the absence of any wellbore problems. In any case, the licensee must inform all affected parties, including the landowner. Directive 020 requires that a testing regime be implemented as part of the abandonment operation, regardless of whether it is routine or non-routine. After completing downhole operations, the ERCB must be provided with tour reports in compliance with Directive 059: Well Drilling and Completion Data Filling Requirements, and plug logs must be submitted within 30 days.
According to the Oil and Gas Conservation Regulations, if suspension activities are not performed in accordance with the Board Directives, the licensee must abandon the well.14
Legislative Directions with Respect to Well Suspension The Oil and Gas Conservation Regulations define a suspended well as a well “at which no significant producing or injecting operations have occurred during the past 12 months”, and the regulations require that such wells be suspended unless they are for observation or seasonal use.13
Board Directives with Respect to Suspension Directive 013: Suspension Requirements for Wells15
states that inactive
wells – those wells that have not reported any type of production, injection or disposal activity for 12 consecutive months – are subject to suspension requirements. Wells that are inactive must be brought into compliance with the suspension requirements of Directive 013 within 60 days of the one-year anniversary of no production or injection. Suspension requirements apply to critical sour and inactive acid gas wells that have experienced inactivity for a period of only six months. Thus, sour and acid gas wells may trigger suspension requirements much more quickly on account of inactivity.
One of the key components of Directive 013 is its classification of inactive wells into three levels of risk: low, medium and high. Low-risk wells include non-critical sour cased wells with no perforations,
OLGA 7 - because time matters
Cooperating with all major oil and engineering companies - we continuously develop OLGA to solve complicated onshore and offshore flow assurance challenges.
The Pipeline Act and its regulation is the governing legislation for all pipelines in Alberta, with a few exceptions.
water-source wells, Class 4 injector wells and non-flowing oil wells with an H2S content of less than 50 moles per kilomole. Medium-risk wells include non-flowing oil wells with an H2S content of greater than 50 moles per kilomole, flowing oil wells, Class 2 and 3 injection wells, Class 1B waste disposal wells and cavern service wells. High-risk wells include critical all sour gas wells, acid gas wells and Class 1A waste disposal wells. Certain gas wells, other than critical sour wells, may be classified as low risk or medium risk depending on the characteristics of the well. If the flow rate for any concentration of H2S from the gas well is greater than 28,000m3 per day, the gas well must be classified as medium risk. For gas wells with flow rates of H2S concentrations less than 28,000m3 per day, the risk classification of the well is dependent on whether the actual flow rate of H2S concentrations from the well is greater than the allowable rate as determined by a formula found within Directive 013.
EXPLORATION & PRODUCTION – VOLUME 9 ISSUE 2
Our simulator technology is regularly challenged to extend areas of application and document accuracy. The OLGA 7 release contains enhancements realized through the OLGA Verification and Improvement Project (OVIP), the research programs in HORIZON, the CO2
modelling project and other endeavours.
New features include: • Easy to use interface and workflows • OLGA High Definition model for stratified flow • Open framework for easy integration • Application for risk management and production optimisation
OLGA 7 - because flow matters
Proven accuracy through 30 years of innovation and validation
be dynamic®
www.sptgroup.com
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