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Directive017.pdf
/home/dck/Programming/ducklake/vlm_llm_doc_processing/pdfs/Directive017.pdf
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Alberta Energy Regulator * A licensee may deviate from the minimum requirements without specific AER approval if no royalty, equity, or reservoir engineering concerns are associated with the volumes being measured and the licensee is able to demonstrate that the alternative measurement equipment and/or procedures will provide measurement accuracy within the applicable uncertainties. In some cases, as described in section 5, “Site-specific Deviation from Base Requirements,” the licensee does not need to demonstrate compliance with the applicable uncertainties, but may instead demonstrate compliance with other specific criteria. In such cases, AER inspectors and auditors will review the licensees’ records for demonstrated compliance with the uncertainty limits or with the other specified criteria. * If royalty, equity, or engineering concerns are associated with the volumes being measured, a licensee may be allowed, upon application to the AER, to deviate from the minimum requirements. The application must demonstrate that the proposed alternative measurement equipment and/or procedures will either provide measurement accuracy within the applicable uncertainties or meet specific criteria described in section 5, “Site-specific Deviation from Base Requirements.” Applications will also be considered if measurement accuracy will be marginally outside the uncertainty limits or specified criteria will be marginally exceeded. In such cases, AER inspectors and auditors will review the licensees’ records for documentation to confirm that approval has been obtained to deviate from the minimum requirements and for compliance with the approval conditions. 1.3 Maximum Uncertainty of Monthly Volume The AER requires production data to be reported on a calendar month basis. “Maximum uncertainty of monthly volume” relates to the limits applicable to equipment and/or procedures used to determine the total monthly volume. Total monthly volumes may result from a single month-long measurement, but more often result from a combination of individual measurements and/or estimations. For example, consider a well in an oil proration battery to which a maximum uncertainty of monthly volume would apply: * First, the well is tested, and the oil test rate is used to estimate the well’s production for the period until the next test is conducted. * The well’s total estimated oil production for the month is combined with the month’s estimated oil production for the other wells in the battery to arrive at the total estimated monthly oil production for the battery. * The total actual monthly oil production for the battery is determined based on measured deliveries out of the battery and inventory change. * A proration factor is determined by dividing the actual battery production by the estimated battery production. <page_number>1-2</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Directive017.pdf
/home/dck/Programming/ducklake/vlm_llm_doc_processing/pdfs/Directive017.pdf
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Alberta Energy Regulator * The proration factor is multiplied by the well’s estimated production to determine the well’s actual monthly production. 1.4 **Single Point Measurement Uncertainty** “Single point measurement uncertainty” relates to the limits applicable to equipment and/or procedures used to determine a single-phase specific volume at a single measurement point. The oil volume determined during a 24-hour well test conducted on a well in a proration battery is an example of a specific volume determination to which a single point measurement uncertainty limit would apply. 1.5 **Confidence Level** The stated uncertainties are not absolute limits. The confidence level, which indicates the probability that true values will be within the stated range, is 95 per cent. This implies that there is a 95 per cent probability (or 19 chances in 20) that the true value will be within the stated range. 1.6 **Determination of Uncertainties** The uncertainties referred to relate to the accuracies associated with measurement devices, device calibration, sample gathering and analysis, variable operating conditions, etc. These uncertainties are for single-phase specific volume determination points of specific fluids (oil, gas, or water) or for combinations of two or more such points. These uncertainties do not relate to comparisons of two or more measurement points, such as comparison of inlet volumes to outlet volumes. Such comparisons are typically expressed as proration factors, allocation factors, or metering differences. The uncertainties are relevant to equipment at the time of installation. No uncertainty adjustment is required to account for the effects of multiphase fluids, wear, sludge or scale buildup, etc., as it is accepted that such conditions would constitute a bias error to be monitored and accounted for through the use of proration factors, allocation factors, or metering differences. The methods to be used for determining and combining uncertainties are found in the latest edition of the American Petroleum Institute (API) *Manual of Petroleum Measurement Standards (MPMS)*, chapter 13, “Statistical Aspects of Measuring and Sampling” or the latest edition of the International Standard Organization (ISO) *Standard 5168: Measurement of Fluid Flow—Estimation of Uncertainty of a Flow-rate Measurement*. <footer>Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024) <page_number>1-3</page_number></footer>
