12th plan document ongc

12th Five Year Plan
(2012-2017)
For Internal Circulation
Oil and Natural Gas Corporation Limited
Corporate Planning
New Delhi / Dehradun
July - 2013

12th Five Year Plan
(2012‐2017)

Oil and Natural Gas Corporation Limited
Corporate Planning
New Delhi / Dehradun

July 2013
For Internal Circulation

Preface

Since opening up of Indian Petroleum Sector, the Upstream Exploration and Production segment has witnessed
structural realignments, bringing with it opportunities, as well as challenges. Brisk economic progress in this
period has led the Indian economy eyeing high GDP growth. Higher economic growth essentially involves greater
demand for energy. With more than 75% of the nation’s crude oil being imported at international market prices,
the pressures on the economy are mounting.

During 11th plan period, the crude oil prices touched a new high and put a real pressure on fast growing economies
like India. Towards the end of 11th plan crude oil prices cooled down & world also saw an economic slowdown.
The formulation of 12th plan posed major challenges in terms of reviving the economies, boosting investment &
continuing with the nation’s growth story. In the recent past there have been no big/major discoveries of Crude
Oil & producing oil fields are getting mature. Amidst global decline of major oil producing fields, ONGC’s fields are
no exception. Most of the major ONGC fields are more than 30 years old and have entered into natural decline
phase. Implementation of 24 schemes of IOR‐EOR has to a large extent compensated& is expected to compensate
for the decline of these major fields.

The resolve of the Indian government to provide petroleum products of mass consumption at affordable prices is
reflected in its policy of providing indigenously produced crude oil at discount to the Oil Marketing Companies
(OMCs) for subsidizing their under‐recoveries. This discount has resulted in lower realization for crude oil

produced by ONGC. With higher crude oil price, the cost of the services to E&P Industry are going up worldwide,
resulting in squeeze in the surplus for investment in exploration and production activities.
In the recent years ONGC has made significant discoveries in the East Coast in G‐1 & GS‐15, G‐4 & GS‐29,
Vashishtha, S‐1 and in block KG‐DWN‐98/2. Most of these discoveries relate to gas reserves. ONGC proposes to
develop these reserves by combining nearby locations in to cluster/ hub based development, which means using
common facilities like pipeline etc to optimize cost.

ONGC’s 12th Plan Exploration & Development program reflects both challenges and opportunities. ONGC
submitted a draft five year plan to Ministry of Petroleum & Natural Gas in July 2011. Many rounds of discussions
took place at various levels to deliberate the 12th Plan document.Planning Commission formulated India’s 12th
Plan including the inputs from entire nation. This 12th Plan document brings out detailed exploration &
Production programme of ONGC. This document contains detailed tables pertaining to Physical & Financial targets
of 12th Plan. A section of this document is dedicated to figure out the achievements during 11th Plan.

The figures stated for Crude oil production includes condensate receipt, where ever applicable, unless stated
otherwise. The summary of 11th Plan Achievements & 12th Plan targets is presented in Table A1 & A2 of the
document.

Besides the above, Planning Commission in its 12th Plan document observed that Oil & Gas companies need to
focus attention on the following:

The Petroleum Sector Companies are required to produce 5 MMTOE of energy from renewable and
unconventional energy sources towards becoming carbon neutral. The achievement of targets could be met by the
end of 12th plan to produce energy amounting to 5 MMTPA. Out of this, 1 MMTOE has been given as a target for
ONGC.
The oil companies have been informed to utilize the National Clean Energy Funds (NCEF) available for this
purpose.
It was also stressed that MOPNG may take up following issues recommended for implementation during the 12th
plan period for the Petroleum & Natural Gas sector as approved by the National Development Council (NDC):
 Take up exploration in un‐licensed offshore areas‐Deccan basins and other technologically challenging
areas in Deep Water and sub‐basalt sediments.
 Government should encourage import of cutting edge technology by upstream oil companies in Offshore
field development projects.
 The oil companies may approach the National Clean Energy Fund (NCEF) to fund the innovative R&D
projects.
 Induct qualified technical work force in large numbers.
 Deploy the CSR funds for creating health and educational resources.

INDEX
S.No Description Table Number
1 Summary of 12th Plan – Text part Page 1 to 19
2 Summary Sheet for 11th Plan achievements &12th Plan Targets A1 to A2
3 Activity‐wise 11th Plan Target vs Achievements B1 to B13
4 Activity‐wise 12th Plan Targets ‐ Physical C1 to C10
5 Financial Summary Sheet & IR Statement D1 to D3
6 Asset‐wise Summary Sheet‐ Physical & Financial E1 to E19
7 Basin‐wise Summary Sheet – Physical & Financial F1 to F8
8 Seismic Survey‐ Detailed Break‐up Physical Targets G1 to G9
9 Exploratory Drilling ‐ Detailed Break‐up Physical Targets H1 to H10
10 Reserve Accretion ‐ Detailed Break‐up Physical Targets I1 to I10
11 Field‐wise Oil & Gas Production J1 to J2
12
Asset Basin summary, Capital Projects, JV, North East, Institutes &
Integration Projects ‐ Financial
K1 to K11
13 List of Abbreviations used in Document L

1
Oil and Natural Gas Corporation Ltd.
12th
Five Year Plan (2012-17) - Summary
1.0 Introduction
Amidst global decline of major oil producing fields, ONGC’s fields are no exception. Most of the major ONGC fields are more than 30
years old and have entered into natural decline phase. Implementation of IOR-EOR schemes has compensated for the decline of these
major fields to a large extent. ONGC’s 12th
Plan Exploration & Development program reflects both challenges and opportunities. The
12th
Plan proposals are based on the priorities of the organization and existing ground realities. The exploration activities are as per the
long term strategy of the organization. The summary of ONGC’s exploration & development plan is given in subsequent sections.
ONGC had submitted a draft five year plan to Ministry of Petroleum & Natural Gas in July 2011. Many rounds of discussions took place
at various levels to deliberate the 12th
Plan document. Planning Commission has formulated India’s 12th
Plan including the inputs from
various sectors across the country. This document has been worked out to bring the details of ONGC’s Exploration & Development
plan. This document contains detailed tables pertaining to Physical & Financial targets of 12th
Plan.
2.0 Exploration Programme:
An aggressive exploration programme is envisaged in 12th
Plan with focus on:
 Nomination PEL blocks
 Existing NELP & pre-NELP blocks
 Existing PML blocks
 Next phase in existing NELP blocks where ONGC may opt to enter into
 Applied/ new PML blocks likely to be approved based on the positive results of exploration activities carried out in the current phase
 Selected PML blocks to pursue the new deeper plays which require additional resources

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 New blocks likely to be obtained under future NELP/ OLP rounds
2.1 Seismic Survey
During the 12th
plan period, the number of acreages available for exploration will keep on reducing every year & hence the seismic
survey is also expected to go down. As per the existing government policy, new exploration acreages can be acquired through the open
bidding process only. This policy is now proposed to be replaced by a new Open Licensing Policy under which a company can apply for
new exploration blocks any time. As almost all the areas in the producing basins has already seen a lot of activities in the past, only
relinquished portions of the nomination blocks held by ONGC till recently or NELP blocks relinquished by ONGC and other operators will
be available for bidding. These blocks may therefore require less of exploratory inputs. However, there are large blocks/ areas in other
Category-II/III/IV onland basins and deep / ultra deep water areas of producing as well as non-producing basins where still exists scope
of exploration.
ONGC’s activity planned for 2D seismic survey would be of the order of 28,170 Line Km (LKM) while 3D survey would be 24,163 sq. km
during the 12th
Plan period. The 2D and 3D survey are about 52% and 32% of the 11th
Plan target. The 2D survey would be gradually
falling down during the course of the 12th
Plan Period. Out of the total 2D data, ONGC plans to acquire 19670 LKM of 2D data in
existing nomination & NELP current phase blocks. Around 6500 LK of 2D and 12100 SK of 3D seismic data acquisition is planned to be
carried out in these future blocks.
Basin wise break-up of 2D & 3D seismic survey is given in table C-6. Further detailed break-up of 2D & 3D surveys in various NELP,
Nomination & future blocks is detailed in tables G1 to G9.

3
2.2 Exploratory Drilling:
A total 611 exploratory wells are being planned to be drilled during the 12th
Plan which is marginally less (around 6.1%) from the 11th
Plan firm + upside target of 651 wells. However, this would enable ONGC to accrete initial in-place volume of hydrocarbon of 1080.0
MMToe for the 12th
Plan period which is about 108 % of the firm + upside figure for 11th
Plan target.
In the exploratory drilling activity, a total of 400 wells are planned to be drilled in onshore blocks & 211 wells in offshore blocks. Out of
211 offshore wells, 57 wells are planned in deep water (20 in MBA Basin, 23 in KG DW, 8 in Cauvery DW & 6 wells in West coast deep
waters). It is important to note that many of the blocks especially the ones awarded in NELP-VI and later rounds do not have much of
drilling commitments in the first phase. Depending on the results of seismic API, ONGC intends to enter into phase-II in some of the
blocks and drill the exploratory wells.
Basin wise break-up of exploratory drilling activities is given in table C-7. Further detailed break-up in various NELP, Nomination &
future blocks is detailed in tables H-1 to H-10.
Table: 1
S.No Activity Units 2012-13 2013-14 2014-15 2015-16 2016-17 12th Plan
1
Seismic Surveys 2D LKM 12470.0 13420.0 230.0 1000.0 1050.0 28170.0
Seismic Surveys 3D SKM 4290.0 9482.0 5091.0 3140.0 2160.0 24163.0
2
Exploratory Metreage KM 491.34 428.42 376.68 330.06 297.15 1923.65
Wells Nos 156 133 117 107 98 611
3
Reserves Accretion IIH MMToE 285.5 255.5 194.5 173.0 171.5 1080.0
Reserves Accretion UR MMToe 86.3 73.7 69.6 65.2 65.3 360.0

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2.3 Reserve Accretion:
As an outcome of exploration activities, ONGC plans to accrete initial in place hydrocarbon of 1080 MMToE which is about 8% more
than 11th plan target. Further the ultimate reserve accretion shall be 360 MMToe during this period.
The summary of year-wise physical activities of exploratory programme are stated in Table 1 above and comparison of 11th & 12th Plan
targets is given in Table 2 below:
Table: 2
3.0 Production & Development Programme
In the recent years ONGC has made significant discoveries in the East Coast in G-1 & GS-15, G-4 & GS-29, Vashishtha, S-1 and in
block KG-DWN-98/2 (i.e, D, E, KT-1, U, W, A, Kanakdurga and Padmavati). Most of these discoveries relate to gas reserves. During
12th
Plan ONGC proposes to develop these reserves by combining nearby locations in to cluster/ hub based development, which means
using common facilities like pipeline etc to optimize cost. The production from GS-15 has already commenced from 31st
August 2011,
while the other discoveries are currently under appraisal.
S.No
Activity Unit
11th
Plan
Target
12th
Plan Target
12th
Plan Target
with 11th
Plan
1 Seismic Surveys 2 D GLK 54359 28170 51.8 %
Seismic Surveys 3 D SKM 76398 24163 31.6 %
2 Exploratory Wells Nos. 651 611 93.8 %
3 Reserve Accretion –UR MMToe 339.7 360.0 105.9 %
Reserve Accretion –IIH MMToe 1000.70 1080.0 107.9 %

