Nevada
|
98-0511130
|
(State or other jurisdiction of incorporation or organization)
|
(I.R.S. Employer Identification No.)
|
7582 Las Vegas Boulevard South #247
Las Vegas, Nevada
|
89123
|
(Address of principal executive offices)
|
(Zip Code)
|
Large accelerated filer o
|
Accelerated filer o
|
Non-accelerated filer o
|
Smaller reporting company ý
|
|
·
|
In the Original Form 10-K, the Report of Independent Registered Public Accounting Firm was filed separately as Amendment No. 1 on Form 10-K/A, apart from the financial statements and other disclosures contained in the Initial Form 10-K. This Amendment No. 2 includes the financial statements, the Report of Independent Registered Public Accounting Firm and all other Form 10-K required disclosures in a single filing.
|
|
·
|
Attached as Exhibit 31 to this Amendment No. 2 is an updated and revised certification of our Chief Executive and Financial Officer that includes all language required by Item 601(b)(31) of Regulation S-K.
|
|
·
|
The Report of Independent Registered Public Accounting Firm under Item 8 of this Amendment No. 2 has been revised to include an opinion for all required financial statements.
|
|
·
|
Attached as Exhibit 99.1 to this Amendment No. 2 is the reserve report of Chapman Petroleum Engineering Ltd.
|
|
·
|
We have revised our disclosures on pages 5-6 and 26-27 concerning our option to acquire Hawker Energy LLC and certain potential follow-on transactions whereby the sellers of Hawker Energy LLC may be entitled to receive additional shares of our Common Stock.
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PART I
|
Page
|
|
Item 1
|
Business
|
4 |
Item 1A
|
Risk Factors
|
7 |
Item 1B
|
Unresolved Staff Comments
|
7 |
Item 2
|
Properties
|
7 |
Item 3
|
Legal Proceedings
|
9 |
Item 4
|
Mine Safety Disclosures
|
9 |
PART II
|
||
Item 5
|
Market for Registrant’s Common Equity, Related Stockholder Matters
and Issuer Purchases of Equity Securities
|
10 |
Item 6
|
Selected Financial Data
|
10 |
Item 7
|
Management’s Discussion and Analysis of Financial Condition and
Results of Operations
|
11 |
Item 7A
|
Quantitative and Qualitative Disclosures About Market Risk
|
13 |
Item 8
|
Financial Statements and Supplementary Data
|
14 |
Item 9
|
Changes in and Disagreements With Accountants on Accounting and
Financial Disclosure
|
28 |
Item 9A
|
Controls and Procedures
|
28 |
Item 9B
|
Other Information
|
28 |
PART III
|
||
Item 10
|
Directors, Executive Officers and Corporate Governance
|
29 |
Item 11
|
Executive Compensation
|
30 |
Item 12
|
Security Ownership of Certain Beneficial Owners and Management and
Related Stockholder Matters
|
30 |
Item 13
|
Certain Relationships and Related Transactions, and Director Independence
|
31 |
Item 14
|
Principal Accounting Fees and Services
|
31 |
PART IV
|
||
Item 15
|
Exhibits, Financial Statement Schedules
|
32 |
Item 1
|
Business
|
Item 1A
|
Risk Factors
|
Item 1B
|
Unresolved Staff Comments
|
Item 2
|
Properties
|
Proved Reserves Category
|
Net
STB (1)(2)
|
PV10
(before tax)
|
|||||||
Proved, Developed Producing
|
1,900
|
$ |
57,000
|
||||||
Proved, Undeveloped
|
176,600
|
3,227,000
|
|||||||
Total Proved
|
178,500
|
$ |
3,284,000
|
(1)
|
STB = one stock-tank barrel.
|
|
(2)
|
Net STB is based upon SCNRG’s net revenue interest. Net reserve or other net information is based on our 52.72 percent net working interest as of August 31, 2013, being SCNRG’s 66.67% working interest less 20.92% overriding royalties. See also “Net Profits Interest” below.
|
Twelve Months
Ended
August 31, 2013
|
Twelve Months
Ended
August 31, 2012
|
|||||||
Net production - oil (barrels)
|
796
|
827
|
||||||
Average sales price per barrel of oil
|
$
|
94.57
|
$
|
99.48
|
||||
Average production cost (1) per barrel of oil
|
$
|
94.27
|
$
|
73.32
|
||||
Average lifting costs (2) per barrel of oil
|
$
|
72.55
|
$
|
51.59
|
Project Name
|
Developed Acreage
|
Undeveloped Acreage
|
Total Acreage
|
|||||||||||||||||||||
Gross
|
Net
|
Gross
|
Net
|
Gross
|
Net
|
|||||||||||||||||||
Total
|
7.5
|
5.0
|
32.5
|
21.7
|
40.0
|
26.7
|
Item 3
|
Legal Proceedings
|
Item 4 | Mine Safety Disclosures |
Item 5
|
Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
|
Bid Prices ($)
|
||
2013 Fiscal Year
|
High
|
Low
|
November 30, 2012
|
0.15
|
0.12
|
February 28, 2013
|
0.10
|
0.08
|
May 31, 2013
|
0.10
|
0.08
|
August 31, 2013
|
0.20
|
0.09
|
2012 Fiscal Year
|
||
November 30, 2011
|
0.15
|
0.08
|
February 22, 2012
|
0.10
|
0.10
|
May 31, 2012
|
0.10
|
0.10
|
August 31, 2012
|
0.10
|
0.10
|
Item 6
|
Selected Financial Data
|
Item 7
|
Management’s Discussion and Analysis of Financial Condition and Results of Operations
|
Item 7A
|
Quantitative and Qualitative Disclosures About Market Risk
|
Item 8
|
Financial Statements and Supplementary Data
|
SARA CREEK GOLD CORP.