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Directive017.pdf
/home/dck/Programming/ducklake/vlm_llm_doc_processing/pdfs/Directive017.pdf
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Alberta Energy Regulator # 1.6.1 Example Calculation Determination of single point measurement uncertainty for well oil (proration battery) using “root sum square” methodology: Individual uncertainties from historical AER research: For oil/emulsion measurement, Oil meter uncertainty = 0.5% (typical manufacturer’s specification) Meter proving uncertainty = 1.5% S&W determination uncertainty = 0.5% Combined uncertainty = √[(0.5)² + (1.5)² + (0.5)²] = 1.66% (rounded to 2.0%) For delivery point gas measurement, Primary measurement device – gas meter uncertainty = 1.0% Secondary device (pulse counter or transducer, etc.) uncertainty = 0.5% Secondary device calibration uncertainty = 0.5% Tertiary device (flow calculation, electronic flow measurement [EFM], etc.) uncertainty = 0.2% Gas sampling and analysis uncertainty = 1.5% Combined uncertainty = √[(1.0)² + (0.5)² + (0.5)² + (0.2)² + (1.5)²] = 1.95% (rounded to 2.0%) # 1.7 Explanation of Standards of Accuracy ## 1.7.1 Oil Systems (i) **Total battery/facility oil** (delivery point measurement), including single-well batteries For figure 1.1, m = single point measurement uncertainty <page_number>1-4</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Directive017.pdf
/home/dck/Programming/ducklake/vlm_llm_doc_processing/pdfs/Directive017.pdf
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Alberta Energy Regulator <img>Diagram showing various oil and gas flow paths with measurement points (m) and oil pipelines. The paths include: 1) Oil Battery/Facility to Oil Pipeline, 2) Oil Battery/Facility to Pipeline Terminal, 3) Oil Battery/Facility to Pipeline Terminal or Gas Plant, 4) Oil Battery/Facility to Pipeline Terminal or Gas Plant, 5) Oil Battery/Facility to Pipeline Terminal or Gas Plant, 6) Oil Battery/Facility to Custom Treating Facility or Third-Party Licensed Clean Oil Terminal, and 7) Oil Battery/Facility to Custom Treating Facility or Third-Party Licensed Clean Oil Terminal.</img> **Figure 1.1 Total battery/facility oil (delivery point measurement)** Maximum uncertainty of monthly volume = N/A The uncertainty of the monthly volume will vary, depending upon the number of individual measurements that are combined to yield the total monthly volume. Single point measurement uncertainty: Delivery point measures > 100 m³/d = 0.5% Delivery point measures ≤ 100 m³/d = 1.0% <footer>Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024) <page_number>1-5</page_number></footer>
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Directive017.pdf
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Alberta Energy Regulator The royalty trigger point for oil is at the wellhead; thus, delivery point measurements are required at the following locations: * facility dispositions * trucked-in receipts * pipeline receipts * sales * Lease Automatic Custody Transfer (LACT) Excluded: Test points and group points if they are not used for accounting or inventory. (ii) **Total battery gas** (includes produced gas that is vented, flared, or used as fuel), including single-well batteries—also referred to as “associated gas,” as it is the gas produced in association with oil production at oil wells For figure 1.2, m = single point measurement uncertainty <img>A diagram showing an oil battery with an oil tank, a flare, and a gas gathering system. The diagram includes arrows for gas, oil, water, fuel, and vented gas, with a box labeled "m" indicating single point measurement uncertainty at various points.</img> **Figure 1.2** Total battery gas Single point measurement uncertainty: > 0.50 10³ m³/d = 3.0% ≤ 0.50 10³ m³/d = 10.0% <page_number>1-6</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Directive017.pdf
/home/dck/Programming/ducklake/vlm_llm_doc_processing/pdfs/Directive017.pdf
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Alberta Energy Regulator Maximum uncertainty of monthly volume (M) > 16.9 10³ m³/d = 5.0% ≤ 16.9 10³ m³/d but > 0.50 10³ m³/d = 10.0% ≤ 0.50 10³ m³/d = 20.0% Note that M is dependent upon combined deliveries, fuel, and vented gas measurement. The maximum uncertainty of total monthly battery gas volumes allows for reduced emphasis on accuracy as gas production rate declines. For gas rates up to 0.50 10³ m³/d, the gas volumes may be determined by using estimates; therefore, the maximum uncertainty of monthly volume is set at 20.0 per cent. If gas rates exceed 0.50 10³ m³/d, the gas must be metered; however, a component of the total monthly gas volume may include estimates for low volumes of fuel, vented, or flared gas that may add to the monthly uncertainty. At the highest gas production rates, it is expected the use of estimates will be minimal or at least have a minor impact on the accuracy of the total monthly gas volume, thereby resulting in the 5.0 per cent maximum uncertainty of monthly volume. The