Document Number : UPSTREAM GUIDELINES No.1 / 2016 Issue : Revision 2 Release : January 2017 Document Owner : Energy and Industry Department, Prime Minister’s Office (EIDPMO)
Oil and Gas Exploration and
Production Guidelines
VOLUME 2
RESERVES AND RESOURCES CLASSIFICATION
AND REPORTING GUIDELINES
BRUNEI
DARUSSALAM
Volume 2: Reserves and Resources Classification and Reporting Guidelines
1
Revision Record
Issue Title Issue By / Date
Rev.0 Guidelines for the Classification and Reporting of
Hydrocarbon Resources Volumes in Brunei Darussalam
Brunei Petroleum Unit /
July 2007
Rev.1 Reserves and Resources Classification and Reporting
Guidelines
Energy and Industry
Department EIDPMO /
October 2016
Rev.2 Reserves and Resources Classification and Reporting
Guidelines
Energy and Industry
Department EIDPMO /
January 2017
Notice
Copyright © 2016, The Authority.
This document is the property of The Authority. Circulation is restricted to The Authority and its
designated subsidiaries and affiliates. It must not be copied or used for any other purpose other than
which it is supplied, without the expressed written consent of The Authority.
Except where provided for purposes of contractual requirements, The Authority disclaims any
responsibility or liability for any use or misuse of the document by any person and makes no warranty
as to the accuracy or suitability of the information to any third party, if so relied.
For any unauthorised usage of this document, The Authority will take appropriate actions, including
legal recourse if necessary, to protect such of its rights and account for its losses and damage.
This document:
Will be held in the common Library and can be accessed via The Authority Internet. Controlled versions and revision announcements will be published on the web, and communicated to The Authority staff; JV’s Partners, PSA Operators and The Authority’s Contractors accordingly. Copies or extracts of this document, which have been downloaded from the website, are uncontrolled copies and cannot be guaranteed to be the latest version.
May set requirements supplemental to applicable law. However, nothing herein is intended to replace, amend, supersede or otherwise depart from any applicable law relating to the subject matter of this document. In the event of any conflict or contradiction between the provisions of this document and applicable law as to the implementation and governance of this document, the provisions of applicable law shall prevail.
Volume 2: Reserves and Resources Classification and Reporting Guidelines
2
Table of Contents
1. Introduction __________________________________________________________________ 3
Reserves and Resources Classifications ___________________________________________ 4
2. Classifications and Definitions ___________________________________________________ 5
3. Reporting Format and Requirement _______________________________________________ 9
4. Abbreviations ________________________________________________________________ 13
5. Definitions __________________________________________________________________ 14
6. References __________________________________________________________________ 16
7. Appendices __________________________________________________________________ 17
Volume 2: Reserves and Resources Classification and Reporting Guidelines
3
Introduction
These Reserves and Resources Classification and Reporting Guidelines serves to aid the user in the reporting of hydrocarbon reserves and resources in Brunei Darussalam.
The objective of these guidelines is to provide a consistent reserves and resources reporting standard for all oil and gas operators in Brunei.
The classifications are strictly project based where all reserves and resources are treated as project dependent. Projects and the associated reserves and resources are classified with respect to their maturity in the hydrocarbon life cycle.
The classification in this guidelines is align with the November 2011 Guidelines for Application of Petroleum Resources Management System (Ref. 1)
All reporting of Brunei’s reserves and resources are strictly owned by The Government of Brunei Darussalam currently via The Authority1 and remain confidential for any external release.
1 The Authority refers to Authorise Government personnel / body association appointed by The Brunei Government
Volume 2: Reserves and Resources Classification and Reporting Guidelines
4
Reserves and Resources Classifications
Under the November 2011 Guidelines for Application of Petroleum Resources Management System (PRMS), each project is classified according to its maturity or status (broadly corresponding to its chance of commerciality) using three main classes with the option to subdivide further using subclasses. The three classes are Reserves, Contingent Resources and Prospective Resources. These three classes are then further subdivided that can be used together or separately to identify particular characteristics of the project and its associated recoverable quantities. The sub-classification options are project maturity subclasses, reserves status and economic status.
