. Funds flow from operations for the first half of 2014 was $148.7 million ($0.85 per basic share), up 101% from $74.1 million ($0.69 per basic share) in the first six months of 2013.
• Crude oil, condensate and NGLs produced 57% and 56% of petroleum and natural gas sales revenue for the three and six month periods ended June 30, 2014, respectively.
• Production expenses for Q2 2014 were $7.80/boe ($25.8 million), compared to $8.64/boe ($17.4 million) for Q2 2013 and $8.12/boe ($25.6 million) for Q1 2014. Production expenses for the six months ended June 30, 2014 were $7.96/boe ($51.4 million), compared to $8.65/boe ($32.4 million) for the same period in 2013.
• Operating netbacks after including risk management for the six months ended June 30, 2014 were $25.43/boe, up from $22.58/boe in the first half of 2013. Operating netbacks before risk management for the six months ended June 30, 2014 were $30.85/boe, compared with $21.04/boe in the same period in 2013. The netback increased between the periods as a result of higher commodity prices and reduced production expenses, partially offset by higher royalties and transportation expenses.|
• Operating netbacks after including risk management for Q2 2014 were $23.98/boe, up from $20.68/boe in Q2 2013. Operating netbacks before risk management for Q2 2014 were $28.93/boe, up from $21.06/boe in Q2 2013. The greater netback including risk management between the periods was primarily the result of higher commodity prices, reduced production expenses, partially offset by higher royalty expenses.
• G&A expenses for Q2 2014 increased on a per boe basis to $1.37/boe ($4.5 million), compared to $1.24/boe ($2.5 million) for Q2 2013. G&A expenses for the six months ended June 30, 2014 were $1.56/boe ($10.1 million), compared to $1.62/boe ($6.1 million) in the same period in 2013.
• As at June 30, 2014, Bellatrix had $301.5 million undrawn on its total $625 million credit facilities.
• Total net debt as of June 30, 2014 was $363.4 million.

Commodity Price Risk Management

As of August 5, 2014, the Company has entered into the following commodity price risk management arrangements:

Type

Period

Volume

Price Floor

Price Ceiling

Index

Crude oil fixed

January 1, 2014 to Dec. 31, 2014

500 bbl/d

$

93.30 US

$

93.30 US

WTI

Crude oil fixed

January 1, 2014 to Dec. 31, 2014

1,500 bbl/d

$

94.00 CDN

$

94.00 CDN

WTI

Crude oil fixed

January 1, 2014 to Dec. 31, 2014

500 bbl/d

$

95.00 US

$

95.00 US

WTI

Crude oil fixed

January 1, 2014 to Dec. 31, 2014

1,500 bbl/d

$

95.22 CDN

$

95.22 CDN

WTI

Crude oil fixed

January 1, 2014 to Dec. 31, 2014

500 bbl/d

$

98.30 CDN

$

98.30 CDN

WTI

Crude oil fixed

January 1, 2014 to Dec. 31, 2014

1,000 bbl/d

$

99.50 CDN

$

99.50 CDN

WTI

Crude oil fixed

January 1, 2014 to Dec. 31, 2014

500 bbl/d

$

99.60 CDN

$

99.60 CDN

WTI

Natural gas fixed

January 1, 2014 to Dec. 31, 2014

20,000 GJ/d

$

3.30 CDN

$

3.30 CDN

AECO

Natural gas fixed

January 1, 2014 to Dec. 31, 2014

20,000 GJ/d

$

3.60 CDN

$

3.60 CDN

AECO

Natural gas fixed

July 1, 2014 to Dec. 31, 2014

15,000 GJ/d

$

3.71 CDN

$

3.71 CDN

AECO

Natural gas fixed

February 1, 2014 to Dec. 31, 2014

10,000 GJ/d

$

3.79 CDN

$

3.79 CDN

AECO

Natural gas fixed

February 1, 2014 to Dec. 31, 2014

10,000 GJ/d

$

3.80 CDN

$

3.80 CDN

AECO

Natural gas fixed

February 1, 2014 to Dec. 31, 2014

15,000 GJ/d

$

3.85 CDN

$

3.85 CDN

AECO

Natural gas fixed

February 1, 2014 to Dec. 31, 2014

10,000 GJ/d

$

3.84 CDN

$

3.84 CDN

AECO

Natural gas fixed

March 1, 2014 to Dec. 31, 2014

10,000 GJ/d

$

4.14 CDN

$

4.14 CDN

AECO

Outlook

Bellatrix continues to develop its core assets and conduct exploration programs utilizing its large inventory of geological prospects.

2014 cash flow forecasts for the year have been updated to reflect the recent softening natural gas prices due to the current cooler summer weather conditions. 2014 funds flow from operations expectations have been lowered to approximately $350 million or $1.90 per basic share. This represents a 144% increase over 2013 funds flow from operations of $143.5 million or $1.27 per basic share.

Based on an assumed 2014 average Edmonton Light oil price of $96.85/bbl and AECO $4.34/GJ, average 2014 royalty rates of 18% and estimated 2014 operating costs of $116.5 million or $7.75 boe/d, the Company expects to exit 2014 with total net debt of approximately $390 million or approximately 1.0 times total net debt to annualized estimated fourth quarter 2014 funds flow from operations.

For the remainder of 2014, Bellatrix will be active in drilling with 10 to 12 rigs operating in its two core resource plays, the Cardium light oil play (Bellatrix is the second largest land holder with 338 net sections in the Cardium) and Mannville condensate rich gas play, utilizing horizontal drilling multi-fracturing technology. A revised net capital budget of $515 million has been set for fiscal 2014. Based on the timing of proposed expenditures, downtime for anticipated plant turnarounds and normal production declines, execution of the 2014 budget is anticipated to provide 2014 average daily production of approximately 41,000 boe/d and an exit rate of approximately 48,000 boe/d.

Value is constantly created as we expand with a dominating control of our core area and infrastructure thereby managing our destiny and future growth.

Raymond G. Smith, P. Eng. President and CEO August 5, 2014

Note:

A conference call to discuss Bellatrix's 2014 second quarter financial and operating results and address investor questions will be held on August 6, 2014 at 9:00 am MDT/11:00 am EDT. To participate, please call toll-free 1-888-390-0546 or 416-764-8688. The conference call will also be recorded and available until August 13, 2014 by calling 1-888-390-0541 or 416-764-8677 and entering passcode 631737 followed by the pound sign.