|
||||||
(AN EXPLORATION STAGE COMPANY)
|
||||||
BALANCE SHEETS
|
August 31, 2013
|
August 31, 2012
|
|||||||
ASSETS
|
||||||||
Current assets
|
||||||||
Cash
|
$ | 8,079 | $ | 15,942 | ||||
Accounts receivable
|
1,552 | - | ||||||
Total current assets
|
9,631 | 15,942 | ||||||
Deposit
|
5,000 | - | ||||||
Oil and gas properties, proven
|
26,500 | - | ||||||
Total other assets
|
31,500 | - | ||||||
Total assets
|
$ | 41,131 | $ | 15,942 | ||||
LIABILITIES AND STOCKHOLDERS' DEFICIT
|
||||||||
Current liabilities
|
||||||||
Accounts payable
|
$ | 13,065 | $ | 57,407 | ||||
Accounts payable - related party
|
15,000 | - | ||||||
Notes payable - related party
|
- | 13,966 | ||||||
Total current liabilities
|
28,065 | 71,373 | ||||||
Total liabilities
|
28,065 | 71,373 | ||||||
Stockholders' deficit
|
||||||||
Common stock; $0.001 par value; 750,000,000
|
||||||||
shares authorized, 11,961,985 and 9,281,985
|
||||||||
shares issued and outstanding, respectively
|
11,962 | 9,282 | ||||||
Common stock payable
|
2,000 | 300 | ||||||
Additional paid in capital
|
876,406 | 682,320 | ||||||
Deficit accumulated during the development stage
|
(877,302 | ) | (747,333 | ) | ||||
Total stockholders' deficit
|
13,066 | (55,431 | ) | |||||
Total liabilities and stockholders' deficit
|
$ | 41,131 | $ | 15,942 |
SARA CREEK GOLD CORP.
|
||||||||
(AN EXPLORATION STAGE COMPANY)
|
||||||||
STATEMENTS OF OPERATIONS
|
From June 12, 2006
|
||||||||||||
For the Years Ended
|
(Inception) to
|
|||||||||||
August 31, 2013
|
August 31, 2012
|
August 31, 2013
|
||||||||||
Revenue
|
||||||||||||
Oil and gas activities
|
$ | 3,932 | $ | - | $ | 3,932 | ||||||
Operating expenses
|
||||||||||||
Direct oil & gas costs
|
2,380 | - | 2,380 | |||||||||
General and administrative
|
79,305 | 59,227 | 817,579 | |||||||||
Total operating expenses
|
81,685 | 59,227 | 819,959 | |||||||||
Loss from operations
|
(77,753 | ) | (59,227 | ) | (816,027 | ) | ||||||
Other expense
|
||||||||||||
Gain on foreign currency translation
|
518 | - | 518 | |||||||||
Gain on settlement of debt
|
8,755 | - | 8,755 | |||||||||
Interest expense
|
(61,489 | ) | (5,133 | ) | (70,548 | ) | ||||||
Total other expense
|
(52,216 | ) | (5,133 | ) | (61,275 | ) | ||||||
Loss from operations before income taxes
|
(129,969 | ) | (64,360 | ) | (877,302 | ) | ||||||
Provision for income taxes
|
- | - | - | |||||||||
Net loss
|
$ | (129,969 | ) | $ | (64,360 | ) | $ | (877,302 | ) | |||
Net loss per common share - basic and diluted
|
$ | (0.01 | ) | $ | (0.01 | ) | ||||||
Weighted average common shares outstanding -
|
||||||||||||
basic and diluted
|
10,907,958 | 5,187,077 |
SARA CREEK GOLD CORP.
|
||||||||
(AN EXPLORATION STAGE COMPANY)
|
||||||||
STATEMENTS OF STOCKHOLDERS' (DEFICIT)
|
|
Stock
|
Total
|
||||||||||||||||||||||||||||||
Common Stock
|
Common Stock Payable
|
Subscription
|
Additional
|
Accumulated
|
Stockholders'
|
|||||||||||||||||||||||||||
Shares
|
Amount
|
Shares
|
Amount
|
Receivable
|
Paid-in Capital
|
Deficit
|
Deficit
|
|||||||||||||||||||||||||
Balance, June 12, 2006 (Inception)
|
- | $ | - | - | $ | - | $ | - | $ | - | $ | - | $ | - | ||||||||||||||||||
Issuance of stock at $0.001 per share
|
1,000,000 | 1,000 | - | - | (10,000 | ) | 9,000 | - | - | |||||||||||||||||||||||
Net loss
|
- | - | - | - | - | - | (1,230 | ) | (1,230 | ) | ||||||||||||||||||||||
Balance, August 31, 2006
|
1,000,000 | 1,000 | - | - | (10,000 | ) | 9,000 | (1,230 | ) | (1,230 | ) | |||||||||||||||||||||
Receipt of stock subscription receivable
|
- | - | - | - | 10,000 | - | - | 10,000 | ||||||||||||||||||||||||
Net loss
|
- | - | - | - | - | - | (5,855 | ) | (5,855 | ) | ||||||||||||||||||||||
Balance, August 31, 2007
|
1,000,000 | 1,000 | - | - | - | 9,000 | (7,085 | ) | 2,915 | |||||||||||||||||||||||
Issuance of common stock in exchange
|
||||||||||||||||||||||||||||||||
for cash at $0.10 per share
|
490,000 | 490 | - | - | - | 48,510 | - | 49,000 | ||||||||||||||||||||||||
Net loss
|
- | - | - | - | - | - | (58,567 | ) | (58,567 | ) | ||||||||||||||||||||||
Balance, August 31, 2008
|
1,490,000 | 1,490 | - | - | - | 57,510 | (65,652 | ) | (6,652 | ) | ||||||||||||||||||||||
Net loss
|
- | - | - | - | - | - | (30,806 | ) | (30,806 | ) | ||||||||||||||||||||||
Balance, August 31, 2009
|
1,490,000 | 1,490 | - | - | - | 57,510 | (96,458 | ) | (37,458 | ) | ||||||||||||||||||||||
Net loss
|
- | - | - | - | - | - | - | - | ||||||||||||||||||||||||
Balance, August 31, 2010
|
1,490,000 | 1,490 | - | - | - | 57,510 | (610,179 | ) | (551,179 | ) | ||||||||||||||||||||||
Issuance of common stock in exchange
|
||||||||||||||||||||||||||||||||
for debt at $0.30 per share
|
1,676,977 | 1,677 | - | - | - | 501,416 | - | 503,093 | ||||||||||||||||||||||||
Net loss
|
- | - | - | - | - | - | (72,794 | ) | (72,794 | ) | ||||||||||||||||||||||
