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THE MINISTRY OF
INDUSTRY
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THE SOCIALIST REPUBLIC OF VIETNAM
Independence– Freedom – Happiness
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No. 38/2005/QĐ-BCN
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Hanoi, December 06,
2005
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DECISION
ON THE CLASSIFICATION
OF PETROLEUM RESOURCES AND RESERVES, AND PETROLEUM RESERVES REPORTING
THE
MINISTER OF INDUSTRY
Pursuant to the Law on Petroleum dated July 06, 1993,
and the Law on amending and supplementing a number of articles of the Law on Petroleum
dated June 09, 2000;
Pursuant to the Government's Decree No. 48/2000/NĐ-CP
dated September 12, 2000, detailing the implementation of the Law on Petroleum
Pursuant to the Government's Decree No. 55/2003/NĐ-CP
dated May 28, 2003, defining the functions, tasks, powers and organizational
structure of the Ministry of Industry;
At the proposal of the Director of the Department of
Energy and Petroleum,
DECIDES:
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Article 2. This Decision takes effect after 15 days as from its
publication on the Official Gazette. The
previous provisions in contravention of this Decision are all abolished.
Article 3. The Chief of the Ministry Office, The Ministerial
Chief Inspector, Directors of Departments affiliated to Ministries, Directors
of Departments of Industry of central-affiliated cities and provinces, the
General Director of Petrovietnam, and Heads of relevant units are responsible
for implementing this Decision./.
THE MINISTER
Hoang Trung Hai
REGULATION
ON THE CLASSIFICATION OF PETROLEUM RESOURCES AND RESERVES,
AND PETROLEUM RESERVES REPORTING
(Promulgated
together with the Decision No. 38/2005/QĐ-BCN dated December 06, 2005 of the
Minister of Industry)
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GENERAL PROVISIONS
Article 1. Purposes
This Regulation unifies the classification of petroleum
resources and reserves, and petroleum reserves reporting.
Article 2. Subjects and scope of application
This Regulation is applicable to all the organizations and
individuals permitted by the Government of Vietnam to explore and extract
petroleum on land, islands, territorial sea, exclusive economic zones, and the
continental shelves of the Socialist Republic of Vietnam.
Article 3. Interpretation of terms
The terms in this Regulation are construed as follows:
1. “Current economic conditions” are the economic criteria, including
the norms, unit prices, sale prices, and other criteria applicable at the time
of estimating the reserves.
2. “Reasonable certainty” is the certainty value corresponding to the probabilities
≥ 0.85 on the cumulative probability distribution curve according to probability
and statistics
theory.
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4. “Medium certainty” is the certainty value corresponding to the probabilities
= ± 0.5 on the cumulative probability distribution curve according to probability
and statistics theory.
5. “”Incremental production” is the amount of petroleum extracted from
the beginning to a certain time.
6. “Group of prospects – Play” is a group of petroleum prospects in the same set of geographical and geological
circumstances, and the same conditions
and characteristics of the source, reservoir, and seal .
7. “Flow testing” is the test of the petroleum well in order to collect
the data about the producing formation such as the flow rate of oil, gas,
water, pressure, temperatures, and other data.
8. “Well testing” is the technique to determine the productivity and
other data of the producing formation.
Chapter 2:
CLASSIFICATION OF PETROLEUM RESOURCES AND RESERVES
Article 4. Petroleum resources
Petroleum resources are the total petroleum-in-place, estimated on a
given date, including the amount of petroleum extracted from the discovered
petroleum accumulations, and the amount of petroleum estimated to exist in the accumulations
that will be discovered.
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- Discovered resources.
- Undiscovered resources.
Article 5. Discovered resources.
Discovered resources are the total petroleum-in-place, estimated on a
given date, in the petroleum accumulations discovered through oil drilling. The
discovered resources, including the total recoverable petroleum and potentially
recoverable resources.
1. The recoverable petroleum is the amount that has been and will be economically
recoverable from the accumulations discovered by reasonable technologies,
suitable for current economic and legal conditions.
Total recoverable petroleum includes the total petroleum amount
extracted and the residual petroleum reserves at that time.
The residual petroleum reserves include the proven reserves (P1) and unproven
reserves (P2 and P3) specified in Clause 1 Article 5 of this Article.
