0001144204-12-055860.txt : 20121012 0001144204-12-055860.hdr.sgml : 20121012 20121012141917 ACCESSION NUMBER: 0001144204-12-055860 CONFORMED SUBMISSION TYPE: 10-Q/A PUBLIC DOCUMENT COUNT: 11 CONFORMED PERIOD OF REPORT: 20120731 FILED AS OF DATE: 20121012 DATE AS OF CHANGE: 20121012 FILER: COMPANY DATA: COMPANY CONFORMED NAME: BRINX RESOURCES LTD CENTRAL INDEX KEY: 0001212641 STANDARD INDUSTRIAL CLASSIFICATION: GOLD & SILVER ORES [1040] IRS NUMBER: 980388682 FISCAL YEAR END: 1031 FILING VALUES: FORM TYPE: 10-Q/A SEC ACT: 1934 Act SEC FILE NUMBER: 333-102441 FILM NUMBER: 121141701 BUSINESS ADDRESS: STREET 1: C/O DILL DILL CARR STONBRAKER & HUTCHING STREET 2: 455 SHERMAN STREET, #300 CITY: DENVER STATE: CO ZIP: 80203 BUSINESS PHONE: (877) 226-8002 MAIL ADDRESS: STREET 1: C/O DILL DILL CARR STONBRAKER & HUTCHING STREET 2: 455 SHERMAN STREET, #300 CITY: DENVER STATE: CO ZIP: 80203 10-Q/A 1 v325605_10qa.htm 10-Q/A

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10-Q/A

(Amendment No. 1)

(Mark One)

xQUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the quarterly period ended July 31, 2012

 

¨TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the transition period from ________________ to _______________

 

333-102441

(Commission file number)

 

BRINX RESOURCES LTD.

(Exact name of registrant as specified in its charter)

 

Nevada

(State or other jurisdiction

of incorporation or organization)

 

98-0388682

(IRS Employer

Identification No.)

 

c/o Dill Dill Carr Stonbraker & Hutchings, P.C., 455 Sherman Street, Suite 300, Denver, Colorado 80203

(Address of principal executive offices)                                   (Zip Code)

 

(505) 250-9992

(Registrant’s telephone number, including area code)

 

820 Piedra Vista Road NE, Albuquerque, NM 87123

(Former name, former address and former fiscal year, if changed since last report)

 

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.

x Yes   ¨ No

 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

x Yes   ¨ No

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 

Large accelerated filer ¨ Accelerated filer ¨
Non-accelerated filer ¨ Smaller reporting company x

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). 

¨Yes   x No

 

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date: 24,629,832 shares of Common Stock, $0.001 par value, as of September 14, 2012

 

 
 

 

EXPLANATORY NOTE

  

The purpose of this Amendment No. 1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended July 31, 2012, filed with the Securities and Exchange Commission on September 14, 2012 (the “Form 10-Q”), is solely to furnish Exhibit 101 to the Form 10-Q. Exhibit 101 provides the financial statements and related notes from the Form 10-Q formatted in XBRL (Extensible Business Reporting Language).

 

No other changes have been made to the Form 10-Q. This Amendment No. 1 to the Form 10-Q continues to speak as of the original filing date of the Form 10-Q, does not reflect events that may have occurred subsequent to the original filing date, and does not modify or update in any way disclosures made in the original Form 10-Q.

 

Pursuant to Rule 406T of Regulation S-T, the Interactive Data Files in Exhibit 101 hereto are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections.

 

 
 

 

Part II.      OTHER INFORMATION

 

Item 6.                  Exhibits.

 

Regulation

S-K Number

  Exhibit
     
3.1   Articles of Incorporation (1)
     
3.2   Certificate of Change Pursuant to NRS 78.209 (2)
     
3.3   Amendment to the Articles of Incorporation (3)
     
3.4   Amended and Restated Bylaws (4)
     
3.5   Amendment to Amended and Restated Bylaws (5)
     
4.1   Certificate of Designation of Rights, Preferences, and Privileges for Series A Preferred Stock (4)
     
10.1   Management Consulting Agreement dated February 10, 2012 (5)
     
31.1   Rule 15d-14(a) Certification of Principal Executive Officer
     
31.2   Rule 15d-14(a) Certification of Principal Financial Officer
     
32.1   Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 of Principal Executive Officer
     
32.2   Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 of Principal Financial Officer
     
101*   Financial statements from the Quarterly Report on Form 10-Q of Brinx Resources Ltd. for the quarter ended July 31, 2012, formatted in XBRL: (i) the Balance Sheets; (ii) the Statements of Operations; (iii) the Statements of Cash Flows; and (iv) the Notes to Financial Statements.

 

 

(1)Incorporated by reference to the exhibits to the registrant’s registration statement on Form SB-1, file number 333-102441.
(2)Incorporated by reference to the exhibits to the registrant’s current report on Form 8-K dated September 26, 2004, filed September 27, 2004.
(3)Incorporated by reference to the exhibits to the registrant’s current report on Form 8-K dated December 3, 2008, filed January 13, 2009.
(4)Incorporated by reference to the exhibits to the registrant’s current report on Form 8-K dated December 11, 2009, filed December 15, 2009.
(5)Incorporated by reference to the exhibits to the registrant’s annual report on Form 10-K dated October 31, 2011, filed February 14, 2012.

 

*In accordance with Rule 406T of Regulation S-T, the information in these exhibits shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to liability under that section, and shall not be incorporated by reference into any registration statement or other document filed under the Securities Act of 1933, as amended, except as expressly set forth by specific reference in such filing.

 

 
 

 

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.

  

  BRINX RESOURCES LTD.
  (Registrant)
     
October 12, 2012 By:  /s/ Kenneth Cabianca
    Kenneth Cabianca
    President
    (principal executive officer)
     
October 12, 2012 By:  /s/ Kulwant Sandher
    Kulwant Sandher
    Chief Financial Officer
    (principal financial and accounting officer)

 

 

EX-31.1 2 v325605_ex31-1.htm EXHIBIT 31.1

Exhibit 31.1

 

RULE 15-14(a) CERTIFICATION

 

I, Kenneth Cabianca, certify that:

 

1.I have reviewed this quarterly report on Form 10-Q of Brinx Resources Ltd.;

 

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

 

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a)designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b)designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c)evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d)disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

 

a)all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

 

b)any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

 

Date: October 12, 2012

 

  /s/ Kenneth Cabianca
  Kenneth Cabianca, President
  (principal executive officer)

  

 

 

EX-31.2 3 v325605_ex31-2.htm EXHIBIT 31.2

 

Exhibit 31.2

 

RULE 15-14(a) CERTIFICATION

 

I, Kulwant Sandher, certify that:

 

1.I have reviewed this quarterly report on Form 10-Q of Brinx Resources Ltd.;

 

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

 

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a)designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b)designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c)evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d)disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

 

a)all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

 

b)any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

 

Date: October 12, 2012

 

  /s/ Kulwant Sandher
  Kulwant Sandher, Chief Financial Officer
  (principal financial officer)

 

 

 

EX-32.1 4 v325605_ex32-1.htm EXHIBIT 32.1

Exhibit 32.1

 

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

 

In connection with the Quarterly Report of Brinx Resources Ltd. (the “Company”) on Form 10-Q for the quarter ended July 31, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Ken Cabianca, Principal Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

 

(1)The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

 

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

  

/s/ Kenneth Cabianca  
Kenneth Cabianca  
President  
Principal Executive Officer  

 

Date: October 12, 2012

 

 

 

EX-32.2 5 v325605_ex32-2.htm EXHIBIT 32.2

Exhibit 32.2

 

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

 

In connection with the Quarterly Report of Brinx Resources Ltd. (the “Company”) on Form 10-Q for the quarter ended July 31, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Kulwant Sandher, Principal Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

 

(1)The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

 

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

 

/s/ Kulwant Sandher  
Kulwant Sandher  
Chief Financial Officer  
Principal Financial Officer  

 

Date: October 12, 2012

 

 

 