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Due to the major thrust given to Marginal field development, which was earlier not techno-economically viable to develop, ONGC would
be bringing on production some of the Marginal fields during the 12th
Plan. This would give a boost to oil production in the initial years of
the 12th
Plan; however, being marginal in nature, production from these fields may fall sharply after achieving peak production.
Gas production is well poised to take off due to substantial discoveries in the East Coast and also due to the fact that the new and
marginal fields would be coming on to the production, though gas discoveries in deep and ultra deep waters may take little longer time
to come on production stream.
3.1 Crude oil Target
The 12th Plan envisages a crude oil (including condensate receipt) production target of 133.06 MMT of which 97.37 MMT is slated to
come from offshore and 35.69 MMT from onshore. The total production envisaged is around 7% more than the 11th plan actual
achievement. The contribution of ONGC’s crude share in JV fields is expected around 15.93 MMT during the 12th
Plan.
The envisaged increase in production in 12th
Plan from the estimated actual of the 11th
Plan would owe largely to the New and Marginal
Fields (NMFD) many of which would be coming on stream during the 12th Plan period, viz: Cluster 7, WO series, etc. Together with
other NMFDs like B-22+, B-193+ etc. the NMFDs contribution is likely be of over 11.7 MMT during the 12th
Plan Period. Some of the
discoveries made in the Eastern Offshore, viz, G-1, GS-15, and GS-29 and KG-98/2 are also expected to contribute over 1.8 MMT
during the plan period. Thus production during the plan period is expected to remain well above 25 MMT with a peak production of
28.27 MMT in 2013. However, being marginal in nature the production from these fields may not sustain after attaining the peak
production, and therefore production decline is envisaged after 2013-14 of the Plan Period.

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3.2 Natural Gas Production Target
The Natural Gas production target is envisaged at 144.30 BCM from ONGC operated fields, which would be the highest ever Five Year
Plan target. This target is almost 128 % more than the 11th Plan target. The offshore fields alone would contribute 116.02 BCM which
itself would be higher by 45 % from the 11th
Plan Target. The onshore fields share would be 27.891 BCM. The contribution of ONGC’s
Natural Gas share in JV fields is expected around 9.91 BCM during the 12th Plan.
Here again, NMFDs is expected to give a boost to the Natural Gas production during the 12th
Plan ie about 23.03 BCM, but the major
boost is expected to come due to production from the discoveries made in the East Coast. While fields like G-1/ GS-15, Vashistha etc.
would contribute over 6.27 BCM during the Plan period, the KG-98/2 discovery, which would come on stream in the far end of the Plan
period, i.e. in 2016-17 would alone contribute over 10 BCM. Another major production is envisaged from Daman+C-24 field which
would come on stream in 2015-16 and contribute around 4.9 BCM during the 12th
Plan. The other New and Marginal Fields in the
western Coast viz., B-22+, B-193, SB-14 B-series, Cluster 7, WO+, North Tapti etc. together are likely to contribute substantially during
12th
Plan period. Thus Gas production would remain above 25 BCM throughout, gradually increasing to a record 38.676 BCM in
terminal year 2016-17 of the Plan Period.
3.3 Natural Gas Sales
Natural gas sales target for the 12th Plan has been fixed at 117.06 BCM which is 141 % of the 11th Plan target of 82.912 BCM. The
total Gas Sales including ONGC’s share in JV fields of 9.12 BCM, shall be 126.18 BCM.
3.4 Value Added Products
Production target for Value Added Products (VAP) during the 12th Plan has been kept at 17.602 MT which is 7.7% higher than the 11th
Plan target of 16.346 MT.

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3.5 Development Drilling
The development drilling is expected to be of the order of 1120 wells during the 12th
Plan which is 112% of the 11th
Plan target of 1000
wells. The Onshore would contribute the lion share of 900 wells while development drilling in offshore would be of the order of 220 wells.
Out of 220 offshore wells, 87 wells are planned in New & Marginal field development and about 22 development wells are planned in
Eastern Offshore Assets.
The summary of year-wise physical activities of production programme are stated in Table 3 and comparison of 11th
& 12th
Plan targets
is given in Table 4 below:
Table: 3
Sl.
No.
ACTIVITY UNIT 2012-13 2013-14 2014-15 2015-16 2016-17 12th
Plan
1
Crude Oil Production - ONGC MMT 25.045 28.269 28.002 26.285 25.457 133.058
Crude Oil Production - JV Share MMT 3.721 3.882 3.176 2.627 2.527 15.932
Total Crude Oil Production MMT 28.766 32.151 31.178 28.912 27.983 148.989
2
Natural Gas Production - ONGC MMSCM 25266.18 25471.54 26669.43 28214.56 38676.10 144297.82
Natural Gas Production -JV Share MMSCM 2113.44 1952.52 1956.36 1742.07 2143.52 9907.91
Total Natural Gas Production MMSCM 27379.62 27424.07 28625.79 29956.63 40819.62 154205.73
3
Natural Gas Sales - ONGC MMSCM 20089.58 20078.54 21016.15 22623.83 33247.07 117055.17
Natural Gas Sales - JV Share MMSCM 1951.34 1803.47 1809.46 1602.49 1953.15 9119.91
Total Natural Gas Sales MMSCM 22040.92 21882.01 22825.61 24226.32 35200.21 126175.08
4 Value Added Products KT 3580.96 3635.76 3606.14 3498.45 3281.21 17602.51
5 Development Wells Nos 325 275 212 158 150 1120
Note: Crude Oil Production quantity as stated above includes Condensate receipt

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Table: 4
Activity Unit
11th
Plan 12th
Plan
Target
12th
Plan Target over
11th
Plan ActualTarget Actual
Crude Oil Production- ONGC MMT 140.06 124.11 133.06 107.2%
Crude Oil Production- JV
Share
MMT 13.58 11.41 15.93 139.6%
Total Crude Oil Production MMT 153.64 135.52 148.99 109.9%
Gas Production -ONGC BCM 112.39 114.34 144.30 126.2%
Gas Production - JV Share BCM 14.79 12.64 9.91 78.4%
Total Gas Production BCM 127.18 126.98 154.21 121.4%
Total Gas Sales (excl JV) BCM 82.91 90.20 117.06 129.8%
Value Added Product MMT 16.35 16.45 17.60 107.0%
Development Wells Nos. 1,000 1,227 1,120 91.3%
4.0. Strategy Options for enhancing Crude oil and Natural gas production
ONGC has been continuously taking various actions to improve/ augment the crude oil production. Various strategies have been
adopted not only to offset decline from producing mature fields but also, new frontiers are being explored for sustaining / improving
production. Following are the major strategies adopted in this regard:-
4.1 Focus areas
Gandhar sand pinchout prospects in the west of Gandhar field acquire significance in view of the recent discovery of gas in Aliabet.
Kalol/ Chhatral (Eocene Pays) hold significant hydrocarbon potential in the Cambay-Tarapur block as proved by discoveries in Chaklasi,
Nadiad, Siswa Anklav and Vadtal areas.

9
Recent discoveries in Kalol / Kadi pays in Linch, Kadi and Jotana areas point to the left out hydrocarbon potential of these known plays
in the area to the east of Mehsana horst extending right upto basin margin where small accumulations in Mehsana and Mandhali
members are established.
Deeper Sylhet and Tura play exploration in Upper Assam is also an upcoming play which will be pursued in the 12th
Plan. However,
drilling issues will have to be addressed for deeper plays in Upper Assam and AAFB (M/ Lower Bhuban). Meanwhile, continuing
exploration for known and established plays (Tipam/ Barail in Upper Assam and Bokabil/ U Bhuban in AAFB) has given good results in
Geleki, Banmali, Khubal, Gojalia and Rokhia areas. To exploit the field growth potential of these known plays and also to commercialize
the nascent deeper plays in producing sectors of the basin, vigorous exploration in priority sectors is planned in 12th
Plan.
Recent significant successes obtained in synrift exploration in KG onland (Malleswaram), KG Offshore (Yanam, G-4-6) and Cauvery
onland (Periyakudi) show that, it is likely to be the play of next decade to be pursued in 12th
and 13th
Plan period. The important key to
success in exploration for these deeper plays is the improved seismic image. Large volumes of 3D seismic data were acquired in last 3-
4 years in both KG Cauvery basins and number of prospects based on these new data are identified which will be taken up for drilling in
the 12th
plan period. Drilling of these prospects is likely to give significant reserve accretion in both the known and new emerging plays
in these two basins. However, most of the wells could not be conclusively tested for want of tools and technology suited for HP-HT (High
Pressure & High Temperature) conditions. Proper drilling, testing and completion of HP-HT wells is a point of concern which has to be
overcome in the future.
Exploration for Cretaceous synrift plays in deep offshore, despite some setbacks, is likely to be continued in the 12th Plan also
considering the fact that this is one play in deep water where thermogenic accumulations can be expected.
The story though is not as successful in W Offshore basin as far as synrift Panna exploration in 11th plan is concerned; some serious
initiatives were taken with drilling of number of prospects in the basin. While significant gas shows have been observed while drilling

10
through the Panna section, a commercial success may require some more efforts and better planning for drilling and testing of the
interesting objects in view of the high pressure / high temperature regime. Apart from this, the focus on known plays and subsidiary
plays in younger formations in the entire producing sector will definitely give reasonable returns.
Exploration efforts for Tertiary plays in Kutch Saurashtra have received a big boost with discovery of oil and gas in GK-28 area. In
addition, there is additional incentive for exploration in this area in the form of possibility of more hydrocarbons in Cretaceous section
also. However, success for the deeper Mesozoic play will be highly dependent on the seismic image quality. Efforts to improve the
image at deeper levels will continue to be focus of exploration.
4.2 Production enhancement through implementation of additional redevelopment projects/ IOR/EOR schemes by improving
recovery from existing fields
ONGC has already initiated actions in 15 major producing fields where production is being enhanced with the help of various additional
redevelopment projects/ IOR/EOR schemes, totalling 21 in numbers. The components of these projects include drilling of additional in-
fill wells with best available technologies to reduce the well spacing, rehabilitation of old wells by approaching new/ extended area,
drilling of additional wells through clamp-on structures on existing well platforms with the augmentation of production facilities, in-situ
combustion etc.
The contribution through IOR-EOR projects during 12th Plan is envisaged at 40.07 MMT of which 29.58 MMT would come from 9 of the
Offshore projects and 10.49 from 12 Onshore projects. This is over 30% of the total crude oil production targeted for the 12th
Plan
period.
Contribution from IOR-EOR projects
2012-13 2013-14 2014-15 2015-16 2016-17 Total
9.759 9.158 7.933 6.929 6.291 40.07