2. Potentially recoverable resources are the discovered and recoverable
petroleum, but are not able to be economically extracted at the time of estimating
due to technical, technological, economic, environmental reasons, and other criteria.
Potentially recoverable resources are classified as proven (P4) and unproven
(P5 and P6). The determination of Potentially recoverable resources classifications
depends on the conditions similar to that of the recoverable reserves.
Article 6. Undiscovered resources.
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Undiscovered resources include estimated undiscovered recoverable
resources (R1) and undiscovered technically recoverable resources (R2).
1. Estimated undiscovered recoverable resources (R1) are petroleum
resources estimated to be recoverable, on a given date, from the prospects
marked on maps without knowing the existence of petroleum through drilling, or
the reservoirs under the producing strata of the fields being extracted, in geological
conditions considered favorable for petroleum accumulation, but is not yet reached.
2. Undiscovered technically recoverable resources (R2) are the
recoverable petroleum resources estimated on a given date, regarding the
petroleum accumulations estimated to exist technically in a Play, in favorable
geological conditions for petroleum accumulation, but are not marked on maps.
Article 7. Petroleum reserves
Petroleum reserves are the estimated amount of petroleum that remains
in the natural petroleum accumulations on a given date, discovered with various
certainties, depending on the geological survey results.
Depending on the declining certainty, petroleum reserves are classified
as proven reserves and unproven reserves.
1. Proven reserves (P1)
Proven reserves are the economically recoverable petroleum, estimated on
a given date with reasonable certainty, of the discovered petroleum accumulations
that are planned to be extracted in the current technical, technological,
economic, and social conditions.
The reserves are classified as proven when the following conditions are
satisfied:
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- The permeability, capacity, and saturation of petroleum of the
petroleum reservoir are certified by the core and well logging data.
- The well test results of the economic flow from at least 1 oil well.
2. Unproven reserves.
Unproven reserves include probable reserves and possible reserves.
a. Probable reserves (P2)
Probable reserves are the economically recoverable petroleum, estimated
on a given date, with medium certainty, that is not certified by the well testing
results.
The probable reserves of each oil reservoir is determined by
extrapolation methods suitable for the geological conditions of the oil
reservoir (Annex II).
b. Possible reserves (P3)
Probable reserves are the economically recoverable petroleum, estimated
on a given date, with low certainty, that is not certified by the drilling data.
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The diagram of petroleum resources and reserves classification is
provided in Annex I of this Regulation.
Chapter 3:
PETROLEUM RESERVES REPORTING
Article 8. Petroleum reserves report contents
1. The petroleum reserves reports are made by the operator or the
competent advisory agency, and approved by the contractor.
2. Petroleum reserves report contents.
A petroleum reserves report includes the full and summary report.
The full report comprises 02 parts:
- Part I - Description
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The details of the Reserve report and the enclosed Annexes are provided
for in Annex III of this Regulation.
Article 9. Petroleum reserves boundary estimate
1. The petroleum reserves estimate report must cite the principles used
to determine the boundary of the petroleum reservoir for estimating the
reserves.
If similar methods are applied, it is required to provide the original
figures and explain the use of such figures for the field or reservoir being
estimated to certify the reliability of the method and the figures.
2. The petroleum reserves are classified as prescribed in Chapter II of
this Regulation.
Article 10. Petroleum reserves estimate methods
1. The reserves of petroleum and condensates may be estimated using the
volumetric method, materials balance method, and other methods suitable for the
geological structure and existing data. The application of the volumetric method
is compulsory. Other methods may be applied depending on the particular
conditions, enclosed with the explanation for the selection. The petroleum
reserves must be estimated on the basis of Monte Carlo simulation. The values
of reserves must be classified as Low estimate, High estimate, or Best
estimate.
2. When re-estimating the reserves of a petroleum field, it is required
to compare the figures of the new calculations with the previous ones, and find
the reasons of such differences.
3. The reserves of oil, gas, condensates, and their combination in each
reservoir and the whole field must be separately estimated, together with
finding the possibility of practical extraction.
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Chapter 4:
PROCEDURES FOR SUBMITTING PETROLEUM RESERVES REPORTS
Article 11. Procedures for report submission
Before applying for the approval for the petroleum reserves report, the
authorized operator or contractor must reach an agreement with Petrovietnam on
the contents, and submit the report to the Ministry of Industry via the
contractor, operator, or Petrovietnam for approval.
