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1 November 2001
The Norwegian Petroleum Directorate (NPD)
The purpose of these regulations is to ensure that accurate measurements form the basis of the calculation of taxes, royalties and fees etc. to the Norwegian state, including the CO2 tax, and the income of the licensees. The regulations contain supplementary provisions to the requirements of the Petroleum Act and the CO2 Tax Act relating to measurement of petroleum and stipulate framework requirements concerning the organisation, planning and implementation of the activity as referred to in the Petroleum Act and the CO2 Tax Act. Put into force 30 October 2006, the requirements for measuring systems for liquids other than water are changed to be in conformance with the Directive 2004/22/EU, Measuring Instruments Directive (MID) and are harmonized with the Regulation of 21 December 2007 no. 1738, “Requirements for measuring system s for liquids other than water” adopted by Department for Industry and Trade (NHD) and Norwegian Metrology Service cf. remarks to Section 13a. Practically this applies to measuring systems for Liquid Petroleum and NGL.
The measurement regulations define functional and specific requirements to the design and operation of the metering equipment, elaborates on the responsibility of the individual participant to comply with requirements laid down in or pursuant to applicable law and shall contribute to ensur ing that the metering equipment and method at all times comply with the requirements of these regulations relating to accumulated measuring uncertainty. The regulations stipulate requirements with regard to how the quantities of fuel and flare gas are to be reported and documented. Furthermore the regulations provide for suitable supervision of the activities. These regulations replace the previous Regulations for fiscal measurement of oil and gas etc. and the previous Regulations relating to measurement of fuel and flare gas for calculation of CO2 tax in the petroleum activities. Particular points relating to CO2 tax measurement are dealt with in comments re. Section 14. If provisions contained in these regulations apply to either fuel gas or flare gas this will appear from the text.
The comments to Section 1 of these Regulations describe the process concerning equipment and methods for measuring NOx emissions.
The regulations provide for a practice whereby not all documentation needs to be submitted to the Norwegian Petroleum Directorate, but may instead be available from the operator and be submitted to the Norwegian Petroleum Directorate on request. Furthermore provision is made for transfer of information electronically.
Comments have been prepared to the individual provisions of these regulations. The comments provide explanation and guidance in relation to the provisions of the regulations. Examples are given to show how the requirements of regulations can be complied with, or reference is made to recognised standards, including industry standards, as one way in which the requirements of the authorities may be complied with. Standards which are not mentioned in the Regulations including comments may be applied following consultation with the Norwegian Petroleum Directorate. Trading in petroleum takes place across national borders with international actors. Technical standards should therefore be internationally accepted. Reference is further made to comments re. Section 4. Guidelines to Plan for devel opment and operation of a petroleum deposit, PDO, and Plan for installation and operation of facilities for transport and utilisation of petroleum, PIO, of 18 May 2000 contain details on the information which should be contained in a PDO/PIO with regard to fiscal measurement systems.
Regulations relating to measurement of petroleum for fiscal purposes and for calculation of CO2 tax, issued by the Norwegian Petroleum Directorate 1 November 2001 pursuant to Section 86 of Regulations to Act relating to petroleum activities issued by Royal Decree 27 June 1997 No. 653, cf. Act of 29 November 1996 No. 72 relating to petroleum activities, Section 4-10 and Section 5 of Act of 21 December 1990 No.72 relating to tax on discharge of CO 2 in connection with petroleum activities on the continental shelf, cf. Decision on delegation issued by the Ministry of Petroleum and Energy 28 June 19 85 and 27 December 1990. Regulations of 11 December 2001 nr. 1451 on Excise Duties (NO x duties) section 3-19-7. EEA Agreement, Annex II, Chapter IX, paragraph 27b (Directive 2004/22/EF). Last amended 8 March 2012.
These regulations are applicable to the petroleum activities in areas comprised by Section 1 - 4 of the Act of 29 November 1996 No. 72 relating to petroleum activities and Section 2 of the Act of 21 December 1990 No. 72 relating to tax on discharge of CO2 in connection with petroleum activities on the continental shelf, specifically:
a) in planning, design, construction and operation of metering systems for measuring produced, transported and sold quantities of oil and gas (fiscal measurement systems)
b) in planning, design, construction and operation of metering systems and metering equipment for determination and reporting of quantities used for fuel and flare gas in petroleum activities.