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OIL AND GAS INTERESTS (Details 2) link:presentationLink link:definitionLink link:calculationLink 028 - Disclosure - OIL AND GAS INTERESTS (Details Textual) link:presentationLink link:definitionLink link:calculationLink 029 - Disclosure - ASSET RETIREMENT OBLIGATIONS (Details) link:presentationLink link:definitionLink link:calculationLink 030 - Disclosure - ASSET RETIREMENT OBLIGATIONS (Details Textual) link:presentationLink link:definitionLink link:calculationLink 031 - Disclosure - COMMON STOCK (Details) link:presentationLink link:definitionLink link:calculationLink 032 - Disclosure - COMMON STOCK (Details Textual) link:presentationLink link:definitionLink link:calculationLink 033 - Disclosure - RELATED PARTY TRANSACTIONS (Details Textual) link:presentationLink link:definitionLink link:calculationLink 034 - Disclosure - MAJOR CUSTOMERS (Details Textual) link:presentationLink link:definitionLink link:calculationLink 035 - Disclosure - CONTINGENCIES (Details Textual) link:presentationLink link:definitionLink link:calculationLink EX-101.CAL 8 bnxr-20120731_cal.xml XBRL TAXONOMY EXTENSION CALCULATION LINKBASE EX-101.DEF 9 bnxr-20120731_def.xml XBRL TAXONOMY EXTENSION DEFINITION LINKBASE EX-101.LAB 10 bnxr-20120731_lab.xml XBRL TAXONOMY EXTENSION LABEL LINKBASE EX-101.PRE 11 bnxr-20120731_pre.xml XBRL TAXONOMY EXTENSION PRESENTATION LINKBASE ZIP 12 0001144204-12-055860-xbrl.zip IDEA: XBRL DOCUMENT begin 644 0001144204-12-055860-xbrl.zip M4$L#!!0````(`&]R3$&2I"N"M8(``,T"!P`1`!P`8FYX%`R7WA0=7@+``$$)0X```0Y`0``[%W[<^*XEO[]5LW_X)NM MG=JM:H+?0/IQB[RZF>F$W)">GMY'I11;@*:-S&:JI[$EG4_G?'H=']/A%/^A,.F9NG$'+P_^?)P76N> M_./#3W][]_=:C?N(34R1@W7.M>$]=_57[??S^\]!=DXYY4^%4Y'[;[Y5%^2Z MR`LBQTMG$G\FR]S=S?]R3Q/N$CGH@2+MN\W5:D'!Y\B&0J$$KSCQ5)B_\YY< M6IH[PJ;#W0"P/H&T+\09,OF_$?R"*??;%`'@/U5.FZRH:TIT-'G#=37'>H(D M@OB&\Q$)9[QRI@A<^V8JYO6)&N2,_]/AHXS/JO77UY>3I\H M@4?8MERJ8?M4LT9>[?B&))Q,\QC$_![)P\H[M>@`4O)2G;U^@FH&R=E;G&7\<&,I%CTE9IL8+M;EM-)=28/6J?-.W,1EU3.+SP(N8 MY/A5&\:G9V]B,A#S&=M.?!;_74PF$Q'-CL_CO6)9A&@6FVCQ&>!%7')G3%>D MASLZ=>"MGWZ:NLG]:"7 MNK!,![\Z7`]K#NML(KV'-GU)@.+3A(]M^[';?^35&O1!4":O/':)T3;UC\B^ M\[%-KEW#N+!LYP8[0TMOOQ+[\0&`X!XR=9;H#Y#5_6Z@H35"-W@$'=G)7";T MB,29S'\3G3V!_I%RGL:B"@I,>-'Y]>0##SV"*(BJ++RK+V:>%VCC`>MV@PH``,320^KQ MNC&6@]FB)O`U7IWGGK\-GLSSUR,V7F_TZV]7CY)0F7PO3`XFI0Y,.;!O=+GF M=5RA$D/O9QK6YQD\EDA"6&#P-D^6J!5+]H@E2E:6J$6QQ!]`)+[VBVLRGC3R MX,GC+1KA;O\*]&=1;X;U%1N&?4F)86"_A*_P5X)&WO.*7#0]DD353G$L*[C( M`8\Q!\:ZFL1O--@%_R82%:9XOR"/J*U41/7T`@M)2#*@:!38HFOB@R)=4C4+ MG^NTV,Q;$/.?ZT@WWBA6&7T_C+XPCC6SCF,M?X56V#B6,U,>+Q!S0]U9Q'0Z M((C"([[%L6AMQ6SL@QB*]0Z%;]"N>5T8F%RYM6)E4S.=A]^5-PLA)OQ MNJVHZ1GAX<6JJ+E:*Q4ULT_]^%I[3'/L,].L3`<&GAP#,?/K,],O2N>Z+6%Z M"M04LTY/95C#%C4]%97:#9JD9_.O8#/[`FH,:>PQUIP+9!"8&YGDL!QRB?4L MHQ-3:J)2U/@JM`+_6C[CZX'8?8L!,S>SJS6A59S;PC4JH^^!T9?'!27KN-`H MQ&V1(T^RS'%ZV!@ALW*(%33-65!OQ>CB&7V.!B_PK.)S$7R.*+=B<_%L;E.] M8G(13)XI]JA8/'?RY3D?K39'=N'EV^'F2*,0-]^%:SO6*/=>]K#95O+<,O,F M;Y']F"#6VNY@^WZ,!>H<`U="%2VCEV@6&0W;1PT5&_V:>[]238VS]T,_]N1X@:"YAV>41="C#-`HC9\["]$HB)[! 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RELATED PARTY TRANSACTIONS (Details Textual) (USD $)
9 Months Ended
Jul. 31, 2012
Jul. 31, 2011
Leroy Halterman [Member]
   
Management Fee, Amount Paid $ 30,000 $ 54,000
Company Reimbursement For Office Space, Related Party 0 3,600
Affiliated Entity [Member]
   
Administrative Fees, Amount Paid 54,000 53,000
Director [Member]
   
Management Fee, Amount Paid 81,500 75,500
Chief Financial Officer [Member]
   
Professional Fees $ 58,673 $ 57,628
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OIL AND GAS INTERESTS (Details) (USD $)
Jul. 31, 2012
Oct. 31, 2011
Asset retirement cost $ 4,534 $ 4,534
Less: Accumulated depletion and impairment (1,267,869) (1,127,444)
Oil and Gas Property, Full Cost Method, Net 2,175,592 2,074,900
2008-3 Drilling Program, Oklahoma [Member]
   
Oil and Gas Property, Full Cost Method, Gross 309,152 302,361
2009-2 Drilling Program, Oklahoma [Member]
   
Oil and Gas Property, Full Cost Method, Gross 114,420 114,420
2009-3 Drilling Program, Oklahoma [Member]
   
Oil and Gas Property, Full Cost Method, Gross 335,612 300,080
2009-4 Drilling Program, Oklahoma [Member]
   
Oil and Gas Property, Full Cost Method, Gross 190,182 190,146
2010-1 Drilling Program, Oklahoma [Member]
   
Oil and Gas Property, Full Cost Method, Gross 253,967 253,855
Washita Bend 3D, Oklahoma [Member]
   
Oil and Gas Property, Full Cost Method, Gross 526,926 482,882
Double T Ranch #1 Swdw, Oklahoma [Member]
   
Oil and Gas Property, Full Cost Method, Gross 29,312 0
Kings City Prospect, California [Member]
   
Oil and Gas Property, Full Cost Method, Gross 388,837 263,561
Three Sands Project, Oklahoma [Member]
   
Oil and Gas Property, Full Cost Method, Gross 1,451,557 1,451,543
South Wayne Prospect, Oklahoma [Member]
   
Oil and Gas Property, Full Cost Method, Gross 61,085 61,085
PP F-12-2, PP F-12-3, PP F-12-4 and PP F-52, Mississippi [Member]
   
Oil and Gas Property, Full Cost Method, Gross $ (222,123) $ (222,123)
XML 16 R9.htm IDEA: XBRL DOCUMENT v2.4.0.6
OIL AND GAS INTERESTS
9 Months Ended
Jul. 31, 2012
Oil and Gas Interests [Abstract]  
Oil and Gas Interests [Text Block]
4.  
OIL AND GAS INTERESTS
 
The Company holds the following oil and natural gas interests:
 
      July 31, 2012       October 31, 2011  
2008-3 Drilling Program, Oklahoma
  $ 309,152     $ 302,361  
2009-2 Drilling Program, Oklahoma
    114,420       114,420  
2009-3 Drilling Program, Oklahoma
    335,612       300,080  
2009-4 Drilling Program, Oklahoma
    190,182       190,146  
2010-1 Drilling Program, Oklahoma
    253,967       253,855  
Washita Bend 3D, Oklahoma
    526,926       482,882  
Double T Ranch #1 SWDW, Oklahoma
    29,312       --  
Kings City Prospect, California
    388,837       263,561  
Three Sands Project, Oklahoma
    1,451,557       1,451,543  
South Wayne Prospect, Oklahoma
    61,085       61,085  
PP F-12-2, PP F-12-3, PP F-12-4 and PP F-52, Mississippi
    (222,123 )     (222,123 )
Asset retirement cost
    4,534       4,534  
Less:  Accumulated depletion and impairment
    (1,267,869 )     (1,127,444 )
    $ 2,175,592     $ 2,074,900  
 
2008-3 Drilling Program, Oklahoma
 
On January 12, 2009, the Company acquired a 5% working interest in the Ranken Energy Corporation’s 2008-3 Drilling Program for a total buy-in cost of $28,581.  The Company agreed to participate in the drilling operations to casing point in the initial test well of each prospect.  The Before Casing Point Interest (“BCP”) shall be 6.25% and the After Casing Point Interest (“ACP”) shall be 5.00%.  During January to July 2009, the Company expended a $213,925 in addition to $18,850 that was spent in previous periods.  The well, Wigley#1-11, was abandoned during March 2009.  The cost and its buy-in cost total of $33,423 were moved to the proved properties.  Selman#1-21 and Bagwell#1-20 started producing during May 2009, the cost and its buy-in cost total of $67,632 for Selman#1-21 and $65,209 for Bagwell#1-20 were moved to the proved properties. Ard#1-36 started producing during June 2009 and the cost and its buy-in cost total of $42,647 was moved to the proved properties.  Selman#2-21 started producing during July 2009 and was abandoned on April 20, 2010; the cost and its buy-in cost total of $55,940 were moved to the proved properties pool.  The total cost of the 2008-3 Drilling Program as at July 31, 2012 was $309,152.  The interests are located in Garvin County, Oklahoma.
 
2009-2 Drilling Program, Oklahoma
 
On June 19, 2009, the Company acquired a 5% working interest in the Ranken Energy Corporation’s 2009-2 Drilling Program for a total buy-in cost of $26,562.  The Company agreed to participate in the drilling operations to casing point in the initial test well of each prospect.  The BCP Interest shall be 6.25% and the ACP Interest shall be 5.00%.  The well,  James#1-18, was abandoned on September 21, 2009.  The cost and its buy-in cost total of $41,934 were moved to the proved properties.  Little Chief#1-3 was abandoned on November 17, 2009; the cost and its buy-in cost total of $35,528 were moved to the proved properties.  J.C. Carlton#1-31 was abandoned on April 30, 2010; the cost and its buy-in cost total of $36,957 were moved to the proved properties.  As at July 31, 2012, the total cost of the 2009-2 Drilling Program was $114,420.  The interests are located in Garvin County, Oklahoma.
 
2009-3 Drilling Program, Oklahoma
 
On August 12, 2009, the Company acquired a 5.00% working interest in Ranken Energy Corporation’s 2009-3 Drilling Program for a total buy-in cost of $37,775.  The Company agreed to participate in the drilling operations to casing point in the initial test well of each prospect.  The BCP Interest shall be 6.25% and the ACP Interest shall be 5.00%.  Jackson#1-18 started producing during January 2010; an amount of $66,106 which included the buy-in cost was moved to the proved property pool.  Miss Gracie#1-18 started producing during March 2010; an amount of $69,056 which included its buy-in cost was moved to the proved property pool.  Brewer#1-20 was abandoned on June 2, 2010; the cost and its buy-in cost total of $65,984 were moved to the proved properties.  Waunice#1-36 started producing during June 2010 and was abandoned on September 23, 2010; an amount of $42,838 which included its buy-in cost was moved to the proved property pool.
 
As at July 31, 2012, the total cost of the 2009-3 Drilling Program was $335,612.  The interests are located in Garvin County, Oklahoma.
 