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4.3 Production enhancement through Monetization of Marginal fields
In addition to re-development / additional development of existing fields, ONGC is giving major thrust to develop its marginal fields. The
main focus is on exploitation of hydrocarbon from Marginal fields (C series, B-193 cluster, B-22 cluster, North Tapti, Cluster 7 marginal
fields, B 46 and WO+ series) which were discovered earlier but could not be put on production due to adverse techno-economics and
want of new technology.
Some fields like D-1, SB-11 (Vasai West), Vasai East, C series and B134A have already been put on production. Development of
several other marginal fields like B-193+ cluster, B-46+ cluster, B-22+ cluster, Cluster 7, WO series and North Tapti etc., have been
approved and feasibility reports (FR) of few other marginal fields are under various stages of preparation.
ONGC is also fully committed to develop its oil and gas discoveries in the prolific Krishna Godavari basin, off the country's east coast.
Integrated development of G-1 and GS-15 project is under implementation. Also, ONGC has initiated actions for developing G-4, & GS-
29 Vashistha, S1 Field in KG offshore.
4.4 Production enhancement through Technology Induction and services of domain experts
ONGC has been employing the best in class technologies for pursuing its objective of improving production from its oil fields/wells.
These measures include application of state-of-the-art and fit-for-purpose technologies suited for western offshore reservoirs. ONGC
has adopted the latest technologies in the area of Drilling operations, Well completion, Stimulation; Work over Operations, Artificial Lift,
Water Injection, Offshore Production facilities and remote monitoring/ control of operations and production optimization.
ONGC has been sourcing the services of international experts/ consulting firms for assisting in finding technical solutions for various
critical problems/ offshore operations and for better technology absorption for improving productivity.

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5.0 Strategies for development of alternate sources of Oil & Gas
Being finite resources, oil and gas may need substitution and may need it sooner if we go by the proponent of Peak Oil theory.
Moreover, with growing climate concern we also need to look for cleaner fuel.
ONGC had been the pioneer in exploration for some of the alternate forms of gas, viz. CBM, UCG, Shale Gas and Gas Hydrates. Some
of the strategies proposed to be adopted during 12th
Plan for further exploration and exploitation of these alternate sources are given
under.
5.1 Coal Bed Methane (CBM)
The CBM strategies for 12th
Plan envisage focus on activities in the Jahria and Raniganj nomination blocks and the Bokaro and North
Karanpura CBM Blocks. The strategies for each of these blocks during the 12th Plan are given here under:
5.1.1 Jharia Block
Parbarpur Sector: Out of 18 sq. km of Parbatpur area 8.8 sq km in the overlapping coal mining Block is not considered for any CBM
activities in the 12th Plan. Out of remaining 9.2 sq. km, available area (after allowances for inhabited area, railway lines, forest land etc.)
works out to be only 5 sq. km in 3 patches in North, West and South and an approx. estimation indicates maximum number of wells that
can be drilled is only 20. The overlapping area is kept out of any future plan.
Other Sector: The prospective area in Other Sector is 20 sq km (approx.) in 3 disjointed areas (Mahal in the East of Parbatpur, Aluara-
Dumarda in the West of Parbatpur and Dharmabundh-Kharkharee in the Northwestern part of the Block located on the other side in the
North of Damodar River). With 40 Acre spacing, keeping allowances for other factors viz. inhabited areas, railway lines, forest land etc.
approx. a total of 82 wells can be drilled in this Sector. However, the techno-economic viability of the project is to be established. In the
light of interest shown by a Company to work jointly with ONGC in these areas through farm-in option, the same with Operatorship to
the other Company seems to be a better proposition. With the assumption that such an alliance will materialise in near future, 102 wells
(82 in Other Sector + 20 in Parbatpur Sector) are kept under Upside Category for Jharia Block.

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5.1.2 Raniganj Block
Sector-B: In this Sector the prospective area is approx. 40 sq. km. There are overlapping issues with Bengal Aerotropolis Project
(BAPL), Ichapur and Moira Madhujhore coal mining Blocks. Besides these complications it may be relevant to mention that acquisition
of land, being in the highly industrialised area, is extremely difficult following all procedures and also involve huge cost. 2-3 Companies,
however, has shown interest to join hands with ONGC for a quick assessment of the area through farm-in option with Operatorship and
continue to work subsequently for developmental work. With the assumption that such an alliance will materialise in near future, the
developmental work involving drilling in 40 sq. km area (with 80 Acre spacing) has been provisioned in the Upside Category of 12th
Plan.
5.1.3 Bokaro Block
The Development Plan of the Block has been submitted to DGH. In the Technical Committee Meeting held in May, 2011 the
Development Plan is agreed with certain modifications. The Development Plan involves drilling of 146 wells in 2 disjointed patches.
From the past experience in the Exploratory and Pilot Phases extreme difficulties have been faced in acquisition of land. Under the
circumstances, to overcome these difficulties, again the farm-in option with Operatorship to the other Company seems to be the
available way forward. With the assumption for such an alliance to materialise in near future, the 146 wells (110 wells in Patch-A and 36
wells in Patch-B) are kept under Firm Category for Bokaro Block.
5.1.4 North Karanpura Block
The Block has a prospective area of 80 sq. km (in Sector-C). No gas break has been observed yet and at present testing is continued
through cluster wells to achieve early gas break out. Anticipating gas break shortly, 247 Development wells are planned (considering 80
Acre spacing) and kept in Upside Category of 12th and 13th Plan with 123 and 124 wells respectively. In view of difficulties in land
acquisition, availability of site plots matching with the drilling schedule is not possible. To tide over the difficulties, farm-in option with
Operatorship to the other Company is the viable option. However, in case gas break cannot be achieved prior to the time available for
Phase-II work completion, ONGC may have to surrender the Block.

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5.2 Shale Gas
As of now Shale Gas exploration is in the nascent R&D stage in the Indian hydrocarbon sector and ONGC is the first to venture into this
play which is a technology and capital intensive venture. The shale gas flow recorded in ONGC’s maiden well in the Raniganj area is a
first step in Shale gas exploration. However, the well is to be conclusively tested to know the flow rates, reservoir parameters and
commerciality. Activities envisaged in the field of Shale Gas Exploration in the 12th Five Year Plan and later are as follows:
Initially, in the absence of Shale Gas Policy in the Country, special permission to carry out Shale Gas R&D in our CBM acreages was
obtained from MOP&NG. Nevertheless, ONGC can apply for award of its present areas of R&D, on nomination basis, depending on
Policy and prospectivity concluded from the Shale Gas Project.
Generation of Shale Gas critical parameters like gas content, shale characterization and other geochemical parameters, are to be
generated in other Basins as an R&D measure, while drilling through the shale sections. Shale reservoir characterization and modeling
of various basins/ fields/ with novel data set to find optimum well locations. Gain insights into the best hydraulic fracturing technologies
and frac fluids which may help optimize production and find cost-effective solution to the challenges associated with water management
and other environmental issues.
Permission to carry out Shale Gas R&D was accorded vide letter of MOP&NG No. 19018/3/2009-ONG-I dtd.06th Nov.’09 which states
“In case after the studies, shale gas is found commercially viable, then ONGC will submit the detailed proposal which will be separately
considered by the Government and will be governed by separate policies, outside the existing CBM Contract”.
Therefore, after completion of the Shale Gas R&D Project in Damodar Valley a comprehensive evaluation of their potential will be
realized, facilitating the decision to seek award on nomination basis. As of now, it appears that the Raniganj acreage is prospective and
needs to be pursued further. Appraisal horizontal well in the Raniganj Block can be drilled to know the actual potential and deliverability

15
of the Barren Measures Shales. Shale gas/oil Pilot project similar to the present Project can be launched in Cambay and KG Basins with
requisite permission from MOP&NG.
2D seismic campaign in Raniganj Block for delineating the Barren Measures is for further Shale Gas exploration in the area. Generation
of Shale gas specific data (desorption, shale typing etc.) to continue in other basins as an R&D endeavor.
Upside: Other acreages likely to be opened up in the first offer are in Cambay, KG, Cauvery and Ganga Basins. Of these Cambay and
KG, prima facie have Shale Gas potential and need to be pursued in the forthcoming bidding rounds.
5.3 Underground Coal Gasification (UCG)
ONGC took initiative for exploitation of UCG with signing of an Agreement of Collaboration (AOC) with Skochinsky Institute of Mining,
Russia on 25th November, 2004 for implementation of Underground Coal Gasification (UCG) project in India.
In order to make a dent on the energy front through use of UCG technology, a number of additional sites, besides Vastan where Pilot
Project were jointly identified by ONGC & NLC for studying their suitability to UCG. These are Tadkeshwar in Gujarat and Hodu -
Sindhari & East Kurla in Rajasthan. One more site was jointly identified by ONGC & GMDC viz. Surkha in Bhavnagar Distt., Gujarat.
The data of all the fields have already been analysed for evaluating the suitability of these sites for UCG and all the sites have been
found suitable for UCG. The projects will be taken up on the basis of learning curve from Vastan project. Tadkeshwar site of NLC is
likely to be taken up after Vastan project.
5.4 Gas Hydrates
ONGC envisages continuing effort to identify prospective areas for drilling/ coring/ logging for exploration/ exploitation of Gas Hydrate in
Indian offshore and design novel technique for its production/ extraction. NGHP, Steering Committee in collaboration with MOP&NG is
to decide the physical future Plan for GH exploration in the XII and XIII Plan.