For flow meters for liquids other than water the Regulation of 26 April 2006 no. 466 concerning requirements (for liquids other than water) issued by Department of Industry and Trade (NHD) and Norwegian Metrology Service, with the clarifications pursuant to this regulation, is prevailing.
For the purpose of these regulations, the following definitions shall apply:
An official recognition to the effect that an organisation is operating in accordance with a documented quality assurance system and that it has demonstrated is competency to carry out specified tasks.
Apportionment of petroleum between various owner groups and owner companies. Recognised standard: Standards, guidelines and similar which within a technical sphere are internationally and/or nationally recognised. Acts or regulations which are not directly applicable but which regulate corresponding or neighbouring areas may equally be recognised standard.
Natural gas, oil, condensate or diesel used for operation of combustion machinery such as turbines and similar.
Place of operation:
Facility or terminal where the metering system is in service.
Place of manufacture:
Place where fabrication, assembly and testing of one or more of the metering system‟s main components takes place.
That part of the metering system which consists of computers and receives metering signals from A/D converters or from digital instrument loops.
Natural gas burnt off or vented to the atmosphere.
Metering carried out in connection with purchase and sale and the calculation of taxes and royalties.
A device that responds to the condition which is to be measured, so that the device produces a signal proportional to this condition.
Flow meter for liquids other than water:
An instrument for continuous measurement, registration and display of the amount of liquid which flows in a liquid filled pipe under defined conditions.
An assembly consisting of a transducer and one or more sensing elements. The signal from an instrument represents a physical condition. A technical device used to measure a physical parameter.
Part of the metering system from and including the instrument to the digital input of the computer part.
Establishment of relationship between measured value and reference value with known uncertainty. The English term “proving” is often used for calibrating meters against a known volume.
Calibration factor, K-factor:
Relationship between the measured value coming from a meter and the measured value from a reference measurement system. (Normally a designated value that signifies pulses per volume unit).
Calibration factor (meter factor) for flow meter:
Non designated value which st ates the relationship between the flowmeter‟s registration and the flow volume.
Selectable condition of the computer part to carry out verification whilst the associated meter tubes are closed.
Monitoring, supervision, inspection and similar of conditions, processes, products etc. to ensure that they comply with specifications.
1. Deviation between a calibration curve for a device and a straight line.
2. Correlation between variables where a change in one c auses a precise and proportional change for the other.
Liquefied Natural Gas (LNG):
Natural gas mainly consisting of methane (CH4) refrigerated to liquefied form at about minus 160 degrees C, with density at atmospheric pressure of around 430 – 460 kg/m3 . Standard density is typically in the area 0,67 – 0,74 kg/Sm3.
All mechanical equipment included in an oil or gas metering system.
Straight pipe section where a flow meter is installed.
Assembly of all equipment and computer links etc. from sensor input to the visual representation in the computer part.
Assembly of metering equipment dedicated to the determination of measured quantities.
An expression of the result of a measured value which characterises the range within which true value is expected to lie.
Consists of a mechanical part, an instrument part and a computer part, as well as appurtenant documentation and procedures.
Indicates the least variation in signal level which produces a noticeable change in the displayed value.
Marketable products fractionated from crude oil or natural gas. Examples are: Ethane, propane, petrol, paraffin.
Device for calibration of dynamic flow meter, based on displacement of a body through a calibrated tube.
A marking of a flow meter with a "CE" mark, additional metrological marking and identification number for the relevant notified body as described in the Regulation for flow meters (for liquids other than water).
A declaration that a product fulfill the technical requirements which are issued for flow meters in the the Regulation for flow meters (for liquids other than water).
Flow meter (Gas):
Equipment located in or clamped to a pipe with associated signal transformer providing a primary signal proportional to the amount of flow through the pipe.
Technical device which changes the nature of the measured signal. Used in these regulations solely in respect of ultrasonic meters.
The licensee and other parties participating in petroleum activit ies comprised by these regulations are responsible according to the regulations and individual administrative decisions issued by virtue of the regulations.
In addition the licensee has a duty to see to it that anyone carrying out work for him, either personally, by employees, contractors or sub - contractors, complies with these regulations and individual administrative decisions issued by virtue of the regulations.
Activities as mentioned in Section 1 of the present regulations shall be carried out in accordance with requirements stipulated by or pursuant to these regulations, and in accordance with recognised standards for such activities.