equipment and/or procedures used to determine the metered gas volumes (when metering is required) must be capable of meeting a 3.0 per cent single point measurement uncertainty. Due to the difficulty associated with metering very low gas rates, the equipment and/or procedures used in determining GORs or other factors to be used in estimating gas volumes where rates do not exceed 0.50 10³ m³/d are expected to be capable of meeting a 10.0 per cent single point measurement uncertainty. These uncertainties do not apply to gas produced in association with heavy oil (density of 920 kg/m³ or greater at 15°C). (iii) Total battery water, including single-well batteries For figure 1.3, M = maximum uncertainty of monthly volume <footer>Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024) <page_number>1-7</page_number></footer>
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Directive017.pdf
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Alberta Energy Regulator <img>Diagram showing a flow from Gas to Battery, Gas Gathering System, and/or Gas Plant. From the Battery, Oil flows to a Water Tank. The Water Tank is labeled M. From the Water Tank, Water flows to the Battery. The diagram indicates that no single point measurement uncertainty is required, and the maximum uncertainty of monthly volume relates to the determination of total monthly volumes (M).</img> Figure 1.3 Total battery water Maximum uncertainty of monthly volume: > 50 m³/month = 5.0% ≤ 50 m³/month = 20.0% Single point measurement uncertainty = N/A Total battery water may be determined by measurement or estimation, depending on production rates, so no basic requirement has been set for single point measurement uncertainty. Total battery water production volumes not exceeding 50 m³/month may be determined by estimation; therefore, the maximum uncertainty of monthly volume is set at 20.0 per cent. If the total battery water production volumes exceed 50 m³/month, the water must be separated from the oil and measured; therefore, the maximum uncertainty of monthly volume is set at 5.0 per cent. (iv) Well oil (proration battery) For figure 1.4, m = single point measurement uncertainty <page_number>1-8</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Directive017.pdf
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Alberta Energy Regulator <img>Well oil (proration battery) diagram</img> **Figure 1.4 Well oil (proration battery)** Single point measurement uncertainty: All classes = 2.0% Maximum uncertainty of monthly volume (M): Class 1 (high) > 30 m³/d = 5.0% Class 2 (medium) ≤ 30 m³/d but > 6 m³/d = 10.0% Class 3 (low) ≤ 6 m³/d but > 2 m³/d = 20.0% Class 4 (stripper) ≤ 2 m³/d = 40.0% M is dependent upon oil and gas test volumes and the number of days the test is used for estimating production, plus correction by a proration factor. The maximum uncertainty of monthly well oil production volumes for light- and medium-density oil wells in proration batteries has been developed to allow for reduced emphasis on accuracy as oil production rates decline. Rather than being determined by continuous measurement, monthly well oil production volumes are estimated from well tests and corrected by the use of proration factors to result in “actual” volumes. Lower rate wells are allowed reduced testing frequencies, which, coupled with the fact that wells may exhibit erratic production rates between tests, results in less certainty that the reported monthly oil production volume will be accurate. The equipment and/or procedures used to determine oil volumes during the well tests must be capable of meeting a 2.0 per cent single point measurement uncertainty for all classes of wells. These uncertainties do not apply to heavy oil wells (density of 920 kg/m³ or greater at 15°C) in proration batteries. (v) **Well gas (proration battery)—also referred to as “associated gas,” as it is the gas produced in association with oil production at oil wells** <footer>Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024) <page_number>1-9</page_number></footer>
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Directive017.pdf
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Alberta Energy Regulator For figure 1.5, m = single point measurement uncertainty <img>Well gas (proration battery) diagram showing oil wells, test, oil & GIS, gas, m, oil battery, and connections to gas gathering system, oil sales, and water disposal.</img> Total test gas must include GIS with test oil. **Figure 1.5 Well gas (proration battery)** Single point measurement uncertainty: > 0.50 10³ m³/d = 3.0% ≤ 0.50 10³ m³/d = 10.0% Maximum uncertainty of monthly volume (M): > 16.9 10³ m³/d = 5.0% ≤ 16.9 10³ m³/d but > 0.50 10³ m³/d = 10.0% ≤ 0.50 10³ m³/d = 20.0% M is dependent upon oil and gas test volumes and the number of days the test is used for estimating production, plus correction by a proration factor. The maximum uncertainty of monthly oil well gas volumes has been developed to allow for reduced emphasis on accuracy as gas production rates decline. Rather than being determined by continuous metering, monthly oil well gas production volumes are estimated from well tests and corrected by the use of proration factors to result in “actual” volumes. Low gas production rates are typically associated with wells that are allowed reduced testing frequencies, which, coupled with the fact that wells may exhibit erratic production rates between tests, results in less certainty that the reported monthly gas production volume will be accurate. For gas rates up to 0.50 10³ m³/d, the well test gas volume may be determined by using estimates; therefore, the maximum uncertainty of monthly volume is set at 20.0 per cent. If gas rates exceed 0.50 10³ m³/d, the test gas must be measured; however, a component of a well’s total test gas <page_number>1-10</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Directive017.pdf