2009-4 Drilling Program, Oklahoma
 
On December 19, 2009, the Company acquired a 5.00% working interest in Ranken Energy Corporation’s 2009-4 Drilling Program for a total buy-in cost of $13,482.  The Company agreed to participate in the drilling operations to casing point in the initial test well of each prospect.  The BCP Interest shall be 6.25% and the ACP Interest shall be 5.00%.  Dennis#1-8 started producing during May 2010; an amount of $89,726 which included the buy-in cost was moved to the proved property pool, it was abandoned on September 27, 2010.  Dennis#2-8 was abandoned on November 17, 2010; an amount of $34,341 which included the buy-in cost was moved to the proved property pool.  Murray Trust#3-19 was abandoned on December 13, 2010; an amount of $13,168 which included the buy-in cost was moved to the proved property pool.  Murray Trust#2-19 started producing during November 2010; an amount of $52,910 which included the buy-in cost was moved to the proved property pool.   As at July 31, 2012, the total cost of the 2009-4 Drilling Program was $190,182.  The interests are located in Garvin County, Oklahoma.
 
2010-1 Drilling Program, Oklahoma
 
On April 23, 2010, the Company acquired a 5.00% working interest in Ranken Energy Corporation’s 2010-1 Drilling Program for a total buy-in cost of $39,163.  The Company agreed to participate in the drilling operations to casing point in the initial test well of each prospect.  The BCP Interest shall be 6.25% and the ACP Interest shall be 5.00%.  Julie#1-14 was abandoned on October 2, 2010; the cost and its buy-in cost total of $48,938 were moved to the proved properties.  Jack#1-13 started producing during November 2010; an amount of $74,144 which included the buy-in cost was moved to the proved property pool.  Miss Jenny started producing during December 2010; an amount of $68,620 which included the buy-in cost was moved to the proved property pool.  As at July 31, 2012, the total cost of the 2010-1 Drilling Program was $253,967.  The interests are located in Garvin County, Oklahoma.
 
Washita Bend 3D Exploration Project, Oklahoma
 
On March 1, 2010, the Company acquired a 5.00% working interest in Ranken Energy Corporation’s Washita Bend 3D Exploration Project for a buy-in cost of $46,250.  The BCP Interest shall be 5.625% and the ACP Interest shall be 5.00% on the first eight wells and then 5% before and after casing point on succeeding wells.  As at July 31, 2012, the total costs, including seismic costs was $526,926.
 
Double T Ranch#1 SWDW, Oklahoma
 
On July 17, 2012, the Company acquired a 3.00% working interest in the drilling, completion and operations of the Double T Ranch#1 SWDW located in Garvin County from Ranken Energy Corporation. As at July 31, 2012, the cost of the Double T Ranch#1 SWDW was $29,312.
 
Kings City Prospect, California
 
A Farmout agreement was made effective on May 25, 2009 between the Company and Sunset Exploration, Inc., to explore for oil and natural gas on 10,000 acres located in west central California.  The Company paid $100,000 (50% pro rata share of $200,000)  to earn a 20% working interest in project by funding a maximum of 50% of a $200,000 in a geophysical survey composed of gravity and seismic surveys and carry Sunset exploration for 33.33% of dry hole cost of the first well.  Completions and drilling of this first well and completion of subsequent wells on the 10,000 acres will be proportionate to each parties working interest.  The total cost of the King City prospect as at July 31, 2012 was $388,837.
 
Three Sands Project, Oklahoma
 
On October 6, 2005, the Company acquired a 40% working interest in Vector Exploration Inc’s Three Sands Project for a total buy-in cost of $88,000 plus dry hole costs.  For the year ended October 31, 2006, the Company expended $530,081 in exploration costs.  In June 2007, the Company acquired a 40% working interest in William #4-10 well for a total cost of $285,196 and paid a further $17,000 in costs relating to the well.  On March 19, 2008, the Company participated in the KC 80#1-11 well and paid $75,000 for the prepaid drilling costs.  During March and April 2008, the Company expended an additional amount of $48,763 for the intangible and tangible costs, and $161,650 during May to July 2008 for the KC 80#1-11 well.  The total cost of the Three Sands Project as at July 31, 2012 was $1,451,557.  The interests are located in Oklahoma.
 
South Wayne Prospect, Oklahoma
 
On March 14, 2010, the Company acquired a 5.00% working interest in McPherson#1-1 well for a payment for leasehold, prospect and geophysical fees of $5,000, and dry hole costs of $32,370.  The Company agreed to participate in the drilling operations to casing point in the initial test well of each prospect.  The BCP Interest shall be 6.25% and the ACP Interest shall be 5.00%.  The interests are located in McClain County, Oklahoma.  The total cost of the South Wayne prospect as at July 31, 2012 was $61,085.
 
Palmetto Point Project, Mississippi
 
On August 12, 2011, the Company signed an asset purchase agreement to sell its oil and gas assets in Mississippi for a total of $400,000 and received 800,000 shares of restricted common stock in Lexaria Corp.  These properties consist principally of the Belmont Lake Oil Field and all undeveloped acreage in the Palmetto Point Project.  $200,000 was received on August 12, 2011.  $10,000 per month was paid in November and December 2011 and the balance of $200,000 was paid on January 13, 2012. The disposed reserves represented more than 25% of the total reserves which the Company considered to represent a significant alteration between capitalized costs and proved reserves and hence a loss on the sale was recognized in the Statement of Operations in the amount of $109,299 for the period ended October 31, 2011.
 
Impairment
 
Under the full cost method, the Company is subject to a ceiling test.  This ceiling test determines whether there is an impairment to the proved properties.  The impairment amount represents the excess of capitalized costs over the present value, discounted at 10%, of the estimated future net cash flows from the proven oil and gas reserves plus the cost, or estimated fair market value.  There was no impairment cost for the nine-month periods ended July 31, 2012 and 2011, respectively.
 
Depletion
 
Under the full cost method, depletion is computed on the units of production method based on proved reserves, or upon reasonable estimates where proved reserves have not yet been established due to the recent commencement of production.  Depletion expense recognized was $140,425 and $282,241 for the nine-month periods ended July 31, 2012 and 2011, respectively.
 
Capitalized Costs
 
   
July 31, 2012
   
October 31, 2011
 
Proved properties
  $ 2,438,387     $ 2,395,902  
Unproved properties
    1,005,075       806,443  
Total Proved and Unproved properties
    3,443,462       3,202,345  
Accumulated depletion expense
    (1,130,138 )     (989,713 )
Impairment
    (137,732 )     (137,732 )
Net capitalized cost
  $ 2,175,592     $ 2,074,900  
 
Results of Operations
 
Results of operations for oil and gas producing activities during the nine-month periods ended are as follows:
 
   
July 31, 2012
   
July 31, 2011
  Revenues
  $ 422,570     $ 1,062,679  
  Production costs
    (87,023 )     (162,262 )
  Depletion and accretion
    (142,795 )     (285,481 )
  Results of operations (excluding corporate overhead)
  $ 192,752     $ 614,936
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ASSET RETIREMENT OBLIGATIONS (Details) (USD $)
9 Months Ended 12 Months Ended
Jul. 31, 2012
Oct. 31, 2011
Balance, beginning of period $ 26,335 $ 27,494
Liabilities assumed 0 774
Revisions 0 (5,232)
Accretion expense 2,370 3,299
Balance, end of period $ 28,705 $ 26,335