When technology or methods not described in recog nised standards are used, criteria for development, testing and operation are required to be produced.
The licensee and others participating in the petroleum activities shall establish, follow up and assure the development of a management control system which shall include organisation, processes, procedures and resources necessary to ensure compliance with the requirements of the present regulations.
A management control system for metering shall be prepared and maintained in a systematic and controlled manner. Update and revision shall be announced within the organisation itself, to the Norwegian Petroleum Directorate and other parties concerned. The management control system shall ensure that relevant experience and information is conveyed from one shift of personnel to the next and from the construction phase to the operational phase.
Executive responsibility for, and supervision of, the manageme nt control system shall be placed with the unit responsible for the other management control systems of the enterprise.
A quality assurance manual for the operation of metering systems shall be prepared.
The funct ional scope and areas of responsibility of personnel who carry out supervision of or tasks in connection with the metering system shall be documented in the organisation chart of the licensee. The duties, responsibilities and authority of the personnel sha ll be described.
The licensee shall nominate the person responsible for the metering system. The nominated person shall be responsible to see that procedures relating to operation, maintenance, calibration and control are followed.
All personnel carrying out tasks related to the metering systems shall possess documented qualifications within the relevant technical sphere. A system shall be established to show that updating and skills/competence advancement is ensured.
When planning, designing, purchasing, building and operating fiscal measurement systems as mentioned in these regulations, the licensee shall be able to verify that the provisions of the regulations or individual administrative decisions have been complied with. In dependent verification of critical parameters may be required.
The licensee shall see to verification of fiscal figures and calibration reports for equipment comprised by these regulations.
|Measurement system||Uncertainty limit at 95 percent (%) confidence level
(expanded uncertainty with coverage factor k=2)
|Oil metering for sale and allocation purposes||0.30% of standard volume|
|Gas metering for sale and allocation purposes||1.0% of mass|
|Fuel gas metering||1.5% of standard volume|
|Flare gas metering||5.0% of standard volume|
|Sales measurement of LNG||0.50% of measured energy contents per ship load|
The measurement system shall be designed so that systematic measurement errors are avoided or compensated for.
It shall be possible to document the total uncertainty of the measurement system. An uncertainty analysis shall be prepared for the measurement system within a 95 percent confidence level. In the present regulations a confidence interval equal to ± 2, i.e. coverage factor k=2, is used. This gives a confidence level slightly higher than 95 percent.
LNG shall be measured and analyzed at the place of loading. The operator is responsible for, and shall be able to document, that the measurement system is in accordance with recognized norms. LNG volumes may be determined in connection with loading by use of traceable measured vessel tanks and calibrated level gauges.
In respect of the measurement system‟s individual components the following maximum limits apply:
|Component||Circuit uncertainty limits||Uncertainty limits component/ Linearity band||Repeatability limits (band)|
|Meter prover oil||NA||0.04% for all 4 volumes||0.02% for all 4 volumes|
|Turbin meter oil||1 pulse of 100000, 0.001%, during pulse transmission of the measurement signal.||0.25% in working range (10:1) Band: 0.50% (10:1) and 0.30% (5:1)||0.027%, uncertainty, cf. Table B1, API MPMS Ch. 5.8.|
|Ultrasonic flow meter oil||1 pulse of 100000. 0.001%, at pulse transmission of signal||0.20% in working range (10:1) Band: 0.30% (10:1)||0.027%, uncertainty, cf. Table B1, API MPMS Ch. 5.8.|
|Coriolis meter oil||1 pulse of 100000. 0.001%, during pulse transmission of the measurement signal||0.20%, in the working range. Band: 0.30% (10:1)||0.027%, uncertainty, cf. Table B1, API MPMS Ch. 5.8.|
|Turbine meter gas (sales - allocation)||1 pulse of 100000. 0.001%, during pulse transmission of the measurement signal||0.70% in working range (10:1) Band: 1.0 % (10:1)||0.28% in working range (10:1)|
|Ultrasonic flow meter gas (sales - allocation)||1 pulse of 100000. 0.001%, at pulse transmission of signal||0.70% in the working range (20:1) after performing zero point correction and entering K - factor. Deviation from reference, see NORSOK I - 104.||0.40% in working range (20:1) after zero point control|