Balance, August 31, 2011
|
3,166,977 | 3,167 | - | - | - | 558,926 | (682,973 | ) | (120,880 | ) | ||||||||||||||||||||||
Adjustment for rounding differences
|
8 | - | - | - | - | - | - | - | ||||||||||||||||||||||||
Issuance of common stock in exchange
|
||||||||||||||||||||||||||||||||
for debt at $0.01 per share
|
5,000,000 | 5,000 | - | - | - | 45,000 | - | 50,000 | ||||||||||||||||||||||||
Issuance of common stock in exchange
|
||||||||||||||||||||||||||||||||
for debt at $0.05 per share
|
600,000 | 600 | - | - | - | 29,400 | - | 30,000 | ||||||||||||||||||||||||
Accrued interest waived by stockholders
|
- | - | - | - | - | 9,059 | - | 9,059 | ||||||||||||||||||||||||
Issuance of common stock in exchange
|
||||||||||||||||||||||||||||||||
for services rendered at $0.05 per share
|
515,000 | 515 | - | - | - | 25,235 | - | 25,750 | ||||||||||||||||||||||||
Issuance of common stock in exchange
|
||||||||||||||||||||||||||||||||
for cash at $0.05 per share
|
- | - | 300,000 | 300 | - | 14,700 | - | 15,000 | ||||||||||||||||||||||||
Net loss
|
- | - | - | - | - | - | (64,360 | ) | (64,360 | ) | ||||||||||||||||||||||
Balance, August 31, 2012
|
9,281,985 | 9,282 | 300,000 | 300 | - | 682,320 | (747,333 | ) | (55,431 | ) | ||||||||||||||||||||||
Issuance of common stock in exchange
|
||||||||||||||||||||||||||||||||
for cash at $0.05 per share
|
1,000,000 | 1,000 | (300,000 | ) | (300 | ) | - | 34,300 | - | 35,000 | ||||||||||||||||||||||
Beneficial conversion feature
|
- | - | - | - | - | 59,000 | - | 59,000 | ||||||||||||||||||||||||
Issuance of common stock in exchange
|
||||||||||||||||||||||||||||||||
for oil & gas properties at $0.013 per share
|
500,000 | 500 | 2,000,000 | 2,000 | - | 29,000 | - | 31,500 | ||||||||||||||||||||||||
Issuance of common stock in exchange
|
||||||||||||||||||||||||||||||||
for conversion of debt at $0.05 per share
|
1,180,000 | 1,180 | - | - | - | 57,820 | - | 59,000 | ||||||||||||||||||||||||
Notes payable - related party waived by
|
||||||||||||||||||||||||||||||||
stockholders
|
- | - | - | - | - | 13,966 | - | 13,966 | ||||||||||||||||||||||||
Net loss
|
- | - | - | - | - | - | (129,969 | ) | (129,969 | ) | ||||||||||||||||||||||
Balance, August 31, 2013
|
11,961,985 | $ | 11,962 | 2,000,000 | $ | 2,000 | $ | - | $ | 876,406 | $ | (877,302 | ) | $ | 13,066 |
SARA CREEK GOLD CORP.
|
||||||||
(AN EXPLORATION STAGE COMPANY)
|
||||||||
STATEMENTS OF CASH FLOWS
|
From June 12, 2006
|
||||||||||||
For the Years Ended
|
(Inception) to
|
|||||||||||
August 31, 2013
|
August 31, 2012
|
August 31, 2013
|
||||||||||
Cash flows from operating activities:
|
||||||||||||
Net loss
|
$ | (129,969 | ) | $ | (64,360 | ) | $ | (877,302 | ) | |||
Adjustments to reconcile net loss to net
|
||||||||||||
cash used in operating activities:
|
||||||||||||
(Gain) loss on settlement of debt
|
(8,755 | ) | - | 424,139 | ||||||||
Gain on foreign currency translation
|
(518 | ) | - | (518 | ) | |||||||
Amortization of beneficial conversion feature
|
59,000 | - | 59,000 | |||||||||
Accrued interest on notes payable
|
- | 5,133 | 9,059 | |||||||||
Issuance of common stock for services
|
- | 25,750 | 25,750 | |||||||||
Changes in operating assets and liabilities:
|
||||||||||||
Accounts receivable
|
(1,552 | ) | - | (1,552 | ) | |||||||
Accounts payable
|
23,931 | 7,961 | 81,338 | |||||||||
Accounts payable - related party
|
15,000 | - | 15,000 | |||||||||
Net cash used by operating activities
|
(42,863 | ) | (25,516 | ) | (265,086 | ) | ||||||
Cash flows from investing activities:
|
||||||||||||
Notes receivable, net
|
- | - | (432,894 | ) | ||||||||
Net cash used in investing activities
|
- | - | (432,894 | ) | ||||||||
|
||||||||||||
Cash flows from financing activities:
|
||||||||||||
Proceeds from notes payable
|
- | 25,000 | 618,414 | |||||||||
Repayment of notes payable
|
- | - | (21,355 | ) | ||||||||
Issuance of common stock for cash
|
35,000 | 15,000 | 109,000 | |||||||||
Net cash provided by financing activities
|
35,000 | 40,000 | 706,059 | |||||||||
|
||||||||||||
Net change in cash
|
(7,863 | ) | 14,484 | 8,079 | ||||||||
Cash, beginning of period
|
15,942 | 1,458 | - | |||||||||
Cash, end of period
|
$ | 8,079 | $ | 15,942 | $ | 8,079 | ||||||
- | ||||||||||||
Supplemental disclosure of cash flow information:
|
||||||||||||
Interest paid
|
$ | - | $ | - | $ | - | ||||||
Taxes paid
|
$ | - | $ | - | $ | - | ||||||
Supplemental disclosure of non-cash financing activities
|
||||||||||||
Stock issued in exchange for debt
|
$ | 59,000 | $ | 80,000 | $ | 642,093 | ||||||
Stock issued in exchange for oil & gas properties
|
$ | 31,500 | $ | - | $ | 31,500 | ||||||
Notes payable - related party waived by stockholders
|
$ | 13,966 | $ | - | $ | 13,966 | ||||||
Accrued interest waived by stockholders
|
$ | - | $ | 9,059 | $ | 9,059 |
1.