XML 19 R28.htm IDEA: XBRL DOCUMENT v2.4.0.6
OIL AND GAS INTERESTS (Details Textual) (USD $)
9 Months Ended 3 Months Ended 7 Months Ended 3 Months Ended 3 Months Ended 4 Months Ended 3 Months Ended 3 Months Ended 3 Months Ended 3 Months Ended 3 Months Ended 3 Months Ended 3 Months Ended 3 Months Ended 12 Months Ended 12 Months Ended 9 Months Ended 12 Months Ended 12 Months Ended 3 Months Ended 2 Months Ended 3 Months Ended 12 Months Ended 9 Months Ended
Jul. 31, 2012
Jul. 31, 2011
Jan. 31, 2009
Drilling Program Oklahoma One [Member]
Jul. 31, 2009
Drilling Program Oklahoma One [Member]
Jan. 31, 2009
Drilling Program Oklahoma One [Member]
Jul. 31, 2012
Drilling Program Oklahoma One [Member]
Oct. 31, 2011
Drilling Program Oklahoma One [Member]
Jan. 12, 2009
Drilling Program Oklahoma One [Member]
Apr. 30, 2009
Drilling Program Oklahoma One [Member]
Wigley [Member]
Jul. 31, 2009
Drilling Program Oklahoma One [Member]
Selman One [Member]
Apr. 30, 2010
Drilling Program Oklahoma One [Member]
Selman Two [Member]
Jul. 31, 2009
Drilling Program Oklahoma One [Member]
Bagwell [Member]
Jul. 31, 2009
Drilling Program Oklahoma One [Member]
Ard [Member]
Jan. 31, 2009
Drilling Program Oklahoma One [Member]
After Casing Point [Member]
Jan. 31, 2009
Drilling Program Oklahoma One [Member]
Before Casing Point [Member]
Jul. 31, 2009
Drilling Program Oklahoma Two [Member]
Jul. 31, 2012
Drilling Program Oklahoma Two [Member]
Oct. 31, 2011
Drilling Program Oklahoma Two [Member]
Jun. 19, 2009
Drilling Program Oklahoma Two [Member]
Nov. 30, 2009
Drilling Program Oklahoma Two [Member]
James [Member]
Nov. 30, 2009
Drilling Program Oklahoma Two [Member]
Little Chief [Member]
Apr. 30, 2010
Drilling Program Oklahoma Two [Member]
J C Carlton [Member]
Jan. 31, 2009
Drilling Program Oklahoma Two [Member]
After Casing Point [Member]
Jul. 31, 2009
Drilling Program Oklahoma Two [Member]
Before Casing Point [Member]
Oct. 31, 2009
Drilling Program Oklahoma Three [Member]
Jul. 31, 2012
Drilling Program Oklahoma Three [Member]
Oct. 31, 2011
Drilling Program Oklahoma Three [Member]
Aug. 12, 2009
Drilling Program Oklahoma Three [Member]
Jan. 31, 2010
Drilling Program Oklahoma Three [Member]
Jackson [Member]
Apr. 30, 2010
Drilling Program Oklahoma Three [Member]
Miss Graci [Member]
Jul. 31, 2010
Drilling Program Oklahoma Three [Member]
Brewer [Member]
Oct. 31, 2010
Drilling Program Oklahoma Three [Member]
Waunice [Member]
Oct. 31, 2009
Drilling Program Oklahoma Three [Member]
After Casing Point [Member]
Oct. 31, 2009
Drilling Program Oklahoma Three [Member]
Before Casing Point [Member]
Jan. 31, 2010
Drilling Program Oklahoma Four [Member]
Jul. 31, 2012
Drilling Program Oklahoma Four [Member]
Oct. 31, 2011
Drilling Program Oklahoma Four [Member]
Dec. 19, 2009
Drilling Program Oklahoma Four [Member]
Jul. 31, 2010
Drilling Program Oklahoma Four [Member]
Dennis One [Member]
Jan. 31, 2011
Drilling Program Oklahoma Four [Member]
Dennis Two [Member]
Jan. 31, 2011
Drilling Program Oklahoma Four [Member]
Murray Trust One [Member]
Jan. 31, 2011
Drilling Program Oklahoma Four [Member]
Murray Trust Two [Member]
Jan. 31, 2010
Drilling Program Oklahoma Four [Member]
After Casing Point [Member]
Jan. 31, 2010
Drilling Program Oklahoma Four [Member]
Before Casing Point [Member]
Apr. 30, 2010
Drilling Program Oklahoma Five [Member]
Jul. 31, 2012
Drilling Program Oklahoma Five [Member]
Oct. 31, 2011
Drilling Program Oklahoma Five [Member]
Apr. 23, 2010
Drilling Program Oklahoma Five [Member]
Oct. 31, 2010
Drilling Program Oklahoma Five [Member]
Julie [Member]
Jan. 31, 2011
Drilling Program Oklahoma Five [Member]
Jack [Member]
Jan. 31, 2011
Drilling Program Oklahoma Five [Member]
Miss Jenny [Member]
Apr. 30, 2010
Drilling Program Oklahoma Five [Member]
After Casing Point [Member]
Apr. 30, 2010
Drilling Program Oklahoma Five [Member]
Before Casing Point [Member]
Apr. 30, 2010
Washita Bend Oklahoma [Member]
Jul. 31, 2012
Washita Bend Oklahoma [Member]
Oct. 31, 2011
Washita Bend Oklahoma [Member]
Mar. 01, 2010
Washita Bend Oklahoma [Member]
Apr. 30, 2010
Washita Bend Oklahoma [Member]
After Casing Point [Member]
Apr. 30, 2010
Washita Bend Oklahoma [Member]
Before Casing Point [Member]
Oct. 31, 2011
Palmetto Point Project Mississippi [Member]
Jul. 31, 2012
Palmetto Point Project Mississippi [Member]
Oct. 31, 2011
Palmetto Point Project Mississippi [Member]
Monthly Payment One [Member]
Jul. 31, 2012
Palmetto Point Project Mississippi [Member]
Monthly Payment Two [Member]
Jul. 31, 2012
Palmetto Point Project Mississippi [Member]
Monthly Payment Three [Member]
Jul. 31, 2012
Palmetto Point Project Mississippi [Member]
Monthly Payment Four [Member]
Oct. 31, 2009
Kings City Prospect California [Member]
Jul. 31, 2012
Kings City Prospect California [Member]
Oct. 31, 2011
Kings City Prospect California [Member]
May 25, 2009
Kings City Prospect California [Member]
Oct. 31, 2006
Three Sands Project Oklahoma [Member]
Oct. 31, 2005
Three Sands Project Oklahoma [Member]
Jul. 31, 2012
Three Sands Project Oklahoma [Member]
Oct. 31, 2011
Three Sands Project Oklahoma [Member]
Oct. 06, 2005
Three Sands Project Oklahoma [Member]
Jun. 30, 2007
Three Sands Project Oklahoma [Member]
William Wells [Member]
Apr. 30, 2008
Three Sands Project Oklahoma [Member]
Kc Wells [Member]
Jul. 31, 2008
Three Sands Project Oklahoma [Member]
Kc Wells [Member]
Oct. 31, 2008
Three Sands Project Oklahoma [Member]
Kc Wells [Member]
Oct. 31, 2010
South Wayne Prospect Oklahoma [Member]
Jul. 31, 2012
South Wayne Prospect Oklahoma [Member]
Oct. 31, 2011
South Wayne Prospect Oklahoma [Member]
Mar. 14, 2010
South Wayne Prospect Oklahoma [Member]
Oct. 31, 2010
South Wayne Prospect Oklahoma [Member]
After Casing Point [Member]
Oct. 31, 2010
South Wayne Prospect Oklahoma [Member]
Before Casing Point [Member]
Jul. 31, 2012
Double T Ranch #1 Swdw, Oklahoma [Member]
Oct. 31, 2011
Double T Ranch #1 Swdw, Oklahoma [Member]
Business Acquisition, Percentage of Voting Interests Acquired               5.00%           5.00% 6.25%       5.00%       5.00% 6.25%       5.00%         5.00% 6.25%       5.00%         5.00% 6.25%       5.00%       5.00% 6.25%       5.00% 5.00% 5.625%                   20.00%         40.00%               5.00% 5.00% 6.25% 3.00%  
Costs Incurred, Acquisition of Oil and Gas Properties     $ 28,581                         $ 26,562                 $ 37,775                   $ 13,482                   $ 39,163                 $ 46,250                                 $ 88,000       $ 285,196                   $ 29,312  
Costs Incurred for drilling operations       213,925 18,850                                                                                                                                                                  
Cost and Buy In Cost Moved To Proved Properties                 33,423 67,632 55,940 65,209 42,647             41,934 35,528 36,957             66,106 69,056 65,984 42,838             89,726 34,341 13,168 52,910             48,938 74,144 68,620                                                                      
Oil and Gas Property, Full Cost Method, Gross           309,152 302,361                   114,420 114,420               335,612 300,080                 190,182 190,146                 253,967 253,855               526,926 482,882       (222,123) (222,123)           388,837 263,561       1,451,557 1,451,543             61,085 61,085       29,312 0
Description Of Land Allocated For Exploration                                                                                                                                   10,000 acres located in west central California                                        
Percentage Of Costs Incurred To Explore and Develop Oil and Gas Properties                                                                                                                                   50.00%                                        
Costs Incurred To Explore and Develop Oil and Gas Properties                                                                                                                                   200,000                                        
Dry Hole Cost Of Exploration Projects                                                                                                                                                             32,370              
Dry Hole Cost Of Exploration Projects, Percentage                                                                                                                                   33.33%                                        
Exploration Costs, Period Cost                                                                                                                                           530,081         17,000                      
Equity Method Investment, Ownership Percentage                                                                                                                                                     40.00%                      
Capitalized Exploratory Well Costs                                                                                                                                                           75,000                
Payments to Acquire Oil and Gas Property and Equipment                                                                                                                                                       48,763 161,650                  
Payment For Lease Hold Prospect and Geophysical Fees                                                                                                                                                             5,000              
Sale proceeds of natural gas and oil working interests 200,000 0                                                                                                                   400,000   200,000 10,000 10,000 200,000                                          
Equity Instrument Consideration Restricted Shares Received (in shares)                                                                                                                       800,000                                                    
Payments to Explore and Develop Oil and Gas Properties                                                                                                                                   100,000                                        
Business Acquisition Percentage Of Voting Interests Acquired One                                                                                                                   5.00% 5.00%                                                      
Depletion 140,425 282,241                                                                                                                                                                        
Loss on Sale of Proved Property                                                                                                                       $ 109,299                                                    
Disposed Reserves Percentage                                                                                                                       25.00%                                                    
Impairment Of Proved Properties Discounted Rate 10.00%                                                                                                                                                                          
XML 20 R30.htm IDEA: XBRL DOCUMENT v2.4.0.6
ASSET RETIREMENT OBLIGATIONS (Details Textual)
9 Months Ended
Jul. 31, 2012
Liability, Weighted Average Risk Free Discount Rate 12.00%
XML 21 R31.htm IDEA: XBRL DOCUMENT v2.4.0.6
COMMON STOCK (Details) (USD $)
9 Months Ended
Jul. 31, 2012
Options Outstanding Number of Shares, Balance at October 31, 2011 300,000
Options Outstanding Number of Shares, Expired on November 2, 2011 (300,000)
Options Outstanding Number of Shares, Balance at July 31, 2012 0
Options Outstanding Weighted Average Exercise Price, Balance at October 31, 2011 (in dollars per share) $ 0.10
Options Outstanding Weighted Average Exercise Price, Expired on November 2, 2011 (in dollars per share) $ 0.10
Options Outstanding Weighted Average Exercise Price, Balance at July 31, 2012 (in dollars per share) $ 0
XML 22 R8.htm IDEA: XBRL DOCUMENT v2.4.0.6
ACCOUNTS RECEIVABLE
9 Months Ended
Jul. 31, 2012
Receivables [Abstract]  
Loans, Notes, Trade and Other Receivables Disclosure [Text Block]
3.  
ACCOUNTS RECEIVABLE
 
Accounts receivable consists of revenues receivable from the operators of the oil and gas projects for the sale of oil and gas by the operators on the Company’s behalf and are carried at net receivable amounts less an estimate for doubtful accounts.  Management considers all accounts receivable to be fully collectible at July 31, 2012 and October 31, 2011.  Accordingly, no allowance for doubtful accounts or bad debt expense has been recorded.
 
   
July 31, 2012
   
October 31, 2011
 
Accounts receivable
  $ 53,999     $ 329,748  
Less: allowance for doubtful account
    -       -  
    $ 53,999     $ 329,748
XML 23 R32.htm IDEA: XBRL DOCUMENT v2.4.0.6
COMMON STOCK (Details Textual)
Jul. 31, 2012
Oct. 31, 2011
Feb. 10, 2012
Series A Preferred Stock [Member]
Preferred Stock, Shares Issued 500,001 0 500,001
XML 24 R2.htm IDEA: XBRL DOCUMENT v2.4.0.6
BALANCE SHEETS (USD $)
Jul. 31, 2012
Oct. 31, 2011
ASSETS    
Cash and cash equivalents $ 344,551 $ 401,047
Investment - Certificate of deposit 400,000 400,000
Marketable securities 88,000 208,000
Accounts receivable 53,999 329,748
Prepaid expenses and deposit 40,810 37,254
Total current assets 927,360 1,376,049
Undeveloped mineral interests, at cost 1,981 1,981
Oil and gas interests, full cost method of accounting, net of accumulated depletion 2,175,592 2,074,900
Total assets 3,104,933 3,452,930
LIABILITIES AND STOCKHOLDERS' EQUITY    
Accounts payable and accrued liabilities 19,340 10,971
Total current liabilities 19,340 10,971
Asset retirement obligations 28,705 26,335
Total liabilities 48,045 37,306
Stockholders' equity    
Preferred stock - $0.001 par value; authorized - 1,000,000 shares Issued and outstanding - 500,001 shares 500 0
Common stock - $0.001 par value; authorized - 100,000,000 shares Issued and outstanding - 24,629,832 shares 24,630 24,630
Capital in excess of par value 2,868,057 2,868,057
Accumulative other comprehensive loss (184,000) (64,000)
Retained earnings 347,701 586,937
Total stockholders' equity 3,056,888 3,415,624
Total liabilities and stockholders' equity $ 3,104,933 $ 3,452,930
XML 25 R6.htm IDEA: XBRL DOCUMENT v2.4.0.6
ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
9 Months Ended
Jul. 31, 2012
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Organization, Consolidation and Presentation of Financial Statements Disclosure and Significant Accounting Policies [Text Block]
1.  
ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
 
Brinx Resources Ltd. (the “Company”) was incorporated under the laws of the State of Nevada on December 23, 1998, and issued its initial common stock in February 2001.  The Company holds an undeveloped mineral interest located in New Mexico and holds oil and gas interests located in Oklahoma and California.  In 2006, the Company commenced oil and gas production and started earning revenues.
 
