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Application Resource Book
December 2006
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TABLE OF CONTENTS
APPLICATION INFORMATION
COMPLIANCE AND ENFORCEMENT
GENERAL DEVELOPMENT PERMITS
GEOPHYSICAL
MISCELLANEOUS
OPERATIONS ENGINEERING
PIPELINES AND FACILITIES
RESERVOIR ENGINEERING
WELLS AND TEST HOLES INTRODUCTION
USER FRIENDLY FORMAT
USAGE AND PRINTING INSTRUCTIONS
APPLICATION INFORMATION
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When submitting notification of an amalgamation or a name change, or requesting assignment of surface rights and tenures, the following must be completed. For further information on any requirements listed below, please call (250) 261-5700 and ask to speak to an Examiner:
FOR AN AMALGAMATION OR A NAME CHANGE OF SURFACE RIGHTS AND TENURES THE FOLLOWING MUST BE SUBMITTED: Copy of British Columbia Corporate Registry Amalgamation or Name Change Certificate (Alberta or Saskatchewan certificates are not acceptable and will be returned)
Proof of liability insurance in the amount of $1,000,000 (Oil and Gas commission and Her Majesty the Queen in Right of the Province of British Columbia, her employees, servants and agents to be added as named insured) in the new company name
GST Registration number of the new company
Ensure Additional Requirements listed below are completed
FOR AN ASSIGNMENT OF SURFACE RIGHTS AND TENURES THE FOLLOWING MUST BE SUBMITTED: One original Assignment of Surface Tenure Agreement (including a schedule of Crown file numbers and/or document numbers, plan number and location, and company file numbers)
Proof of liability insurance in the amount of $1,000,000 (Oil and Gas commission and Her Majesty the Queen in Right of the Province of British Columbia, her employees, servants and agents to be added as named insured) in the new company name
GST Registration number of Assignee
Ensure Additional Requirements listed below are completed
Note: Temporary Permits, expired documents and access roads are not assignable. Access roads that have Petroleum Development Road status may be transferred. For further information contact the Oil & Gas Resource Officer responsible for PDR’s ADDITIONAL REQUIREMENTS - for all amalgamations, name changes and assignments: Pre-application requirements must be met
Assignee must be a registered company in British Columbia. For further information contact:Corporate Registry Website Transfer of Well Authorization and Change of Well Name
Required Fees Well Authorization Transfer Agreement Transfer of Pipeline Project
Required Fees Property taxes must be paid
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Revised April,1 2006
Cheque to be made payable to the Minister of Finance
There are no application fees required for the following: Land Act Applications – Temporary Permit, Licence Of Occupation, Statutory Right of Way, Assignment of Land Act Dispositions |
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The following is a list of items, which clients should complete prior to submitting applications to the Oil & Gas Commission:
To be eligible to conduct business in British Columbia, corporations must be registered with BC Corporate Registry in the Province of British Columbia or incorporated under the laws of Canada. For further information, contact the Registrar of Companies at (250) 387-5101.
A drilling deposit must be submitted to the Ministry of Energy and Mines under Section 4 of the Petroleum and Natural Gas General Regulation, as security for the proper drilling, control, completion, suspension or abandonment of a well or test hole, and to provide for the reclamation and restoration of well sites or test hole sites. For further information, contact the Oil & Gas Commission at (250) 261-5700 and ask to speak with an Examiner.
Comprehensive general liability insurance with a limit of $1,000,000 (Oil and Gas Commission and Her Majesty the Queen in Right of the Province of British Columbia, her employees, servants and agents to be added as named insured) is required in order to hold a Crown land surface tenure document.
A Master Licence to Cut on Crown land is required for each forest district you will be working within (Peace and Fort Nelson). For further information, contact Sheila Tompkins at (250) 261-5709 or Susan Paulsen at (250) 261-5704.
For guidance regarding wellsite, pipeline and facility construction, reference the forms and guidelines on the OGC web site or the British Columbia Oil and Gas Handbook. |
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The following government agencies should be informed when oil and gas assets are being transferred:
WELLS
Approval of well transfers is required under the Drilling and Production Regulation. Submit an Application to Transfer a Well Authorization and an Application To Change a Well Name, along with the appropriate fees (no GST) with the cheque made payable to Minister of Finance. Project Assessment Branch For general inquiries contact: (250) 261-5700 and ask to speak to an examiner. SURFACE RIGHTS AND TENURES
(Wellsites, Pipelines, Production Facilities, etc.)
Assignment of an interest in a Surface Lease, License or Right of Way on Crown land requires approval under the Land Act. Project Assessment Branch For general inquiries contact: (250) 261-5700 and ask to speak to an examiner. PRODUCTION FACILITIES
(Batteries, Compressor Stations, Dehydrators)
Transfer of production facilities requires approval under the Drilling and Production Regulation. Project Assessment Branch For general inquiries contact: George Holland (250) 261-5760 or George.Holland@gems6.gov.bc.ca PIPELINESTransfer of pipeline ownership requires approval under the Pipeline Act. Compliance and Enforcement Branch For general inquiries contact: (250) 261-5700 and ask to speak to an examiner. PETROLEUM DEVELOPMENT ROADSAnnual Letter, company transfer requests, change of operator name must be submitted to the OGC. Termination of appointment as operator must be submitted as a letter of intent under the Petroleum Development Road Regulation. Project Assessment Branch For general inquiries contact: Margaret Fenton (250) 261-5719 or Margaret.Fenton@gems4.gov.bc.ca PROPERTY ASSESSMENT AND TAXATIONTransfer of production processing and pipeline facilities (this includes everything from small wellsite facilities to large gas plants), is required in accordance with the Assessment Act. For general inquiries contact: For general inquiries contact: Herb Lexa (250) 782-8515 or 1-800-990-1160 or Herb.Lexa@gems7.gov.bc.ca SUBSURFACE OIL AND GAS RIGHTSTo register changes in ownership of Petroleum and Natural Gas Leases, Drilling Licenses and Permits Energy and Minerals Division, Petroleum Lands Branch For general inquires contact: Christine McCarthy (250) 952-0341 or Christine.McCarthy@gems4.gov.bc.ca |
COMPLIANCE AND ENFORCEMENT
| The Adobe Acrobat document containing the Compliance and Enforcement Deficiency Codes is available here. |
| The Adobe Acrobat document containing the Compliance and Enforcement Equipment Spacing for Well Servicing Conventional Wells is available here. |
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| The Adobe Acrobat file containing the Surface Equipment Spacing Guideline is available here. |
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Re: Vegetation Control
The following are recommended measures for vegetation control at various oilfield facilities pursuant to Regulation 62 (Fire Control) of The Drilling and Production Regulations. General - All facilities are to be kept free of noxious weeds at all times and other vegetation control is as follows:
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GENERAL DEVELOPMENT PERMITS
GEOPHYSICAL
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| To view the Environmental Upgrade & Minor Changes to Approved Activities Spreadsheet, please click here. |
| The Microsoft Excel Spreadsheet containing the Geophysical Final Line Width Data Sheet is available here. |
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File # _______________________
Company: ____________________WA # _______________________ Geo # _______________________ GDP XRef # _______________________ Land Agent _______________________ Project: ____________________ Based on an Application Pre-Assessment, an application package for the above-noted project was NOT sent to the _______________ First Nation(s) for review for the following reasons (explanation of what is being applied for and why): Application Notes: Total area required for the project: _______ hectares Is the area required within an existing cleared area: Yes No Partially
Is this an Amendment or a Revision?