Following the November 2011 Guidelines for application of PRMS sub-classifications, Energy and Industry Department (EIDPMO) has made a revision to the 2007 Reserves and Resources Classifications and Reporting Guidelines (Ref.2). The 2016 Reserves and Resources Classifications and Reporting Guidelines provides a common standards for petroleum reserves and resources definition for all Operators in Brunei Darussalam. Figure 1 shows the comparison of the reserves and resources sub-classifications between November 2011 Guidelines for application of PRMS and the 2016 Reserves and Resources Classification and Reporting Guidelines.
Figure 1. Comparison of the Reserves and Resources Classifications between the 2011 Guidelines for Application of PRMS and 2016 Reserves and Resources Classification
Volume 2: Reserves and Resources Classification and Reporting Guidelines
5
Classifications and Definitions
Any new, incremental or accelerated hydrocarbon production must be the outcome of a project, which in turn must be classifiable into one of the revised reserves and resources maturity classifications listed below. The hierarchical relationship between the various classifications is depicted in Figure 2.
Figure 2. 2016 Reserves and Resources Classifications
Volume 2: Reserves and Resources Classification and Reporting Guidelines
6
Class 0 – Cumulative Production
Defined as the volume of oil, condensate and natural gas that are already recovered from the fields or reservoirs.
Class 1 – Developed Reserves
Defined as the hydrocarbon volumes associated with projects that have already been implemented up to economic cut-off. The projects delivering the Developed Reserves should not require any further expenditure beyond what is required for routine operations and maintenance.
Class 2 – Undeveloped Reserves
Defined as the hydrocarbon volumes associated with projects that have been approved for execution by all involved parties and have made final Investment decision.
The development should be under way or due to start imminently or within 5-year time frame.
Class 3 – Justified for Development
Defined as the hydrocarbon volumes associated with projects that the field development plan has been approved, but pending final Investment decision. These project may be subjected to lack of funding or the planned start date for development is more than five (5) years.
Class 4 – Contingent Resources Development Pending
Defined as the discovered hydrocarbon volumes associated with projects that are at an appraisal or detailed evaluation stage. These projects are technically feasible and expected to have reasonable chance of commerciality. This includes:
Exploration discoveries of which a Discovery2 Report has been submitted, and/or an approved Appraisal Programme is in progress and / or field development planning is under way.
Incremental projects that are undergoing evaluation, e.g. infill wells, facility modifications, process optimization, secondary and tertiary recovery methods.
Class 5 - Contingent Resources On Hold / Unclarified / Not Viable
Defined as discovered hydrocarbon volumes associated with projects classified under 3 different categories:
Contingent Resources On Hold3 are projects considered to have a least reasonable chance of commerciality to be executed. This also includes major non-technical contingencies e.g. environmental issues that need to be resolved before project can move towards development.
2 Discovery refers to encounter of hydrocarbon accumulation of which the volumes are deem economical. 3 The volumes shall include the volumes beyond Economic Cut-Off to End of Field Life (EOFL).
Volume 2: Reserves and Resources Classification and Reporting Guidelines
7
Contingent Resources Unclarified are projects that are still under evaluation or require significant further appraisal to clarify the potential for development and where the contingencies have yet to be fully defined. In such cases the chance of commerciality may be difficult to assess with any confidence.
Contingent Resources Not Viable4 are hydrocarbon volumes associated with projects that has been technically assessed to have insufficient potential to warrant any further appraisal activities or any direct efforts to remove commercial contingencies. Projects categorized as Not Viable would be expected to have a low chance of commerciality. It also includes discovered hydrocarbons accumulations that are deemed uneconomical due to its size.
Class 6 - Prospective Resources Prospect
Defined as the undiscovered hydrocarbon volumes associated with prospects which are structurally and geographically defined considered viable drilling targets. This includes all prospects beyond exploration license period.
Class 7 - Prospective Resources Lead
Defined as the undiscovered hydrocarbon volumes associated with leads with potential accumulation that requires more data acquisition and/or evaluation to further understand the structure and geology of the projects. This includes all leads beyond exploration license period.
Class 8 - Prospective Resources Play
Defined as the undiscovered hydrocarbon volumes associated with plays which are of a conceptual nature. This includes all plays expected to be explored beyond exploration license period.