|
DESCRIPTION OF BUSINESS
|
2.
|
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
|
2.
|
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
|
2.
|
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
|
3.
|
GOING CONCERN
|
4.
|
OIL AND GAS PROPERTIES
|
5.
|
NOTES PAYABLE
|
5.
|
NOTES PAYABLE (CONTINUED)
|
6.
|
INCOME TAX
|
6.
|
INCOME TAX (CONTINUED)
|
August 31,
2013
|
August 31,
2012
|
|||||||
Deferred tax asset:
|
||||||||
Net operating loss
|
$ | 877,302 | $ | 747,333 | ||||
Less: non-deductable expenses
|
(625 | ) | (625 | ) | ||||
876,677 | 746,708 | |||||||
Income tax rate
|
35 | % | 35 | % | ||||
306,837 | 261,348 | |||||||
Less valuation allowance
|
(306,837 | ) | (261,348 | ) | ||||
Deferred tax asset
|
$ | - | $ | - |
7.
|
STOCKHOLDERS’ EQUITY (DEFICIT)
|
7.
|
STOCKHOLDERS’ EQUITY (DEFICIT) (CONTINUED)
|
7.
|
STOCKHOLDERS’ EQUITY (DEFICIT) (CONTINUED)
|
8.
|
LEGAL PROCEEDINGS
|
9.
|
SUBSEQUENT EVENTS
|
9.
|
SUBSEQUENT EVENTS (CONTINUED)
|
Item 9
|
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
|
Item 9A
|
Controls and Procedures
|
|
1.
|
Lack of an audit committee of our Board of Directors.
|
|
2.
|
Inadequate number of accounting and finance personnel or consultants sufficiently trained to address some of the complex accounting and financial reporting matters that arise from time-to-time.
|
|
3.
|
Lack of control procedures and documentation thereof.
|
|
4.
|
Lack of segregation of duties.
|
Item 9B
|
Other Information
|
Item 10
|
Directors, Executive Officers and Corporate Governance
|
Name
|
Age
|
Position
|
Darren Katic
|
40
|
Chief Executive Officer, Chief Financial Officer, President and Director
|
Kristian Andresen
|
41
|
Secretary and Director
|
Item 11
|
Executive Compensation
|
Item 12
|
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
|
|
·
|
By each person who is known by us to beneficially own more than 5% of our Common Stock;
|
|
·
|
By each of our officers and directors; and
|
|
·
|
By all of our officers and directors as a group.
|
Name and address
of beneficial owner
|
Amount of
beneficial
ownership (1)
|
Percent
of class
|
Darren Katic
326 S. Pacific Coast Highway, Suite 102
Redondo Beach, CA 90277
|
6,000,000
|
23.1%
|
Manhattan Holdings, LLC
1800 Washington Blvd Suite 140
Baltimore, MD 21230
|
6,000,000
|
23.1%
|
Ryan Bateman
c/o B&C Capital Ltd
19 Fort Street
P.O. Box 822
Grand Cayman KY1-1103
|
2,500,000 (2)
|
8.9%
|
Gerald Tywoniuk
326 S. Pacific Coast Highway, Suite 102
Redondo Beach, CA 90277
|
2,000,000
|
7.7%
|
Kristian Andresen
10 Market St #328
Camana Bay, GC, Cayman Islands, KY1-9006
|
822,288 (3)
|
3.2%
|
All Officers and Directors (2 persons)
|
6,822,288 (3)
|
26.3%
|
Item 13
|
Certain Relationships and Related Transactions, and Director Independence
|
Item 14
|
Principal Accounting Fees and Services
|
Fiscal
|
Audit-Related
|
|||
Year
|
Audit Fees
|
Fees
|
Tax Fees
|
All Other Fees
|
2012
|
$21,000
|
-
|
-
|
-
|
2013
|
$20,000
|
-
|
-
|
-
|
Item 15
|
Exhibits, Financial Statement Schedules
|
Number
|
Exhibit
|
10.1
|
Amended and Restated Option Agreement dated November 20, 2013.(1)
|
10.2
|
Option Agreement dated October 15, 2013.(2)
|
10.3
|
Agreement and Plan of Reorganization dated September 18, 2013.(3)
|
10.4
|
Assignment of Working Interest dated July 18, 2013.(4)
|
21
|
Subsidiaries
|
23.1
|
Consent of Chapman Petroleum Engineering Ltd.
|
23.2 | Consent of Independent Registered Public Accounting Firm |
31
|
Rule 13a-14(a) Certification of Chief Executive and Chief Financial Officer
|
32
|
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 of Chief Executive and Chief Financial Officer
|
99.1
|
Reserve Report of Chapman Petroleum Engineering Ltd.
|
101.INS*
|
XBRL Instance Document
|
101.SCH*
|
XBRL Taxonomy Extension Schema Document
|
101.CAL*
|
XBRL Taxonomy Extension Calculation Linkbase Document
|
101.LAB*
|
XBRL Taxonomy Extension Label Linkbase Document
|
101.PRE*
|
XBRL Taxonomy Extension Presentation Linkbase Document
|
101.DEF*
|
XBRL Taxonomy Extension Definition Linkbase Document
|
|
(1)
|
Incorporated by reference to Exhibit 10.1 of the Company’s Annual Report on Form 10-K for the fiscal year ended August 31, 2013 filed on November 27, 2013.
|
|
(2)
|
Incorporated by reference to Exhibit 10 of the Company’s Current Report on Form 8-K dated October 21, 2013.
|
|
(3)
|
Incorporated by reference to Exhibit 10 of the Company’s Current Report on Form 8-K dated September 23, 2013.
|
|
(4)
|
Incorporated by reference to Exhibit 10 of the Company’s Current Report on Form 8-K dated July 22, 2013.
|
Sara Creek Gold Corp.
|
||
Date: July 22, 2014
|
/s/ Darren Katic
|
|
Darren Katic
Chief Executive Officer
|
Chapman Petroleum Engineering Ltd.
|
|
/s/ C.W. Chapman, P. Eng. | |
C.W. Chapman, P. Eng.
|
|
President
|
|
445, 708 11th Avenue S.W., Calgary, Alberta
|
|
July 21, 2014
|
1.