16
6.0 Plan Outlay 12th
Plan:
The 12th Plan envisages a Plan outlay of Rs. 163,956 Crore which is 216% higher than the 11th Plan outlay of Rs. 75,984 Crore.
However, the 12th Plan outlay is 136% of the envisaged actual Plan expenditure of Rs. 120,552 Crore during 11th Plan. The major
jump in the outlay from 11th Plan is due to the exploratory and development drilling and Capital projects component. While there is
373% increase in plan outlay of Exploratory drilling, rising from Rs. 11,984 Crore in 11th Plan to Rs.44661.8 crore during 12th Plan due
to higher thrust in deep water drilling. The deep water wells envisaged in 12th plan STP are 57 against STP target of 33 wells in 11th
plan STP for ONGC. Further there is 168% increase in total development drilling cost ( Development wells envisaged in 12th plan STP
are 1120 vis a vis 1000 wells in 11th plan) and 257% increase in Capital projects from 11th Plan outlay. Increase in capital outlay is
mainly due to schemes pertaining to Marginal field development which were not techno-economically feasible earlier.
6.1 Survey Expenditure
As brought out earlier, the planned activity for survey during the XII th five year plan is 28,170 GLK for 2D and 24,163 SKM for 3D. The
corresponding expenditure for the XII five year plan is Rs 6,293 Crore. In the XI Five year plan the planned activity for survey was
54,359 GLK for 2D and 76,398 SKM for 3D. The corresponding outlay for the XI five year plan was Rs 7,581.38 Crores. The total
expenditure on account of survey is lower in XII five year plan as compared to XI Five year plan because of lower physical targets.
6.2 Exploratory Expenditure
As brought out, the planned activity for exploration during the 12th five year plan is 611 wells, out of which 57 are deep water wells, 154
shallow water and 400 are onshore wells. The corresponding total expenditure for the 12th five year plan is Rs 44,662 Crore. In the
11th five year plan the planned activity for exploratory drilling was 651 wells. The corresponding plan outlay for the 11th five year plan
was Rs 11,984 Crore. The expenditure on account of exploratory is higher under 12th five year plan as compared to 11th five year plan

17
because of higher number of deep water wells and increase in rig hiring charges. The higher expenditure, however, on account of
survey and exploratory well amounting to Rs 50,955 Crore in 12th Plan will result in higher reserve accretion than the 11th Plan.
6.3 Development Drilling
The planned activity for development drilling during the 12th
five year plan is 1,120 wells. The corresponding expenditure for the 12th
five
year plan is Rs 26,505 crore. In the 11th
five year plan, the planned activity for development was 1,000 wells. The outlay on account of
development is higher under 12th
five year plan as compared to 11th five year plan because of increase in rig hiring charges and
increase in physical plan to sustain production from aging field and incremental production from marginal fields.
6.4 Captial Projects & Purchases
The total capital outlay for 12th five year plan is kept at Rs 79263.52 Crore (excl JV). The expenditure on account of capital includes
major schemes approved by the ONGC Board and under implementation stage. Further schemes envisaged during the 12th
five year
plans have also been included at an estimated price. During 11th
five year plan the total capital outlay was kept at Rs 30,834 crore which
is lower than 12th
five year plan because of major schemes in Offshore for development of new and marginal fields as well as
development of East Coast discoveries, Daman + C24 discovery, and Redevelopment of Assam and Western Onshore Assets, which
will translate into increase in Crude oil/Gas production.
6.5 Integration/ Acquisition projects
The outlay on account of Integration/ Acquisition projects during 12th
five year plan has been kept at Rs 1403 Crore against the 11th
plan
of Rs 4,189 Crore. Towards integration projects, ONGC is planning to venture in City Gas Distribution (CGD) projects in 10 cities along
with BPCL. At the same time ONGC is also planning to secure equity stake in upcoming LNG Projects as well as bringing equity gas as
LNG to the country. In line with Jawaharlal Nehru National Solar Mission, ONGC is planning to set up grid connected solar power
projects (25 MW each for PV and Thermal).

18
6.6 Research & Development and Institutes
Plan outlay for R&D in the 12th
Plan has been kept at Rs. 2,012 Crore which is higher than the Rs. 834 crore targeted during the 11th
Plan. Some of the significant R&D planned in 12th
Plan is:
 Method and techniques of Basin Centered Gas (BCG) exploration in the major lows of the matured basins of India.
 Shale Gas Potential of Indian Sedimentary Basins
 3D Petroleum System Basin Modeling in Indian Sedimentary Basins
 Development of newer light weight platforms for marginal fields
 Technological scheme for development deepwater reservoirs
6.7 The details of 12th Plan Outlay is tabulated hereunder:
(Rs Crore)
S.No Activity 2012-13 2013-14 2014-15 2015-16 2016-17 Total 12th Plan
1 Seismic Survey 1719.64 2467.00 888.76 661.94 555.58 6292.93
2 Exploratory Drilling 7667.50 10917.58 9647.76 8242.34 8186.64 44661.82
3 Development Drilling 5830.57 8058.39 6472.31 3245.46 2898.69 26505.43
4 Capital 15606.70 13316.53 15552.83 17206.91 17580.54 79263.52
5 R&D 245.93 409.78 430.27 451.78 474.36 2012.11
6 JV Domestic 1322.98 867.54 444.96 603.42 578.50 3817.39
7 Integration 671.98 126.00 605.00 0.00 0.00 1402.98
Total Plan Outlay 33065.31 36162.81 34041.89 30411.86 30274.31 163956.18

19
6.8 Estimated Revenue, Profit, Cash Flow etc. during 12th
Plan Period
The total income during the 12th Plan period is estimated at Rs. 413,798 Crore. The details of the financial parameters
are tabulated hereunder:
(Rs. Crore)
S.No Items 2012-13 2013-14 2014-15 2015-16 2016-17
Total 12th
Plan
1 Total Revenue 86239.01 83426.09 82110.60 78191.69 83830.34 413797.73
2 Total Expenditure 55401.11 58125.73 56954.47 56437.38 57001.45 283920.15
3 P.A.I.B.T. 30837.89 25300.35 25156.13 21754.31 26828.90 129877.58
4 Profit After Tax 20832.54 17091.65 16994.22 14696.12 18124.26 87738.80
5 I.R. Operations 27971.06 34289.91 33302.46 31978.38 34535.54 162077.35
6 I.R. After Invest / (disinv) 33065.31 36162.81 34041.89 30411.86 30274.31 163956.18
7 Plan Outlay 33065.31 36162.81 34041.89 30411.86 30274.31 163956.18

SUMMARY SHEETS
(Tables A1 to A2)

Sl. No. ACTIVITY UNIT 11th PLAN 200708 200809 200910 201011 201112 11th PLAN
TARGET ACTUAL ACTUAL ACTUAL ACTUAL ACTUAL ACTUAL
(I)
1 CRUDE OIL PRODUCTION MMT 140.063 25.944 25.367 24.671 24.419 23.712 124.113
CRUDE OIL ‐ JV SHARE MMT 13.578 1.895 1.650 1.792 2.860 3.213 11.410
TOTAL CRUDE OIL ( Incl Condensate) MMT 153.640 27.839 27.017 26.463 27.278 26.925 135.522
2 NATURAL GAS PRODUCTION MMSCM 112390.37 22333.90 22486.42 23108.76 23094.57 23316.34 114340.00
NATURAL GAS ‐ JV SHARE MMSCM 14785.27 2786.77 2949.43 2485.50 2227.58 2194.00 12643.29
TOTAL NATURAL GAS PRODUCTION MMSCM 127175.64 25120.67 25435.85 25594.27 25322.15 25510.35 126983.28
3 NATURAL GAS SALES MMSCM 82912.07 17762.84 17711.90 18239.70 18261.58 18228.37 90204.39
GAS SALES‐ JV SHARE MMSCM 13918.40 2667.43 2819.61 2360.66 2026.20 1974.00 11843.35
TOTAL GAS SALES MMSCM 96830.47 20430.27 20531.51 20600.36 20287.78 20202.37 102047.75
PHYSICAL :
OIL AND NATURAL GAS CORPORATION LTD.
11th PLAN TARGETS vs ACHIEVEMENTS
PHYSICAL PROGRAMME  AND PLAN OUTLAY SUMMARY
Table A1
TOTAL GAS SALES MMSCM 96830.47 20430.27 20531.51 20600.36 20287.78 20202.37 102047.75
4 VALUE ADDED PRODUCTS KT 16345.59 3257.00 3313.45 3456.75 3203.16 3217.67 16448.03
5 (a) DEVELOPMENT  METREAGE K.M. 2203.04 482.23 477.14 509.10 500.09 558.69 2527.25
   (b)                              WELLS Nos. 1000 224 218 249 256 280 1227
6 (a) SEISMIC SURVEYS   2D GLK 54359.0 8157.5 77126.4 24992.9 13115.7 13605.8 136998.3
   (b)                                     3D SKM 76398.0 19358.6 26785.0 21741.9 19354.7 9820.4 97060.8
7 (a) EXPLORATORY  METREAGE K.M. 1817.83 251.58 298.95 368.66 384.02 375.44 1678.65
   (b)                              WELLS Nos. 651 98 106 128 125 135 592
8 (a) RESERVES ACCRETION   IIH MMToe 1000.7 # 182.23 284.82 250.60 236.92 242.53 1197.10
   (b)                                             UR MMToe 339.7 # 63.82 68.89 82.98 83.56 84.13 383.38
9 CBM WELLS    EXPLORATORY Nos. 46 28 5 10 7 7 57
(II)
1      SEISMIC SURVEYS Rs Crore 7581.38 2345.52 3071.83 2158.72 1656.74 1225.89 10458.70
2      EXPLORATORY  DRILLING Rs Crore 11984  $ 2432.14 4299.48 7252.70 8625.27 8463.02 31072.62
3      DEVELOPMENT DRILLING Rs Crore 15784  $$ 4054.03 4373.53 4574.39 3511.63 4287.59 20801.17
4      CAPITAL PROJECTS  & PURCHASES Rs Crore 30834.10 6445.59 7119.18 7012.27 12209.09 14139.20 46925.33
5      R&D AND INSTITUTES Rs Crore 833.67 175.33 157.44 219.95 370.66 338.79 1262.17
6      JV DOMESTIC Rs Crore 4777.51 1498.30 2049.52 1742.62 1233.85 769.07 7293.35
7      INTEGRATION Rs Crore 4189.12 700.13 749.12 598.40 668.30 23.00 2738.95
TOTAL PLAN OUTLAY Rs Crore 75983.78 17651.04 21820.11 23559.05 28275.54 29246.55 120552.29
PLAN OUTLAY & EXPENDITURE :
# including Upside Potential
$ Includes Rs 378 62 Crore for CBM Exploration for 11th Plan $$ Includes Rs 2346 51 Crore for CBM Development for 11th Plan