The Reserves and Resources Classification definitions is summarized in the table below (Table.1)
4 The volumes shall include volumes beyond Economic Cut-Off to End of License
Volume 2: Reserves and Resources Classification and Reporting Guidelines
8
Dis
cove
red
Hyd
roca
rbo
n
Vo
lum
es
Tech
nic
al V
iab
ilit
yEc
on
om
ic /
Co
mm
erc
ial V
iab
ilit
yD
eve
lop
me
nt
Stat
us
Ye
sY
es
Ye
sA
pp
rove
d -
Imp
lem
en
ted
an
d p
roce
ed
Ye
sY
es
Ye
sA
pp
rove
d -
Un
de
r w
ay o
r d
ue
to
sta
rt im
min
en
tly
Ye
sY
es
Ye
s b
ut
pe
nd
ing
Fin
al In
vest
ion
De
cisi
on
(FID
)
Ap
pro
ved
bu
t st
ill r
eq
uir
ed
su
ffic
ien
t ju
stif
icat
ion
to
pro
cee
d
Ye
sY
es
Ye
s w
ith
fu
rth
er
stu
dy
and
eva
luat
ion
s
to c
on
firm
co
mm
erc
ially
via
ble
Furt
he
r st
ud
y an
d e
valu
atio
ns
req
uir
ed
to
just
ify
th
e
bas
is f
or
sele
ctio
n o
f an
ap
pro
pri
ate
de
velo
pm
en
t p
lan
Co
nti
nge
nt
Re
sou
rce
s O
n H
old
Ye
sY
es
bu
t fu
rth
er
app
rais
al/e
valu
atio
n
acti
viti
es
are
on
ho
ld
Co
nsi
de
red
to
hav
e a
leas
t re
aso
nab
le
chan
ce o
f co
mm
erc
ialit
y
De
velo
pm
en
t p
lan
ne
d p
en
din
g /
on
ho
ld
Co
nti
nge
nt
Re
sou
rce
s U
ncl
arif
ied
Ye
sY
es
bu
t si
gnif
ican
t ap
pra
isal
/eva
luat
ion
acti
viti
es
req
uir
ed
to
cla
rify
Dif
ficu
lt t
o a
sse
ss w
ith
an
y co
nfi
de
nce
Re
qu
ire
d s
ign
ific
ant
furt
he
r ap
pra
isal
to
cla
rify
po
ten
tial
de
velo
pm
en
t p
lan
Co
nti
nge
nt
Re
sou
rce
s N
ot
Via
ble
Ye
sN
oN
oD
eve
lop
me
nt
no
t fe
asib
le t
o p
roce
ed
du
e t
o t
ech
nic
ally
and
co
mm
erc
ially
no
t vi
able
No
No
No
N/A
No
No
No
N/A
No
No
No
N/A
Pro
ject
Mat
uri
ty S
ub
clas
s
Cla
ss 0
- C
um
ula
tive
Pro
du
ctio
n
Cla
ss 7
- P
rosp
ect
ive
Re
sou
rce
s Le
ad
Cla
ss 8
- P
rosp
ect
ive
Re
sou
rce
s P
lay
Cu
rre
ntl
y o
n c
om
me
rcia
l pro
du
ctio
n
Cla
ss 6
- P
rosp
ect
ive
Re
sou
rce
s P
rosp
ect
Cla
ss 1
- D
eve
lop
ed
Re
serv
es
Cla
ss 2
- U
nd
eve
lop
ed
Re
serv
es
Cla
ss 3
- J
ust
ifie
d f
or
De
velo
pm
en
t
Cla
ss 4
- C
on
tin
gen
t R
eso
urc
es
De
velo
pm
en
t
Pe
nd
ing
Cla
ss 5
√ √ √ √ √ √ √
√√
√√
√√ √
√
√√
√X
XX
XX
XX
XX
X X X
Tab
le 1
. Su
mm
ary
ta
ble
of
the
20
16
Res
erve
s a
nd
Res
ou
rces
Cla
ssif
ica
tio
n D
efin
itio
ns
Volume 2: Reserves and Resources Classification and Reporting Guidelines
9
Reporting Format and Requirement
1. Operators shall report and submit to the Responsible Authority the Annual Review of Petroleum Resources (ARPR) not later than end of February of each new calendar year.