|Coriolis gas meters (allocation)||1 pulse of 100000. 0.001%, du ring pulse transmission of the measurement signal||0.70% in the working range 20:1||0.40% for gas velocities exceeding the minimum specified velocity.|
|Pressure measuring oil, gas||0.30% of measured value in working range||0.10% of measured value in working range||NA|
|Pressure measuring fuel gas, flare gas||0.50% of measured value in working range||0.20% of measured value in working range||NA|
|Temperature measuring oil, gas||0.30°C||0.20°C||NA|
|Temperature measuring fuel gas, flare gas||0.50°C||0.30°C||NA|
|Density measuring oil||0.50 kg/m3||0.30 kg/m3||NA|
|Density measuring gas||0.30% of measured value||0.20% of measured value||NA|
|Differential pressure measuring||0.30% of measured value in working range||0.10% of measured value in working range||NA|
|Water in oil measuring||0.05 volume % absolute for 0 to 1.0 volume % water content, ± 5.0% of measured value over 1.0 volume % water content||0.50% of measured value at water content over 0.01volum%|
|Density measurement LNG||N/A||0.30% of measured value||N/A|
|Volume measurement LNG||N/A||0.30% of measured value||N/A|
|Online GC||N/A||0.30% of calorific value||0 - 25 mol %: 0.02 mol % 25 - 100 mol %: 0.05 mol %.|
|Calorific value gas||NA||0.30% of calorific value||NA|
|Uncertainty computer part for oil and gas||NA||0.001%||NA|
|Uncertainty computer part for fuel and flare gas||NA||0.1%||NA|
|With regard to fuel gas: cf. comment re. Section 14.|
The linearity band can be used as a test criterion when accepting meters and is stated in the component uncertainty column where this is relevant.
The repeatability requirement for fluid meters is now an uncertainty require ment of 0.027%, cf. Table B1, in API MPMS Ch. 5.8.
For measuring systems for liquids other than water, cf. this Regulation section 13 a, the minimum requirements for uncertainty limits as included into the Regulation of 21 December 2007 no. 1738, section 29, cf. this Regulation section 3. The equivalent requirements apply to modules of a measuring system if pursuant to requirements stated in the Regulation concerning requirements for measuring systems for (liquids other than water).
The measuring system shall give readings in SI units. Reporting of fiscal figures to the Norwegian Petroleum Directorate shall be in SI units.
Reporting of fuel and flare gas to the Norwegian Petroleum Directorate shall be in standard cubic meters in respect of natural gas and litr es in respect of diesel or other hydrocarbons in liquid phase.
Determination of the critical parameters of the measuring system by measurements shall be in SI units.
Standard reference conditions for pressure and temperature shall in measuring oil and gas be 101.325 kPa and 15°C. In the measuring of petroleum products other reference pressure may be used.
Gas composit ion from continuous flow proportional gas chromatography or from automatic flow proportional sampling shall be used for determination of energy content.
With regard to sales gas metering stations two independent systems shall be installed.
When oil or ga s is analysed to determine physical and/or chemical properties and the analysis results are used for sale or allocation purposes, this shall be carried out by a competent laboratory.
Bypassing of the metering system is not permitted.
The measuring system shall be planned according to the requirements in this regulation and according to recognised standards for such measuring systems. Additional requirements following from Section 13a apply for flowmeters for liquids (other than water).
The metering system shall be capable of metering the full range of planned hydrocarbon flows without a ny component involved operating outside its working range.
The measurement system shall, to the extent possible, be equipped with duplicated instrument functions for signals from primary meters and instrumentation for facilitating condition based monitoring and reducing the need for preventive maintenance. Sign als from parallel metering runs can be used in connection with condition monitoring.
Wireless communication between different parts of the fiscal measurement system can be used if it is demonstrated that the solution s are equal to or better than the traditional solution s using a communication cable, with regard to integrity.
On sales metering stations the number of parallel meter runs shall be such that the maximum flow of hydrocarbons can be measur ed with one meter run out of service, whilst the rest of the meter runs operate within their specified operating range.
The metering system shall be suitable for the relevant type of measuring, the given fluid properties and the hydrocarbon volumes to be measured.
If necessary, flow straighte ners shall be installed.
In areas where inspection and calibration takes place there shall be adequate protection against the outside climate and vibration.
The metering tube and associated equipment shall be insulated upstream and downstream for a distance sufficient to prevent temperature changes affecting the instruments that provide input signals for the fiscal calculations.