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Alberta Energy Regulator volume may include estimates for solution gas dissolved in the test oil volume (gas-in-solution [GIS]), which may add to the monthly uncertainty. At the highest gas production rates, it is expected that the use of estimates will be minimal or at least have a minor impact on the accuracy of the total monthly gas volume, thereby resulting in the 5.0 per cent maximum uncertainty of monthly volume. The equipment and/or procedures used to determine the measured test gas volumes (if measurement is required) must be capable of meeting a 3.0 per cent single point measurement uncertainty. Due to the difficulty associated with measuring very low gas rates, the equipment and/or procedures used in determining GORs or other factors to be used in estimating gas volumes if rates do not exceed 0.50 10³ m³/d are expected to be capable of meeting a 10.0 per cent single point measurement uncertainty. These uncertainties do not apply to gas produced by heavy oil wells (density of 920 kg/m³ or greater at 15°C) in proration batteries. (vi) Well water (proration battery) For figure 1.6, m = single point measurement uncertainty <img>Figure 1.6 Well water (proration battery)</img> Figure 1.6 Well water (proration battery) Single point measurement uncertainty = 10.0% Maximum uncertainty of monthly volume = N/A The uncertainty of the monthly volume will vary, depending upon the method used to determine test water rates and the frequency of well tests. <footer>Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024) <page_number>1-11</page_number></footer>
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Directive017.pdf
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Alberta Energy Regulator Rather than being determined by continuous measurement, monthly oil well water production volumes are estimated from well tests and corrected by the use of proration factors to result in “actual” volumes. The water rates determined during the well tests may be inferred from determining the water content of emulsion samples. In some cases, estimates may be used to determine water rates. Therefore, the single point measurement uncertainty is set at 10.0 per cent. These uncertainties do not apply to heavy oil wells (density of 920 kg/m³ or greater at 15°C) in proration batteries. 1.7.2 Gas Systems (i) Gas deliveries (sales gas) For figure 1.7, m = single point measurement uncertainty <img>Diagram showing a Gas Plant connected to a meter (m) which is connected to Transmission Pipelines, Other Gas Plants, Injection Systems, or Fuel for Other Facilities.</img> <img>Diagram showing a Battery or Gas Gathering System connected to a meter (m) which is connected to Transmission Pipelines or Injection Systems.</img> Figure 1.7 Gas deliveries (sales gas) Single point measurement uncertainty = 2.0% Maximum uncertainty of monthly volume = N/A The total monthly volume may result from a single month-long measurement, making the uncertainty of the monthly volume equivalent to the single point measurement uncertainty. The delivery point or royalty trigger point for gas is generally for clean processed gas disposition (DISP) at the plant gate or for raw gas that is sent to another facility for FUEL usage only. The measurement at this point determines the gas volumes upon which royalties will be based. <page_number>1-12</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Directive017.pdf
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Alberta Energy Regulator Therefore, a stringent expectation is set for the single point measurement uncertainty. In some cases, this type of gas may be delivered to other plants for further processing or to injection facilities; thus, delivery point measurements are required at the following locations: * gas plant dispositions * sales to downstream – TCPL, ATCO, etc. * purchase from downstream facilities – co-ops, TCPL, ATCO, etc. * cross-border and cross-jurisdiction * gas delivered from one upstream facility to another that is not tied to the same system for FUEL, such as from a gas battery to an oil battery * condensate disposition to an oil facility or for sales Excluded: Return fuel to the original source facility after the gas has been sweetened. **(ii) Hydrocarbon liquid deliveries** For figure 1.8, m = single point measurement uncertainty <img>Diagram of Hydrocarbon liquid deliveries. The top diagram shows a Gas Plant connected to a meter (m) and then to a Pipeline. The bottom diagram shows a Gas Plant, Battery, or Gas Gathering System connected to a meter (m) and then to a Pipeline Terminal or Other Facilities. Both diagrams depict oil or condensate flow.</img> **Figure 1.8 Hydrocarbon liquid deliveries** Single point measurement uncertainty: Delivery point measures > 100 m³/d = 0.5% Delivery point measures ≤ 100 m³/d = 1.0% <footer>Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024) <page_number>1-13</page_number></footer>