If this is an amendment, please indicate the difference in the area required from what was originally proposed: Increase of ____ hectares; Decrease of ____ hectares; No change in area required
If this is an amendment, were there any issues identified by First Nations in the original application? Yes No If yes, please elaborate:
Trapper notification sent: Yes No
Project Assessment Branch First Nation Comments: Agree Disagree ________________________________ _________________ Senior Aboriginal Program Specialist Date Upon completion return to: _____________________________________ Project Assessment Branch Program Manager |
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File # _____________
To:WA # _____________ Geo # _____________ GDP XRef # _____________ Kelly Lake Cree Nations Kelly Lake First Nation Kelly Lake Metis Settlement Society Other The Oil and Gas Commission has received an application for a:
Proponent/Company: _________________________ Project Name: _________________________ For your information, attached is a copy of the application package for the above noted project proposed for development in your area. Any comments can be sent to the attention of the Area Director, Project Assessment Branch at the address below. Attachments: Timber Harvesting & Field Assessment Geophysical Application and Field Assessment Survey/Construction Plan (if applicable) 1:20,000 BCGS Sketch Plan (Pipelines Only) 1:50 000 Project Map 1:250 000 Access Map AAIF (Archaeological Assessment Information Form) |
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Fish and Wildlife Timing Windows for Oil and Gas Exploration and Development in Northeast British Columbia
Background The purpose of this document is to provide direction with respect to fish and wildlife timing windows for oil and gas operations in northeast British Columbia. When accompanied by appropriate, mitigation measures, adherence to timing windows is a valuable tool in reducing industrial disturbances to fish and wildlife species during sensitive lifecycle stages. Harassment or disruption of wildlife is prohibited at any time under the Wildlife Act of British Columbia; as such, operators are advised to be mindful of potential impacts regardless of the timing of operations. In addition, these windows may require a site-specific review to determine the level of sensitivity to a particular operation. Timing windows may be subject to revision or refinement by the Oil and Gas Commission, as well as other Provincial and Federal agencies. Throughout the lifecycles of most species, there are critical stages of development during which fish and wildlife are more sensitive to particular types of disturbance. In the Peace Region, it has been observed that many species are most susceptible during early life stages. Some species are also sensitive to disturbance during seasonal migrations, rutting, and while occupying their winter habitat. The attached table of timing windows considers a selection of species only. This list was reduced to those species that are considered to be: 1) ecosystem indicators, 2) of special management concern, and 3) those that are more susceptible to disturbance. In the event that additional species of concern are detected at a site, an operator should seek direction from the Oil and Gas Commission regarding the appropriateness of added timing considerations. The type of disturbance is an important factor in planning the timing of oil and gas operations. Typically, on fish bearing watercourses, most in-stream works are subject to timing windows. In comparison, terrestrial wildlife can be particularly sensitive to aerial disruptions; and therefore, timing windows are commonly applied to geophysical operations. Timing windows may also apply to ground based operations where site sensitivities are high. Site sensitivity is primarily determined by the species present, habitat type, abundance of habitat, forest cover type (e.g., open versus closed forest canopy), and the importance of a habitat type to a critical lifecycle stage. Variances and Mitigation The Oil and Gas Commission will consider a variance request for an identified timing window, if an application is accompanied by a mitigation plan outlining how potential adverse impacts to wildlife will be minimized. Mitigation plans must clearly identify: 1) rationale for operating outside of a timing window, 2) site specific habitat information (including photos), 3) the species potentially impacted by activities, 4) inventory information available for any species at risk affected, 5) operational modifications to reduce the impacts to wildlife, and 6) project monitoring. Issues that potentially could be addressed in a mitigation plan include, but are not limited to the following:
Monitoring plays a key role in the development of mitigation strategies, as it permits project modifications to occur as more site-specific information becomes available. Any project monitoring and assessments must be conducted by a qualified environmental technician/biologist, who has experience working with the species and ecosystems of concern. The monitor retained for use on a specific project must be able to issue stop work orders and recommend project modifications, as necessary. Additional information pertaining to setbacks for specific habitat features can be found in the Planning and Construction Guide (2004) document published by the Oil and Gas Commission. Fisheries work windows and Best Management Practices are further defined in the Forest Practices Code of British Columbia – Fish Stream-crossing Guidebook (March 2002). Also note specific timing requirements in any relevant land use plans, pre-tenure plans and tenure caveats, etc. |
| The Microsoft Word document containing the Fish and Wildlife Timing Windows Table is available here. |
| The Microsoft Word document containing the Fish Stream Identification Risk Management Tool is available here. Please note the file size for this document is 12.6 MB. |
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| The Microsoft Word document containing the Geophysical Application and Field Assessement Guide is available here. |
Please use this guideline to assist in a timely review of each application.
Sections 1 to 3 inclusive apply to all applications
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Please use this guideline to assist in a timely review of each application.
For amendments on private property - see Sections 1 to 3 inclusive
For amendments on Crown land - see Sections 1 to 4 inclusive
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Please use this guideline to assist in a timely review of each application.
For geophysical applications on private land only - see Sections 1 and 2. For geophysical applications on Crown land - see Sections 1 to 4 inclusive.
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Before Application – Pre-work
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Please use this guideline to assist in a timely review of each application.
A revision should be submitted if program lines are shifted and/or increased in length by 400 meters or more, or if additional new cut lines or access are added to the program.
For revisions on private property - see Sections 1 to 3 inclusive.
For revisions on Crown land - see Sections 1 to 5 inclusive.
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Please use this guideline to assist in a timely review of each application.
Use this guideline for all applications on Crown land unless a specific guideline exists for your application type.
Sections 1 to 3 inclusive and section 5 apply to all applications.
Section 4 is not required if the area being applied for is located fully within an existing clearing.
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Background For heli-assisted/heliportable geophysical programs proposed within the province of British Columbia, the Oil and Gas Commission (OGC) has developed a guideline to assist companies in selecting helipad locations. The guideline provides direction that helps mitigate the impacts of helipad construction on the forested landbase, and the ecosystems comprising it. This Helipad Placement Guideline will continually be revised and updated as new information becomes available. Companies operating in British Columbia are encouraged to monitor the OGC website to check for updated versions of this guide. Application Submission Requirements Geophysical application submissions to the Oil and Gas Commission must clearly:
Site Selection Criteria Helipads are to be placed utilizing the following criteria, which appear in order of increasing habitat and timber values:
* Reforested areas including naturally regenerating aspen plantations will be treated as immature types (ranked as the 5th choice above). Any operations proposed within areas under active forest management should be planned to minimize negative effects on the Crown investment in the province’s future forest resource. General Protection Measures Wildlife Habitat Although some naturally open areas or forest landscapes with a lesser timber value would present themselves as prime helipad locations, the habitat value of these areas and the impacts of helicopter traffic on wildlife, to and from these locations, cannot be dismissed. As a generalization, such areas, at specific times of the year can provide critical habitat for a variety of species life requisites. This stated, the Oil and Gas Commission requires that the following mitigative measures be incorporated into helipad site selection.
Compliance With Other Legislation and Regulations Be advised that the upfront direction provided within this document does not supersede the requirements of the Worker’s Compensation Act or it’s regulation, or any other related provincial or federal legislation. For further information regarding this guideline, please contact the Geophysical Program Manager. |
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ACCESS
Time of Year:
Location of Access:
Natural Barrier:
SLASH
RANGE IMPROVEMENT DAMAGE – Rates to be removed or revised.
WELLSITES
OTHER
APPROVED PROJECTS REFER TO THIS GUIDE DISPUTES REFER TO MINISTRY OF FORESTS |
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The following will assist the Oil and Gas Proponent or Designate in accurately completing the Oil and Gas Commission (OGC) Application for Road Use Permit Form (RUP). A Road Use Permit is required to utilize Ministry of Forests (MoF) designated Forest Service Roads (FSR’s) in British Columbia.
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FORT NELSON DISTRICT - FORAGE SEED RECLAMATION MIX May 2003 DRY FOOTHILLS SITE MIX
RIVER BANKS It is suggested that all those involved in this project review the "Native Plant Re-vegetation Guidelines for Alberta, February 2001". This document is a great resource, and is ahead of what is being done in BC. This document can be viewed at: http://www.agric.gov.ab.ca/publiclands/nprg/.
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PEACE DISTRICT - FORAGE SEED RECLAMATION MIX May 2003
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File: 19720-10 PRWA, Woodlot Licensees
December 05, 2000 To: Woodlot Licensees in the Fort St. John Forest District From: Ministry of Forests, Fort St. John Forest District Re: Seismic and Pipeline Referrals on Woodlot License Areas As many of you are aware, any oil and gas activities being proposed on your woodlot are referred to you by a company or industry representative for your information and comments. As multiple forest tenures cannot be issued over a woodlot area, the License to Cut cutting permit issued by the Oil and Gas Commission (OGC) does not apply over your woodlot area. Thus to legally encompass the cutting of trees associated with these oil and gas activities within your woodlot, the Ministry of Forests has been issuing a Cutting Permit “Z” (CP Z) in the name of the Woodlot Licensee. What does this mean to you? Since the CP “Z” is issued in your name, this also makes you legally responsible for the harvesting activities associated with the oil and gas activities occurring under your tenure. What this means is that any infractions, as determined under the Forest Practices Code of British Columbia Act or the Forest Act, as a result of their activities under the CP “Z” apply firstly to the Woodlot Licensee. Please be well aware of this fact when completing a referral with an oil and gas company representative discussing proposed operations within your woodlot. The company responsible for the operation is ultimately working under your tenure, so careful consideration should be given when deciding what the desired end result should be. Whether the program is for seismic or pipeline, ensure that the contract entered into details your expectations clearly, and that both parties understand these expectations. Should there be an infraction the standard of care you have exercised with the company in detailing your expectations of their activities under your cutting permit will be determined by evaluating the circumstances on a case by case basis. The CP “Z” also allows for the accurate recording of the amount of timber harvested on your woodlot area due to these oil and gas activities. All of this timber is recorded against your five year cut control commitment which may allow for future adjustments. Your Allowable Annual Cut (AAC) as determined for your woodlot is based on the utilization of all merchantable timber within the woodlot. Therefore, any timber that is cut through the use of low impact seismic operations, which is left behind and not utilized, would still contribute to your cut control position and in addition, the Woodlot Licensee may be billed for residual waste. If the program is large, or a 3D seismic, this can result in a significant loss of volume in the cut control period if the timber is wasted. Should you require any further clarification on any of the above information, please do not hesitate to contact the Fort St. John Forest District at 787-5600. |
| The Microsoft Word document containing the Stream Crossing Planning Guide is available here. |
MISCELLANEOUS
| The Microsoft Word document containing the Fish Stream Identification Risk Management Tool is available here. Please note the file size for this document is 12.6 MB. |
Please use this guideline to assist in a timely review of each application.