The accompanying financial statements of the Company are unaudited.  In the opinion of management, the financial statements include all adjustments, consisting only of normal recurring adjustments, necessary for fair presentation.  The results of operations for the nine-month period ended July 31, 2012 are not necessarily indicative of the operating results for the entire year.  These financial statements should be read in conjunction with the financial statements and notes included in the Company’s Form 10-K for the year ended October 31, 2011.
 
USE OF ESTIMATES
 
The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting period.  Actual results could differ from those estimates.
 
The oil and gas industry is subject, by its nature, to environmental hazards and clean-up costs.  At this time, management knows of no substantial costs from environmental accidents or events for which the Company may be currently liable.  In addition, the Company’s oil and gas business makes it vulnerable to changes in prices of crude oil and natural gas.  Such prices have been volatile in the past and can be expected to be volatile in the future.  By definition, proved reserves are based on current oil and gas prices and estimated reserves.  Price declines reduce the estimated quantity of proved reserves and increase annual depletion expense (which is based on proved reserves).
 
OIL AND GAS INTERESTS
 
The Company utilizes the full cost method of accounting for oil and gas activities.  Under this method, subject to a limitation based on estimated value, all costs associated with property acquisition, exploration and development, including costs of unsuccessful exploration; are capitalized within a cost center.  No gain or loss is recognized upon the sale or abandonment of undeveloped or producing oil and gas interests unless the sale represents a significant portion of oil and gas interests and the gain significantly alters the relationship between capitalized costs and proved oil and gas reserves of the cost center.  Depreciation, depletion and amortization of oil and gas interests is computed on the units of production method based on proved reserves, or upon reasonable estimates where proved reserves have not yet been established due to the recent commencement of production.  Amortizable costs include estimates of future development costs of proved undeveloped reserves.
 
Capitalized costs of oil and gas interests may not exceed an amount equal to the present value, discounted at 10%, of the estimated future net cash flows from proved oil and gas reserves plus the cost, or estimated fair market value, if lower, of unproved interests.  Should capitalized costs exceed this ceiling, an impairment is recognized.  The present value of estimated future net cash flows is computed by applying average prices, in the preceding twelve months, of oil and gas to estimated future production of proved oil and gas reserves as of year end, less estimated future expenditures to be incurred in developing and producing the proved reserves and assuming continuation of existing economic conditions.
 
REVENUE RECOGNITION
 
Revenue from sales of crude oil, natural gas and refined petroleum products are recorded when deliveries have occurred and legal ownership of the commodity transfers to the customer.  Title transfers for crude oil, natural gas and bulk refined products generally occur at pipeline custody points or when a tanker lifting has occurred.  Revenues from the production of oil and natural gas properties in which the Company shares an undivided interest with other producers are recognized based on the actual volumes sold by the Company during the period.  Gas imbalances occur when the Company’s actual sales differ from its entitlement under existing working interests.  The Company records a liability for gas imbalances when it has sold more than its working interest of gas production and the estimated remaining reserves make it doubtful that the partners can recoup their share of production from the field.  At July 31, 2012 and 2011, the Company had no overproduced imbalances.
 
ACCOUNTS RECEIVABLE
 
Accounts receivable are carried at net receivable amounts less an estimate for doubtful accounts.  Management determines the allowance for doubtful accounts by regularly evaluating individual customer receivables and considering a customer’s financial condition, credit history, and current economic conditions.  Trade receivables are written off when deemed uncollectible.  Recoveries of receivables previously written off are recorded when received.
 
IMPAIRMENT OF LONG-LIVED ASSETS
 
The Company has adopted FASB ASC 360 “Accounting  for the  Impairment  or Disposal of Long-Lived  Assets,” which requires that long-lived  assets to be held and used be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.  Oil and gas interests accounted for under the full cost method are subject to a ceiling test, described above, and are excluded from this requirement.
 
ASSET RETIREMENT OBLIGATIONS
 
The Company follows FASB ASC 410-20 "Accounting for Asset Retirement Obligations," that addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs.
 
FASB ASC 410-20 requires recognition of the present value of obligations associated with the retirement of tangible long-lived assets in the period in which it is incurred. The liability is capitalized as part of the related long-lived asset's carrying amount.
 
Over time, accretion of the liability is recognized as an operating expense and the capitalized cost is depreciated over the expected useful life of the related asset.  The Company's asset retirement obligations are related to the plugging, dismantlement, removal, site reclamation and similar activities of its oil and gas exploration activities.
 
INCOME / (LOSS) PER SHARE
 
Basic income/(loss) per share is computed based on the weighted average number of common shares outstanding during each period.  The computation of diluted earnings per share assumes the conversion, exercise or contingent issuance of securities only when such conversion, exercise or issuance would have a dilutive effect on income/(loss) per share.  The dilutive effect of outstanding options was nil as of July 31, 2012 and 2011.  500,000 options were included in the earnings per share calculation for the nine-month period ended July 31, 2011.  The table below presents the computation of basic and diluted earnings per share for the nine-month periods ended July 31, 2012 and 2011:
 
 
    July 31, 2012   July 31, 2011   
Basic earnings per share computation:          
 
Income/(Loss) from continuing operations
  $ (239,236 )   $ 20,159  
Basic shares outstanding
    24,629,832       24,629,832  
Basic earnings per share
  $ (0.010 )   $ 0.001  
Diluted earnings per share computation:                
Income (Loss) from continuing operations
  $ (239,236 )   $ 20,159  
Basic shares outstanding
    24,629,832       24,629,832  
Incremental shares from assumed conversions:
               
    Stock options
    -       119,482  
    Warrants
    -       -  
Diluted shares outstanding
    24,629,832       24,749,314  
Diluted earnings per share   $ (0.010 )   $ 0.001  
 
 
INCOME TAXES
 
Deferred tax assets and liabilities are recognized for temporary differences between the financial reporting and tax bases of the firm’s assets and liabilities. Valuation allowances are established to reduce deferred tax assets to the amount that more likely than not will be realized. The firm’s tax assets and liabilities, if any, are presented as a component of “Other assets” and “Other liabilities and accrued expenses,” respectively, in the balance sheet.  Tax provisions are computed in accordance with FASB ASC 740, “Accounting for Income Taxes.”
 
The Company applies the provisions of FASB ASC 740-10 “Accounting for Uncertainty in Income Taxes — an Interpretation.” A tax position can be recognized in the financial statements only when it is more likely than not that the position will be sustained upon examination by the relevant taxing authority based on the technical merits of the position. A position that meets this standard is measured at the largest amount of benefit that will more likely than not be realized upon settlement. A liability is established for differences between positions taken in a tax return and amounts recognized in the financial statements. FASB ASC 740-10 also provides guidance on de-recognition, classification, interim period accounting and accounting for interest and penalties.
 
CASH EQUIVALENTS
 
For purposes of reporting cash flows, the Company considers as cash equivalents all highly liquid investments with a maturity of three months or less at the time of purchase.  On occasion, the Company may have cash balances in excess of federally insured amounts.
 
MARKETABLE SECURITIES AND INVESTMENTS
 
All equity investments are classified as available for sale and any subsequent changes in the fair value are recorded in comprehensive income. If in the opinion of management there has been a decline in the value of the investment below the carrying value that is considered to be other than temporary, the valuation adjustment is recorded in net earnings in the period of determination.  The fair value of investments is based on the quoted market price on the closing date of the period.
 
FAIR VALUE
 
The Company adopted FASB ASC 820-10-50, “Fair Value Measurements.” This guidance defines fair value, establishes a three-level valuation hierarchy for disclosures of fair value measurement and enhances disclosure requirements for fair value measures.  The three levels are defined as follows:
 
Level 1 inputs to the valuation methodology are quoted prices (unadjusted) for identical assets or liabilities in active markets.
 
Level 2 inputs to the valuation methodology include quoted prices for similar assets and liabilities in active markets, and inputs that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the financial instrument.
 
Level 3 inputs to valuation methodology are unobservable and significant to the fair measurement.
 
The carrying amounts reported in the balance sheets for cash and cash equivalents, investments in certificates of deposit, receivables and current liabilities each qualify as financial instruments and are a reasonable estimate of fair value because of the short period of time between the origination of such instruments and their expected realization and their current market rate of interest. Marketable securities are valued using Level 1 inputs.
 
CONCENTRATION OF CREDIT RISK
 
Financial instruments which potentially subject the Company to concentrations of credit risk consist of cash and cash equivalents, investments in certificates of deposit and accounts receivable.  The Company maintains cash at one financial institution.  The Company periodically evaluates the credit worthiness of financial institutions, and maintains cash accounts only in large high quality financial institutions, thereby minimizing exposure for deposits in excess of federally insured amounts.  The Company believes credit risk associated with cash and cash equivalents to be minimal.
 
The Company has recorded trade accounts receivable from business operations. Management periodically evaluates the collectability of trade receivables and believes that the Company’s receivables are fully collectable and that the risk of loss is minimal.
 
EQUITY BASED COMPENSATION
 
The Company adopted the fair value recognition provisions of FASB ASC 718 “Share Based Payment.”
 
RECENT ACCOUNTING PRONOUNCEMENTS
 
In June 2011, authoritative guidance was issued on the presentation of comprehensive income.  Specifically, the guidance allows an entity to present components of net income and other comprehensive income in one continuous statement, referred to as the statement of comprehensive income, or in two separate but consecutive statements. The new guidance eliminates the current option to report other comprehensive income and its components in the statement of changes in equity. This guidance has been applied retrospectively and will be effective for our interim and annual reporting periods beginning after December 15, 2011.
 