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Directive017.pdf
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Alberta Energy Regulator Maximum uncertainty of monthly volume = N/A The uncertainty of the monthly volume will vary, depending upon the number of individual measurements that are combined to yield the total monthly volume. The term “delivery point measurement” for hydrocarbon liquids refers to the point at which the hydrocarbon liquid production from a battery or facility is measured. Where clean hydrocarbon liquids are delivered directly into a pipeline system (LACT measurement) or trucked to a pipeline terminal, it can also be referred to as the “custody transfer point.” The “delivery point” terminology is from the perspective of the producing battery or facility, but the receiving facility (pipeline, terminal, custom treating facility, other battery, etc.) may refer to this point as its “receipt point.” The hydrocarbon liquid volume determined at the delivery point is used in all subsequent transactions involving that liquid. Hydrocarbon liquids delivered out of a gas system at the well, battery, or plant inlet level are typically condensate, and in some cases they may be considered to be oil. The hydrocarbon liquids delivered out of a gas plant may be pentanes plus, butane, propane, ethane, or a mixture of various components. The volumes determined at this point are the volumes upon which royalties are based. The measurement equipment and/or procedures must be capable of determining the hydrocarbon liquid volume within the stated limits. For facilities where the hydrocarbon liquid delivery volumes total ≤ 100 m³/d, the single point measurement uncertainty has been increased to allow for the economical handling of hydrocarbon liquids when minimal volumes would not justify the added expense for improved measurement equipment and/or procedures. (iii) Plant inlet or total battery/group gas For figure 1.9, M = maximum uncertainty of monthly volume m = single point measurement uncertainty <page_number>1-14</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Directive017.pdf
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Alberta Energy Regulator <img>Diagram of Plant Inlet Separator with Gas and Condensate flow</img> Battery or Gas Gathering System Gas m Plant Inlet Separator Condensate M To Plant Processing M is dependent upon combined uncertainties of measured gas and gas equivalent of condensate. <img>Diagram of Battery with Gas and Condensate flow to Gas Plant or Gas Gathering System</img> Battery Gas m M Gas Plant or Gas Gathering System Condensate (recombined with gas) M is dependent upon combined uncertainties of measured gas and gas equivalent of recombined condensate. <img>Diagram of Battery with Gas and Condensate flow to Oil Terminal / other facilities</img> Battery Gas m M Gas Plant or Gas Gathering System Condensate Oil Terminal / other facilities M is dependent upon uncertainties of measured gas only. **Figure 1.9** Plant inlet or total battery/group gas Maximum uncertainty of monthly volume = 5.0% Single point measurement uncertainty = 3.0% Plant inlet gas or total battery/group gas is typically unprocessed gas that may vary in composition and may contain entrained liquids. The total reported gas volume could result from combining several measured volumes from various points and may also include the calculated gas equivalent volume of entrained hydrocarbon liquids (typically condensate). The expectation for the maximum uncertainty of monthly volume is set at 5.0 per cent to allow for the uncertainties associated with measuring gas under those conditions. <footer>Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024) <page_number>1-15</page_number></footer>
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Alberta Energy Regulator The equipment and/or procedures used to determine the measured gas volumes must be capable of meeting a 3.0 per cent single point measurement uncertainty. (iv) **Plant inlet or total battery/group condensate (recombined)** For figure 1.10, m = single point measurement uncertainty <img>Diagram showing a Plant Inlet Separator with a line labeled "Battery or Gas Gathering System" entering and a line labeled "Gas" exiting. A line labeled "Condensate (reported as gas equivalent volume and included in Total Plant Inlet Gas)" exits the separator. Another line labeled "Gas" exits the separator. A block labeled "Gas Plant or Gas Gathering System" receives the gas. A block labeled "Battery" receives the condensate (recombined with gas). A block labeled "Gas Plant or Gas Gathering System" receives the gas. A block labeled "Oil Terminal / Other Facilities" receives the condensate (recombined with gas). A block labeled "m" represents the single point measurement uncertainty.