Sections 1 to 4 inclusive apply to all gate applications.
Section 5 only applies to those gate applications where cutting of timber is required.
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Please use this guideline to assist in a timely review of each application.
Use this guideline for all applications on Crown land unless a specific guideline exists for your application type.
Sections 1 to 3 inclusive and section 5 apply to all applications.
Section 4 is not required if the area being applied for is located fully within an existing clearing.
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Please use this guideline to assist in a timely review of each application.
Sections 1 to 3 inclusive and section 5 apply to all applications.
Sections 4 is not requested if the area being applied for is located fully within an existing clearing.
NOTE: This package is only required if the project being applied for is located within the Fort Nelson First Nation, Prophet River First Nation traditional use areas, and any area outside the Fort Nelson and Peace Forest Districts of Northeast BC. Note: Include one package for each First Nation Community listed on the consultation cover letter or consultation pre-assessment form. |
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| The Microsoft Word Document containing the Application to use land in an Agricultural Land Reserve for Oil and Gas Purposes is available here. |
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The following will assist the Oil and Gas Proponent or Designate in accurately completing the Oil and Gas Commission (OGC) Application for Road Use Permit Form (RUP). A Road Use Permit is required to utilize Ministry of Forests (MoF) designated Forest Service Roads (FSR’s) in British Columbia.
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| The Microsoft Word document containing the Stream Crossing Planning Guide is available here. |
OPERATIONS ENGINEERING
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The form is designed to capture all the required information for flaring approval as required by the Drilling and Production Regulation and the Oil and Gas Waste Regulation.
Section 71(4) of the Drilling and Production Regulation states:
For the first category of well test, notification to the Ministry of Water, Land and Air Protection (MWALP) is not required and there are no discharge fees. The second category will require payment of discharge fees in accordance with Section 9 of the Oil and Gas Waste Regulation. For the purposes of the Oil and Gas Waste Regulation, a manager means the Regional Waste Manager, Pollution Prevention, MWALP. Contact Address: 325, 1011 Fourth Avenue, Prince George, BC, V2L 3H9. Phone: (250) 565-6155, Fax: (250) 565-6629 The completion of the form will ensure the approval process is completed as quickly as possible. It should be noted the completed form must be submitted at least 5 working days prior to the proposed flaring. As some of the information submitted on the form to MWALP may be of a confidential nature, MWALP, under the Freedom of Information and Protection of Privacy Act will not be required to release any information submitted to them by the Oil and Gas Commission and any release of information by the Oil and Gas Commission will be in accordance with section 57 of the Drilling and Production Regulation. Oil and Gas Commission and Ministry of Water, Land, and Air Protection (MWALP) require the information provided in this application. If the estimated H2S content is equal to or greater than 5%, the Commission will forward this approved application to the Regional Waste Manager, Pollution Prevention, MWALP. Section 1 - Well Information
Section 2 - Details of Proposed Flaring
Section 3 - Well and Formation Information
Section 4 - Operator Information
Section 5 - Commission Use Only
The personal information requested on this form is collected under the authority of and used for the purpose of administering the Petroleum and Natural Gas Act and the Waste Management Act. Under certain circumstances, some information may be released subject to the provisions of the Freedom of Information and Protection of Privacy Act. If you have any questions about the collection, use or disclosure of this information, contact the Corporate Services Branch, Records Administrator, in Fort St. John at the address above. |
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Unique Well Identifier (UWI)
The unique well identifier is the standard 16-character code which defines the bottom hole location and each significant drilling or completion event in the well. UWI in the Dominion Land Survey System Example well location 14-36-85-17 W6 UWI 100 14 36 085 17 W6 00
UWI in the NTS System Example well location d-96-H/94-A-15 UWI 200 D 096 H 094A15 00
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PIPELINES AND FACILITIES
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| To view the Environmental Upgrade & Minor Changes to Approved Activities Spreadsheet, please click here. |
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File # _______________________
Company: ____________________WA # _______________________ Geo # _______________________ GDP XRef # _______________________ Land Agent _______________________ Project: ____________________ Based on an Application Pre-Assessment, an application package for the above-noted project was NOT sent to the _______________ First Nation(s) for review for the following reasons (explanation of what is being applied for and why): Application Notes: Total area required for the project: _______ hectares Is the area required within an existing cleared area: Yes No Partially
Is this an Amendment or a Revision?
If this is an amendment, please indicate the difference in the area required from what was originally proposed: Increase of ____ hectares; Decrease of ____ hectares; No change in area required
If this is an amendment, were there any issues identified by First Nations in the original application? Yes No If yes, please elaborate:
Trapper notification sent: Yes No
Project Assessment Branch First Nation Comments: Agree Disagree ________________________________ _________________ Senior Aboriginal Program Specialist Date Upon completion return to: _____________________________________ Project Assessment Branch Program Manager |
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File # _____________
To:WA # _____________ Geo # _____________ GDP XRef # _____________ Kelly Lake Cree Nations Kelly Lake First Nation Kelly Lake Metis Settlement Society Other The Oil and Gas Commission has received an application for a:
Proponent/Company: _________________________ Project Name: _________________________ For your information, attached is a copy of the application package for the above noted project proposed for development in your area. Any comments can be sent to the attention of the Area Director, Project Assessment Branch at the address below. Attachments: Timber Harvesting & Field Assessment Geophysical Application and Field Assessment Survey/Construction Plan (if applicable) 1:20,000 BCGS Sketch Plan (Pipelines Only) 1:50 000 Project Map 1:250 000 Access Map AAIF (Archaeological Assessment Information Form) |
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Fish and Wildlife Timing Windows for Oil and Gas Exploration and Development in Northeast British Columbia
Background The purpose of this document is to provide direction with respect to fish and wildlife timing windows for oil and gas operations in northeast British Columbia. When accompanied by appropriate, mitigation measures, adherence to timing windows is a valuable tool in reducing industrial disturbances to fish and wildlife species during sensitive lifecycle stages. Harassment or disruption of wildlife is prohibited at any time under the Wildlife Act of British Columbia; as such, operators are advised to be mindful of potential impacts regardless of the timing of operations. In addition, these windows may require a site-specific review to determine the level of sensitivity to a particular operation. Timing windows may be subject to revision or refinement by the Oil and Gas Commission, as well as other Provincial and Federal agencies. Throughout the lifecycles of most species, there are critical stages of development during which fish and wildlife are more sensitive to particular types of disturbance. In the Peace Region, it has been observed that many species are most susceptible during early life stages. Some species are also sensitive to disturbance during seasonal migrations, rutting, and while occupying their winter habitat. The attached table of timing windows considers a selection of species only. This list was reduced to those species that are considered to be: 1) ecosystem indicators, 2) of special management concern, and 3) those that are more susceptible to disturbance. In the event that additional species of concern are detected at a site, an operator should seek direction from the Oil and Gas Commission regarding the appropriateness of added timing considerations. The type of disturbance is an important factor in planning the timing of oil and gas operations. Typically, on fish bearing watercourses, most in-stream works are subject to timing windows. In comparison, terrestrial wildlife can be particularly sensitive to aerial disruptions; and therefore, timing windows are commonly applied to geophysical operations. Timing windows may also apply to ground based operations where site sensitivities are high. Site sensitivity is primarily determined by the species present, habitat type, abundance of habitat, forest cover type (e.g., open versus closed forest canopy), and the importance of a habitat type to a critical lifecycle stage. Variances and Mitigation The Oil and Gas Commission will consider a variance request for an identified timing window, if an application is accompanied by a mitigation plan outlining how potential adverse impacts to wildlife will be minimized. Mitigation plans must clearly identify: 1) rationale for operating outside of a timing window, 2) site specific habitat information (including photos), 3) the species potentially impacted by activities, 4) inventory information available for any species at risk affected, 5) operational modifications to reduce the impacts to wildlife, and 6) project monitoring. Issues that potentially could be addressed in a mitigation plan include, but are not limited to the following:
Monitoring plays a key role in the development of mitigation strategies, as it permits project modifications to occur as more site-specific information becomes available. Any project monitoring and assessments must be conducted by a qualified environmental technician/biologist, who has experience working with the species and ecosystems of concern. The monitor retained for use on a specific project must be able to issue stop work orders and recommend project modifications, as necessary. Additional information pertaining to setbacks for specific habitat features can be found in the Planning and Construction Guide (2004) document published by the Oil and Gas Commission. Fisheries work windows and Best Management Practices are further defined in the Forest Practices Code of British Columbia – Fish Stream-crossing Guidebook (March 2002). Also note specific timing requirements in any relevant land use plans, pre-tenure plans and tenure caveats, etc. |
| The Microsoft Word document containing the Fish and Wildlife Timing Windows Table is available here. |
| The Microsoft Word document containing the Fish Stream Identification Risk Management Tool is available here. Please note the file size for this document is 12.6 MB. |
| The Microsoft Excel Spreadsheet containing the Pipelines and Facilities Gas Plant Design Capacities is available here. |
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Please use this guideline to assist in a timely review of each application.