Shutoff valves shall be of the block and bleed type. All valves of significance to the integrity of the metering station shall be accessible for inspection to secure against leakage.
All parts of the metering system shall be easily accessible for maintenance, inspection and calibration.
Multiphase measurement may be used if traditional single phase measurement of hydrocarbons is not possible for financial reasons. The multiphase meter can then be used as a fiscal meter.
The following elements shall be satisfactorily documented to allow use of a concept based on multiphase measurement, cf. Chapter VII and Section 18:
When the multiphase meters are part of the fiscal measurement system, they shall be treated as other fiscal measurement equipment and the administrative requirements which apply pursuant to these Regulations shall therefore be fulfilled.
Measurement systems for liquids other than water which are purchased for use in the petroleum industry, or which are put into use after 30 October 2006 within the scope of this regulation, shall be approved by a notified body according to the procedures for conformity declaration, cf. the Regulation for measuring systems for liquids other tha n water, section 4 and regulation 20 December 2007 no. 1723 “Regulation for measurement units and measurement, chapter 4. Moreover, the same regulation section 8 - 1 applies. The transitional provisions for measurement equipment covered by the directive 2004/22/EF, apply.
The measuring systems for liquids other than water shall have conformity declaration and conformity marking, which include supplementary metrology marking. This also applies if the measuring system is designed and produced solely for own purposes. The equivalent requirements apply to modules of a measuring system if pursuant to requirements stated in the Regulation for measuring systems for liquids other than water.
When in use the measuring systems for liquids other than water shall as a minimum fulfil the requirements of this regulation section 8a.
The mechanical part of the metering system shall be designed so that representative measurements are achieved as input signals for the fiscal calculations (cf. Section 8).
Provision shall be made for necessary redundancy and the possibility of verification of the gas and liquid metering devices.
When turbine meters are used for liquid metering, a permanent prover shall be availabl e for calibration of the metering devices.
It shall be possible to calibrate the prover at the place of operation.
If other types of flow meters are used for liquid metering, permanent equipment for calibration of the metering device shall be available.
It shall be documented that surrounding equipment will not affect the measured signals.
Pressure, temperature density and composition analysis shall be measured in such way that representative measurements are achieved as input signals for the fiscal calculations (cf. Section 8).
The computer part of the metering system shall be designed in such way that the fiscal calculations may be carri ed out within the stipulated uncertainty range (cf. Section 8).
The computer part of the metering system shall be equipped with various security functions to ensure that the fiscal values cannot be changed as a result of incidents of a technical nature or as a result of a manual fault.
With regard to reports the computer part shall be capable of documenting the various fiscal parameters and the fiscal volumes calculated.
The computer part shall have uninterruptible power supply. It shall be ensured that faults are detected as an alarm and that a back-up system is activated. A power failure shall not be able to cause measured fiscal data to be deleted from the storing unit of the computer.
Sampling shall be carried out in a manner which ensures that representative amounts are sampled.
Sampling shall be automatic and flow proportional. In addition it shall be possible to carry out manual sampling.
With regard to oil and condensate the necessary mixing equipment shall be installed upstream of the sampling probe.
The licensee shall obtain consent from the Norwegian Petroleum Directorate prior to startup of the metering system.
Consent for carrying out major rebuilding or change in the purpose for use for the metering system shall also be obtained.
If the basis for consents granted in accordance with the first paragraph of this section is significantly changed, the Norwegian Petroleum Directorate may require the licensee to obtain a new consent before the activities are continued.
Prior to startup of the metering system, procedures shall be prepared for o peration, maintenance, calibration and verification. The procedures shall ensure that the metering system is maintained to the standard to which it is designed.
Procedures for calibrations and verifications to be carried out in order to prepare the metering station for startup, shall be forwarded to the Norwegian Petroleum Directorate enclosed with the application.
Calibrations and verifications as described in this Chapter shall be carried out prior to startup of the metering system at the place of operation.
The Norwegian Petroleum Directorate shall have the opportunity of being present when the activities are carried out.
The prover volume shall be calibrated:
a) before the metering system is delivered from the place of manufacture
b) prior to startup at the place of operation.
The mechanical parts critical to measurement uncertainty shall be measured or subjected to flow calibration in order to document calibration curve.
The fully assembled fluid metering system shall be flow tested at the place of manufacture and a functional test shall be performed on flowmeters.