</img> If condensate is removed from the battery by truck and not sent for further processing, the single point measurement uncertainty for hydrocarbon liquid deliveries must be met. **Figure 1.10** Plant inlet or total battery/group condensate (recombined) Single point measurement uncertainty = 2.0% Maximum uncertainty of monthly volume = N/A The condensate volume is included in the total gas volume for reporting purposes and is therefore covered by the maximum uncertainty of monthly volume for the plant inlet or total battery/group gas. <page_number>1-16</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Alberta Energy Regulator Plant inlet condensate is typically separated from the inlet stream and sent through the plant for further processing. For reporting purposes, the gas equivalent of the plant inlet condensate is included in the total plant inlet gas volume. If total battery/group condensate upstream of the plant inlet is separated and measured prior to being recombined with the gas production, the condensate is converted to a gas equivalent volume and included in the gas production volume. In either case, the condensate single point measurement uncertainty is set at 2.0 per cent for the liquid volume determination. Note that if plant inlet or total battery/group condensate is separated and delivered out of the system at that point, the condensate measurement is subject to the single point measurement uncertainties stipulated for hydrocarbon liquid deliveries (above). (v) Fuel gas For figure 1.11, m = single point measurement uncertainty <img>Figure 1.11 Fuel gas</img> Figure 1.11 Fuel gas Single point measurement uncertainty: > 0.50 10³ m³/d = 3.0% ≤ 0.50 10³ m³/d = 10.0% Maximum uncertainty of monthly volume (M): > 0.50 10³ m³/d = 5.0% ≤ 0.50 10³ m³/d = 20.0% Note that M is dependent upon combined uncertainties of various fuel sources at each reporting facility. The maximum uncertainty of monthly fuel gas volumes allows for reduced emphasis on accuracy as gas flow rates decline. <footer>Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024) <page_number>1-17</page_number></footer>
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Alberta Energy Regulator For all upstream oil and gas facilities such as well sites, gas plants, batteries, and compressor sites, operators may estimate fuel gas use volumes for sites with an annual average fuel gas use of 0.50 10³ m³/d or less. Therefore, the maximum uncertainty of the monthly volume is set at 20.0 per cent. For any site that was constructed after May 7, 2007, and that was designed for annual average fuel gas use exceeding 0.50 10³ m³/d or for any site where annual average fuel gas use exceeds 0.50 10³ m³/d, fuel gas must be metered and the maximum uncertainty of the monthly volume is set at 5.0 per cent. For information on metering and reporting fuel usage at sites with more than one reporting facility, see section 4.2.2. The equipment and/or procedures used to determine the measured gas volumes (if measurement is required) must be capable of meeting a 3.0 per cent single point measurement uncertainty. Due to the difficulty associated with measuring very low gas rates, the equipment and/or procedures used in determining GORs or other factors to be used in estimating gas volumes if rates do not exceed 0.50 10³ m³/d are expected to be capable of meeting a 10.0 per cent single point measurement uncertainty. (vi) Flare and vent gas For figure 1.12, M = maximum uncertainty of monthly volume m = single point measurement uncertainty <img>Figure 1.12 Flare and vent gas</img> Figure 1.12 Flare and vent gas Maximum uncertainty of monthly volume = 20.0% Single point measurement uncertainty = 5.0% Flare gas may be clean processed gas or it may be unprocessed gas, depending on the point in the system from which gas is being flared. Continuous and intermittent flared and vented volumes at all oil or gas production or processing facilities (including thermal in situ facilities, but see section 12.2.2 for cold heavy oil and crude bitumen requirements) where annual average total flared <page_number>1-18</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Alberta Energy Regulator and vented volumes per facility exceed 0.5 10³ m³/d (excluding pilot, purge, or dilution gas) must be metered. Effective January 1, 2020, uncombusted gas released to the atmosphere that is not fugitive emissions must be reported as vent gas. Sites requiring flare/vent gas metering may estimate up to 0.50 10³ m³/d. Flare lines usually operate in a shut-in condition and may be required to accommodate partial or full volumes of gas production during flaring conditions. In some cases if flaring is infrequent and no measurement equipment is in place, flare volumes must be estimated (such as flaring at southeastern Alberta gas wells in a proration battery where there is no on-site measurement equipment). Therefore, the maximum uncertainty of the monthly volume is set at 20.0 per cent, to allow for the erratic conditions associated with flare measurement. The equipment and/or procedures used to determine the measured gas volumes (if measurement, not an estimate, is required) must be capable of meeting a 5.0 per cent single point measurement uncertainty. (vii) Acid gas For figure 1.13, m = single point measurement uncertainty <img>A diagram showing a flow from Batteries and Gas Gathering Systems to a Gas Plant, with a measurement device (m) measuring the gas flow to an Acid Gas to Sulphur Plant, Flare, or Injection. The Gas Plant also outputs Residue Gas.</img> Figure 1.13 Acid gas Single point measurement uncertainty is 10.0% for low-pressure acid gas before compression, and 3.0% after compression Maximum uncertainty of monthly volume = N/A The total monthly volume may result from a single month-long measurement, making the uncertainty of the monthly volume equivalent to the single point measurement uncertainty. <footer>Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024) <page_number>1-19</page_number></footer>