Land Agent: Company: For on-lease plants - see Sections 1 to 2 inclusive
For off-lease plants on private property - see Sections 1 to 4 inclusive
For off-lease plants on Crown land - see Sections 1 to 7 inclusive
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Please use this guideline to assist in a timely review of each application.
Use this guideline for all applications on Crown land unless a specific guideline exists for your application type.
Sections 1 to 3 inclusive and section 5 apply to all applications.
Section 4 is not required if the area being applied for is located fully within an existing clearing.
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Please use this guideline to assist in a timely review of each application.
Land Agent: Company: For facilities on private property - see Sections 1 to 3 inclusive
For facilities on Crown land - see Sections 1 to 7 inclusive
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Please use this guideline to assist in a timely review of each application.>
Land Agent: Company: For revisions and amendments on Private Property - see Sections 1 to 4 inclusive
For revisions and amendments on Crown land - see Sections 1 to 7 inclusive
NOTE: This package is only required if the project being applied for is located within the Fort Nelson First Nation, Prophet River First Nation traditional use areas, and any area outside the Fort Nelson and Peace Forest Districts of Northeast BC. Note: Include one package for each First Nation Community listed on the consultation cover letter or consultation pre-assessment form. |
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Please use this guideline to assist in a timely review of each application.
Sections 1 to 3 inclusive apply to all applications.
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NOTE: This section of the ARB no longer applies for new pipeline applications submitted after October 12, 2004. It will continue to apply for amendments to applications submitted prior to October 12, 2004. For details on the new Pipeline application process, please click here. Please use this guideline to assist in a timely review of each application.
For pipelines on private property - see Sections 1 to 4 inclusive
For pipelines on Crown land - see Sections 1 to 7 inclusive
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NOTE: This Guideline no longer applies for pipeline applications submitted after October 12, 2004. Please also apply the new process when submitting Amendments or Revisions to pipeline applications submitted prior to October 12, 2004. If you require assistance with this please contact Shelley Calder at 250-261-5717 or email Shelley Calder@gov.bc.ca. For details on the new pipeline application process, please click here.
Please use this guideline to assist in a timely review of each application. Land Agent: Company: For revisions and amendments on Private Property - see Sections 1 to 4 inclusive
For revisions and amendments on Crown land - see Sections 1 to 7 inclusive
Note: Include one package for each First Nation Community listed on the consultation cover letter or consultation pre-assessment form. |
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The following sets out the Minimum Mapping Criteria that should be shown on the Schedule A that is submitted with the Timber Harvesting and Field Assessment form. The requirements have minor changes to the original requirements (pre 2001/10/15).
General Requirements Actual Schedule A (small scale detail site plan, preferred 1:5000 or 1:10 000))
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| The Microsoft Word Document containing the Application to use land in an Agricultural Land Reserve for Oil and Gas Purposes is available here. |
| The Microsoft Word document containing the Maximum Planning and Construction Guide is available here. |
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ACCESS
Time of Year:
Location of Access:
Natural Barrier:
SLASH
RANGE IMPROVEMENT DAMAGE – Rates to be removed or revised.
WELLSITES
OTHER
APPROVED PROJECTS REFER TO THIS GUIDE DISPUTES REFER TO MINISTRY OF FORESTS |
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The following will assist the Oil and Gas Proponent or Designate in accurately completing the Oil and Gas Commission (OGC) Application for Road Use Permit Form (RUP). A Road Use Permit is required to utilize Ministry of Forests (MoF) designated Forest Service Roads (FSR’s) in British Columbia.
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FORT NELSON DISTRICT - FORAGE SEED RECLAMATION MIX May 2003 DRY FOOTHILLS SITE MIX
RIVER BANKS It is suggested that all those involved in this project review the "Native Plant Re-vegetation Guidelines for Alberta, February 2001". This document is a great resource, and is ahead of what is being done in BC. This document can be viewed at: http://www.agric.gov.ab.ca/publiclands/nprg/.
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PEACE DISTRICT - FORAGE SEED RECLAMATION MIX May 2003
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File: 19720-10 PRWA, Woodlot Licensees
December 05, 2000 To: Woodlot Licensees in the Fort St. John Forest District From: Ministry of Forests, Fort St. John Forest District Re: Seismic and Pipeline Referrals on Woodlot License Areas As many of you are aware, any oil and gas activities being proposed on your woodlot are referred to you by a company or industry representative for your information and comments. As multiple forest tenures cannot be issued over a woodlot area, the License to Cut cutting permit issued by the Oil and Gas Commission (OGC) does not apply over your woodlot area. Thus to legally encompass the cutting of trees associated with these oil and gas activities within your woodlot, the Ministry of Forests has been issuing a Cutting Permit “Z” (CP Z) in the name of the Woodlot Licensee. What does this mean to you? Since the CP “Z” is issued in your name, this also makes you legally responsible for the harvesting activities associated with the oil and gas activities occurring under your tenure. What this means is that any infractions, as determined under the Forest Practices Code of British Columbia Act or the Forest Act, as a result of their activities under the CP “Z” apply firstly to the Woodlot Licensee. Please be well aware of this fact when completing a referral with an oil and gas company representative discussing proposed operations within your woodlot. The company responsible for the operation is ultimately working under your tenure, so careful consideration should be given when deciding what the desired end result should be. Whether the program is for seismic or pipeline, ensure that the contract entered into details your expectations clearly, and that both parties understand these expectations. Should there be an infraction the standard of care you have exercised with the company in detailing your expectations of their activities under your cutting permit will be determined by evaluating the circumstances on a case by case basis. The CP “Z” also allows for the accurate recording of the amount of timber harvested on your woodlot area due to these oil and gas activities. All of this timber is recorded against your five year cut control commitment which may allow for future adjustments. Your Allowable Annual Cut (AAC) as determined for your woodlot is based on the utilization of all merchantable timber within the woodlot. Therefore, any timber that is cut through the use of low impact seismic operations, which is left behind and not utilized, would still contribute to your cut control position and in addition, the Woodlot Licensee may be billed for residual waste. If the program is large, or a 3D seismic, this can result in a significant loss of volume in the cut control period if the timber is wasted. Should you require any further clarification on any of the above information, please do not hesitate to contact the Fort St. John Forest District at 787-5600. |
| The Microsoft Word document containing the Stream Crossing Planning Guide is available here. |
| The Adobe Acrobat file containing the Surface Equipment Spacing Guideline is available here. |
This document will assist proponents in completing the Timber Harvesting and Field Assessment form (THFA), which is required for all activities on Crown land within British Columbia, with the exception of seismic operations.