The changes in presentation of comprehensive income had no effect on the calculation of net income, comprehensive income or earnings per share.
XML 26 R35.htm IDEA: XBRL DOCUMENT v2.4.0.6
CONTINGENCIES (Details Textual) (USD $)
3 Months Ended 9 Months Ended 12 Months Ended
Jul. 31, 2012
Jul. 31, 2011
Jul. 31, 2012
Jul. 31, 2011
Oct. 31, 2011
Natural gas and oil sales $ 75,811 $ 291,527 $ 422,570 $ 1,062,679  
Oil and Gas Revenue Unrecognized         119,295
Drilling Program Oklahoma Three [Member]
         
Percentage of Pending Outcome of Legal Proceedings (in percentage)     50.00%    
Natural gas and oil sales     43,989    
Oil and Gas Revenue Unrecognized         $ 163,284
Drilling Program Oklahoma Three [Member] | Before Casing Point Interest Percentage [Member]
         
Cost Method Investment Ownership Percentage (in percentage)     6.25%    
Drilling Program Oklahoma Three [Member] | After Casing Point Interest Percentage [Member]
         
Cost Method Investment Ownership Percentage (in percentage)     5.00%    
XML 27 R22.htm IDEA: XBRL DOCUMENT v2.4.0.6
ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details Textual)
9 Months Ended
Jul. 31, 2012
Jul. 31, 2011
Stock Options [Member]
Capitalized Costs, Oil and Gas Producing Activities, Discounted Percentage 10.00%  
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount   500,000
XML 28 R24.htm IDEA: XBRL DOCUMENT v2.4.0.6
ACCOUNTS RECEIVABLE (Details) (USD $)
Jul. 31, 2012
Oct. 31, 2011
Accounts receivable $ 53,999 $ 329,748
Less: allowance for doubtful account 0 0
Accounts Receivable, Net, Current $ 53,999 $ 329,748
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XML 30 R7.htm IDEA: XBRL DOCUMENT v2.4.0.6
MARKETABLE SECURITIES
9 Months Ended
Jul. 31, 2012
Marketable Securities [Abstract]  
Marketable Securities [Text Block]
2.  
MARKETABLE SECURITIES
 
In August 2011, the Company received 800,000 common shares in Lexaria Corp. on the sale of its oil and natural gas interests in Mississippi, with a value of $0.34 per share.  The value of the shares at July 31, 2012 was $0.11 per share, as compared to $0.26 per share as at October 31, 2011, giving rise to an unrealized loss of $120,000 for the nine-month period ended July 31, 2012.
XML 31 R3.htm IDEA: XBRL DOCUMENT v2.4.0.6
BALANCE SHEETS [Parenthetical] (USD $)
Jul. 31, 2012
Oct. 31, 2011
Preferred stock, par value (in dollars per share) $ 0.001 $ 0.001
Preferred stock, shares authorized 1,000,000 1,000,000
Preferred stock, shares issued 500,001 0
Preferred Stock, Shares Outstanding 500,001 0
Common stock, par value (in dollars per share) $ 0.001 $ 0.001
Common stock, shares authorized 100,000,000 100,000,000
Common stock, shares issued 24,629,832 24,629,832
Common stock, shares outstanding 24,629,832 24,629,832
XML 32 R17.htm IDEA: XBRL DOCUMENT v2.4.0.6
ACCOUNTS RECEIVABLE (Table)
9 Months Ended
Jul. 31, 2012
Receivables [Abstract]  
Schedule of Accounts, Notes, Loans and Financing Receivable [Table Text Block]
 
   
July 31, 2012
   
October 31, 2011
 
Accounts receivable
  $ 53,999     $ 329,748  
Less: allowance for doubtful account
    -       -  
    $ 53,999     $ 329,748  
XML 33 R1.htm IDEA: XBRL DOCUMENT v2.4.0.6
DOCUMENT AND ENTITY INFORMATION
9 Months Ended
Jul. 31, 2012
Sep. 30, 2012
Entity Registrant Name BRINX RESOURCES LTD  
Entity Central Index Key 0001212641  
Current Fiscal Year End Date --10-31  
Entity Filer Category Smaller Reporting Company  
Trading Symbol bnxr  
Entity Common Stock, Shares Outstanding   24,629,832
Document Type 10-Q  
Amendment Flag false  
Document Period End Date Jul. 31, 2012  
Document Fiscal Period Focus Q3  
Document Fiscal Year Focus 2012  
XML 34 R18.htm IDEA: XBRL DOCUMENT v2.4.0.6
OIL AND GAS INTERESTS (Tables)
9 Months Ended
Jul. 31, 2012
Oil and Gas Interests Abstract [Abstract]  
Schedule of Exploratory Wells Drilled [Table Text Block]
The Company holds the following oil and natural gas interests:
 
      July 31, 2012       October 31, 2011  
2008-3 Drilling Program, Oklahoma
  $ 309,152     $ 302,361  
2009-2 Drilling Program, Oklahoma
    114,420       114,420  
2009-3 Drilling Program, Oklahoma
    335,612       300,080  
2009-4 Drilling Program, Oklahoma
    190,182       190,146  
2010-1 Drilling Program, Oklahoma
    253,967       253,855  
Washita Bend 3D, Oklahoma
    526,926       482,882  
Double T Ranch #1 SWDW, Oklahoma
    29,312       --  
Kings City Prospect, California
    388,837       263,561  
Three Sands Project, Oklahoma
    1,451,557       1,451,543  
South Wayne Prospect, Oklahoma
    61,085       61,085  
PP F-12-2, PP F-12-3, PP F-12-4 and PP F-52, Mississippi
    (222,123 )     (222,123 )
Asset retirement cost
    4,534       4,534  
Less:  Accumulated depletion and impairment
    (1,267,869 )     (1,127,444 )
    $ 2,175,592     $ 2,074,900
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]
 
   
July 31, 2012
   
       October 31, 2011
 
Proved properties
  $ 2,438,387     $ 2,395,902  
Unproved properties
    1,005,075       806,443  
Total Proved and Unproved properties
    3,443,462       3,202,345  
Accumulated depletion expense
    (1,130,138 )     (989,713 )
Impairment
    (137,732 )     (137,732 )
Net capitalized cost
  $ 2,175,592     $ 2,074,900  
Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block]
Results of operations for oil and gas producing activities during the nine-month periods ended are as follows:
 
   
July 31, 2012
   
July 31, 2011
  Revenues
  $ 422,570     $ 1,062,679  
  Production costs
    (87,023 )     (162,262 )
  Depletion and accretion
    (142,795 )     (285,481 )
  Results of operations (excluding corporate overhead)
  $ 192,752     $ 614,936  
XML 35 R4.htm IDEA: XBRL DOCUMENT v2.4.0.6
STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME/(LOSS) (UNAUDITED) (USD $)
3 Months Ended 9 Months Ended
Jul. 31, 2012
Jul. 31, 2011
Jul. 31, 2012
Jul. 31, 2011
REVENUES        
Natural gas and oil sales $ 75,811 $ 291,527 $ 422,570 $ 1,062,679
DIRECT COSTS        
Production costs 33,848 40,385 (87,023) (162,262)
Depletion and accretion 36,710 79,388 (142,795) (285,481)
General and administrative 131,611 223,766 451,999 595,677
Total Expenses (202,169) (343,539) (681,817) (1,043,420)
OPERATING INCOME/(LOSS) (126,358) (52,012) (259,247) 19,259
OTHER INCOME        
Interest income 202 350 11 900
Other Income 0 0 20,000 0
NET INCOME/(LOSS) BEFORE COMPREHENSIVE LOSS (126,156) (51,662) (239,236) 20,159
COMPREHENSIVE INCOME/(LOSS)        
Unrealized (loss) on held for sale marketable security (20,000) 0 (120,000) 0
COMPREHENSIVE INCOME/(LOSS) FOR THE PERIODS $ (146,156) $ (51,662) $ (359,236) $ 20,159
Net Income/(Loss) Per Common Share        
- Basic (in dollars per share) $ (0.005) $ (0.002) $ (0.010) $ 0.001
- Diluted (in dollars per share) $ (0.005) $ (0.002) $ (0.010) $ 0.001
Weighted average number of common shares outstanding        
- Basic (in shares) 24,629,832 24,629,832 24,629,832 24,629,832
- Diluted (in shares) 24,629,832 24,629,832 24,629,832 24,749,314
XML 36 R12.htm IDEA: XBRL DOCUMENT v2.4.0.6
RELATED PARTY TRANSACTIONS
9 Months Ended
Jul. 31, 2012
Related Party Transactions [Abstract]  
Related Party Transactions Disclosure [Text Block]
7.
RELATED PARTY TRANSACTIONS
 
During the nine-month periods ended July 31, 2012 and 2011, the Company entered into the following transactions with related parties:
 
a)    
The Company paid $30,000 (2011 - $54,000) in management fees and reimbursement of office space of $nil (2011 - $3,600) to the then President of the Company.
 
b)    
The Company paid $54,000 (2011 - $53,000) to a related entity, for administration services.
 
c)    
The Company paid $81,500 (2011 - $75,500) in management fees to the director and current President of the Company.
 
d)    
The Company paid $58,673 (2011 - $57,628) in consulting and accounting fees to the Chief Financial Officer of the Company.
XML 37 R11.htm IDEA: XBRL DOCUMENT v2.4.0.6
COMMON STOCK
9 Months Ended
Jul. 31, 2012
Stockholders' Equity Note [Abstract]  
Stockholders' Equity Note Disclosure [Text Block]
6.
COMMON STOCK
 
PREFERRED STOCK
 
On February 10, 2012, the Company issued 500,001 Series A preferred stock at par value.
 
               STOCK OPTIONS
 
Although the Company does not have a formal stock option plan, all options granted in the past have been approved by the Board of Directors.
 