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Alberta Energy Regulator Acid gas usually contains a great deal of water vapour and has other conditions associated with it, such as very low pressure that affects measurement accuracy. Therefore, the single point measurement uncertainty is set at 10.0 per cent. When the acid gas is compressed and then injected into a well, the single point measurement uncertainty is set at 3.0 per cent. (See section 11.4.4.3 for details.) (viii) Dilution gas For figure 1.14, M = maximum uncertainty of monthly volume m = single point measurement uncertainty <img>A diagram showing a Gas Plant with two inputs: "Batteries and/or Gas Gathering Systems" and "Unprocessed Dilution Gas". The output from the Gas Plant is "Processed Dilution Gas" and "Residue Gas". Arrows indicate flow from the Gas Plant to the Flare, and from the Gas Plant to the Residue Gas. The diagram includes a box with "m" and "m" indicating single point measurement uncertainty.</img> M is dependent upon combined uncertainties of various dilution gas sources. Figure 1.14 Dilution gas Maximum uncertainty of monthly volume = 5.0% Single point measurement uncertainty = 3.0% Dilution gas is gas used to provide adequate heating value for incinerating or flaring acid gas. Since it must be measured, it is subject to the same uncertainties as stated above for fuel gas that must be determined by measurement. (ix) Well gas (well site separation) For figure 1.15, M = maximum uncertainty of monthly volume m = single point measurement uncertainty <page_number>1-20</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Alberta Energy Regulator <img>Diagram of well gas (well site separation) with separator, gas meter, and gas gathering system or gas plant. The diagram shows well gas entering a separator, with gas flowing to a meter (m) and then to a gas gathering system or gas plant. The separator is labeled "Separator" and the gas gathering system or gas plant is labeled "Gas Gathering System or Gas Plant".</img> M is dependent upon combined uncertainties of measured gas plus gas equivalent of condensate. <img>Diagram of well gas (well site separation) with separator, gas meter, and pipeline terminal. The diagram shows well gas entering a separator, with gas flowing to a meter (m) and then to a pipeline terminal. The separator is labeled "Separator" and the pipeline terminal is labeled "Pipeline Terminal".</img> M is dependent upon uncertainties of measured gas only. **Figure 1.15 Well gas (well site separation)** Maximum uncertainty of monthly volume: > 16.9 10³ m³/d = 5.0% ≤ 16.9 10³ m³/d = 10.0% Single point measurement uncertainty = 3.0% If production components from gas wells are separated and continuously measured, the maximum uncertainty of monthly well gas volumes allows for reduced emphasis on accuracy as gas production rates decline. Since the separated gas is unprocessed and may still contain entrained liquids at the measurement point and a component of the total reported well gas production may include the calculated gas equivalent volume of the well’s condensate production, the maximum uncertainty of monthly volumes also allows for the uncertainties associated with measuring gas under those conditions. The equipment and/or procedures used to determine the separated measured well gas volumes must be capable of meeting a 3.0 per cent single point measurement uncertainty. (x) **Well gas (proration battery)** For figures 1.16 and 1.17, M = maximum uncertainty of monthly volume m = single point measurement uncertainty <footer>Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024) <page_number>1-21</page_number></footer>
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Directive017.pdf
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Alberta Energy Regulator <img>Figure 1.16 Well gas (effluent proration battery)</img> M is dependent upon well effluent measurement, correction by an effluent correction factor, and a proration factor. **Figure 1.16** Well gas (effluent proration battery) <img>Figure 1.17 Well gas (southeastern Alberta or other approved proration battery)</img> M is dependent upon well estimates and correction by a proration factor. **Figure 1.17** Well gas (southeastern Alberta or other approved proration battery) Maximum uncertainty of monthly volume = 15.0% Single point measurement uncertainty = 3.0% If production components from gas wells are not separated and continuously measured, the gas wells are subject to a proration accounting system. There are two types of gas proration batteries. “Wet” gas wells have continuous effluent measurement, and the “actual” production is prorated based on the measurement of group gas and liquid components following separation at a central location. “Dry” gas wells approved to operate without continuous measurement have the production <page_number>1-22</page_number> Directive 017: Measurement Requirements for Oil and Gas Operations (December 2024)
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Document OCR using Nanonets-OCR2-3B