Additional Stream Crossing Information: Photos, habitat assessments, and fish inventory data are encouraged to support applications for in-stream activities. Only those individuals with an appropriate background and experience should conduct fisheries habitat and inventory assessment work. Proponents are encouraged to include information pertaining to monitoring, mitigation measures, reclamation, crossing selection and deactivation. The Oil and Gas Commission will request additional habitat and geotechnical evaluations where it is perceived crossings may incur a risk to the aquatic environment. Proponents are advised to complete this work prior to application submission. Signing Authority The person signing the THFA must have signing authority for the licensee and must have a letter on file with the OGC stating this. |
RESERVOIR ENGINEERING
| The Microsoft Word document containing the Reservoir Engineering Assigned Coordinating Operators for Pool Pressure Surveys is available here. |
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Field Codes
Formation Codes (alphabetic) Formation Codes (strategraphic) (last 2 links down) |
| The Microsoft Powerpoint Presentation containing the Reservoir Engineering BC Off Target Rules, Production Allowables and Reservoir Projects is available here. |
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The following is an example of an acceptable cover letter to be submitted to the OGC when applying for waiver of an off-target production penalty. For further information see the Guideline for Application for Waiver of the Off-Target Production Penalty.
However, the applicant is not limited to the exclusive use of this format. [Company] [Address] [Date] Oil and Gas Commission Resource Conservation Branch PO Box 9329 Stn Prov Gov't Victoria BC V8W 9N3 Dear Sir: RE: Application for Waiver of Off-Target Production Penalty Factor [Company], as licence holder and operator of the subject well, hereby applies for waiver of the off-target production penalty for [oil/gas] production from the [formation name] formation. The subject well has been completed in an off-target location due to [reason]. Attached is a map illustrating the title ownership and well location, the wellbore directional survey and letter(s) of no objection to waiver from the affected offsetting lease owners. Should there be any questions, [Applicant] may be reached at [phone number, fax number and email address]. Sincerely, [Applicant signature and printed name and title] |
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The following is an example of an acceptable letter that may be provided to the OGC when applying for a reservoir project (Good Engineering Practice, Waterflood or Gas Injection Pressure Maintenance, Concurrent Production, Salt Water or Acid Gas Disposal), from each of the subsurface tenure holders (as registered with the British Columbia Ministry of Energy and Mines, Titles Branch), within the area and formation of application. Consent letters are not required where the applicant is the designated operator of a Unit Agreement for the zone of application.
This format may also be used when requesting an area amendment to a previously approved project. However, the consenting tenure holder is not limited to the exclusive use of this format. [Consenting Company] [Address] [Date] Oil and Gas Commission Resource Conservation Branch PO Box 9329 Stn Prov Gov’t Victoria BC V8W 9N3 Dear Sir: RE: Consent to Application For [Project type, example Good Engineering Practice] Please be advised that [Consenting Company], as the registered tenure holder of: Petroleum and Natural Gas Lease(s) # _[Lease number]__ Drilling Licence(s) # _[Licence number]__ hereby consents to the inclusion of those lands in [Company making application]’s application for [Project type, example Good Engineering Practice], dated [date of application], for the [Field and Pool name]. Sincerely, [Signature and printed name and title] [Phone number] [FAX number] [Email address] |
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The following is an example of an acceptable letter that may be provided to the OGC when applying for a reservoir project (Good Engineering Practice, Waterflood or Gas Injection Pressure Maintenance, Concurrent Production, Salt Water or Acid Gas Disposal or Commingled Production) from each of the potentially affected well operators within the pool of application.
However, the consenting operator is not limited to the exclusive use of this format. This letter is not a requirement when making an application to the OGC, however is advisable in cases where objection to approval is anticipated. A notice of application for a reservoir project is normally advertised in the BC Gazette, allowing for objections to be filed with both the OGC and the applicant. [Consenting Company] [Address] [Date] Oil and Gas Commission Resource Conservation Branch PO Box 9329 Stn Prov Gov't Victoria BC V8W 9N3 Dear Sir: RE: Non-Objection to Application For [Project type, example Salt Water Disposal] Please be advised that [Consenting Company], as an operator of wells within the same pool, hereby advises that it has no objection to [Company making application]’s application for [Project type, example Salt Water Disposal], dated [date of application], for the [Field and Pool name]. Sincerely, [Signature and printed name and title] [Phone number] [FAX Number] [Email address] |
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The following is an example of an acceptable letter that may be provided to the OGC when applying for waiver of an off-target production penalty, from each of the affected subsurface tenure holders (as registered with the British Columbia Ministry of Energy and Mines, Titles Branch), for the formation and spacing area adjoining an off-target well’s spacing area. The consent of the tenure holder in only the off-target direction need be considered. Please be aware that the offsetting rights must be held under a valid Petroleum and Natural Gas Lease, not a Drilling Licence. Waiver of the off-target penalty will be conditional upon the ongoing consent of the current tenure holder.
However, the consenting tenure holder is not limited to the exclusive use of this format. This consent letter is not required where the applicant applying for waiver is the holder of the affected offsetting title, unless there is more than one registered owner. [Consenting Company] [Address] [Date] Oil and Gas Commission Resource Conservation Branch PO Box 9329 Stn Prov Gov't Victoria BC V8W 9N3 Dear Sir: RE: Non-objection to Waiver of Off-Target Production Penalty Factor Please be advised that [Consenting Company], as tenure holder of: Petroleum and Natural Gas Lease(s) # _[Lease number]__ hereby has no objection to the waiver of the off-target production penalty factor for the subject well, for [oil or gas] production from the [name of formation] formation. Sincerely, [Signature and printed name and title] [Phone number] [FAX Number] [Email address] [Consenting Company] |
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The Petroleum and Natural Gas Act applies to all storage projects. Part 14 of the Petroleum and Natural Gas Act was enacted to regulate the exploration and development of underground storage areas.
An application for approval of an underground hydrocarbon storage scheme in the Western Canadian Sedimentary Basin of Northeast British Columbia under the Petroleum and Natural Gas Act may contain, when applicable:
Additional information may be supplied for underground storage in an aquifer consisting of:
Additional information may be supplied for underground storage in a depleted or partially depleted hydrocarbon reservoir consisting of:
Three copies of the application are to be submitted to the Director of the Resource Conservation Branch of the Oil and Gas Commission in Victoria at the address noted above. A fourth copy is to be forwarded to the Manager, Operations Engineering of the Oil and Gas Commission in Fort St. John (200 10003 110 Ave, Fort St. John BC V1J 6M7). Notice of an application may be published in The British Columbia Gazette. A fee of $5,000.00 is payable for the processing of an application for a storage license. |
An application for approval of a Good Engineering Practice (GEP) area under Section 101 of the Drilling and Production Regulation may contain, when applicable:
Two copies of the application are to be submitted to the Director of the Resource Conservation Branch of the Oil and Gas Commission in Victoria at the address noted above. Additional copies may be made available to owners directly affected, upon request. Notice of an application may be published in The British Columbia Gazette. |
An application for concurrent production of oil and gas under Section 97 of the Petroleum and Natural Gas Act may contain, when applicable:
Two copies of the application are to be submitted to the Director of the Resource Conservation Branch of the Oil and Gas Commission in Victoria at the address noted above. Additional copies may be made available to owners directly affected, upon request. Notice of an application may be published in The British Columbia Gazette. |
An application for approval of a pressure maintenance or improved recovery scheme under Section 100 of the Petroleum and Natural Gas Act may contain, when applicable:
Two copies of the application are to be submitted to the Director of the Resource Conservation Branch of the Oil and Gas Commission in Victoria at the address noted above. Additional copies may be made available to owners directly affected upon request. Notice of an application may be published in The British Columbia Gazette. |
An application to dispose of non-special waste generated by the upstream oil and gas industry under the Petroleum and Natural Gas Act may contain, when applicable:
Two copies of the application are to be submitted to the Director of the Resource Conservation Branch of the Oil and Gas Commission in Victoria at the address noted above. A third copy, together with a copy of the Application to Alter form is to be forwarded to the Director of the Operations Engineering Branch of the Oil and Gas Commission in Fort St. John (200 10003 110 Ave, Fort St. John BC V1J 6M7). Additional copies may be made available to owners directly affected, upon request. Notice of the application may be published in The British Columbia Gazette. In addition, an application is to be made to the Waste Management Specialist of the Operations Engineering Branch of the Oil and Gas Commission in Fort St. John. |
Unitization Agreements are approved according to Section 114 of the Petroleum and Natural Gas Act. The purpose of unitization is generally to allow enhanced exploration of pool hydrocarbon resources underlying leases operated by a diversity of leaseholders. The following additional features are present:
The Crown will need to provide assurances of title continuation and will need assurances of safeguarding the royalty share. The Unitization Agreement must therefore be submitted to the Crown in accordance with Section 105 of the Drilling and Production Regulation. If the unitized operation includes a scheme for repressuring, recycling or pressure maintenance operations, Oil and Gas Commission approval will be required under Section 100 of the Petroleum and Natural Gas Act. Unitization proposals are to be submitted to the Director, Petroleum Lands Branch of the Ministry of Energy and Mines in Victoria, which will refer technical submissions and requests to the Resource Conservation Branch of the Oil and Gas Commission at the address noted above. Four copies of technical submissions are required. |
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Recommended to be supplied with each application submitted (1 copy)
"Non-Annual" testing of a pool may be granted, under section 95.2 of the Drilling and Production Regulation (the Regulation) in cases where an adequate pressure history exists, wells have low productivity, and/or there are few remaining reserves. The testing requirement may be modified to an interval of two or more years, or a total exemption may be granted in some cases. For a listing of pools with non annual testing approvals, please see Table 1–Pools With Non-Annual Pressure Survey Approval, posted on our website. The application for modification of the annual pool pressure testing requirement should contain, when applicable:
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An application for waiver of off-target production penalty under Section 9 (oil) or 10 (gas) of the Drilling and Production Regulation may contain, when applicable:
The consent of the tenure holder in only the off-target direction need be considered; see the example letter - No Objection to Waiver of Off-Target Production Penalty. A consent letter is not required where the applicant for waiver is the holder of the affected offsetting title, unless there is more than one registered owner. Please be aware that the offsetting rights must be held under a valid Petroleum and Natural Gas Lease, not a Drilling Licence, in order for waiver to be granted. Waiver of the off-target penalty will be conditional upon the ongoing consent of the current tenure holder. Note: the off-target production penalty does not apply to a well recognized by the OGC as the "discovery well" of a new pool. One copy of the application is to be submitted to the Director of the Resource Conservation Branch of the Oil and Gas Commission in Victoria at the address noted above. |
An application for a scheme to dispose of produced acid gas under Section 100 of the Petroleum and Natural Gas Act may contain, when applicable:
Three copies of the application are to be submitted to the Director of the Resource Conservation Branch of the Oil and Gas Commission in Victoria at the address noted above. A fourth copy is to be forwarded to the Manager, Operation Engineering of the Oil and Gas Commission in Fort St. John (200 10003 110 Ave, Fort St. John BC V1J 6M7). Notice of an application may be published in The British Columbia Gazette. |
An application to commingle production from two or more zones within a well bore, under Section 41 of the Drilling and Production Regulation, may contain, when applicable:
Two copies of the application are to be submitted to the Director of the Resource Conservation Branch of the Oil and Gas Commission in Victoria at the address noted above. A copy of the Application to Alter a Well form is to be forwarded to the Manager, Operations Engineering of the Oil and Gas Commission in Fort St. John (200 10003 110 Ave, Fort St. John BC V1J 6M7). |
An application for disposal of produced water under Section 94 of the Drilling and Production Regulation may contain, when applicable:
Two copies of the application are to be submitted to the Director of the Resource Conservation Branch of the Oil and Gas Commission in Victoria at the address noted above. A third copy, together with a copy of the Application to Alter form is to be forwarded to the Manager, Operations Engineering of the Oil and Gas Commission in Fort St. John (200 10003 110 Ave, Fort St. John BC V1J 6M7). Additional copies may be made available to owners directly affected, upon request. Notice of an application may be published in The British Columbia Gazette. |
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The normal spacing area for oil wells is one unit or 1/4 section (approximately 65 hectares), with the unadjusted oil allowable calculation based on a ten-year depletion rate for reserves underlying that tract. Gas wells have a spacing area of four units or one section; however, for most gas wells, there is no allowable restriction.
Approval of a Good Engineering Practice project status for an approved area or conclusion of a Unitization Agreement allows the Oil and Gas Commission to release the operator(s) from some of the detailed spacing and allowable regulations under Sections 101 or 105 of the Drilling and Production Regulation, thus permitting greater operational flexibility. Where an individual well bore, such as that of a horizontal well, contacts a pool in more than one normal spacing area, and is not within a project, an application may be made to create a larger spacing area under section 65.1 of the Petroleum and Natural Gas Act. Provided that only one well is productive from the pool within the spacing area, the assigned area is increased accordingly. An application will not normally be processed by Commission staff until the prospective well has been successfully completed, as experience has shown that well bore trajectories and lengths will vary from those planned prior to drilling. Notice of application may be published in The British Columbia Gazette. An application for other than normal spacing under section 65.1 may contain, when applicable:
Two copies of the application are to be submitted to the Director of the Resource Conservation Branch of the Oil and Gas Commission in Victoria at the address noted above. |
| The Microsoft Word Document containing the Reservoir Engineering NTS Unit Dimensions for Off-Target Penalty Calculations is available here. |
| The Microsoft Word document containing the Pools with Non-Annual Pressure Testing Approval is available here. |
The form “Production Allowable Report—Crude Oil” (Form OGC_032_PROD_RPT) is required for each producing oil well or project in British Columbia under section 83.2 of the Drilling and Production Regulation (unless otherwise approved). Regulations pertinent to this Report can be found in sections 76 to 85, inclusive. The form must be submitted monthly and received by the 16th of the month following the reported production. The following are some notes to assist in the proper completion of the Production Allowable Report. These notes accompany two sample forms of a fictitious well from the time of initial oil production into the successive production period.
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| The Reservoir Engineering Production Allowable Report- Crude Oil (Instructions) Example 1 is available here. |
| The Reservoir Engineering Production Allowable Report- Crude Oil (Instructions) Example 2 is available here. |
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This form is supplementary to the test report and does not replace it. All test data and applicable analysis must still be submitted, as per the requirements of Section 95 of the Drilling and Production Regulation. Well testing requirements are further detailed in Section 6.7 of the British Columbia Oil and Gas Handbook. Oil and Gas Commission (Commission) staff will continue to input values to the provincial database and make corrections to common pool datum depths.
Report Filing PST reports are due within 60 days of the completion of the test. Test reports, with the form attached to the front, are to be sent to the Victoria office of the Commission. Dual Guages Where dual gauges are used during testing, the data from only one gauge should be included on the form. The gauge that best meets the following criteria should be used:
Pressures are to be reported to the nearest kPa. The Commission accepted correction factor for gauge to absolute is 101 kPa. Gas wells are to be reported in absolute pressure, oil and gas-cap wells in gauge. Build-up & Fall-off Tests The test date is the date of the last recorded pressure. For build-up or fall-off tests, the Commission records not only the extrapolated pressure at stable reservoir conditions but also the last measured pressure (LMP) at the end of the test. The comparison of these two values aids in quality assessment and planning of future tests. The extrapolated pressure must be noted as either a P* value or Pr, averaged for the drainage area. Care must be taken when reporting the P* or Pr value; they must be reported at the recorder run depth, not corrected to a well datum. Deviated Wells Tests on deviated and horizontal wells are problematic in correcting pressures to a common pool datum. Every effort should be made to report the run depth corrected to the true vertical depth (TVD) referenced from the CF. Where this is not possible, the operator must indicate that the run depth is referenced as measured depth (MD) by checking the appropriate box. Gradients Where the fluid in the wellbore differs from that expected from the pay zone of the formation, both the wellbore and formation gradient must be noted. A common example would be a gas well in which a static gradient test encounters a bottom-hole water leg. The form contains a box to note any liquid level indicated in the wellbore. Well Deliverability Test Report A PST form is to be submitted with each gas deliverability/AOF test. Where applicable, both the initial static pressure and the reservoir pressure following testing should be reported, on separate forms. The deliverabilty test flow data must be submitted with a Well Deliverability Test Report form. Test Remarks Note remarks pertinent to the well or specific test. Please indicate any information that would help in interpreting the test data or in designing future tests on the well. Examples:
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| The Memorandum containing the Road Allowance Consideration for Target Areas is a Microsoft Word Document and available here. |
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Report Filing
A report is required for all:
Test Type Indicate the appropriate test type by selecting the corresponding check box. Where the sole purpose of the test is a well clean-up, select “CU” as the test type and enter the applicable rate and volume data. However, if a clean-up period is carried out in conjunction with a subsequent deliverability test, select the test type corresponding to the deliverability test and include the clean-up flow rate and production volumes on the same form with the AOF data. Under-Balanced Drilling This form is to be submitted for under-balanced drilling operations that result in burnable gas to surface. Reported test type should be “UBD”. Flared gas volumes reported are to be the net volume produced by the target formation (gas produced minus gas injected). Net gas rates should be representative of the burnable gas produced near the end of the UBD operations with the duration being the cumulative time that flaring occurs. A copy of the field notes recorded during drilling must be provided with this report. Test Date The test date is the final date the well was flowing during the testing period. AOF and n Value The sandface and wellhead AOF values should be calculated at both extended and stabilized conditions. For low productivity wells with test rates less than 20 e3m3/d, the calculation of only wellhead AOF values is permitted. Complete details of all AOF calculations must be included with the test submission. The Commission records the reciprocal slope “n” value as derived from the Simplified Analysis technique. Where the value of “n” is derived from the test data, the assumed flag should be checked as “no”. Single point test is normally checked as “yes”, unless the “n” is derived from an earlier test on the well under similar wellbore and reservoir conditions. Pressures Pressure data is reported for all test types other than “CU” or “UBD”. The “Shut-in Pressure” is defined as the bottomhole pressure as measured prior to each flow rate. The “Final Flow Pressure” is the bottomhole pressure as measured at the end of that flow period. The stabilized reservoir pressure is entered on the form under “Reservoir Pressure”. Pressure is to be reported in absolute, to the nearest kPa. The Commission accepted correction factor for gauge to absolute is 101 kPa. All tests, other than stand-alone clean up flows and under-balanced drilling operations, also require the submission of a corresponding Reservoir Pressure Survey Test (PST) Report form with the pressure data. If a valid stabilized reservoir pressure recording is made both prior to and following the flow test, then a separate PST form must be submitted for each point. Test Remarks Please use the “Comments” section to make remarks pertinent to the well or specific test, indicating any information that would help in interpreting the test data or in designing future tests on the well. Examples:
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| The Reservoir Engineering Well Testing and Reporting Overview Powerpoint Presentation is available here. |
Reservoir pressure measurements are required on all producing oil and gas pools in British Columbia, in accordance with section 95 of the Drilling and Production Regulation (the Regulation). The Commission reserves the right to order additional tests other than the outlined minimum requirement. Initial Pressure Testing: All new wells/completed zones are required to have an initial pressure test prior to any production. A valid DST test meets this requirement. Initial pressures are credited toward the minimum annual testing requirement for a pool.
