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1
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Question:
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Why is my well still identified on the ERCB Outstanding Initial Pressure and Deliverability Testing Requirements List when I have a successful submission response from the WTC system?
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Answer:
| There can be several reasons for this. One could be that the data were submitted just before or just after the list was updated. This list is updated every Friday; however, there could be a timing issue between when the submission was made and when the list was updated. Another reason could be that the PAS file submitted does not pass certain edit rules for fulfilling the initial testing requirement (e.g., incorrect tested interval [TTOPL/TBASL] or test purpose flag [PRPS]). |
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2
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Question:
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I have submitted an initial pressure, but it is still showing up on the outstanding list. Why?
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Answer:
| If the answer to Question 8 does not apply, then check that the pressure test type code (PRSTY) in the TRG.PAS file has been populated. This code must be provided in the file or the ERCB system cannot associate the pressure to the well. Also check that the correct PRSTY is being used according to the PAS Format Business Rules and Edits provided in Bulletin 2004-15: New Well Test Capture (WTC) System Implementation Date Reminder: Changes to Final WTC Pressure ASCII Standard (PAS) Formats and Version 4.0 PAS File Business Rules Implications. |
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3
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Question:
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Why do we need two hours on bottom for static gradients?
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Answer:
| The two-hour requirement is to establish that a stable reservoir pressure has been reached when the test is intended to fulfill either an initial or an annual requirement AND there is less than 14 days of shut-in. |
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4
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Question:
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I have a static gradient and flow and buildup to submit to fulfill annual or initial requirements and have analysis data for the buildup. How would I submit the static gradient to fulfill the requirements if the pressure is still building?
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Answer:
| Only one test is required to fulfill the requirements. Submit the flow and buildup with your Pr or P* as test purpose [PRPS] = (A)nnual or (I)nitial to fulfill and submit the GRD as [PRPS] = (O)ther. |
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5
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Question:
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If my pressure test is failing because the pressure is still building (i.e., > 2.5 kPa/hr), how can I get the data into the ERCB?
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Answer:
| If this is to fulfill initial or annual requirements, the pressure must either indicate stabilization (i.e., building < 2.5 kPa/hour over the last six hours of the test) or an extrapolated pressure (preferably from a pressure transient analysis [PTA]) must be conducted. Tests that are conducted only for information purposes and are to be submitted to fulfill Section 11.102(1) of the Oil and Gas Conservation Regulation can be submitted as a Test Purpose “Other” to avoid the edits. |
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6
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Question:
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Can acoustic tests fulfill initial test requirements?
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Answer:
| Section 5.2.1: Verification of Acoustic Methods in Directive 040: Pressure and Deliverability Testing Oil and Gas Wells states that acoustic surveys are not accepted for an initial pressure. For oil wells, if liquid was produced, a multishot (> 5) acoustic would be a minimum requirement. However, if the well is a shallow dry gas well, providing that there is verification the well is “dry” by means of an acoustic/sonic shot, then yes, acoustic tests fulfill initial pressure requirements. (Note that using well production to indicate dry gas is not accurate, especially when it comes to lower-pressured wells). |
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7
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Question:
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How much time do we have before results of test data need to be submitted?
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Answer:
| Sections 3.7 and 4.9 of Directive 040 set out the submission timeframe for specific test data. Confidential well data are required to follow the same timeframe, but be assured that these data will not be released to the public domain until confidential status is removed. |
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8
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Question:
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Once the successful submission message has been received, can I assume that all outstanding requirements have been met?
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Answer:
| Not necessarily. There are specific business rules incorporated in the Information Collection Compliance database with respect to actually fulfilling either initial or annual requirements. For example:
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The PRPS (test purpose field) must be flagged as “I” for initial and “A” for annual fulfillment. Any file submitted as PRPS = O does not fulfill any requirement.
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The gross completion intervals reported in the Petroleum Registry should correspond with the tested intervals in the file.
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The test dates should be in accordance with Sections 4.2 and 4.3 of Directive 040 for conventional wells and should be in accordance with the issuance date for CBM control wells.
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9
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Question:
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If it is not possible to achieve a stable flow rate due to liquid slugging, how do we get this requirement removed from the Outstanding Initial Pressure and Deliverability Testing Requirements list?