Statistical methods to provide documentation for repeatability requirements may be used.
The instrument loops shall be calibrated and the calibration results shall be accessible.
The instrument loops shall be calibrated at a number of values necessary to detect any non linearity errors within its working range. Calibration of the instrument loops shall be carried out using the display reading of the visual signal from the computer part.
Verification of the computer part shall be carried out for each metering tube to confirm that all functions are operational.
Each independent program routine shall be verified to show that calculations are carried out with requirements equal to or better than those mentioned in Section 8 of the present regulations. Integration shall be verified with at least three values in the flow range.
The calculations for calibrations as mentioned in Section 20 of these regulations shall be verified. This includes K-factor in respect of the individual calibration and the average value within the predetermined range of variation.
The metering system shall be maintained to the standard according to which it is designed.
The equipment which is an integral part of the metering system, and which is of significant importance to the measuring uncertainty, shall be calibrated using traceable equipment before start of operation, and subsequently be maintained to that standard.
Control to ensure th at equipment mentioned in the first paragraph of this section is within given limit values shall be carried out regularly by qualified personnel. If during calibration equipment is shown to be outside the given limit values, correction shall be carried out by qualified personnel or by calibration and associated correction in a competent laboratory. Traceable calibration of test instruments shall be carried out regularly by competent laboratories.
The meter prover volume shall be calibrated annually Calibration shall also be carried out if the volume may have changed as a result of equipment failure.
Turbine meters for oil shall be calibrated against the permanent meter prover with a repeatability such that 5 consecutive single calibrations in se quence fall within a range of 0.05% of the average calibration factor.
The calibration factor for the flow meters shall be within the control limits according to recognised standard. Flow meters installed after workover, modification or replacement shall immediately be calibrated to verify that they meet the requirements to linearity and repeatability.
After startup of the metering system, calibration of flow mete rs shall be carried out in order to verify requirements to repeatability and linearity. It shall furthermore be verified to what extent the calibration factor is affected by flow volume, temperature, pressure and crude composition when these vary within their normal operating range.
The calibration of flow meters shall satisfy the following requirements:
a) If there is a correlation between calibration factor and flow rate, temperature, pressure, density, viscosity or composition, calibration factor limits shall be established. A new calibration shall be carried out if the limits are exceeded.
b) The time i nterval between calibration of the flow meters shall not exceed four days. Calibration factor for flow meters in use shall be established for each tanker loading.
Statistical methods may be used to document requirements to repeatability.
The orifice plat es shall be inspected with regard to edge sharpness, surface roughness and flatness. An inspection shall be carried out at startup and then once a month during the first six months. Subsequently the intervals may be extended, however if at a later time dam age or wear - and - tear is detected, the interval between inspections of the orifice plates shall be reduced. The orifice plate shall also be inspected after incidents which may have affected the fiscal measuring quality. The orifice plates shall be certified prior to installation in meter tubes and subsequently if visible damage is detected.
In the case of ultrasonic flow measurement of gas the condition parameters shall be verified.
During orifice plate gas measuring or ultrasonic gas measuring the meter tubes shall be checked if there is indication of change in internal surface.
All sensors shall be monitored continually and/or shall be regularly calibrated in accordance with the requirements of Sect ion 8. Calibration shall comprise several values in the sensor‟s operating range. If the outlet signals from the sensors deviate from the preset limits, necessary maintenance and subsequent new calibration shall be undertaken.
The calibration methods shall be such that systematic measurement errors are avoided or compensated for.
Gas densitometers shall be verified against calculated density or other relevant method.
Online gas chromatographs shall be validated against a traceable reference gas with a stipulated frequency. Pursuant to the uncertainty statement in Section 8, validation criteria shall be stipulated. If a gas chromatograph is outside the stated criteria d uring validation, calibration shall be performed and new factors established. A new validation shall be perform ed following such a correction to confirm that the gas chromatograph is now within the given test criteria.
Variations in gas composition shall b e monitored and, in the event of variation exceeding ± 5%, a reference gas with a different calorific value and a new linearity test should be considered.
Critical data shall be filed regularly. Procedures shall be established for handling of fault messages from the computer part or faults otherwise discovered.
In the case of software changes and replacement of computer parts an independent verification shall be carried out of the calculation requirements of the computer part, cf. Section 22 of the present regulations.