Minimum Annual Requirement: The OGC requires adequate pool pressure survey coverage annually. The minimum number of reservoir pressure tests to be conducted annually for each producing pool should be equal in number to:
Test Methods: The preferred method of determining static bottom-hole pressure is with a bottom-hole recorder. In those cases where the reservoir pressure is calculated from wellhead pressures and fluid level measurements, or pressure build-up or fall-off data, comprehensive details of the data and calculations must be included with the survey report. Test Submission: All reservoir pressure tests conducted must be reported. Test reports, accompanied by the Reservoir Pressure Survey Test (PST) Report form (available from our website) must be submitted to the Victoria office of the Commission within 60 days of the completion of the test. Complete reports must include an accurate well shut-in time for each test. Where insufficient shut-in time was allocated during a test to measure or extrapolate a reservoir pressure, the test may be deemed invalid and additional testing ordered.
Every gas well is required to be flow tested with its absolute open-flow (AOF) potential determined before six months have elapsed from the time the well was placed on initial production, as per section 84 of the Regulation. Tests may be completed prior to commercial production, or in-line with gas flow to pipeline. If gas flaring is planned, prior approval is required from the Commission office in Fort St. John. Test Submission: Detailed reports, accompanied by a Well Deliverability Test Report form, must be submitted to the Victoria office of the Commission within 60 days of the final test date. Complete reports should include the pressure data, flow rates, produced volumes, and fluid sample analyses. Specific analysis of the data should include the calculations of the wellhead and sandface AOF values at both stabilized and extended rate conditions.
Low Deliverability Wells: A calculation of only the wellhead AOF may be acceptable for low productivity wells with test rates typically less than 20 e3m3/d.
Clean-Up Flows: Reports must also be filed for any clean-up flows, indicating the flow rates and total produced volumes. For clean-up flows immediately preceding an AOF test, a separate report is not required but the clean-up data should be included on the Deliverability Test Report in the appropriate fields.
Under-Balanced Drilling: If under-balanced drilling operations result in gas being flared, a Well Deliverability Test Report form must be submitted to the Victoria office indicating net gas rates and net gas volume produced (gas produced – gas injected). This information along with a copy of the field notes recorded during drilling must be submitted to the Commission within 60 days of the final drilling date.
Copies of the required reporting forms along with instructions on their completion may be obtained from the Commission web site. Visit www.ogc.gov.bc.ca/formschecklists.asp and select Reservoir Engineering. Additional information is also available at this site on topics such as Modification of Annual Pool Testing Requirements, Coordinating Operators, and Pools with Non-Annual Testing Approval. All test data, analysis, and related questions should be directed to: Resource Conservation Branch Oil and Gas Commission
Your cooperation in this matter is appreciated and will ensure the maintenance of this valuable database resource. |
WELLS AND TEST HOLES
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| To view the Environmental Upgrade & Minor Changes to Approved Activities Spreadsheet, please click here. |
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File # _______________________
Company: ____________________WA # _______________________ Geo # _______________________ GDP XRef # _______________________ Land Agent _______________________ Project: ____________________ Based on an Application Pre-Assessment, an application package for the above-noted project was NOT sent to the _______________ First Nation(s) for review for the following reasons (explanation of what is being applied for and why): Application Notes: Total area required for the project: _______ hectares Is the area required within an existing cleared area: Yes No Partially
Is this an Amendment or a Revision?
If this is an amendment, please indicate the difference in the area required from what was originally proposed: Increase of ____ hectares; Decrease of ____ hectares; No change in area required
If this is an amendment, were there any issues identified by First Nations in the original application? Yes No If yes, please elaborate:
Trapper notification sent: Yes No
Project Assessment Branch First Nation Comments: Agree Disagree ________________________________ _________________ Senior Aboriginal Program Specialist Date Upon completion return to: _____________________________________ Project Assessment Branch Program Manager |
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File # _____________
To:WA # _____________ Geo # _____________ GDP XRef # _____________ Kelly Lake Cree Nations Kelly Lake First Nation Kelly Lake Metis Settlement Society Other The Oil and Gas Commission has received an application for a:
Proponent/Company: _________________________ Project Name: _________________________ For your information, attached is a copy of the application package for the above noted project proposed for development in your area. Any comments can be sent to the attention of the Area Director, Project Assessment Branch at the address below. Attachments: Timber Harvesting & Field Assessment Geophysical Application and Field Assessment Survey/Construction Plan (if applicable) 1:20,000 BCGS Sketch Plan (Pipelines Only) 1:50 000 Project Map 1:250 000 Access Map AAIF (Archaeological Assessment Information Form) |
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Fish and Wildlife Timing Windows for Oil and Gas Exploration and Development in Northeast British Columbia
Background The purpose of this document is to provide direction with respect to fish and wildlife timing windows for oil and gas operations in northeast British Columbia. When accompanied by appropriate, mitigation measures, adherence to timing windows is a valuable tool in reducing industrial disturbances to fish and wildlife species during sensitive lifecycle stages. Harassment or disruption of wildlife is prohibited at any time under the Wildlife Act of British Columbia; as such, operators are advised to be mindful of potential impacts regardless of the timing of operations. In addition, these windows may require a site-specific review to determine the level of sensitivity to a particular operation. Timing windows may be subject to revision or refinement by the Oil and Gas Commission, as well as other Provincial and Federal agencies. Throughout the lifecycles of most species, there are critical stages of development during which fish and wildlife are more sensitive to particular types of disturbance. In the Peace Region, it has been observed that many species are most susceptible during early life stages. Some species are also sensitive to disturbance during seasonal migrations, rutting, and while occupying their winter habitat. The attached table of timing windows considers a selection of species only. This list was reduced to those species that are considered to be: 1) ecosystem indicators, 2) of special management concern, and 3) those that are more susceptible to disturbance. In the event that additional species of concern are detected at a site, an operator should seek direction from the Oil and Gas Commission regarding the appropriateness of added timing considerations. The type of disturbance is an important factor in planning the timing of oil and gas operations. Typically, on fish bearing watercourses, most in-stream works are subject to timing windows. In comparison, terrestrial wildlife can be particularly sensitive to aerial disruptions; and therefore, timing windows are commonly applied to geophysical operations. Timing windows may also apply to ground based operations where site sensitivities are high. Site sensitivity is primarily determined by the species present, habitat type, abundance of habitat, forest cover type (e.g., open versus closed forest canopy), and the importance of a habitat type to a critical lifecycle stage. Variances and Mitigation The Oil and Gas Commission will consider a variance request for an identified timing window, if an application is accompanied by a mitigation plan outlining how potential adverse impacts to wildlife will be minimized. Mitigation plans must clearly identify: 1) rationale for operating outside of a timing window, 2) site specific habitat information (including photos), 3) the species potentially impacted by activities, 4) inventory information available for any species at risk affected, 5) operational modifications to reduce the impacts to wildlife, and 6) project monitoring. Issues that potentially could be addressed in a mitigation plan include, but are not limited to the following:
Monitoring plays a key role in the development of mitigation strategies, as it permits project modifications to occur as more site-specific information becomes available. Any project monitoring and assessments must be conducted by a qualified environmental technician/biologist, who has experience working with the species and ecosystems of concern. The monitor retained for use on a specific project must be able to issue stop work orders and recommend project modifications, as necessary. Additional information pertaining to setbacks for specific habitat features can be found in the Planning and Construction Guide (2004) document published by the Oil and Gas Commission. Fisheries work windows and Best Management Practices are further defined in the Forest Practices Code of British Columbia – Fish Stream-crossing Guidebook (March 2002). Also note specific timing requirements in any relevant land use plans, pre-tenure plans and tenure caveats, etc. |
| The Microsoft Word document containing the Fish and Wildlife Timing Windows Table is available here. |
| The Microsoft Word document containing the Fish Stream Identification Risk Management Tool is available here. Please note the file size for this document is 12.6 MB. |
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Please use this guideline to assist in a timely review of each application.