|
I have reviewed this annual report on Form 10-K of Sara Creek Gold Corp.; |
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.
|
As the registrant’s sole certifying officer, I am responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal controls 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 my supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to me 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 my 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 my 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.
|
As the registrant’s sole certifying officer, I have disclosed, based on my 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: July 22, 2014
|
/s/ Darren Katic
|
|||
Darren Katic
Chief Executive Officer and Chief Financial Officer
|
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.
|
Date: July 22, 2014
|
/s/ Darren Katic
|
|||
Darren Katic
Chief Executive Officer and Chief Financial Officer
|
PERMIT TO PRACTICE
CHAPMAN PETROLEUM ENGINEERING LTD.
|
|||
Signature
|
[Original Signed By:]
C.W. Chapman
|
||
Date
|
November 25, 2013
|
||
PERMIT NUMBER: P 4201
The Association of Professional Engineers
and Geoscientists of Alberta
|
|
I, C. W. CHAPMAN, P. Eng., Professional Engineer of the City of Calgary, Alberta, Canada, officing at Suite 445, 708 – 11th Avenue S.W., hereby certify:
|
1.
|
THAT I am a registered Professional Engineer in the Province of Alberta and a member of the Australasian Institute of Mining and Metallurgy.
|
2.
|
THAT I graduated from the University of Alberta with a Bachelor of Science degree in Mechanical Engineering in 1971.
|
3.
|
THAT I have been employed in the petroleum industry since graduation by various companies and have been directly involved in reservoir engineering, petrophysics, operations, and evaluations during that time.
|
4.
|
THAT I have in excess of 25 years in the conduct of evaluation and engineering studies relating to oil & gas fields in Canada and around the world.
|
5.
|
THAT I participated directly in the evaluation of these assets and properties and preparation of this report for SCNRG LLC, dated November 19, 2013 and the parameters and conditions employed in this evaluation were examined by me and adopted as representative and appropriate in establishing the value of these oil and gas properties according to the information available to date.
|
6.
|
THAT I have not, nor do I expect to receive, any direct or indirect interest in the properties or securities of SCNRG LLC its participants or any affiliate thereof.
|
7.
|
THAT I have not examined all of the documents pertaining to the ownership and agreements referred to in this report, or the chain of Title for the oil and gas properties discussed.
|
8.
|
A personal field examination of these properties was considered to be unnecessary because the data available from the Company's records and public sources was satisfactory for our purposes.
|
PERMIT TO PRACTICE
CHAPMAN PETROLEUM ENGINEERING LTD.
|
|||
Signature
|
[Original Signed By:]
C.W. Chapman
|
||
Date
|
November 25, 2013
|
||
PERMIT NUMBER: P 4201
The Association of Professional Engineers
and Geoscientists of Alberta
|
|
I, MIRO STROMAR, M. Sc., P. Eng., Professional Engineer of the City of Calgary, Alberta, Canada,officing at Suite 445, 708 – 11th Avenue S.W., hereby certify:
|
1.
|
THAT I am a registered Professional Engineer in the Province of Alberta.
|
2.
|
THAT I graduated from the University of Zagreb with a Masters of Science degree in Chemical Engineering in 1974.
|
3.
|
THAT I have been employed in the petroleum industry since graduation by various companies and have been directly involved in reservoir engineering, petrophysics, operations, and evaluations during that time.
|
4.
|
THAT I have in excess of 20 years in the conduct of evaluation and engineering studies relating to oil & gas fields in Canada and around the world.
|
5.
|
THAT I participated directly in the evaluation of these assets and properties and preparation of this report for SCNRG LLC, dated November 19, 2013 and the parameters and conditions employed in this evaluation were examined by me and adopted as representative and appropriate in establishing the value of these oil and gas properties according to the information available to date.
|
6.
|
THAT I have not, nor do I expect to receive, any direct or indirect interest in the properties or securities of SCNRG LLC, its participants or any affiliate thereof.
|
7.
|
THAT I have not examined all of the documents pertaining to the ownership and agreements referred to in this report, or the chain of Title for the oil and gas properties discussed.
|
8.
|
A personal field examination of these properties was considered to be unnecessary because the data available from the Company's records and public sources was satisfactory for our purposes.
|
|
I, HAROLD J. RYAN, P. Geol., Professional Geologist of the City of Calgary, Alberta, Canada, officing at Suite 445, 708 – 11th Avenue S.W., hereby certify:
|
1.
|
THAT I am a registered Professional Geologist in the Province of Alberta, a Fellow of the Geological Association of Canada and a Fellow of the Geological Society of London.
|
2.
|
THAT I graduated from the University of Calgary with a Bachelor of Science degree in Geology in 1983.
|
3.
|
THAT I have been employed in the petroleum industry since graduation by various companies and have been directly involved in petroleum geology, petrophysics, operations, and evaluations during that time.
|
4.
|
THAT I have in excess of 15 years of experience in the conduct of evaluation and geological studies relating to oil and gas fields in Canada and internationally.
|
5.
|
THAT I participated directly in the evaluation of these assets and properties and preparation of this report for SCNRG LLC, dated November 19, 2013 and the parameters and conditions employed in this evaluation were examined by me and adopted as representative and appropriate in establishing the value of these oil and gas properties according to the information available to date.
|
6.
|
THAT I have not, nor do I expect to receive, any direct or indirect interest in the properties or securities of SCNRG LLC, its participants or any affiliate thereof.
|
7.
|
THAT I have not examined all of the documents pertaining to the ownership and agreements referred to in this report, or the chain of Title for the oil and gas properties discussed.
|
8.
|
A personal field examination of these properties was considered to be unnecessary because the data available from the Company’s records and public sources was satisfactory for our purposes.
|
Scope of Report
|
||
Authorization
|
||
Purpose
|
||
Reserve Definitions
|
||
Barrels of Oil Equivalent
|
||
Sources of Information
|
||
Product Prices
|
||
Product Sales Arrangements
|
||
Capital Expenditures and Operating Costs
|
||
Income Tax Parameters
|
||
Abandonment and Restoration
|
||
Economics
|
||
Constant Price Parameters
|
||
Orientation Map
|
||
Discussion
|
||
CALIFORNIA, USA
|
||
D.E.E.P. Property, Midway – Sunset Field
|
||
Glossary
|
||
Company Representation Letter
|
|
(i) |
The area of the reservoir considered as proved includes:
|
|
(A)
|
The area identified by drilling and limited by fluid contacts, if any, and
|
|
(B)
|
Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.