Article 12. The report dossier
The dossier of petroleum reserves report or petroleum reserves
re-estimate report, enclosed with the request for approval of Petrovietnam,
that is sent to the Ministry of Industry, includes:
a. The full report (in Vietnamese or English);
b. The summary report (in Vietnamese and English);
c. The CDs containing the digitized contents and figures of the report;
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Article 13. Appraisal and approval
According to the statement of the authorized operator or contractor,
and the agreement of Petrovietnam, the Petroleum Reserves Appraisal Council,
presided by the Ministry of Industry, shall appraise the petroleum reserves
report. After the petroleum reserves report is passed, the Ministry of Industry
shall submit it to the Prime Minister for approval.
Chapter 5:
PETROLEUM RESERVES REGISTRATION
Article 14. Petroleum reserves registration
After receiving the approval from the Prime Minister for the petroleum
reserves estimate, the authorized operator or contractor must register the
approved reserves with Petrovietnam for monitoring, summarizing, and reporting
as prescribed by current law provisions.
Article 15. Registering and re-estimating petroleum
reserves
If the petroleum reserves approved by the Prime Minister change during
the estimate, development, and extraction, the authorized operator or
contractor must register with Petrovietnam. If the petroleum reserves differ
more than 15% compared to the nearest approval, the authorized operator or
contractor must make the report on the reserves re-estimate and submit for
approval as prescribed in Chapter IV of this Regulation. The re-estimate shall
be recorded under the form in Annex V of this Regulation.
Chapter 6:
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Article 16. Organizations
and individuals participating in the petroleum activities and Petrovietnam are
recommended to send feedbacks on the difficulties arising during the course of
implementation to the Ministry of Industry for consideration and settlement
ANNEX
Promulgated
together with the Decision No. 38/2005/QĐ-BCN)
Annex I:
CLASSIFICATION OF
PETROLEUM RESOURCES AND RESERVES
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DETERMINATION OF THE
RANGE OF RESERVES (P2 AND P3) BY EXTRAPOLATION
1. Probable reserves - P2
Probable reserves of each petroleum accumulation is determined using
the distance bisection method (picture 1) as follows:
I.1. For oil:
a. From the Highest point of oil (HPO) to the midpoint of
the range between the Highest point of oil (HPO) and the Lowest point of gas
(LPG), or the Structural top (ST) if the Lowest point of gas (LPG) is not
identifiable.
b. From Lowest point of oil (LPO) to the midpoint of the range between
the Lowest point of oil (LPO) and the Highest point of water (HPW), or the
Structural spill point (SSP) if the Highest point of water (HPW) is not
identifiable.
I.2. For gas:
a. From the Lowest point of gas (LPG) to the midpoint of the range
between the Lowest point of gas (LPG) and the Highest point of oil (HPO), or:
b. From Lowest point of gas (LPG) to the midpoint of the range between
the Lowest point of gas (LPG) and the Highest point of water (HPW), or the
Structural spill point (SSP) if the Highest point of water (HPW) is not
identifiable.
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I.4. The following cases are also classified as Probable reserves (P2):
a. The reserves of the formations may be increased and classified as
Proven when carrying out intensive drilling, but at the time of estimating the
reserves, the intensive drilling is not available.
b. The reserves of the formation may be increased and classified as
Proven if carrying out extensive drilling, but at the time of estimating the
reserves, the extensive drilling is not available, and the structural map of
the formation is not sufficient for classifying it as Proven.
c. The reserves in the strata show potential to producing the petroleum
flow according to the well logging data, but the core samples or well testing
data are not sufficient, and they do not have similar characteristics compared
to that of the formation being extracted or the Proven formation in the same
area.
d. The reserves belonging to the area of the proven stratum produce the
petroleum low in other area of the field, but such area appears to be separated
by faults or geological seals, and the structural position is higher than the
area classified as proven, according to the geology interpretation and analysis
data.
e. The reserves from the application of enhanced oil recovery method are
completed and commercialized when the pilot program or project has been
established and installed but have not commenced, and the characteristics of
reservoir rocks, formation fluid and formation factor are appropriate for
commercially apply such methods.
f. The reserves from the repair, processing, reprocessing, or
replacement of well parts, or other technical processing, but such processes
have not been recognized as successful when being applied to the wells with the
same conditions and in the similar formations.
g. The increased reserves from the re-analysis and re-interpretation of
the formation dynamic, or the data about volume parameters show that there are
considerable reserves apart from the reserves specified as proven.