After the Plan for development and operation of petroleum deposits (PDO) and Plan for installation and operation of facilities for transport and utilisation of petroleum (PIO) have been approved and prior to start-up of the metering system, the operator shall have the following documents available,
a) technical description of the metering system;
b) an overview showing the location of the metering system in the process and transportation system;
c) drawings and description of equipment included in the metering system;
d) list of documentation for the metering system;
e) progress plan for the project up to the time of application for consent to use;
f) description of the operator„s and the supplier‟s management control system for follow-up of the metering system;
g) uncertainty analysis.
The Norwegian Petroleum Directorate shall on request receive documentation as mentioned in the first paragraph of this Section.
An archive shall be established and maintained which shall contain documentation in respect of the metering system. It shall be possible to document that the quality of measurements are as described in the present regulations and that there is accordance between reported and measured quantities.
Fixed parameters shall be easy to verify. Correction shall be made for documented measurement errors.
Correction shall be carried out if the deviation is larger than 0.02% of the total volume. If measurement errors have a lower percentage value, correction shall nevertheless be carried out when the total value of the error is considered to be significant.
If there is doubt as to the time at which a measurement error arose, correction shall apply for half of the maximum possible time span since it could have occurred.
Reporting of CO2 tax metering for payment of the CO2 tax shall take place every six months as stated in Section 4 of the CO2 Tax Act and in accordance with the form issued by the Norwegian Petroleum Directorate.
In the event that measured figures are not available for technical reasons, it shall be possible to document the reported figures in a manner which is acceptable from a calculation point of view.
Quantities of diesel delivered to the facility during the tax period in question shall be reported as taxable basis for calculation of CO2 tax. Deduction in respect of diesel which has not been used as fuel shall be documented and reported to the Norwegian Petroleum Directorate as mentioned in the fourth paragraph of this Section.
All measured data comprised by these regulations shall be reported in the PetroBank system.
When the PDO has been approved, the licensee shall inform the Norwegian Petroleum Directorate about all significant changes that affect the quality of fiscal measurements or figures reported from them.
The Norwegian Petroleum Directorate shall be informed about
a) annual plan for activities within the technical field in question;
b) procedure for ownership allocation of petroleum between licensees in production licenses.
c) measurement errors;
d) when fiscal measure ment data have been corrected based upon calculations;
e) change in calibration interval;
f) change in calculation software;
g) changes affecting the basis of the consent;
h) cargo claims procedures applicable for sale of hydrocarbons in liquid phase.
Description of procedure during calibration and inspection, as well as an overview of results where measurement deviation before and after calibration is shown, shall be documented. The documentation shall be available for verification at the place of operation.
The Norwegian Petroleum Directorate shall supervise compliance with provisions laid down in or decisions made pursuant to the present regulations. The Norwegian Petroleum Directorate may make such individual administrative decisions as are necessary to implement provisions contained in the present regulations.
The Norwegian Petroleum Directorate may in particular cases grant exemption from provisions contained in the present regulations.
Violation of these regulations or of decisions made pursuant to these regulations shall be punishable as stat ed in the Petroleum Act Section 10-17 and the CO2 Tax Act Section 7, cf. the Criminal Code Chapter 3a.
1. These regulations enter into force 1 January 2002.
2. As from the same date, the following amendments shall be made:
a) Regulation for fiscal measurement of oil and gas etc. issued by the Norwegian Petroleum Directorate 3 July 1991, No. 532, shall be repealed.
b) Regulations relating to measurement of fuel and flare gas for calculation of CO2 tax in the petroleum activities, issued by the Norwegian Petroleum Directorate 12 August 1993, No. 806, shall be repealed.
3. Decisions made pursuant to the regulations mentioned in th is section item 2 shall remain in force until such time as they may be repealed or altered by the Norwegian Petroleum Directorate.
4. a) The general requirements of these regulations and requirements relating to testing and operation of measuring equipment (Chapters I, II, III, V, VI, VII and VIII) are applicable to all metering systems.
b) Requirements to design (Chapter IV) apply only to metering systems where the design was commenced after 1 January 2002. The Norwegian Petroleum Directorate may by individual administrative decisions directed at the individual operator make requirements to design fully or partly applicable to measuring equipment or metering systems designed prior to the time mentioned in the preceding sentence, cf. Section 32 of the present regulations.
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Last translated 2 July 2012
English version is not necessarily updated according to recent changes at any time.