 
A summary of the changes in stock options for the nine-month period ended July 31, 2012 is presented below:
 
   
Options Outstanding
 
         
Weighted Average
 
   
Number of Shares
   
Exercise Price
 
Balance, October 31, 2011
    300,000     $ 0.10  
Expired on November 2, 2011
    (300,000 )     0.10  
 
Balance, July 31, 2012
     -     $ -
XML 38 R23.htm IDEA: XBRL DOCUMENT v2.4.0.6
MARKETABLE SECURITIES (Details Textual) (USD $)
1 Months Ended 9 Months Ended 12 Months Ended
Aug. 31, 2011
Jul. 31, 2012
Oct. 31, 2011
Marketable Securities Number Of Shares (in shares) 800,000    
Marketable Securities (in dollars per share) $ 0.34 $ 0.11 $ 0.26
Marketable Securities, Unrealized Gain (Loss)   $ 120,000  
XML 39 R19.htm IDEA: XBRL DOCUMENT v2.4.0.6
ASSET RETIREMENT OBLIGATIONS (Table)
9 Months Ended
Jul. 31, 2012
Asset Retirement Obligation Disclosure [Abstract]  
Schedule of Change in Asset Retirement Obligation [Table Text Block]
The information below reflects the change in the asset retirement obligations during the nine-month period ended July 31, 2012 and the year ended October 31, 2011:
 
   
July 31, 2012
   
October 31, 2011
 
Balance, beginning of period
  $ 26,335     $ 27,494  
Liabilities assumed
    -       774  
    Revisions     -       (5,232
Accretion expense
    2,370        3,299  
Balance, end of period
  $ 28,705     $ 26,335  
XML 40 R15.htm IDEA: XBRL DOCUMENT v2.4.0.6
ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)
9 Months Ended
Jul. 31, 2012
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Use of Estimates, Policy [Policy Text Block]
USE OF ESTIMATES
 
The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting period.  Actual results could differ from those estimates.
 
The oil and gas industry is subject, by its nature, to environmental hazards and clean-up costs.  At this time, management knows of no substantial costs from environmental accidents or events for which the Company may be currently liable.  In addition, the Company’s oil and gas business makes it vulnerable to changes in prices of crude oil and natural gas.  Such prices have been volatile in the past and can be expected to be volatile in the future.  By definition, proved reserves are based on current oil and gas prices and estimated reserves.  Price declines reduce the estimated quantity of proved reserves and increase annual depletion expense (which is based on proved reserves).
Oil and Gas Interests Policy [Policy Text Block]
OIL AND GAS INTERESTS
 
The Company utilizes the full cost method of accounting for oil and gas activities.  Under this method, subject to a limitation based on estimated value, all costs associated with property acquisition, exploration and development, including costs of unsuccessful exploration; are capitalized within a cost center.  No gain or loss is recognized upon the sale or abandonment of undeveloped or producing oil and gas interests unless the sale represents a significant portion of oil and gas interests and the gain significantly alters the relationship between capitalized costs and proved oil and gas reserves of the cost center.  Depreciation, depletion and amortization of oil and gas interests is computed on the units of production method based on proved reserves, or upon reasonable estimates where proved reserves have not yet been established due to the recent commencement of production.  Amortizable costs include estimates of future development costs of proved undeveloped reserves.
 
Capitalized costs of oil and gas interests may not exceed an amount equal to the present value, discounted at 10%, of the estimated future net cash flows from proved oil and gas reserves plus the cost, or estimated fair market value, if lower, of unproved interests.  Should capitalized costs exceed this ceiling, an impairment is recognized.  The present value of estimated future net cash flows is computed by applying average prices, in the preceding twelve months, of oil and gas to estimated future production of proved oil and gas reserves as of year end, less estimated future expenditures to be incurred in developing and producing the proved reserves and assuming continuation of existing economic conditions.
Revenue Recognition, Policy [Policy Text Block]
REVENUE RECOGNITION
 
Revenue from sales of crude oil, natural gas and refined petroleum products are recorded when deliveries have occurred and legal ownership of the commodity transfers to the customer.  Title transfers for crude oil, natural gas and bulk refined products generally occur at pipeline custody points or when a tanker lifting has occurred.  Revenues from the production of oil and natural gas properties in which the Company shares an undivided interest with other producers are recognized based on the actual volumes sold by the Company during the period.  Gas imbalances occur when the Company’s actual sales differ from its entitlement under existing working interests.  The Company records a liability for gas imbalances when it has sold more than its working interest of gas production and the estimated remaining reserves make it doubtful that the partners can recoup their share of production from the field.  At July 31, 2012 and 2011, the Company had no overproduced imbalances.
Trade and Other Accounts Receivable, Policy [Policy Text Block]
ACCOUNTS RECEIVABLE
 
Accounts receivable are carried at net receivable amounts less an estimate for doubtful accounts.  Management determines the allowance for doubtful accounts by regularly evaluating individual customer receivables and considering a customer’s financial condition, credit history, and current economic conditions.  Trade receivables are written off when deemed uncollectible.  Recoveries of receivables previously written off are recorded when received.
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]
IMPAIRMENT OF LONG-LIVED ASSETS
 
The Company has adopted FASB ASC 360 “Accounting  for the  Impairment  or Disposal of Long-Lived  Assets,” which requires that long-lived  assets to be held and used be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.  Oil and gas interests accounted for under the full cost method are subject to a ceiling test, described above, and are excluded from this requirement.
Asset Retirement Obligations, Policy [Policy Text Block]
ASSET RETIREMENT OBLIGATIONS
 
The Company follows FASB ASC 410-20 "Accounting for Asset Retirement Obligations," that addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs.
 
FASB ASC 410-20 requires recognition of the present value of obligations associated with the retirement of tangible long-lived assets in the period in which it is incurred. The liability is capitalized as part of the related long-lived asset's carrying amount.
 
Over time, accretion of the liability is recognized as an operating expense and the capitalized cost is depreciated over the expected useful life of the related asset.  The Company's asset retirement obligations are related to the plugging, dismantlement, removal, site reclamation and similar activities of its oil and gas exploration activities.
Earnings Per Share, Policy [Policy Text Block]
INCOME / (LOSS) PER SHARE
 
Basic income/(loss) per share is computed based on the weighted average number of common shares outstanding during each period.  The computation of diluted earnings per share assumes the conversion, exercise or contingent issuance of securities only when such conversion, exercise or issuance would have a dilutive effect on income/(loss) per share.  The dilutive effect of outstanding options was nil as of July 31, 2012 and 2011.  500,000 options were included in the earnings per share calculation for the nine-month period ended July 31, 2011.  The table below presents the computation of basic and diluted earnings per share for the nine-month periods ended July 31, 2012 and 2011:
 
    July 31, 2012   July 31, 2011   
Basic earnings per share computation:          
 
Income/(Loss) from continuing operations
  $ (239,236 )   $ 20,159  
Basic shares outstanding
    24,629,832       24,629,832  
Basic earnings per share
  $ (0.010 )   $ 0.001  
Diluted earnings per share computation:                
Income (Loss) from continuing operations
  $ (239,236 )   $ 20,159  
Basic shares outstanding
    24,629,832       24,629,832  
Incremental shares from assumed conversions:
             
    Stock options
    -       119,482  
    Warrants
    -       -  
Diluted shares outstanding
    24,629,832       24,749,314  
Diluted earnings per share   $ (0.010 )   $ 0.001
Income Tax, Policy [Policy Text Block]
INCOME TAXES
 
Deferred tax assets and liabilities are recognized for temporary differences between the financial reporting and tax bases of the firm’s assets and liabilities. Valuation allowances are established to reduce deferred tax assets to the amount that more likely than not will be realized. The firm’s tax assets and liabilities, if any, are presented as a component of “Other assets” and “Other liabilities and accrued expenses,” respectively, in the balance sheet.  Tax provisions are computed in accordance with FASB ASC 740, “Accounting for Income Taxes.”
 
The Company applies the provisions of FASB ASC 740-10 “Accounting for Uncertainty in Income Taxes — an Interpretation.” A tax position can be recognized in the financial statements only when it is more likely than not that the position will be sustained upon examination by the relevant taxing authority based on the technical merits of the position. A position that meets this standard is measured at the largest amount of benefit that will more likely than not be realized upon settlement. A liability is established for differences between positions taken in a tax return and amounts recognized in the financial statements. FASB ASC 740-10 also provides guidance on de-recognition, classification, interim period accounting and accounting for interest and penalties.
Cash and Cash Equivalents, Policy [Policy Text Block]
CASH EQUIVALENTS
 
For purposes of reporting cash flows, the Company considers as cash equivalents all highly liquid investments with a maturity of three months or less at the time of purchase.  On occasion, the Company may have cash balances in excess of federally insured amounts.
Investment, Policy [Policy Text Block]
MARKETABLE SECURITIES AND INVESTMENTS
 
All equity investments are classified as available for sale and any subsequent changes in the fair value are recorded in comprehensive income. If in the opinion of management there has been a decline in the value of the investment below the carrying value that is considered to be other than temporary, the valuation adjustment is recorded in net earnings in the period of determination.  The fair value of investments is based on the quoted market price on the closing date of the period.
Fair Value of Financial Instruments, Policy [Policy Text Block]
FAIR VALUE
 
The Company adopted FASB ASC 820-10-50, “Fair Value Measurements.” This guidance defines fair value, establishes a three-level valuation hierarchy for disclosures of fair value measurement and enhances disclosure requirements for fair value measures.  The three levels are defined as follows:
 
Level 1 inputs to the valuation methodology are quoted prices (unadjusted) for identical assets or liabilities in active markets.
 
Level 2 inputs to the valuation methodology include quoted prices for similar assets and liabilities in active markets, and inputs that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the financial instrument.
 
Level 3 inputs to valuation methodology are unobservable and significant to the fair measurement.
 
The carrying amounts reported in the balance sheets for cash and cash equivalents, investments in certificates of deposit, receivables and current liabilities each qualify as financial instruments and are a reasonable estimate of fair value because of the short period of time between the origination of such instruments and their expected realization and their current market rate of interest. Marketable securities are valued using Level 1 inputs.
Concentration Risk, Credit Risk, Policy [Policy Text Block]
CONCENTRATION OF CREDIT RISK
 
Financial instruments which potentially subject the Company to concentrations of credit risk consist of cash and cash equivalents, investments in certificates of deposit and accounts receivable.  The Company maintains cash at one financial institution.  The Company periodically evaluates the credit worthiness of financial institutions, and maintains cash accounts only in large high quality financial institutions, thereby minimizing exposure for deposits in excess of federally insured amounts.  The Company believes credit risk associated with cash and cash equivalents to be minimal.
 
The Company has recorded trade accounts receivable from business operations. Management periodically evaluates the collectability of trade receivables and believes that the Company’s receivables are fully collectable and that the risk of loss is minimal.
Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]
EQUITY BASED COMPENSATION
 
The Company adopted the fair value recognition provisions of FASB ASC 718 “Share Based Payment.”
New Accounting Pronouncements, Policy [Policy Text Block]
RECENT ACCOUNTING PRONOUNCEMENTS
 
In June 2011, authoritative guidance was issued on the presentation of comprehensive income.  Specifically, the guidance allows an entity to present components of net income and other comprehensive income in one continuous statement, referred to as the statement of comprehensive income, or in two separate but consecutive statements. The new guidance eliminates the current option to report other comprehensive income and its components in the statement of changes in equity. This guidance has been applied retrospectively and will be effective for our interim and annual reporting periods beginning after December 15, 2011.
 