TableA2
Sl. No. ACTIVITY UNIT 201213 201314 201415 201516 201617 12TH  PLAN
(I)
1 CRUDE OIL PRODUCTION‐ONGC MMT 25.045 28.270 28.002 26.286 25.456 133.058
CRUDE OIL PRODUCTION‐ JV Share MMT 3.721 3.882 3.176 2.627 2.527 15.932
CRUDE OIL PRODUCTION‐TOTAL MMT 28.765 32.151 31.178 28.912 27.983 148.990
2 NATURAL GAS PRODUCTION‐ONGC MMSCM 25266.18 25471.54 26669.43 28214.56 38676.10 144297.82
NATURAL GAS PRODUCTION‐JV Share MMSCM 2113.44 1952.52 1956.36 1742.07 2143.52 9907.91
NATURAL GAS PRODUCTION‐ TOTAL MMSCM 27379.62 27424.07 28625.79 29956.63 40819.62 154205.73
3 NATURAL GAS SALES ‐ ONGC MMSCM 20089.58 20078.54 21016.15 22623.83 33247.07 117055.17
NATURAL GAS SALES ‐ JV Share MMSCM 1951.34 1803.47 1809.46 1602.49 1953.15 9119.91
NATURAL GAS SALES ‐ TOTAL MMSCM 22040.92 21882.01 22825.61 24226.32 35200.21 126175.08
4 VALUE ADDED PRODUCTS KT 3580.96 3635.76 3606.14 3498.45 3281.21 17602.51
5 (a) DEVELOPMENT  METREAGE KM 703.43 653.86 500.31 336.76 314.50 2508.86
   (b)                              WELLS Nos 325 275 212 158 150 1120
6  (a) SEISMIC SURVEYS   2D LKM 12470 13420 230 1000 1050 28170
    (b) SEISMIC SURVEYS   3D SKM 4290 9482 5091 3140 2160 24163
7  (a) EXPLORATORY  METREAGE KM 491.34 428.42 376.68 330.06 297.15 1923.65
    (b)                              WELLS Nos 156 133 117 107 98 611
8  (a) RESERVES ACCRETION   IIH MMToE 285.5 255.5 194.5 173.0 171.5 1080.0
    (b) RESERVES ACCRETION  UR MMToe 86.3 73.7 69.6 65.2 65.3 360.0
(II)      PLAN OUTLAY :
1 SEISMIC SURVEY Rs Crore 1719.64 2467.00 888.76 661.94 555.58 6292.93
2 EXPLORATORY DRILLING Rs Crore 7667.50 10917.58 9647.76 8242.34 8186.64 44661.82
3 DEVELOPMENT DRILLING Rs Crore 5830.57 8058.39 6472.31 3245.46 2898.69 26505.43
4 CAPITAL PROJECTS  & PURCHASES Rs Crore 15606.70 13316.53 15552.84 17206.91 17580.54 79263.52
5 RESEARCH & DEVELOPMENT Rs Crore 245.93 409.78 430.27 451.78 474.36 2012.11
6 JV‐ DOMESTIC Rs Crore 1322.98 867.54 444.96 603.42 578.50 3817.39
7 INTEGRATION Rs Crore 671.98 126.00 605.00 0.00 0.00 1402.98
TOTAL PLAN OUTLAY Rs Crore 33065.31 36162.81 34041.89 30411.86 30274.31 163956.18
Note: Crude oil production includes condensate receipt.
PHYSICAL :
12th PLAN (201217) TARGETS
PHYSICAL PROGRAMME AND PLAN OUTLAY   SUMMARY

11th PLAN TABLES
(Tables B1 to B13)

Sl.No BASINS
2D 3D 2D 3D 2D 3D 2D 3D 2D 3D 2D 3D 2D 3D
1 CAMBAY 2033 102.88 1241.27 30.44 1458.80 894.56 893.34 430.68 522.91 88.80 454.35 1547.36 4570.67
2 RAJASTHAN 240 180.70 258.47 172.11 42.67 653.95
3 GULF OF CAMBAY (SW) 250 261.48 570.64 42.30 874.42
WESTERN ONSHORE 250 2273 364.36 1421.97 601.08 1717.27 936.86 1065.45 430.68 565.58 88.8 454.4 2421.8 5224.6
4 UPPER ASSAM & NAGALAND 1230 2290 198.52 381.10 36.25 73.16 108.01 162.41 121.16 218.06 355.93 942.75
5 CACHAR 490 883 54.29 116.32 612.27 360.03 116.32 1026.59
6 TRIPURA 145.00 186.39 627.48 43.60 49.50 33.42 816.08 269.31
ASSAM AND ASSAM ARAKAN 1720 3173 343.52 621.78 152.57 685.43 627.48 468.04 43.60 211.91 121.2 251.5 1288.3 2238.6
7 BENGAL (ONSHORE) 154.10 1392.00 60.16 2561.85 1532.10 382.50 905.29 4336.35 2651.65
8 BENGAL (SW)
9 PURNEA 483.25 924.10 494.00 401.45 415.93 109.54 1407.35 1420.92
10 MAHANADI (ONSHORE)
11 MAHANADI (SW) 500 500.68 649.63 1150.31
12 MAHANADI (DW) 1300 1916.12 6450.85 2729.26 11096.23
13 ANDAMAN (DW) 5470 3924.17 5125.65 4908.79 10120.02 15028.81 9049.82
MBA 7270 483.25 6495.07 924.10 12720.13 1392.00 3190.87 7470.64 1948.03 10502.5 1014.8 20772.5 25368.9
14 KRISHNA GODAWARI (ONSHORE) 2519 702.62 1271.00 889.41 406.31 127.85 3397.20
15 KRISHNA GODAWARI (SW) 125.81 1129.00 143.59 2649.45 737.00 950.98 451.55 3600.43 2586.95
16 KRISHNA GODAWARI (DW) 2340 1615.10 4348.29 32806.10 131.13 879.95 3935.43 1056.85 3550.40 3133.25 36358.00 15098.50
KRISHNA GODAWARI 4859 1615.10 5176.72 32806.10 2531.13 879.95 4968.43 3706.30 4693.71 951.0 3712.7 39958.4 21082.6
17 CAUVERY (ONSHORE) 1975 1588.23 1359.16 1014.63 600.20 30.96 1109.70 242.87 1709.90 4235.85
18 CAUVERY (SW)
19 CAUVERY (DW) 1600 292.25 30999.15 1305.88 15224.20 2803.77 4958.34 3048.64 46515.60 12116.63
CAUVERY 3575 292.25 1588.23 30999.15 2665.04 15224.20 3818.40 600.20 4989.30 1109.7 3291.5 48225.5 16352.5
20 HIMALYAN FORELAND / GV 25 150 281.40 756.51 22.44 356.58 168.18 432.92 72.26 1827.41 262.88
21 VINDHYAN & GONDWANA 100 35 66.58 887.00 949.95 212.43 507.69 399.69 151.16 2810.91 363.59
GVK (FRONTIER) 125 185 66.58 1168.40 1706.46 234.87 864.27 168.18 832.6 223.4 4638.3 626.5
Q LAND
22 MUMBAI (SW) 7219 3074.65 2016.00 3177.00 5209.55 667.93 2016.00 12129.13
23 KUTCH & SAURASHTRA (SW) 2100 1440 4551.60 980.21 2595.00 2060.81 4777.10 512.62 4551.60 10925.74
24 KERALA KONKAN (SW)
25 DEEP WATER (WC) 3500 500 440.80 8459.00 694.00 4226.00 725.51 1333.05 359.54 13125.80 3112.10
WESTERN OFFSHORE 5600 9159 4992.4 4054.86 10475.00 6466.00 4226.00 7995.87 6778.07 872.2 19693.4 26167.0
(A) SUB TOTAL ONSHORE 1845 10125 996.2 4488.7 2275.51 5526.86 4620.50 4134.01 4500.60 3330.97 2534.8 2314.8 14927.6 19795.4
(B) SUB TOTAL OFFSHORE 5850 20369 7161.2 14869.9 74850.89 21258.14 20372.5 17607.93 8615.09 16023.81 11071.0 7505.6 122070.7 77265.4
(C ) TOTAL ONGC : (A) +(B) 7695 30494 8157.5 19358.6 77126.4 26785.0 24992.9 21741.94 13115.69 19354.73 13605.8 9820.4 136998.3 97060.8
(D) DEEP WATER (WC+EC) 3500.0 11210.0 2348.2 10188.6 72264.3 13707.5 20330.2 10194.0 5965.6 9841.8 10120.0 6541.4 111028.2 50473.3
(E) INDICATIVE (FUTURE ACREAGE) 46664.0 45904.0
(F) TOTAL(FIRM + INDICATIVE) 54359.0 76398.0 8157.5 19358.6 77126.4 26785.0 24992.9 21741.9 13115.7 19354.7 13605.8 9820.4 136998.3 97060.8
ACTUAL
11TH PLAN
TARGET
200910200809
ACTUAL
200708
ACTUAL
Table B1
ACTUAL
201112
ACTUAL
201011
ACTUAL
11th PLAN
PHYSICAL TARGETS SEISMIC SURVEY