II. Possible
reserves - P3
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II.1. For both oil and gas:
a. From the middle point of the range between the Lowest point of oil
or gas (LQO, LPG) and the Highest point of water (HPW), or the Structural spill
point (SSP) if the Highest point of water is not identifiable, to the Highest
point of water (HPW) or the Structural spill point (SSP) if the Highest point
of water is not identifiable.
b. From the middle point of the range between the Highest point of oil (HPO)
and the Structural top (ST), to the Structural top (ST).
II.2. The distance bisection method may be replaced by other
geological, geophysical data and technologies of which the foundation and
theory are clear.
II.3. The following cases are also classified as possible reserves:
a. The reserves extrapolated from the structure or strata, according to
the analysis and interpretation of geological and/or physical data, apart from
the areas classified as possible.
b. The reserves in the strata showing the appearance of petroleum
according to well logging and core sample data, but may produce non-commercial
petroleum flow
c. The reserves estimated by enhanced oil recovery according to pilot
projects or new projects that have not commenced, and the characteristics of
reservoir rocks, formation fluid and formation factor still cause objective
doubt about the commerciality of the project.
d. The reserves belonging to the area of the proven stratum are able to
produce petroleum flow in other areas of the field, but such area appears to be
separated by faults or geological seals, and the structural position is lower
than the area classified as proven, according to the geology interpretation and
analysis.
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f. The formation has high volume of petroleum but the risk is high:
f.1. The coverage of seismic data of the area is small.
f.2. The quality and continuity of the formation are not clear.
f.3. Additional recovery from the application of recovery enhancement
methods.
f.4. The average parameters of the formation are better.
Diagram 1. Classification of petroleum reserves
according to the distance bisection method
Proven (P1/P4), Possible (P2/P5), Probable (P3/P6)
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Annex III:
PETROLEUM
RESERVES REPORT
FIELD: ………………….
PART I
1. Introduction
2. The history of exploration and discovery
3. Materials, results of analysis, researches, samples, and well
testing.
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3.2. Results of the well testing, flow testing, and pilot project (if
any) of oil/gas/water.
3.3. Other surveys and studies (biostratagraphy, sedimentary lithology,
geochemistry…)
4. Exploration geophysics
4.1. Seismogram:
- Seismic-line network.
- Data of Seismic field acquisition and processing.
- Assessment of data.
- Interpretation of data, conversion of time – depth, special
researches – AVO, CTC…
- The vague technical contents that need supplements.
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4.3. Other exploration geophysical surveys (gravity, magnetic field…)
5. Geology
5.1. Local geology
5.2. Geological structural
- Strata.
- Tectonics: the system of faults and folds, and the explanation of the
tectonics of the formation of petroleum traps.
- Appearance of petroleum and the producing formation.
5.3. Petroleum reservoirs:
- The connections and name of the producing formations.
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+ The structural
top and base
reservoir map.
+ The depth map, usable capacity coefficient
+ Geological section of the petroleum reservoir.
- The contact surface of oil, gas, water.
6. Well logging:
6.1. Method, volume, and quality of measurement data.
6.2. Method and results of formation factor interpretation.
6.3. Study and analysis of formation factor according to core samples
in connection with well logging.
6.4. The vague issues that need supplements.
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7.1. Documents and quality.
7.2. Oil/gas characteristics (PVT, API, GOR, CGR, Pb…).
7.3. Reservoir permeability
7.4. Formation temperature and pressure.
7.5. Formation water, properties and dynamics
7.6. Well testing (RFT, MDT, DST…), economic flow testing data…
7.7. The situation of oil – gas – water extraction and pumping.
7.8. Calculation method and description of reserves data.
7.9. Applied reserves estimate method and formula.
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7.11. Conclusion about the lower limits (critical limits) of the
parameters
- The volume of reservoir rock
- The usable storing thickness.
- The porosity
- The water saturation.