|
|
(ii)
|
In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.
|
|
(iii)
|
Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.
|
|
(iv)
|
Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when:
|
|
(A)
|
Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and
|
|
(B)
|
The project has been approved for development by all necessary parties and entities, including governmental entities.
|
|
(v)
|
Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.
|
|
(i)
|
When deterministic methods are used, it is as likely as not that actual remaining quantities recovered will exceed the sum of estimated proved plus probable reserves. When probabilistic methods are used, there should be at least a 50% probability that the actual quantities recovered will equal or exceed the proved plus probable reserves estimates.
|
|
(ii)
|
Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with the proved reservoir.
|
|
(iii)
|
Probable reserves estimates also include potential incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than assumed for proved reserves.
|
|
(i)
|
When deterministic methods are used, the total quantities ultimately recovered from a project have a low probability of exceeding proved plus probable plus possible reserves. When probabilistic methods are used, there should be at least a 10% probability that the total quantities ultimately recovered will equal or exceed the proved plus probable plus possible reserves estimates.
|
|
(ii)
|
Possible reserves may be assigned to areas of a reservoir adjacent to probable reserves where data control and interpretations of available data are progressively less certain. Frequently, this will be in areas where geoscience and engineering data are unable to define clearly the area and vertical limits of commercial production from the reservoir by a defined project.
|
|
(iii)
|
Possible reserves also include incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than the recovery quantities assumed for probable reserves.
|
|
(iv)
|
The proved plus probable and proved plus probable plus possible reserves estimates must be based on reasonable alternative technical and commercial interpretations within the reservoir or subject project that are clearly documented, including comparisons to results in successful similar projects.
|
|
(v)
|
Possible reserves may be assigned where geoscience and engineering data identify directly adjacent portions of a reservoir within the same accumulation that may be separated from proved areas by faults with displacement less than formation thickness or other geological discontinuities and that have not been penetrated by a wellbore, and the registrant believes that such adjacent portions are in communication with the known (proved) reservoir. Possible reserves may be assigned to areas that are structurally higher or lower than the proved area if these areas are in communication with the proved reservoir.
|
|
(vi)
|
Pursuant to paragraph (a)(22)(iii) of this section, where direct observation has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves should be assigned in the structurally higher portions of the reservoir above the HKO only if the higher contact can be established with reasonable certainty through reliable technology. Portions of the reservoir that do not meet this reasonable certainty criterion may be assigned as probable and possible oil or gas based on reservoir fluid properties and pressure gradient interpretations.
|
|
i)
|
Ownership and Burdens have been derived from the Company's land records and other information from the Company as required for clarification
|
|
ii)
|
Production data is acquired from public data sources, except for very recent data or certain wells which are provided directly by the Company
|
|
iii)
|
Well data is accessed from the Company's well files and from public data sources
|
|
iv)
|
Operating Costs are based on actual revenue and expense statements provided by the Company for established properties or from discussions with the Company and our experience in the area for new properties
|
|
v)
|
Price differentials are derived from revenue statements, compared to actual posted prices for the appropriate benchmark price over a period of several months
|
|
vi)
|
Timing of Development Plans and Capital estimates are normally determined by discussions with the Company together with our experience and judgement
|
|
a)
|
Table of Formations
|
|
b)
|
Isopach Total Net Monarch Oil Sand
|
|
c)
|
Isopach of Top Oil Sand
|
|
a)
|
D.E.E.P. Lease – Monarch SS
|
|
a)
|
Proved Developed Producing
|
|
b)
|
Proved plus Probable
|
|
a)
|
Development
|
|
b)
|
Abandonment and Restoration
|
|
a)
|
6 Wells, Monarch SS and Top Oil – Proved Developed Producing
|
|
b)
|
D.E.E.P. Lease, California – Total Proved
|
|
c)
|
D.E.E.P. Lease, California – Total Proved Plus Probable
|
|
d)
|
12 Wells, Monarch SS
|
|
e)
|
6 Wells, Monarch SS and Top Oil
|
|
f)
|
12 Wells, Monarch SS
|
Table 1
|
||||||||||||||||
Schedule of Lands, Interests and Royalty Burdens
|
||||||||||||||||
September 1, 2013
|
||||||||||||||||
SCNRG LLC
|
||||||||||||||||
D.E.E.P Lease, Kern Co., California
|
||||||||||||||||
Appraised Interest
|
Royalty Burdens
|
||||||||||||
Rights
|
Gross
|
Working
|
Royalty
|
Basic
|
Overriding
|
||||||||
Description
|
Owned
|
Acres
|
%
|
%
|
%
|
%
|
|||||||
Twp 11N Rge 23W
|
|||||||||||||
Sec 7:W/2 lsd 2, W/2 lsd 7
|
[A]
|
40
|
66.6700
|
-
|
FH-20.92
|
-
|
Summary of Reserves
|
||||||||||||||
September 1, 2013
|
||||||||||||||
D.E.E.P Lease, Kern Co., California
|
Current or
|
||||||||||||||||||||||||
Initial
|
API
|
Ultimate
|
Cumulative
|
Remaining
|
||||||||||||||||||||
Rate
|
Gravity
|
ROIP
|
Production
|
ROIP
|
||||||||||||||||||||
Description
|
STB/d
|
(Deg)
|
(MSTB)
|
(MSTB)
|
(MSTB)
|
Reference
|
||||||||||||||||||
Heavy Oil
|
||||||||||||||||||||||||
Proved Developed Producing
|
||||||||||||||||||||||||
Six Wells
|
Monarch and Top Oil
|
4 | 15 | 126 | 122 | 4 |
Figure 3a
|
|||||||||||||||||
Total Proved Developed Producing
|
4 | 126 | 122 | 4 | ||||||||||||||||||||
Proved Undeveloped
|
||||||||||||||||||||||||
Thermal Project - Development
|
Monarh SS
|
15 | 335 | 0 | 335 |
Table 2a
|
||||||||||||||||||
Total Proved Undeveloped
|
335 | 0 | 335 | |||||||||||||||||||||
Total Proved
|
461 | 122 | 339 | |||||||||||||||||||||
Probable
|
||||||||||||||||||||||||
Six Wells
|
Monarch and Top Oil
|
(incr.)