2. The Annual Review of Petroleum Resources (ARPR) – 31.12.XXXX report shall include the following:
i. Cover letter:
a) Summary table of reserves and resources per classification 31.12.XXXX (Proved (Low) / Expected / High volume estimates) of:
Liquid volumes estimates (Mln m3)
Gas volumes estimates (Bcm – Wellhead)
Cumulative
Production
Developed
Reserves
Undeveloped
Reserves
Justified
for
Development
Contingent
Resources
Development
Pending
Contingent
Resources
On Hold /
Unclarified /
Not Viable
Prospective
Resources
Prospect
Prospective
Resources
Lead
Prospective
Resources
Play
Classification - 1 2 3 4 5 6 7 8
Proved (Low)
Expected
High
b) Summary table of gas reserves positions (wellhead and sales)
Wellhead Sales
Bcm Tcf Bcm Tcf
Expectation Reserves (Classification 1-3)
P90 Reserves (Classification 1-3)
Proved Reserves (Classification 1-3)
ii. Reserves and Resources summary (31.12.XXXX):
a. Summary table of Reserves changes (Liquid – Mln m3, Gas – Bcm and Total – Mln boe) from previous year to current year (Proved, 2P and 3P Reserves) including methodology - (See Appendix.1)
b. Historical Reserves and Expected Reserves performances trend – Liquid and Gas (5 Years)
c. RRR and R/P ratio reporting for both liquid and gas d. Cumulative Production including hydrocarbon Own Uses and Losses (OUL) at
31.12.XXXX e. Total production during the reporting year (oil (excluding LLG) and gas (Well head)) f. Summary table of Resources changes (Liquid – Mln m3, Gas – Bcm and Total – Mln boe)
from previous year to current year (Contingent Resources 1C, 2C ,3C and Prospective Resources 1U, 2U and 3U volumes) including methodology - (See Appendix.2)
g. Summary table of Ultimate Recovery and Reserves Liquid and Gas as at 31.12.XXXX (Wellhead Volumes with Economic Cut-off with Post License) – (See Appendix.3)
Volume 2: Reserves and Resources Classification and Reporting Guidelines
10
h. Summary table of Total Contingent and Prospective Resources as at 31.12.XXXX (Wellhead Volumes with Economic Cut-off with Post License) – (See Appendix.4)
i. Historical Reserves and Production Data table (Liquid Mln m3 and Gas Bcm)
iii. Summary by field including undiscovered blocks/areas within the field (i.e. sub-blocks area; compartmentalization etc):
a. Reservoir settings b. Depletion rates, RF (%) and ATL estimates (by flow unit) c. Summary of justification to achieve ATL including incremental secondary and tertiary
recovery and the associated UTC. d. Basis of Reserves and Resources estimates i.e. methodology, assumptions and key
parameters e. Summary table of total Reserves and Resources volumes and changes from previous
year to current year including basis of changes f. Table of HCIIP volumes as at 31.12.XXXX (1P, 2P and 3P) – (See Appendix.5) g. Geological maps of each reservoirs showing latest fluid contacts such as structure
map(s), structural cross-section(s) etc h. Historical Production data at 2P (10 Years) i. Historical oil (and condensate) and gas reserves (10 years) j. References e.g. supporting documents
iv. Production Forecast trend from the first year of production by classification (Classification
1 to Classification 8) where applicable.
v. Summary table by classification (Classification 1 to Classification 8) sub-divided into project names listed under NFA, pre- and post- FDP, pre- and post-FID, exploration projects and etc.
Field Report Date: Dec.XXXX
Project
Status
Classification Class #
Start of Production (Year) PoM PoS(G)
(Oil / Gas) UTC
Reserves or Resources (Liquid – Mln m3 and Gas – Bcm)
Proved Expected High
Oil
Condensate
Gas
Sales Oil
Sales NGL
Sales Gas
a. For each individual defined project, the undiscounted life cycle Unit Technical Cost (UTC) and the planned or earliest start date of production shall be reported.
b. The Probability of Maturation (PoM) in case of successful discovery shall be reported and also the Geological Probability of Success (PoS(G))
Volume 2: Reserves and Resources Classification and Reporting Guidelines
11
3. Operators shall provide split tables of the final 31.12.XXXX Domestic (100% Brunei Share) and
International (XX % Brunei Share) Total Hydrocarbon Reserves and Resources Volumes (both digital in Excel format and hardcopy) – (See Appendix.6)
4. Operators shall report all volumes until End of Field Life (EOFL) for each field/project and indicate the Economic Limit.