Land Agent: Company: For test holes on private property - see Sections 1 to 2 inclusive
For test holes on Crown land - see Sections 1 to 5 inclusive
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Please use this guideline to assist in a timely review of each application.
Land Agent: Company: For revisions and amendments on Private Property - see Sections 1 to 2 inclusive
For revisions and amendments on Crown land - see Sections 1 to 5 inclusive
Note: Include one package for each First Nation Community listed on the consultation cover letter or consultation pre-assessment form. |
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It is recommended that copies of all well information and reports connected with or derived from the drilling, production or other work performed on a well should be submitted to the Oil and Gas Commission per Part 6 of the Drilling and Production Regulation. It will help with the review turn around time if all submissions are sufficiently legible to permit reproduction by standard processes.
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Please use this guideline to assist in a timely review of each application.
For wellsites on private property - see Sections 1 to 2 inclusive For wellsites on Crown land - see Sections 1 to 5 inclusive
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Please use this guideline to assist in a timely review of each application.
Land Agent: Company: For wellsite re-entry on private property - see Sections 1 to 2 inclusive
For wellsite re-entry on Crown land - see Sections 1 to 5 inclusive
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Please use this guideline to assist in a timely review of each application.
For revisions and amendments on Private Property - see Sections 1 to 2 inclusive
For revisions and amendments on Crown land - see Sections 1 to 5 inclusive
Note: Include one package for each First Nation Community listed on the consultation cover letter or consultation pre-assessment form. |
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The following sets out the Minimum Mapping Criteria that should be shown on the Schedule A that is submitted with the Timber Harvesting and Field Assessment form. The requirements have minor changes to the original requirements (pre 2001/10/15).
General Requirements Actual Schedule A (small scale detail site plan, preferred 1:5000 or 1:10 000))
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| The Microsoft Word Document containing the Application to use land in an Agricultural Land Reserve for Oil and Gas Purposes is available here. |
| The Microsoft Word document containing the Maximum Planning and Construction Guide is available here. |
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ACCESS
Time of Year:
Location of Access:
Natural Barrier:
SLASH
RANGE IMPROVEMENT DAMAGE – Rates to be removed or revised.
WELLSITES
OTHER
APPROVED PROJECTS REFER TO THIS GUIDE DISPUTES REFER TO MINISTRY OF FORESTS |
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The following will assist the Oil and Gas Proponent or Designate in accurately completing the Oil and Gas Commission (OGC) Application for Road Use Permit Form (RUP). A Road Use Permit is required to utilize Ministry of Forests (MoF) designated Forest Service Roads (FSR’s) in British Columbia.
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Oil and Gas Commission 200, 10003 – 110th Avenue Fort St. John, BC V1J 6M7 Attention: Project Assessment Branch Re: < INSERT WELL NAME AND LOCATION > Pursuant to Section 85 of the British Columbia Petroleum and Natural Gas Act, please be advised that as tenure holder(s) of hereby authorize to drill and operate the subject well and produce petroleum and/or natural gas from the subject well. Notwithstanding this arrangement, the obligation to the Province of British Columbia concerning liabilities will remain with the tenure holder(s). Yours truly, _____________ |
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FORT NELSON DISTRICT - FORAGE SEED RECLAMATION MIX May 2003 DRY FOOTHILLS SITE MIX
RIVER BANKS It is suggested that all those involved in this project review the "Native Plant Re-vegetation Guidelines for Alberta, February 2001". This document is a great resource, and is ahead of what is being done in BC. This document can be viewed at: http://www.agric.gov.ab.ca/publiclands/nprg/.
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PEACE DISTRICT - FORAGE SEED RECLAMATION MIX May 2003
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Completing the Sour Well Section of the Application for a Well Authorization If the well being drilled does not have the potential to release H2S at a rate higher than 0.01m3/s, the sour well section does not have to be completed. Otherwise the sour well section must be completed in full, see below for an example. The cumulative drilling H2S release rate should represent the highest potential H2S concentration matched with the highest potential release rate for each permeable/porous zone penetrated during drilling. The CAPP “H2S Release Rate Assessment Guidelines” should be referenced when carrying out these calculations. When indicating the distance to the nearest occupied dwelling, in remote areas, it is acceptable to indicate distance with a greater than sign (i.e. Distance to nearest occupied dwelling: > 4.2 km). The OGC does not expect operators to search a large radius to identify the nearest occupied residence, it is sufficient to ground truth the area out to the edge of the emergency awareness zone (EAZ). An Emergency Awareness Zone is defined as an area with twice the radius of the Emergency Planning Zone. A
suitable planning zone map must also accompany the application for a well authorization. This map should show details within the
planning zone and the awareness zone, public facilities and residences
(seasonal or otherwise) should be ground truthed to the boundary of the
awareness zone. The
map must show: · the emergency planning zone; · the emergency awareness zone (twice the EPZ radius); · public facilities ‑ schools, churches, community halls, hospitals, campgrounds; · residences within the zones; · location of traplines; · wellsite; · trails, roads, major highways, railroads, airports, rivers and lakes; · all industrial activity sites; · other information relevant to an emergency. Map sheet should be of an appropriate scale, showing sufficient detail to allow Commission staff to make a determination regarding special well classifications. A common scale suitable for most wellsites is 1:20,000 and should not be larger than 76 x 122 cm (30 x 48 inches). Inserts to show necessary detail should be used as needed. Please note that emergency response plans (ERPs) for special sour wells must be submitted to the OGC and approved prior to receiving approval for a well authorization, companies will be notified by the OGC on a site specific basis of this requirement. Additionally, site specific ERPs are now required when one or more residences, public facilities or places of business are contained within the EPZ, these plans must be approved prior to spudding a well. The distance to the nearest urban centre information is used to ensure that minimum setback requirements are met and that appropriate special well classifications are assigned. An urban centre is defined as a city, town, village or other incorporated district with not less than 50 dwellings, any First Nation reserve and includes any similar development the OGC may designate as an urban center. The following is a table indicating areas that would be considered urban centres, this list is not meant to be exhaustive rather is intended as a guide.
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| The Microsoft Word document containing the Stream Crossing Planning Guide is available here. |
| The Adobe Acrobat file containing the Surface Equipment Spacing Guideline is available here. |
This document will assist proponents in completing the Timber Harvesting and Field Assessment form (THFA), which is required for all activities on Crown land within British Columbia, with the exception of seismic operations.
Additional Stream Crossing Information: Photos, habitat assessments, and fish inventory data are encouraged to support applications for in-stream activities. Only those individuals with an appropriate background and experience should conduct fisheries habitat and inventory assessment work. Proponents are encouraged to include information pertaining to monitoring, mitigation measures, reclamation, crossing selection and deactivation. The Oil and Gas Commission will request additional habitat and geotechnical evaluations where it is perceived crossings may incur a risk to the aquatic environment. Proponents are advised to complete this work prior to application submission. Signing Authority The person signing the THFA must have signing authority for the licensee and must have a letter on file with the OGC stating this. |
| The Microsoft Powerpoint presentation containing the Wells and Test Holes WA Application Fee Reduction Diagram is available here. |