- The density of oil/gas, the volume conversion parameters…
- The flow dynamics, and the pressure/energy/productivity of the formation…
- The reserves petroleum-initially-in-pace of the reservoir and the
field.
7.12. Evidence for the petroleum recovery factor of the field.
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7.14. The problems and suggested solutions.
7.15. The reserve calculation results using similar methods or
materials balance method, in comparison with the results given by volumetric
method.
8. Conclusion and suggestion:
- The basic conclusion about the geological structure, the estimate of
the reserves of oil, gas, condensed gas, the hydrographical and geological
conditions, the applicable extraction technology, and its general potential.
- The suggestion about the future geological surveys, and the necessary
scientific research.
- The official opinions of the authorized operator or contractor, and Petrovietnam
about the submission to the Ministry of Industry for appraisal and to the Prime
Minister for approval of the reserve report.
PART II – TABLES AND DIAGRAMS
The Annex must contain all the necessary data and materials related to
the exploration and reserves estimate, together with the tables and diagrams
necessary for illustrating the report.
A - TABLES
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+ The volume of exploration boring.
+ The data about the volume of core samples and method of analysis.
+ Well testing data.
+ The well logging data.
+ Chemical composition and physical properties of formation water.
+ The physical, lithological and sedimentary data about the producing strata.
+ Chemical and physical properties of oil.
+ Dissolved gas content in oil.
+ Properties of free gas.
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+ Average value of porosity, permeability and saturation of petroleum.
+ The value and reserve of oil and dissolved gas of the oil field.
+ The value and reserve of oil and dissolved gas, and other
constituents of the gas field.
+ Comparing the accepted values when recalculating the reserve of oil,
gas, dissolved gas, condensed gas, with the approved data.
+ Comparing the reserves of oil, gas, dissolved gas, and condensed gas with
the approved reserve.
+ The data about the extraction of the producing formations (if any).
B-DIAGRAMS
1. The overall map of the field area and field location
2. The seismic-line network map
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4. The TWT map and the representative cross sections.
5. The depth map of the boundaries of main strata.
6. The thickness of the structural strata of the stratigraphic unit
that contain petroleum.
7. The geological sections through the wells.
8. The geological sections of the petroleum reservoirs of the field through
the wells.
9. The diagram and table of connection data of the producing formation
through the wells.
10. The structural top and base map of the producing formation.
11. The topographical map of the petroleum reserves (the map scale is
1:25,000, and the cross section of the field must use the highest scale
according to the 2D or 3D seismic survey).
12. The interpretation table of well logging and well testing data of
producing formations of each well – vertical scale = 1/200.
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14. The table of description and analysis of core samples and sediment
samples.
15. The data and results of well testing and flow testing and
extraction (if any): the productivity of oil/gas/water, the temperature,
pressure, the well monitoring and examination…
16. The wellbore deviation data.
17. The list of documents used to make the report, the relevant
documents and reports (on demand).
18. The papers and software used for the calculation.
Annex IV:
PETROLEUM
RESERVES REGISTRATION SHEET
No.
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Name of company and estimates
Name of previous reports
Approval symbol
Petroleum-initially-in-place
Approved reserves (m3)
1
2
3
4
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6
7
P1 – P2 – P3
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Gas (hydrocarbon):
Condensate:
…
(continue)
Revised petroleum-in-place
Registered reserves (m3)
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Reason
Current petroleum-in-place
Approved reserves (m3)
Change +/-m3/%
Effective date
Approval symbol
Notes
8
9
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11
12
13
14
15
16
17
P1-P2-P3
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Gas (hydrocarbon):
Condensate:
…
P1-P2-P3
Oil:
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Condensate:
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PETROLEUM
RESERVES STATISTICS
No.
Well
Company
Report name
Registration
Petroleum-in-place
First approved reserves (m3)
Symbol
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P1
P2
P3
…
1
2
3
4
5
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7
8
9
10
11
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Oil:
Gas:
Condensate:
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(continue)
Reserve change
Reason
Extracted petroleum amount
First approved reserves (m3)
Notes
…m3
%
P1
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P3
…
P1
P2
P3
…
12
13
14
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16
17
18
19
20
21
22
23
Oil:
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Condensate:
…
Oil:
...
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Condensate:
…