5. Operators shall provide their domestic supply volumes.
6. A standard reporting unit shall be used in the submitted Reserves and Resources report:
Liquid volumes in million cubic metre (Mln m3)
Gas volumes in billion cubic metre (Bcm)
Total volumes in million barrel of oil equivalent (Mln boe)
7. Operators shall provide the conversion used in the Annual Review of Petroleum Resources report (conversion up to 4 decimal places):
Mln m3 (million cubic metre) Mln boe (million barrel of oil equivalent)
Bcm (billion cubic metre) Mln boe (million barrel of oil equivalent)
Tcf (trillion cubic feet) Bcm (billion cubic metre)
Mln bbl (million barrel) Mln m3 (million cubic metre)
Bscf / Bcf (Billion standard cubic feet) Bcm (billion cubic metre)
8. Any discovered hydrocarbon irrespective of its commerciality must be reported to The Authority
according to the Agreement. Operators shall provide Post-Drilling Notification report as per below: i. Basic well data:
o Project number
o Well name
o Prospect name
o Block / acreage
o Well type (i.e. Inboard, Wildcat, NFE, NIE)
o Well objectives
o Spud date
o End of well date
o Well TD (MD and TVDSS at X formation)
o Well result (i.e. Commercial discovery, Non-commercial discovery, dry)
ii. Volumetric:
o Pre-drill
In place volumes (Mln m3 and Bcm)
Ultimate recoverable volumes (Mln boe)
POS(G) (Oil and Gas)
Volume 2: Reserves and Resources Classification and Reporting Guidelines
12
o Post-drill
Total net pay
Interval penetrated
In place volumes (Mln m3 and Bcm)
Ultimate recoverable volumes (Mln boe)
Recovery factor
iii. Future plan (i.e. appraisal, development)
Volume 2: Reserves and Resources Classification and Reporting Guidelines
13
Abbreviations
Abbreviations Definition
ATL Agreed Technical Limit
ARPR Annual Review of Petroleum Resources
Bcm Billion Cubic Metre
Bcf / Bscf Billion Standard Cubic Feet
EOR Enhanced Oil Recovery
FID Final Investment Decision
FDP Field Development Plan
HCIIP Hydrocarbon Initially In-Place
LLG Lumut Light Gasoline
MD Measured Depth (in metres (m))
Mln m3 Million Cubic Metre
Mmbbl Million Barrel
Mln boe Million Barrel of Oil equivalent
NFA No Further Activities
NFE Near Field Exploration
NGL Natural Gas Liquid
NIE Near Infrastructure Exploration
OUL Own Uses and Losses
PoM Probability of Maturation
POS(G) Geological Probability of Success (Oil / Gas)
RF Recovery Factor (%)
R/P Reserves/Production Ratio
RRR Reserves Replacement Ratio
TD Target Depth
TVDSS True Vertical Depth Subsea (in metres (m))
UTC Unit Technical Cost
Volume 2: Reserves and Resources Classification and Reporting Guidelines
14
Definitions
Agreed Technical Limit (ATL)
The agreed technical limit is an agreed maximum possible recovery from a field or reservoir (or other
reporting unit) given, assuming the use of conventional technology including commonly employed EOR
techniques.
POS(G)
Geological Probability of Success is the probability of discovering a volume of hydrocarbons by taking into
account the possible geological risks such as structures, reservoir, migration, source rocks and
preservation.
PoM
Probability of Maturation is the likelihood that a project, or a very similar project described by the same
project parameters, will come to a such a degree of maturation that the hydrocarbon volumes associated
with the project can be classified as reserves, give the current economic environment and within the
license period.
For mutually exclusive projects, the PoM should reflect the individual project’s chance of being selected.
The combined PoM of mutually exclusive projects should not exceed 1.
Proved Reserves
Proved reserves are those quantities of petroleum, which by analysis of geoscience and engineering data
can be estimated with reasonable certainty to be commercially recoverable from a given date forward,
from known reservoirs and under defined economic conditions, operation methods and government
regulations.
P90 Reserves
P90 Reserves are proven reserves which have at least 90% probability that the quantities recovered will
be equal to or greater than the estimates.
RRR
Reserves Replacement Ratio is the ratio of reserves additions in year divided by the production in a year.
Whereby, Reserves Addition is due to:
1. Matured new volumes booking (new project FID) 2. Revisions (positive and negative)
a. Performance reviews b. Studies
RRR Total (%) = Total Reserves Addition (Maturation+Revisions)
Production in a year
RRR Maturation (%) = Maturation (New Volumes FID)
Production in a year
Volume 2: Reserves and Resources Classification and Reporting Guidelines
15
R/P Ratio
Reserves / Production Ratio defined as Expectation Reserves at year-end divided by Production during the
same year.