|
15 | 2 | 0 | 2 |
Figure 3b
|
|||||||||||||||||
Thermal Project - Development
|
Monarh SS
|
(incr.)
|
15 | 167 | 0 | 167 |
Table 2a
|
|||||||||||||||||
Total Probable
|
169 | 0 | 169 | |||||||||||||||||||||
Total Proved Plus Probable
|
630 | 122 | 508 |
Table 3a
|
||||||||||
Summary of Anticipated Capital Expenditures
|
||||||||||
Development
|
||||||||||
September 1, 2013
|
||||||||||
SCNRG LLC
|
||||||||||
D.E.E.P Lease, Kern Co., California
|
Capital
|
Gross
|
Net
|
||||||||||||||
Interest
|
Capital
|
Capital
|
||||||||||||||
Description
|
Date
|
Operation
|
%
|
M$ | M$ | |||||||||||
Proved Undeveloped
|
||||||||||||||||
Drill twelwe wells
|
2014
|
Drill twelwe wells
|
66.6700 | 4,600 | 3,067 | |||||||||||
Upgrade facilities
|
2015
|
Expand facilities
|
66.6700 | 640 | 427 | |||||||||||
Total Proved Undeveloped
|
5,240 | 3,494 | ||||||||||||||
Total Proved
|
5,240 | 3,494 | ||||||||||||||
Note:
|
The above capital values are expressed in terms of current dollar values without escalation.
|
Table 3b
|
||||||||||||
Summary of Anticipated Capital Expenditures
|
||||||||||||
Abandonment and Restoration
|
||||||||||||
September 1, 2013
|
||||||||||||
SCNRG LLC
|
||||||||||||
D.E.E.P Lease, Kern Co., California
|
||||||||||||
Working
|
Gross
|
Net
|
||||||||||
Interest
|
Capital
|
Capital
|
||||||||||
Well location
|
Operation
|
Year
|
%
|
M$
|
M$
|
|||||||
Abandon wells and future locations
|
Abandon 17 wells
|
66.6700
|
300.0
|
200.0
|
||||||||
Total
|
300.0
|
200.0
|
||||||||||
Table 4 | Contact Prices & Costs |
Summary of Company Reserves and Economics
|
|
Before Income Tax
|
|
September 1, 2013
|
|
SCNRG LLC
|
|
D.E.E.P. LEASE, CALIFORNIA
|
N e t T o A p p r a i s e d I n t e r e s t | |||||||||||||||||||||||||||
Reserves
|
Cumulative Cash Flow (BIT) - M$
|
||||||||||||||||||||||||||
Light and Medium Oil
|
Heavy Oil
|
Sales Gas |
NGL
|
||||||||||||||||||||||||
MSTB
|
MSTB
|
MMscf
|
Mbbls
|
Discounted at:
|
|||||||||||||||||||||||
Description
|
Gross
|
Net
|
Gross
|
Net
|
Gross
|
Net
|
Gross
|
Net
|
Undisc.
|
5%/year
|
10%/year
|
15%/year
|
20%/year
|
||||||||||||||
Proved Developed Producing
|
|
|
|
|
|
|
|||||||||||||||||||||
Total Monarch SS and Top Oil |
0
|
0
|
2
|
2
|
0
|
0
|
0
|
0
|
64
|
61
|
57
|
54
|
52
|
||||||||||||||
Total Proved Developed Producing
|
0
|
0
|
2
|
2
|
0
|
0
|
0
|
0
|
64
|
61
|
57
|
54
|
52
|
||||||||||||||
Proved Undeveloped
|
|||||||||||||||||||||||||||
12 Wells Monarch SS |
0
|
0
|
223
|
177
|
0
|
0
|
0
|
0
|
6,327
|
4,536
|
3,227
|
2,255
|
1,523
|
||||||||||||||
Total Proved Undeveloped
|
0
|
0
|
223
|
177
|
0
|
0
|
0
|
0
|
6,327
|
4,536
|
3,227
|
2,255
|
1,523
|
||||||||||||||
Total Proved
|
0
|
0
|
226
|
179
|
0
|
0
|
0
|
0
|
6,391
|
4,597
|
3,284
|
2,309
|
1,575
|
||||||||||||||
Probable
|
|||||||||||||||||||||||||||
Probable Developed Producing
|
|||||||||||||||||||||||||||
Total Monarch SS and Top Oil |
Incr.
|
0
|
0
|
1
|
1
|
0
|
0
|
0
|
0
|
40
|
34
|
30
|
26
|
23
|
|||||||||||||
Total Probable Developed Producing
|
0
|
0
|
1
|
1
|
0
|
0
|
0
|
0
|
40
|
34
|
30
|
26
|
23
|
||||||||||||||
Probable Undeveloped
|
|||||||||||||||||||||||||||
12 Wells Monarch SS |
Incr.
|
0
|
0
|
112
|
88
|
0
|
0
|
0
|
0
|
6,114
|
4,910
|
4,013
|
3,331
|
2,804
|
|||||||||||||
Total Probable Undeveloped
|
0
|
0
|
112
|
88
|
0
|
0
|
0
|
0
|
6,114
|
4,910
|
4,013
|
3,331
|
2,804
|
||||||||||||||
Total Probable
|
0
|
0
|
113
|
89
|
0
|
0
|
0
|
0
|
6,154
|
4,944
|
4,043
|
3,357
|
2,827
|
||||||||||||||
Total Proved Plus Probable
|
0
|
0
|
339
|
268
|
0
|
0
|
0
|
0
|
12,545
|
9,541
|
7,327
|
5,666
|
4,402
|
||||||||||||||
|
M$ means thousands of United States dollars
|
Gross reserves are the total of the Lease's working and/or royalty interest share before deduction of royalties owned by others.
|
Net reserves are the total of the Lease's working and/or royalty interest share after deducting the amounts attributable to royalties owned by others.
|
Columns may not add precisely due to accumulative rounding of values throughout the report.