Sl. No. BASINS
K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS
1 CAMBAY 289.500 139 54.967 36 63.247 36 70.441 38 73.999 42 84.948 48 347.60 200
2 RAJASTHAN 13.500 5 2.479 2 4.399 1 0.927 1 3.420 1 5.239 2 16.46 7
3 GULF OF CAMBAY (SW) 14.200 6 1.450 1 1.45 1
WESTERN ONSHORE 317.200 150 57.446 38 67.646 37 72.818 40 77.419 43 90.187 50 365.52 208
4 UPPER ASSAM & NAGALAND 229.232 66 39.983 9 47.121 11 58.843 19 50.674 15 47.737 16 244.36 70
5 CACHAR 160.100 60 3.847 2 6.842 1 8.601 4 4.196 5.979 3 29.47 10
6 TRIPURA 11.230 6 17.313 4 17.063 6 25.669 6 21.369 9 92.64 31
ASSAM & ASSAM ARAKAN 389.332 126 55.060 17 71.276 16 84.507 29 80.539 21 75.085 28 366.47 111
7 BENGAL (ONSHORE)+PURNEA 4.000 1 4.536 3.011 1 1 1 8.55 2
8 BENGAL  (SW) 14.000 4 4.089 1 2.701 1 6.79 2
9 MAHANADI   (SW) 4.500 1 3.624 2 3.62 2
10 MAHANADI  (DW) 22.500 8 7.733 2 9.488 3 13.107 3 33.075 4 63.40 12
11 ANDAMAN (DW) 11.400 4 4.79 19.068 5 23.86 5
200809 200910
ACTUAL ACTUAL
200708
ACTUAL
PHYSICAL TARGETS EXPLORATORY DRILLING
ACTUALTARGET
Table B2
201011
ACTUAL
11th PLAN
ACTUAL
11TH PLAN 201112
11 ANDAMAN (DW) 11.400 4 4.79 19.068 5 23.86 5
MBA 56.400 18 15.446 5 2.701 1 14.024 3 20.908 4 53.143 10 106.22 23
12 KRISHNA GODAWARI (ONSHORE) 224.100 67 31.936 9 22.333 9 38.182 9 43.289 11 37.992 10 173.73 48
13 KRISHNA GODAWARI (SW) 59.000 19 15.007 4 28.412 8 13.220 5 18.355 4 12.552 3 87.55 24
14 KRISHNA GODAWARI (DW) 36.300 13 3.954 1 5.633 17.837 5 28.529 6 13.591 5 69.54 17
KRISHNA GODAWARI 319.400 99 50.897 14 56.378 17 69.239 19 90.173 21 64.135 18 330.82 89
15 CAUVERY (ONSHORE) 194.900 65 19.629 7 36.451 11 34.842 14 27.984 8 27.353 8 146.259 48
16 CAUVERY  (SW) 3.321 1 1.804 6.102 3 11.227 4
17 CAUVERY (DW) 10.000 4 7.958 2 3.257 4.475 2 15.690 4
CAUVERY 204.900 69 19.629 7 47.730 14 39.903 14 38.561 13 27.353 8 173.18 56
18 HIMALYAN FORELAND / GV 14.500 3 3.196 0.311 1 1.244 1 4.035 4.174 1 12.96 3
19 VINDHYAN  & GONDWANA 13.550 3 1.701 5.366 1 3.147 1 8.859 2 19.07 4
GVK (FRONTIER) 28.050 6 3.196 2.012 1 6.610 2 7.182 1 13.033 3 32.03 7
20 MUMBAI (SW) 173.850 60 38.111 14 41.701 17 52.034 16 52.125 18 40.868 10 224.84 75
21 KUTCH & SAURASHTRA  (SW) 52.100 13 11.795 3 5.492 2 17.665 3 17.109 4 11.638 8 63.70 20
22 KERALA KONKAN   (SW) 8.000 2 4.015 1 5.652 1 9.67 2
23 DEEP WATER (WC) 17.000 4 6.205 1 6.21 1
WESTERN OFFSHORE 250.950 79 49.906 17 51.208 20 81.556 21 69.234 22 52.506 18 304.41 98
(A) SUB TOTAL ONSHORE 1143.382 409 167.267 71 199.718 74 240.045 93 239.424 85 244.650 100 1091.10 423
(B) SUB TOTAL OFFSHORE 422.850 138 84.313 27 99.233 32 128.612 35 144.592 40 130.792 35 587.54 169
(C ) TOTAL ONGC : (A) +(B) 1566.232 547 251.580 98 298.951 106 368.657 128 384.016 125 375.442 135 1678.65 592
(D) DEEP WATER (WC +EC) 97.200 33 11.687 3 13.591 2 36.787 9 50.901 11 65.734 14 178.70 39
(E) INDICATIVE 251.600 104
(F) TOTAL (INDICATIVE+FIRM) 1817.832 651 251.58 98 298.95 106 368.66 128 384.02 125 375.44 135 1678.65 592

Sl. No. AREA
K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS
1 AHMEDABAD 366.275 245 86.042 57 93.307 60 97.202 61 97.100 60 90.138 57 463.79 295
2 MEHSANA 170.040 109 56.716 39 55.832 37 70.788 57 95.049 65 122.131 89 400.52 287
3 ANKLESHWAR 220.065 85 54.676 21 76.632 27 92.375 37 92.744 38 73.175 29 389.60 152
4 CAMBAY 60.078 21 2.118 3 6.670 7 4.275 6 11.065 10 11.504 13 35.63 39
5 RAJASTHAN
6 ASSAM 409.123 141 57.624 24 43.621 14 57.997 13 74.031 26 85.029 24 318.30 101
7 TRIPURA 17.570 7 2.552 1 5.464 2 2.756 1 1.93 1 8.991 3 21.69 8
8 RAJAMUNDARY 75.005 35 29.157 12 28.958 15 32.878 14 23.356 13 30.053 10 144.40 64
9 KAVERY 62.380 28 19.690 6 11.803 7 27.598 12 24.729 10 24.559 13 108.38 48
ONSHORE 1380.54 671 308.575 163 322.287 169 385.869 201 420.004 223 445.580 238 1882.315 994
10 MUMBAI HIGH 545.000 218 120.008
47
70.162 24 58.074 21 39.067 19 47.157 20 334.47 131
11 HEERA NEELAM 35.000 14 18.887 7 11.910 5 36.799 17 30.091 11 17.406 6 115.09 46
12 BASSEIN & SATELLITE 65.000 26 33.818 6 72.785 20 28.358 10 10.932 3 48.543 16 194.44 55
13 EOA 7.500 3 0.939 1 0.94 1
TOTAL OFFSHORE 822.50 329 173.652 61 154.857 49 123.231 48 80.090 33 113.106 42 644.936 233
TOTAL ONGC 2203.04 1000 482.227 224 477.144 218 509.100 249 500.094 256 558.686 280 2527.251 1227
Table B3
PHYSICAL TARGETS DEVELOPMENT DRILLING
11th PLAN
TARGET ACTUAL
11TH PLAN
ACTUAL
200809200708 200910
ACTUAL
201011
ACTUALACTUAL
201112
ACTUAL

S No Type of Wells
Km WELLS Km WELLS Km WELLS Km WELLS Met. WELLS Km WELLS Km WELLS
1) 4 1.98 2 1.47 2 2.05 2 5.49 6
2) 14.40 12 19.74 26 1.12 1 20.87 27
3) Pilot
a) Verical 55.20 29 11.64 2 6.97 6 7.73 7 8.15 6 34.49 21
b) Horizontal 13 4.01 10.38 2 14.39 2
Total Pilot 42 4.01 11.64 2 17.35 8 7.73 7 8.15 6 48.88 23
Sub Total 69.60 46+12 (CH) 25.73 28 14.23 5 19.40 10 7.73 7 8.15 6 75.24 56
4) 118
5) 184
6) Pilot cum Dev.(Vertical) 1.16 1 1.16 1
Total 69.60
46(E)+
118(D)/184
(V)
25.73 28 14.23 5 19.40 10 7.73 7 9.31 7 76.40 57
Exploratory
Core Holes
Development (Horizontal)
Development (Vertical)
ACTUALTARGET
Table B4
OIL AND NATURAL GAS CORPORATION LIMITED
PHYSICAL TARGETS CBM DRILLING
201011 201112 11th PLAN11TH PLAN 200809
ACTUALACTUAL ACTUAL ACTUAL
200708 200910
ACTUAL

Sl. No. AREA 11TH PLAN 200708 200809 200910 201011 201112 11th PLAN
1 AHMEDABAD 8.600 1.800 1.642 1.667 1.672 1.628 8.409
2 MEHSANA 12.130 2.101 2.116 2.202 2.263 2.322 11.004
3 ANKLESHWAR 9.622 2.035 1.876 1.722 1.642 1.500 8.775
4 CAMBAY 0.705 0.119 0.154 0.194 0.180 0.180 0.827
5 ASSAM 9.470 1.290 1.223 1.191 1.152 1.205 6.060
6 Tripura Condensate
7 RAJAMUNDARY 0.795 0.251 0.284 0.303 0.305 0.305 1.448
8 KAVERI 1.113 0.299 0.265 0.239 0.233 0.246 1.282
ONSHORE 42.435 7.896 7.560 7.517 7.446 7.385 37.804
9 MUMBAI HIGH 59.018 12.108 11.621 10.842 10.593 9.976 55.139
10 HEERA NEELAM 16.828 3.401 3.356 3.409 3.409 3.424 16.998
11 BASSEIN & SATELLITE 5.151 0.505 0.819 1.020 1.078 0.937 4.360
12 NEW & MARGINAL FIELDS 6.242
13 EOA 0.706 0.028 0.005 0.038 0.072
OFFSHORE 87.944 16.042 15.801 15.271 15.080 14.375 76.568
(A) TOTAL ONGCCRUDE OIL 130.379 23.937 23.361 22.788 22.526 21.760 114.372
(B) NATURAL GAS LIQUID (Cond.) 9.684 2.007 2.006 1.883 1.892 1.952 9.741
(C) ONGC OIL + CONDENSATE 140.063 25.944 25.367 24.671 24.419 23.712 124.113
1 PANNA ‐ MUKTA & TAPTI 4.500 0.764 0.646 0.777 0.545 0.567 3.299
2 RAVVA 2.860 0.945 0.780 0.640 0.545 0.536 3.446
3 PY‐3 0.511 0.065 0.046 0.026 0.061 0.020 0.218
4 GAURI & LAXMI (CB‐OS‐2) 0.006 0.11431 0.174 0.207 0.158 0.120 0.773
5 PRAMODA & S. PRAMODA (CB‐ON‐07)* 0.027 0.00557 0.004 0.0036 0.0033 0.003 0.019
6 UNNAWA (CB‐ON‐03 + CB‐ON‐2)* 0.0009 0.0003 0.0042 0.0025 0.0018 0.010
7 RJ‐ON‐90/1 5.674 0.134 1.545 1.966 3.644
(D) JV(ONGC SHARE) 13.578 1.895 1.650 1.792 2.860 3.213 11.410
(E) TOTAL OIL (A+D) 143.956 25.832 25.011 24.580 25.386 24.973 125.782
(F) TOTAL OIL+COND (C+D) 153.640 27.839 27.017 26.463 27.278 26.925 135.522
PHYSICAL TARGETS CRUDE OIL PRODUCTION
Table B5