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Answer:
| If for whatever reason you are not able to achieve a stable flow rate, send a letter to the ERCB Well Test Group requesting exemption. Ensure that there is sufficient information to support your request. |
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10
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Question:
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If there are no initial or annual pressure requirements for commingled wells drilled within a development entity (DE), are there pressure requirements for wells that are completed within a single zone in a DE?
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Answer:
| No. Conducting a commingled fluid analysis is the only testing requirement for commingled or single-zone wells in the DEs. |
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11
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Question:
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How do I find out what pools require annual testing?
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Answer:
| The Annual Oil and Gas Survey Schedule and associated documents are initially posted on the ERCB Web site (ERCB Home : Industry Zone : Rules, Regulations, Requirements : Well Testing Pressure Survey Schedules) in early February for that survey year. These documents are also sent by e-mail to the Well Test Group’s contact list. Updates are posted periodically throughout the year and provided as stated above. |
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12
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Question:
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What does “Special Circumstances” in the Frequency Column mean for pools listed on the Annual Oil and Gas Survey Schedule?
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Answer:
| Special Circumstances indicates that there are certain conditions pertaining to annual testing. These conditions are described briefly in Appendix 1 of the relevant schedule and, among others, cover off-target wells, observation wells, and enhanced recovery schemes.
Documentation is sent to licensees/approval holders detailing the specific requirement. |
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13
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Question:
| Why is a pool not identified on the current annual schedule when it was identified on last years’ schedule? NEW |
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Answer:
| It did not meet the criterion as identified in section 4.5.1 of Directive 040. |
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14
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Question:
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Can a test be started in the previous year but used to fulfill the requirement for the following year? NEW
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Answer:
| As a rule, testing should be started and completed during that particular required survey year with respect to “annual” frequencies. That being said, if a turnaround is scheduled for example in late 2011, the test ends during 2012, and the 2011 requirements were fulfilled more than 6 months prior, the coordinating operator or licensee could apply for acceptance of this late test to be used for fulfillment of the 2010 requirement, to the Well Test Compliance Group. |
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15
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Question:
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What do the different frequencies mean?NEW
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Answer:
| Annual = test every year, Biennial = test every 2 years, Quadrennial = test every 4 years, Triennial = testing conducted within 3 years. Pools identified on the annual pressure survey schedule with a “Survey Requirement = Special Circumstances” are usually an annual requirement unless otherwise stated in the Appendix. |
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16
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Question:
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What is required to change a well status to observation?NEW
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Answer:
| If the licensee wishes to change a well status to observation for the sole purposes of monitoring the reservoir pressure, then a request is required to be submitted to the Welltest-Helpline@ercb.ca for approval. Upon approval, the licensee can change the status in the Petroleum Registry and we will include the associated field and pool on the annual pressure survey schedule and identify the observation well on the Appendix for reference. It is the responsibility of the coordinating operator or licensee to ensure that a pressure test is conducted and submitted by December 31 of each survey year. |
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17
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Question:
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How many tests am I required to conduct if the number of wells in the pool changes between the start of the survey year and the end of the survey year? NEW
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Answer:
| Test 25 per cent of the number of wells in the pool from the date of the first publication of the annual survey schedule. |
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18
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Question:
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If I did not fulfill my annual requirement and was escalated to a Notice of Low Risk Noncompliance, do I still have to obtain this data? NEW
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Answer:
| Yes, although the data was not obtained during the required survey year, you are still responsible for fulfilling the requirement. |
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19
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Question:
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If I fulfill my requirement after being escalated to a Notice of Low Risk Noncompliance, am I still required to pay the invoice? NEW
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Answer:
| Yes, that is the penalty for non-submission of the data requirement by the specific due date (initial – by the due date identified on the “Outstanding Initial Well Testing Requirements List” and annual – by March 31 of the year following the survey year). The invoice is also required to be paid as described in Directive 019 – Compliance Assurance. |
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20
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Question:
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I submitted annual pressure data but the annual schedule still says “outstanding”, why? NEW
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Answer:
| There could a number of reasons for this. One could be that the submission did not pass specific business rules to fulfill the requirement (eg. test purpose = O, tested top and base intervals in PAS file do not correspond to the gross completion interval (GCI) reported in the Petroleum Registry, incorrect well fluid type reported in the PAS file compared to the Resource Type provided on the annual schedule). Testing has been conducted outside of an approval area (if applicable) or not conducted on specific wells identified on the Appendix. |