The changes in presentation of comprehensive income had no effect on the calculation of net income, comprehensive income or earnings per share.
XML 41 R13.htm IDEA: XBRL DOCUMENT v2.4.0.6
MAJOR CUSTOMERS
9 Months Ended
Jul. 31, 2012
Major Customers [Abstract]  
Major Customers [Text Block]
8.  
MAJOR CUSTOMERS
 
We collected $318,909 (2011: $654,172) or 75% (2011: 62%) of our revenues from one of our operators during the nine-month period ended July 31, 2012. As of July 31, 2012, $24,567 was due from this operator.
XML 42 R14.htm IDEA: XBRL DOCUMENT v2.4.0.6
CONTINGENCIES
9 Months Ended
Jul. 31, 2012
Commitments and Contingencies Disclosure [Abstract]  
Commitments and Contingencies Disclosure [Text Block]
9.  
CONTINGENCIES
 
In September 2010, two lawsuits were filed in the District Court of Garvin County in the State of Oklahoma by Harold Hamm (“Hamm”) against certain defendants (“Defendants”) and consolidated together alleging, among other things, that Hamm owns an interest in two oil and gas leases in Garvin County and is entitled to a 50% participatory interest.  The Company was not named as a party in these legal proceedings, but Hamm’s allegations include that he is entitled to a 50% participatory interest in the Joe Murray Farms well drilled as part of the 2009-3 Drilling Program, in which the Company purchased a 6.25% working interest before casing point and 5.0% working interest after casing point.  The Defendants and the Company believe that there is no merit to Hamm’s allegations.  In connection with these proceedings, the Defendants were ordered in January 2011 to escrow fifty percent (50%) of the revenues generated within the subject area pending the outcome of these proceedings.  For this reason, fifty percent (50%) of the revenues the Company is entitled to that have been generated by production from the Joe Murray Farms well is being escrowed and there is no assurance that the Company will be able to recover these proceeds.  The Company recognized $43,989 in revenue during the nine months ended July 31, 2012 and $119,295 in revenue during the year ended October 31, 2011 from the Joe Murray Farms well and a total of $163,284 has not been recognized as revenue and is being escrowed pending the outcome of these proceedings.
XML 43 R16.htm IDEA: XBRL DOCUMENT v2.4.0.6
ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Table)
9 Months Ended
Jul. 31, 2012
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]
The table below presents the computation of basic and diluted earnings per share for the nine-month periods ended July 31, 2012 and 2011:
  
    July 31, 2012   July 31, 2011   
Basic earnings per share computation:          
 
Income/(Loss) from continuing operations
  $ (239,236 )   $ 20,159  
Basic shares outstanding
    24,629,832       24,629,832  
Basic earnings per share
  $ (0.010 )   $ 0.001  
Diluted earnings per share computation:                
Income (Loss) from continuing operations
  $ (239,236 )   $ 20,159  
Basic shares outstanding
    24,629,832       24,629,832  
Incremental shares from assumed conversions:
               
    Stock options
    -       119,482  
    Warrants
    -       -  
Diluted shares outstanding
    24,629,832       24,749,314  
Diluted earnings per share   $ (0.010 )   $ 0.001  
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MAJOR CUSTOMERS (Details Textual) (USD $)
9 Months Ended
Jul. 31, 2012
Jul. 31, 2011
Entity-Wide Revenue, Major Customer, Amount $ 318,909 $ 654,172
Entity-Wide Revenue, Major Customer, Percentage 75.00% 62.00%
Due From Major Customer, Amount $ 24,567  
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ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)
3 Months Ended 9 Months Ended
Jul. 31, 2012
Jul. 31, 2011
Jul. 31, 2012
Jul. 31, 2011
Basic earnings per share computation:        
Income/(Loss) from continuing operations $ (126,156) $ (51,662) $ (239,236) $ 20,159
Basic shares outstanding (in shares) 24,629,832 24,629,832 24,629,832 24,629,832
Basic earnings per share (in dollars per share) $ (0.005) $ (0.002) $ (0.010) $ 0.001
Diluted earnings per share computation:        
Income/(Loss) from continuing operations $ (126,156) $ (51,662) $ (239,236) $ 20,159
Basic shares outstanding (in shares) 24,629,832 24,629,832 24,629,832 24,629,832
Incremental shares from assumed conversions:        
Stock options     0 119,482
Warrants     0 0
Diluted shares outstanding (in shares) 24,629,832 24,629,832 24,629,832 24,749,314
Diluted earnings per share (in dollars per share) $ (0.005) $ (0.002) $ (0.010) $ 0.001
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OIL AND GAS INTERESTS (Details 1) (USD $)
Jul. 31, 2012
Oct. 31, 2011
Proved properties $ 2,438,387 $ 2,395,902
Unproved properties 1,005,075 806,443
Total Proved and Unproved properties 3,443,462 3,202,345
Accumulated depletion expense (1,130,138) (989,713)
Impairment (137,732) (137,732)
Net capitalized cost $ 2,175,592 $ 2,074,900
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STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $)
9 Months Ended
Jul. 31, 2012
Jul. 31, 2011
CASH FLOWS PROVIDED BY (USED IN) OPERATING ACTIVITIES    
Net Income / (loss) $ (239,236) $ 20,159
Adjustments to reconcile net income to net cash provided by operating activities:    
Depletion and accretion 142,795 285,481
Changes in working capital:    
Decrease / (Increase) in accounts receivable 76,249 (36,469)
Decrease / (increase) in prepaid expenses and deposit (3,556) 111,850
Increase / (decrease) in accounts payable and accrued liabilities 8,369 (1,199)
Net cash provided by /(used in) operating activities (15,379) 379,822
CASH FLOWS PROVIDED BY (USED IN) INVESTING ACTIVITIES    
Redemption of Certificate of deposit 0 400,000
Sale proceeds of natural gas and oil working interests 200,000 0
Payments on oil and gas interests (241,117) (486,668)
Net cash (used in) investing activities (41,117) (86,668)
CASH FLOWS PROVIDED BY (USED IN) FINANCING ACTIVITIES    
Net cash (used in) financing activities 0 0
Net increase (decrease) in cash (56,496) 293,154
Cash and cash equivalents, beginning of periods 401,047 21,029
Cash and cash equivalents, end of periods 344,551 314,183
SUPPLEMENTAL SCHEDULE OF NON-CASH INVESTING AND FINANCING ACTIVITIES    
Assets retirement costs incurred (2,370) (3,240)
Investment in natural oil and gas working interests included in accounts payable $ 0 $ 28,640
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ASSET RETIREMENT OBLIGATIONS
9 Months Ended
Jul. 31, 2012
Asset Retirement Obligation Disclosure [Abstract]  
Asset Retirement Obligation Disclosure [Text Block]
5.  
ASSET RETIREMENT OBLIGATIONS
 
The Company follows FASB ASC 410-20 “Accounting for Asset Retirement Obligations”  which addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs.  This policy requires recognition of the present value of obligations associated with the retirement of tangible long-lived assets in the period in which it is incurred.  As of July 31, 2012 and October 31, 2011, the Company recognized the future cost to plug and abandon the gas wells over the estimated useful lives of the wells in accordance with “Accounting for Asset Retirement Obligations.”  The liability for the fair value of an asset retirement obligation with a corresponding increase in the carrying value of the related long-lived asset is recorded at the time a well is completed and ready for production.  The Company amortizes the amount added to the oil and gas properties and recognizes accretion expense in connection with the discounted liability over the remaining life of the respective well.  The estimated liability is based on historical experience in plugging and abandoning wells, estimated useful lives based on engineering studies, external estimates as to the cost to plug and abandon wells in the future and federal and state regulatory requirements.  The liability is a discounted liability using a credit-adjusted risk-free rate of 12%.  Revisions to the liability could occur due to changes in plugging and abandonment costs, well useful lives or if federal or state regulators enact new guidance on the plugging and abandonment of wells.
 
The Company amortizes the amount added to oil and gas properties and recognizes accretion expense in connection with the discounted liability over the remaining useful lives of the respective wells.
 
The information below reflects the change in the asset retirement obligations during the nine-month period ended July 31, 2012 and the year ended October 31, 2011:
 
   
July 31, 2012
   
October 31, 2011
 
Balance, beginning of period
  $ 26,335     $ 27,494  
Liabilities assumed
    -       774  
    Revisions     -       (5,232
Accretion expense
    2,370        3,299  
Balance, end of period
  $ 28,705     $ 26,335  
 
 
The reclamation obligation relates to the Kodesh, Dye Estate, KC 80, Taylor and William wells at the Three Sands Property; ARD#1-36, Bagwell#1-20, Bagwell#2-20, Jackson#1-18, Miss Gracie#1-18, Joe Murray Farm, Dennis#2-8, Gehrke#1-24, Jack#1-13 and Miss Jenny#1-8 wells at Oklahoma Properties, and McPherson#1-1 well at South Wayne Prospect.  The present value of the reclamation liability may be subject to change based on management’s current estimates, changes in remediation technology or changes in applicable laws and regulations.  Such changes will be recorded in the accounts of the Company as they occur.
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OIL AND GAS INTERESTS (Details 2) (USD $)
3 Months Ended 9 Months Ended
Jul. 31, 2012
Jul. 31, 2011
Jul. 31, 2012
Jul. 31, 2011
Revenues $ 75,811 $ 291,527 $ 422,570 $ 1,062,679
Production costs 33,848 40,385 (87,023) (162,262)
Depletion and accretion 36,710 79,388 (142,795) (285,481)
Results of operations (excluding corporate overhead)     $ 192,752 $ 614,936
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COMMON STOCK (Table)
9 Months Ended
Jul. 31, 2012
Stockholders' Equity Note [Abstract]  
Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]
A summary of the changes in stock options for the nine-month period ended July 31, 2012 is presented below:
   
Options Outstanding
 
         
Weighted Average
 
   
Number of Shares
   
Exercise Price
 
Balance, October 31, 2011
    300,000     $ 0.10  
Expired on November 2, 2011
    (300,000 )     0.10  
 
Balance, July 31, 2012
     -     $ -