Sl. No. AREA 11TH PLAN 200708 200809 200910 201011 201112 11th Plan
1 AHMEDABAD 1217.23 340.40 286.58 275.24 261.57 262.59 1426.38
2 MEHSANA 508.10 162.80 166.00 181.08 185.46 181.25 876.58
3 ANKLESHWAR 6638.55 1583.80 1490.38 1467.57 1461.99 1487.82 7491.55
4 CAMBAY 33.70 4.70 6.99 9.13 8.48 7.36 36.66
5 RAJASTHAN 75.00 16.00 12.53 13.86 10.64 15.78 68.80
6 ASSAM 2504.61 499.40 471.28 467.20 462.25 504.13 2404.26
7 TRIPURA 6024.00 533.50 552.66 562.20 609.98 643.90 2902.25
8 RAJAMUNDARY 6401.52 1548.20 1521.26 1478.93 1384.39 1363.79 7296.57
9 KAVERI 5201.00 1169.40 1242.47 1177.75 1119.18 1284.76 5993.57
10 CBM 1240.95
11 UCG 2996.00
ONSHORE 32840 67 5858 20 5750 15 5632 96 5503 94 5751 37 28496 62
Table B6
MMSCM
PHYSICAL TARGETS NATURAL GAS PRODUCTION
ONSHORE 32840.67 5858.20 5750.15 5632.96 5503.94 5751.37 28496.62
12 MUMBAI HIGH 21368.35 5328.90 5074.71 5028.93 4640.52 4546.27 24619.33
13 HEERA NEELAM 4639.93 999.60 1338.20 1173.39 1151.02 1244.29 5906.50
14 BASSEIN & SATELLITE 39408.87 10128.50 10320.45 11273.48 11799.09 11749.35 55270.87
15 NEW & MARGINAL FIELDS 11502.00
16 EOA 2630.56 18.70 2.91 25.07 46.68
OFFSHORE 79549.71 16475.70 16736.27 17475.81 17590.63 17564.97 85843.38
(A) TOTAL ONGC 112390.37 22333.90 22486.42 23108.76 23094.57 23316.34 114340.00
1 PANNA ‐ MUKTA 4036.00 854.64 705.98 830.12 624.867 853.27 3868.88
2 TAPTI 8556.00 1361.23 1720.45 1273.73 1111.415 866.65 6333.47
3 RAVVA 836.09 341.20 303.02 218.70 246.737 253.38 1363.04
4 PY‐3 133.43 17.32 11.65 6.94 16.267 5.40 57.57
5 LAKSHMI 150.07 109.20 109.20
6 GAURI 570.35 70.73 208.02 149.82 146.080 105.96 680.60
7 CBX 25.06 31.67 31.67
8
PRAMODA / S.PRAMODA (CB‐
ON‐7)
0.49 0.32 0.28 0.257 0.18 1.53
9 CB‐ON‐02 0.30 1.000 0.71 2.01
10 RJ‐ON‐6 6.535 18.88 25.42
11 CBM 1.339 3.20 4.54
12 RJ‐ON‐90/1 5.92 73.079 86.35 165.35
(B) JV(ONGC SHARE) 14785.27 2786.77 2949.43 2485.50 2227.58 2194.00 12643.29
TOTAL (A+B) 127175.64 25120.67 25435.85 25594.27 25322.15 25510.35 126983.28

Sl. No. AREA/ TERMINAL 11TH PLAN 200708 200809 200910 201011 201112 11th PLAN
1 EX URAN 18400.00 3645.40 3683.77 3545.35 3477.81 3386.87 17739.20
2 EX HAZIRA 38415.00 9050.10 9086.31 9906.88 10135.75 9993.23 48172.27
3 Suvali + New Terminal
4 EOA 2593.06 15.90 22.16 38.06
OFFSHORE 59408.06 12711.40 12770.08 13452.23 13613.56 13402.25 65949.52
5 ASSAM 1319.60 258.90 262.47 255.07 260.31 269.30 1306.05
6 TRIPURA 2249.00 532.80 551.57 560.77 608.22 642.22 2895.58
ASSAM & TRIPURA 3568.60 791.70 814.04 815.84 868.53 911.52 4201.63
7 AHMEDABAD 502.00 234.00 180.83 168.69 155.66 157.29 896.47
8 MEHSANA 11.18 69.90 71.68 78.59 79.60 82.86 382.63
9 ANKLESHWAR 4472.63 1254.60 1119.28 1076.13 1051.71 1036.38 5538.09
PHYSICAL TARGETS NATURAL GAS SALES
Table B7
10 CAMBAY 23.16 2.04 5.31 5.80 5.39 4.57 23.11
11 RAJASTHAN 75.00 16.00 12.53 13.86 10.64 15.78 68.80
WESTERN ONSHORE 5083.97 1576.54 1389.63 1343.07 1302.99 1296.87 6909.10
12 RAJAMUNDARY 6311.89 1532.50 1507.85 1467.59 1372.36 1343.00 7223.30
13 KAVERY 5150.00 1150.70 1230.30 1160.98 1104.14 1274.72 5920.84
RAJAHMUNDRY & KAVERY 11461.89 2683.20 2738.15 2628.57 2476.50 2617.72 13144.14
14 CBM 992.76
15 UCG 2396.80
TOTAL ONSHORE 23504.02 5051.44 4941.82 4787.47 4648.02 4826.12 24254.87
(A) TOTAL ONGC 82912.07 17762.84 17711.90 18239.70 18261.58 18228.37 90204.39
1 PANNA ‐ MUKTA 3706.20 810.40 667.06 785.94 590.62 1642.65 4496.68
2 TAPTI 8430.40 1345.60 1681.91 1240.78 1077.71 5346.01
3 RAVVA 750.14 309.20 275.12 196.74 223.03 229.23 1233.33
4 PY‐3 0.00 0.00
5 LAKSHMI 21.23
6 GAURI 533.55 201.90 195.28 137.07 133.35 94.45 762.04
7 CBX 24.07
8 AMBE 452.81 0.00 0.00
9 PRAMODA / S.PRAMODA (CB‐ON‐7) 0.33 0.24 0.12 0.14 0.10 0.93
10 CB‐ON‐02 0.41 0.41
11 RJ‐ON‐6 3.95 3.95
(B) JV(ONGC SHARE) 13918.40 2667.43 2819.61 2360.66 2026.20 1974.00 11843.35
TOTAL (A+B) 96830.47 20430.27 20531.51 20600.36 20287.78 20202.37 102047.75

Sl. No. AREA/ TERMINAL 11th Plan 200708 200809 200910 201011 201112 11th Plan
URAN
1 LPG 2175.00 452.00 428.79 458.02 415.68 376.13 2130.62
2 C2‐C3 2550.00 520.00 496.66 532.85 385.52 459.56 2394.59
3 LAN 1330.00 266.00 238.79 258.66 259.06 238.65 1261.16
SUB TOTAL 6055.00 1238.00 1164.25 1249.53 1060.26 1074.34 5786.38
HAZIRA
1 LPG 2736.00 539.00 560.63 609.24 604.45 633.06 2946.38
2 ARN 5387.00 1167.00 1260.95 1293.58 1257.35 1277.83 6256.71
3 SKO 680 00 176 00 167 64 157 77 107 25 71 67 680 33
PHYSICAL TARGETS VALUE ADDED PRODUCTS
Table B8
KT
3 SKO 680.00 176.00 167.64 157.77 107.25 71.67 680.33
4 ATF 7.86 19.28 14.16 41.30
5 PROPANE 2.11 2.49 3.49 8.10
6 SULPHUR 2.60 2.60
7 HSD 73.00 15.00 16.05 17.30 17.36 16.05 81.76
SUB TOTAL 8876.00 1897.00 2005.28 2087.86 2008.18 2018.86 10017.18
ANKLESHWAR
1 LPG 283.00 44.00 36.90 37.69 34.18 27.92 180.69
2 NAPTHA 213.00 16.00 24.69 25.51 32.75 28.19 127.14
SUB TOTAL 496.00 60.00 61.59 63.20 66.93 56.11 307.83
TATIPAKA
1 NAPTHA 250.21 20.00 28.58 12.67 21.03 12.38 94.66
2 SKO 85.63 8.00 10.12 6.96 8.71 8.25 42.05
3 HSD 166.00 17.00 20.14 18.43 21.86 16.83 94.25
4 FUEL OIL/ RCO/LSHS 162.16 17.00 23.50 16.39 16.18 30.89 103.96
SUB TOTAL 664.00 62.00 82.34 54.44 67.79 68.35 334.92
KAVERI
1 NAPTHA 162.79 1.33 1.33
2 SKO 70.63 0.25 0.25
3 HEAVY CUT 21.17 0.16 0.16
SUB TOTAL 254.59 1.73 1.73
TOTAL ONGC 16345.59 3257.00 3313.45 3456.75 3203.16 3217.67 16448.03

MMToE
Sl. No. BASINS 11th Plan 200708 200809 200910 201011 201112 11th Plan
1 WESTERN ONSHORE 70.50 24.43 21.58 37.73 33.95 27.96 145.65
2 ASSAM & AAFB 104 50 12 21 23 35 19 62 17 35 22 83 95 36
ACCRETION TO INITIAL INPLACE HYDROCARBONS RESERVES (IIH)
Table B9
2 ASSAM & AAFB 104.50 12.21 23.35 19.62 17.35 22.83 95.36
3 KG 80.00 13.83 55.59 59.96 37.70 15.64 182.72
4 CAUVERY 23.60 2.00 2.50 20.21 16.31 41.49 82.51
5 FRONTIER 0.00 0.00 0.00 0.00 0.00 0.00 0.00
6 WESTERN OFFSHORE &
GULF OF CAMBAY
177.25 71.54 140.77 66.29 50.16 130.60 459.36
7 MBA 8.00 0.00 0.00 0.00 0.00 0.00 0.00
8 DEEP WATER (EC +WC) 109.00 58.22 41.03 46.77 81.46 4.01 231.49
TOTAL ONGC 572.85 182.23 284.82 250.60 236.92 242.53 1197.10
9 INDICATIVE 427.80
TOTAL ONGC(FIRM+INDI 1000.65 182.23 284.82 250.60 236.92 242.53 1197.10

Sl. No. BASINS 11TH PLAN 200708 200809 200910 201011 201112 11th Plan
1 WESTERN ONSHORE 19.34 9.90 6.05 7.35 10.70 6.19 40.19
2 ASSAM & AAFB 29.93 4.35 4.57 3.92 3.08 5.25 21.17
3 KG 26.48 2.63 1.15 6.13 6.63 7.86 24.40
Table B10
ACCRETION TO RECOVERABLE HYDROCARBONS RESERVES (UR)
MMTOE
3 KG 26.48 2.63 1.15 6.13 6.63 7.86 24.40
4 CAUVERY 7.13 0.40 0.64 8.58 4.74 4.29 18.65
5 FRONTIER 0.00
6 WESTERN OFFSHORE & GULF OF
CAMBAY
61.05 39.09 56.48 54.87 37.52 60.05 248.01
7 MBA 2.90 0.00
8 DEEP WATER (EC+WC) 42.40 7.46 2.12 20.88 0.49 30.95
TOTAL ONGC 189.22 63.82 68.89 82.98 83.56 84.13 383.38
9 INDICATIVE 150.50
TOTAL ONGC(FIRM+INDICATIVE) 339.72 63.82 68.89 82.98 83.56 84.13 383.38

Start of 11th Plan 200708 200809 200910 201011 201112
Actual Actual Actual Actual Actual
As on 142007 As on 1408 As on 1409 As on 1410 As on 1411 As on 1412
1 Crude Oil MMT 560.62 566.36 569.51 563.42 552.61 563.01
(Incl Condensate)
2 Natural Gas BCM 540.44 550.27 569.27 611.5 659.38 687.22
3 O+OEG * MMToE 1101.06 1116.63 1138.78 1174.92 1211.99 1250.23
Table B11
11th PLAN
RESERVES OF CRUDE OIL & NATURAL GAS
*Total Assumes 1 BCM = 1 MMToE
S No. ONGC UNIT