R/P = Expectation Reserves (as at 31.12.XXXX)
Production
Sales Gas
The volume of gas that is directly marketable and can be sold at contractually agreed prices. This would typically exclude impurities, own use and flare volumes, as well as intermediate components that are removed from the gas stream prior to sale.
Sales NGL
Marketable liquids that are derived from the processing of raw gas, but cannot be sold as oil.
Sales Oil
The volume of oil that is directly marketable and can be sold at an indexed market price.
UTC
Unit Technical Cost is the undiscounted costs, comprising operating (OPEX), drilling (DRILLEX), facility construction (CAPEX), and decommissioning costs, divided by the undiscounted expected recoverable volumes, expressed in barrels of oil equivalents.
Volume 2: Reserves and Resources Classification and Reporting Guidelines
16
References
1. Guidelines for Application of the Petroleum Resources Management System,
SPE/AAPG/WPC/SPEE/SEG., November 2011
2. Guidelines for the Classification and Reporting of Hydrocarbon Resource Volumes in Brunei
Darussalam, Petroleum Unit., July 2007
Volume 2: Reserves and Resources Classification and Reporting Guidelines
17
Appendices
Below are the appendices with formatted tables to be included in the Annual Review of Petroleum
Resources report as per reporting format and requirement section above.
Appendix 1
Summary table of Reserves Changes from previous year to current year:
* Reserves volumes include Class 1, Class 2 and Class 3
Proved Reserves Expectation (2P) Reserves 3P Reserves
Liquids Mln m3
Gas Bcm
Liquids Mln m3
Gas Bcm
Liquids Mln m3
Gas Bcm
31.12.XXXX (Previous Year)
Maturation
Revisions, Discoveries etc
Production
31.12.XXXX (Current year)
Appendix 2
Summary table of Contingent Resources and Prospective Resources Changes from previous year to
current year:
Contingent Resources
1C 2C 3C
Liquids Mln m3
Gas Bcm
Total Mmboe
Liquids Mln m3
Gas Bcm
Total Mmboe
Liquids Mln m3
Gas Bcm
Total Mmboe
31.12.XXXX (Previous Year)
31.12.XXXX (Current Year)
Prospective Resources
1U 2U 3U
Liquids Mln m3
Gas Bcm
Total Mmboe
Liquids Mln m3
Gas Bcm
Total Mmboe
Liquids Mln m3
Gas Bcm
Total Mmboe
31.12.XXXX (Previous Year)
31.12.XXXX (Current Year)
Volume 2: Reserves and Resources Classification and Reporting Guidelines
18
Appendix 3
Summary table of Ultimate Recovery and Reserves as at 31.12.XXXX (Wellhead Volumes with Economic
Cut-off with Post License) – Liquid and Gas:
*Total Oil and Condensate in Mln m3 **Total Gas in Bcm *** Total Reserves = Developed Reserves + Undeveloped Reserves + Justified for Development
Field
Name
Discovered HCIIP Ultimate
Recovery RF
(%)
Cumulative
Production
Total Reserves Developed
Reserves
Undeveloped
Reserves
Justified for
Development Production
Low Best High 1P 2P 3P 1P 2P 3P 1P 2P 3P 1P 2P 3P 1P 2P 3P
X1
X2
X3
Total:
Appendix 4
Summary table of Total Contingent and Prospective Resources as at 31.12.XXXX (Wellhead Volumes