|
BIT
|
-
|
Before Income Tax
|
AIT
|
-
|
After Income Tax
|
M$
|
-
|
Thousands of Dollars
|
Effective Date
|
-
|
The date for which the Present Value of the future cash flows and reserve categories are established
|
$US
|
-
|
United States Dollars
|
WTI
|
-
|
West Texas Intermediate – the common reference for crude oil used for oil price comparisons
|
ARTC
|
-
|
Alberta Royalty Tax Credit
|
GRP
|
-
|
Gas Reference Price
|
BPO
|
-
|
Before Payout
|
APO
|
-
|
After Payout
|
APPO
|
-
|
After Project Payout
|
Payout
|
-
|
The point at which a participant’s original capital investment is recovered from its net revenue
|
GORR
|
-
|
Gross Overriding Royalty – percentage of revenue on gross revenue earned (can be an interest or a burden)
|
NC
|
-
|
New Crown – crown royalty on petroleum and natural gas discovered after April 30, 1974
|
SS 1/150 (5%-15%) Oil
|
-
|
Sliding Scale Royalty – a varying gross overriding royalty based on monthly production. Percentage is calculated as 1-150th of monthly production with a minimum percentage of 5% and a maximum of 15%
|
FH
|
-
|
Freehold Royalty
|
P&NG
|
-
|
Petroleum and Natural Gas
|
Twp
|
-
|
Township
|
Rge
|
-
|
Range
|
Sec
|
-
|
Section
|
psia
|
-
|
Pounds per square inch absolute
|
MSTB
|
-
|
Thousands of Stock Tank Barrels of oil (oil volume at 60 F and 14.65 psia)
|
MMscf
|
-
|
Millions of standard cubic feet of gas (gas volume at 60 F and 14.65 psia)
|
Bbls
|
-
|
Barrels
|
Mbbls
|
-
|
Thousands of barrels
|
MMBTU
|
-
|
Millions of British Thermal Units – heating value of natural gas
|
STB/d
|
-
|
Stock Tank Barrels of oil per day – oil production rate
|
Mscf/d
|
-
|
Thousands of standard cubic feet of gas per day – gas production rate
|
GOR (scf/STB)
|
-
|
Gas-Oil Ratio (standard cubic feet of solution gas per stock tank barrel of oil)
|
mKB
|
-
|
Metres Kelly Bushing – depth of well in relation to the Kelly Bushing which is located on the floor of the drilling rig. The Kelly Bushing is the usual reference for all depth measurements during drilling operations.
|
EOR
|
-
|
Enhanced Oil Recovery
|
GJ
|
-
|
Gigajoules
|
Marketable or Sales
Natural Gas
|
-
|
Natural gas that meets specifications for its sale, whether it occurs naturally or results from the processing of raw natural gas. Field and plant fuel and losses to the point of the sale must be excluded from the marketable quantity. The heating value of marketable natural gas may vary considerably, depending on its composition; therefore, quantities are usually expressed not only in volumes but also in terms of energy content. Reserves are always reported as marketable quantities.
|
NGLs
|
-
|
Natural Gas Liquids – Those hydrocarbon components that can be recovered from natural gas as liquids, including but not limited to ethane, propane, butanes, pentanes plus, condensate, and small quantities of non-hydrocarbons.
|
Raw Gas
|
-
|
Natural gas as it is produced from the reservoir prior to processing. It is gaseous at the conditions under which its Volume is measured or estimated and may include varying amounts of heavier hydrocarbons (that may liquefy at atmospheric conditions) and water vapour; may also contain sulphur and other non-hydrocarbon compounds. Raw natural gas is generally not suitable for end use.
|
1.
|
We, SCNRG LLC, (the Client) have made available to you, Chapman Petroleum Engineering Ltd. (the Evaluator) certain records, information, and data relating to the evaluated properties that we confirm is, with the exception of immaterial items, complete and accurate as of the effective date of the reserves evaluation, including the following:
|
•
|
Accounting, financial, tax and contractual data
|
•
|
Asset ownership and related encumbrance information;
|
•
|
Details concerning product marketing, transportation and processing arrangements;
|
•
|
All technical information including geological, engineering and production and test data;
|
•
|
Estimates of future abandonment and reclamation costs.
|
2.
|
We confirm that all financial and accounting information provided to you is, to the best of our knowledge, both on an individual entity basis and in total, entirely consistent with that reported by our Company for public disclosure and audit purposes.
|
3.
|
We confirm that our Company has satisfactory title to all of the assets, whether tangible, intangible, or otherwise, for which accurate and current ownership information has been provided.
|
4.
|
With respect to all information provided to you regarding product marketing, transportation, and processing arrangements, we confirm that we have disclosed to you all anticipated changes, terminations, and additions to these arrangements that could reasonably be expected to have a material effect on the evaluation of our Company's reserves and future net revenues.
|
5.
|
Withthe possible exception of items of an immaterial nature, we confirm the following as of the effective date of the evaluation:
|
•
|
For all operated properties that you have evaluated, no changes have occurred or are reasonably expected to occur to the operating conditions or methods that have been used by our Company over the past twelve (12) months, except as disclosed to you. In the case of non-operated properties, we have advised you of any such changes of which we have been made aware.
|
•
|
All regulatory, permits, and licenses required to allow continuity of future operations and production from the evaluated properties are in place and, except as disclosed to you, there are no directives, orders, penalties, or regulatory rulings in effect or expected to come into effect relating to the evaluated properties.
|
•
|
Except as disclosed to you, the producing trend and status of each evaluated well or entity in effect throughout the three-month period preceding the effective date of the evaluation are consistent with those that existed for the same well or entity immediately prior to this three month period.
|
•
|
Except as disclosed to you, we have no plans or intentions related to the ownership, development or operation of the evaluated properties that could reasonably be expected to materially affect the production levels or recovery of reserves from the evaluated properties.
|
•
|
If material changes of an adverse nature occur in the Company's operating performance subsequent to the effective date and prior to the report date, we will inform you of such material changes prior to requesting your approval for any public disclosure of reserves information.
|
6.
|
We hereby confirm that our Company is in material compliance with all Environmental Laws and does not have any Environmental Claims pending.
|
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