This dataset contains markdown-formatted OCR results from images in stckmn/ocr-input-Directive017-1761354068 using Nanonets-OCR2-3B.

Processing Details

Configuration

  • Image Column: image
  • Output Column: markdown
  • Dataset Split: train
  • Batch Size: 16
  • Max Model Length: 8,192 tokens
  • Max Output Tokens: 4,096
  • GPU Memory Utilization: 80.0%

Model Information

Nanonets-OCR2-3B is a state-of-the-art document OCR model that excels at:

  • 📐 LaTeX equations - Mathematical formulas preserved in LaTeX format
  • 📊 Tables - Extracted and formatted as HTML
  • 📝 Document structure - Headers, lists, and formatting maintained
  • 🖼️ Images - Captions and descriptions included in <img> tags
  • ☑️ Forms - Checkboxes rendered as ☐/☑
  • 🔖 Watermarks - Wrapped in <watermark> tags
  • 📄 Page numbers - Wrapped in <page_number> tags
  • 🌍 Multilingual - Supports multiple languages

Dataset Structure

The dataset contains all original columns plus:

  • markdown: The extracted text in markdown format with preserved structure
  • inference_info: JSON list tracking all OCR models applied to this dataset

Usage 

from datasets import load_dataset
import json

# Load the dataset
dataset = load_dataset("{{output_dataset_id}}", split="train")

# Access the markdown text
for example in dataset:
    print(example["markdown"])
    break

# View all OCR models applied to this dataset
inference_info = json.loads(dataset[0]["inference_info"])
for info in inference_info:
    print(f"Column: {{info['column_name']}} - Model: {{info['model_id']}}")

Reproduction

This dataset was generated using the uv-scripts/ocr Nanonets OCR2 script:

uv run https://huggingface.co/datasets/uv-scripts/ocr/raw/main/nanonets-ocr2.py \
    stckmn/ocr-input-Directive017-1761354068 \
    <output-dataset> \
    --model nanonets/Nanonets-OCR2-3B \
    --image-column image \
    --batch-size 16 \
    --max-model-len 8192 \
    --max-tokens 4096 \
    --gpu-memory-utilization 0.8

Performance

  • Processing Speed: ~0.1 images/second
  • GPU Configuration: vLLM with 80% GPU memory utilization

Generated with 🤖 UV Scripts

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