with Economic Cut-off with Post License):
*Total Oil and Condensate in Mln m3 **Total Gas in Bcm
Field/
Category
CONTINGENT RESOURCES PROSPECTIIVE RESOURCES
Class 4
CR Development
Pending
Class 5
CR On Hold
Class 5
CR Not Viable
Class 5
CR Unclarified
Class 6
PR Prospect
Class 7
PR Lead
Class 8
PR Play
Liquid
Mln m3
Gas
Bcm
Liquid
Mln m3
Gas
Bcm
Liquid
Mln m3
Gas
Bcm
Liquid
Mln m3
Gas
Bcm
Liquid
Mln m3
Gas
Bcm
Liquid
Mln m3
Gas
Bcm
Liquid
Mln m3
Gas
Bcm
X1
X2
Total
Producing
Fields
Y1
Y2
Total
Prospective
Fields
Volume 2: Reserves and Resources Classification and Reporting Guidelines
19
Appendix 5
Field HCIIP Volumes as at 31.12.XXXX:
*Total Oil and Condensate in Mln m3 **Total Gas in Bcm
FIELD_ABBR BLOCK SAND OIL_TYPE GAS_TYPE
STOIIP CIIP GIIP
1P 2P 3P 1P 2P 3P 1P 2P 3P
Volume 2: Reserves and Resources Classification and Reporting Guidelines
20
Rem
ark
: Op
era
tors
to
pro
vid
e a
ll co
nve
rsio
ns
use
d a
nd
rep
ort
ed in
th
e sp
rea
dsh
eet
Appendix 6
The final 31.12.XXXX Domestic and International Total Hydrocarbon Reserves and Resources tables:
Proj
ect
Lead
Oil
Gas
Tota
lO
ilG
asTo
tal
Oil
Gas
Tota
lO
ilG
asTo
tal
Oil
Gas
Tota
lO
ilG
asTo
tal
Oil
Gas
Tota
lO
ilG
asTo
tal
Oil
Gas
Tota
l
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
X1 X2 X3 X4 TOTA
L
Y1 Y2 Y3 Y4 TOTA
L
DO
ME
ST
IC
/ IN
TE
RN
AT
IO
NA
L (3
1.1
2.X
XX
X)
Hyd
ro
ca
rb
on
R
ese
rve
s a
nd
R
eso
urc
es V
olu
me
s
Clas
sific
atio
n 1
Clas
sific
atio
n 2
Clas
sific
atio
n 3
Clas
sific
atio
n2P
3P2P
3P
RE
SE
RV
ES
FIEL
DS/
PRO
SPEC
TS
BLO
CK /
ASS
ETFI
DO
nstr
eam
date
Dev
elop
ed R
eser
ves
Und
evel
oped
Res
erve
sJu
stif
ied
for D
evel
opm
ent
1P1P
2P3P
1P
Oil
Gas
Tota
lO
ilG
asTo
tal
Oil
Gas
Tota
lO
ilG
asTo
tal
Oil
Gas
Tota
lO
ilG
asTo
tal
Mln
m3
Bcm
Mln
bo
eM
ln m
3B
cmM
ln b
oe
Mln
m3
Bcm
Mln
bo
eM
ln m
3B
cmM
ln b
oe
Mln
m3
Bcm
Mln
bo
eM
ln m
3B
cmM
ln b
oe
2C
3C
1C
2C
3C
1C
Cla
ssif
icat
ion
4C
lass
ific
atio
n 5
CO
NT
IN
GE
NT
R
ES
OU
RC
ES
Co
nti
nge
nt
Re
sou
rce
s D
eve
lop
me
nt
Pe
nd
ing
Co
nti
nge
nt
Re
sou
rce
s O
n H
old
/ N
ot
Via
ble
/ U
ncl
arif
ied
Oil
Gas
Tota
lO
ilG
asTo
tal
Oil
Gas
Tota
lO
ilG
asoi
l ga
sTo
tal
Oil
Gas
Tota
lO
ilG
asTo
tal
Oil
Gas
Tota
loi
l ga
soi
l ga
sTo
tal
Oil
Gas
Tota
lO
ilG
asTo
tal
Oil
Gas
Tota
loi
l ga
soi
l ga
sTo
tal
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
bcm
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
boe
Mln
m3
Bcm
Mln
m3
Bcm
Mln
boe
Rem
arks
Oil
Gas
Oil
Gas
Oil
Gas
Mea
n (M
SV)
Risk
ed E
xpt
Vol
umes
Pros
pect
ive
Reso
urce
s Pl
ayCl
assi
ficat
ion
8
PR
OS
PE
CT
IV
E R
ES
OU
RC
ES
POS
(%)
POS
(%)
POS
(%)
1U2U
3U3U
Mea
n (M
SV)
Risk
ed E
xpt
Vol
umes
1U2U
3UM
ean
(MSV
)Ri
sked
Exp
t V
olum
es1U
2U
Pros
pect
ive
Reso
urce
s Pr
ospe
ctPr
ospe
ctiv
e Re
sour
ces
Lead
Clas
sific
atio
n 6
Clas
sific
atio
n 7
Volume 2: Reserves and Resources Classification and Reporting Guidelines
21