Sl.                   Area 11th Plan 200708 200809 200910 201011 201112 11th Plan
No. Target Actual Actual Actual Actual ACTUAL ACTUAL
1 SEISMIC SURVEY
a Western Onshore 729.93 230.21 224.24 162.35 171.93 149.71 938.43
b MBA + CBM 1234.49 585.12 903.44 391.96 311.65 303.56 2495.73
c Assam & Assam Arakan 1087.53 184.72 184.57 174.27 119.36 108.19 771.11
d Frontier basin 231.82 31.85 96.82 66.56 56.30 66.97 318.50
e KGPG 2077.65 636.09 442.52 275.98 451.15 216.54 2022.28
f Cauvery 522.71 49.63 339.88 330.97 178.77 899.25
g Western Offshore 1697.24 627.91 880.36 756.62 546.35 202.15 3013.40
h HQ & Others
Total Survey 7581.38 2345.52 3071.83 2158.72 1656.74 1225.89 10458.70
2 EXPLORATORY  DRILLING
a Western Onshore 914.24 256.68 276.60 403.00 404.52 396.15 1736.96
b MBA 1579 14 314 71 146 73 243 48 611 19 2856 88 4172 99
11th PLAN
ASSET / BASIN WISE PLAN OUTLAY &  EXPENDITURE
Table: B12
b MBA 1579.14 314.71 146.73 243.48 611.19 2856.88 4172.99
c Assam & Assam Arakan 1484.54 429.40 573.60 823.04 890.79 817.66 3534.50
d Frontier basin 99.00 17.37 70.56 115.18 117.12 208.51 528.74
e KGPG 2919.52 610.35 1715.02 2348.72 2182.03 2144.06 9000.17
f Cauvery 820.61 76.98 468.10 209.90 1909.27 193.66 2857.91
g Western Offshore 3788.33 647.64 1048.88 2995.84 2415.02 1720.51 8827.89
h CBM 378.62 79.01 113.53 95.33 125.59 413.46
Total Exploratory Drilling 11984.00 2432.14 4299.48 7252.70 8625.27 8463.02 31072.62
3 DEVELOPMENT  DRILLING
a Ahmedabad 601.65 181.66 206.70 242.04 263.34 260.31 1154.04
b Ankleswar 555.46 204.24 252.73 396.55 407.45 375.36 1636.33
c Mehsana 217.38 143.08 142.95 190.60 264.12 349.15 1089.90
d Western onshore basin 137.20 6.49 25.19 17.46 36.53 35.72 121.40
e Assam asset 1237.52 356.94 304.25 429.12 624.55 702.08 2416.95
f Assam & Assam Arakan 33.29 31.06 11.88 41.80 84.74
g Rajamundry 247.20 95.39 79.72 107.84 138.82 171.61 593.38
h Karaikal 135.38 71.97 39.46 76.10 93.98 101.57 383.08
i Tripura 66.20 16.15 47.33 22.55 15.49 73.58 175.10
j Mumbai High 6932.00 1859.34 1423.79 1190.64 748.53 976.85 6199.14
k Heera & Neelam 457.84 429.37 406.04 907.44 320.10 168.24 2231.19
l Bassein & Satellite fields 2816.36 658.34 1433.49 994.05 556.92 1072.03 4714.84
m EOA 1.09 1.09
n MBP / CBM 2346.51
Total Development Drilling 15784.00 4054.03 4373.53 4574.39 3511.63 4287.59 20801.17

Sl.                   Area 11th Plan 200708 200809 200910 201011 201112 11th Plan
No. Target Actual Actual Actual Actual ACTUAL ACTUAL
4 CAPITAL PROJECTS & PURCHASES
a Assets
i Mumbai High 7278.76 349.99 3255.03 3586.97 6711.74 6358.21 20261.95
ii Heera & Neelam 3636.94 928.67 614.00 724.57 526.81 387.23 3181.28
iii Bassein & Satellite fields 8531.21 3158.98 648.93 343.29 3088.20 3736.08 10975.49
iv Uran Plant 1615.97 177.08 170.03 36.51 67.55 333.98 785.15
v Hazira Plant 265.92 36.71 69.59 22.64 76.52 179.35 384.81
vi          Eastern Offshore Asset 431.10 431.10
vii Ahmedabad 1118.67 136.42 252.74 166.23 160.05 177.26 892.71
viii Ankleswar 1180.58 100.23 218.92 194.09 161.52 280.74 955.50
ix Mehsana 713.32 109.97 198.45 119.72 148.00 211.28 787.41
x Rajamundry 666.24 70.67 178.65 381.59 330.92 135.97 1097.80
xi Karaikal 717.59 54.76 74.89 133.40 92.45 118.87 474.37
xii Tripura 770.30 50.82 59.30 47.50 124.56 172.86 455.04
Table: B13
11th PLAN
ASSET / BASIN WISE PLAN OUTLAY &  EXPENDITURE
xiii Assam 1420.95 236.64 471.01 441.23 225.86 668.67 2043.40
Sub total Assets 27916.44 5410.93 6211.55 6197.75 11714.17 13191.61 42726.01
b Basins
i Western Offshore 333.87 9.56 9.61 ‐42.44 4.45 76.34 57.52
ii Western Onshore 283.71 112.14 273.47 129.62 117.11 38.64 670.97
iii Cauvery 168.75 77.37 8.16 85.53
iv KGPG 89.52 1.00 11.54 3.12 15.66
v Assam & Assam Arakan 404.08 80.80 84.58 67.61 64.68 45.43 343.11
vi MBA 466.12 39.78 16.55 11.61 6.65 96.10 170.70
vii Frontier basin 57.88 28.48 4.59 11.46 2.57 11.30 58.40
viii CBM 2.90 0.50 1.00 1.52 5.92
ix Cambay 15.70 19.84 35.54
x Jodhpur 14.47 3.90 18.36
xi CRW Baroda 1.26 2.61 3.87
Sub total Basins 1803.92 351.03 398.46 177.86 239.43 298.81 1465.59
c HQ / RO & Others 1113.75 683.63 509.18 636.65 255.49 648.78 2733.73
Total Capital / Purchases 30834.10 6445.59 7119.18 7012.27 12209.09 14139.20 46925.33
5 R & D / INSTITUTES 833.67 175.33 157.44 219.95 370.66 338.79 1262.17
6 INTEGRATION 4189.12 700.13 749.12 598.40 668.30 23.00 2738.95
7 JV PROJECTS DOMESTIC 4777.51 1498.30 2049.52 1742.62 1233.85 769.07 7293.35
TOTAL  OUTLAY 75983.78 17651.04 21820.11 23559.05 28275.54 29246.55 120552.29

12th PLAN TABLES
(Tables C1 to L8)

12th PLAN TARGETS
Activitywise – Physical Targets
(Tables C 1 to C 10)

Table C1
Sl. No. AREA 201213 201314 201415 201516 201617 12th PLAN
1 AHMEDABAD 1.659 1.679 1.697 1.715 1.700 8.450
2 MEHSANA 2.303 2.305 2.325 2.357 2.340 11.630
3 ANKLESHWAR 1.307 1.289 1.174 1.035 0.958 5.763
4 CAMBAY 0.178 0.172 0.164 0.159 0.146 0.819
5 ASSAM 1.221 1.311 1.430 1.525 1.591 7.077
6 RAJAHMUNDARY 0.290 0.261 0.195 0.132 0.093 0.971
7 CAUVERY 0.213 0.205 0.192 0.178 0.162 0.950
8 TRIPURA CONDENSATE 0.005 0.006 0.006 0.006 0.006 0.028
ONSHORE 7.175 7.227 7.182 7.107 6.996 35.687
9 MUMBAI HIGH 10.420 10.330 9.802 9.321 8.849 48.722
10 HEERA NEELAM 3.177 2.955 2.914 2.625 2.366 14.037
11 BASSEIN & SATELLITE 1.122 2.074 1.805 1.547 1.290 7.838
12 CONDENSATE 2.461 2.588 2.611 2.845 2.671 13.177
13 NEW & MARGINAL FIELDS 0.360 2.949 3.371 2.564 2.511 11.755
14 EOA 0.3300 0.146 0.316 0.276 0.774 1.842
OFFSHORE 17.870 21.042 20.819 19.179 18.460 97.371
(A) TOTAL ONGC 25.045 28.270 28.002 26.286 25.456 133.058
1 PANNA ‐ MUKTA & TAPTI 0.586 0.574 0.598 0.515 0.558 2.831
2 RAVVA 0.600 0.480 0.480 0.400 0.600 2.560
3 PY‐3 0.129 0.136 0.106 0.079 0.064 0.514
4 GAURI & LAXMI (CB‐OS‐2) 0.150 0.125 0.075 0.050 0.035 0.435
5 PRAMODA & S. PRAMODA (CB‐ON‐07) 0.003 0.003 0.002 0.002 0.002 0.012
6 UNNAWA (CB‐ON‐03 + CB‐ON‐2) 0.0049 0.0501 0.0973 0.0592 0.0626 0.274
7 RJ‐ON‐90/1 2.247 2.514 1.818 1.521 1.206 9.306
(B) JV(ONGC SHARE) 3.721 3.882 3.176 2.627 2.527 15.932
TOTAL (A+B) 28.765 32.151 31.178 28.912 27.983 148.990
Assam Production includes Tripura Condensate
TWELFTH PLAN ( 2012 2017 )
PHYSICAL TARGETS CRUDE OIL PRODUCTION
MMT

Sl. No. AREA 201213 201314 201415 201516 201617 12th PLAN
1 AHMEDABAD 231.80 211.65 199.94 189.43 174.86 1007.68
2 MEHSANA 144.50 139.30 131.60 124.10 115.20 654.70
3 ANKLESHWAR 946.67 867.76 866.44 791.38 704.49 4176.74
4 CAMBAY 7.36 7.24 7.09 6.85 6.38 34.93
5 RAJASTHAN 15.00 15.00 48.50 48.50 48.50 175.50
6 ASSAM 476.29 532.49 594.18 663.33 665.54 2931.83
7 TRIPURA 1439.10 1861.50 1861.50 1866.60 1862.50 8891.20
8 RAJAHMUNDARY 1065.00 855.00 695.00 555.00 441.00 3611.00
9 CAUVERY 1443.00 1423.08 1387.98 1317.03 1226.13 6797.22
ONSHORE 5768.72 5913.02 5792.23 5562.22 5244.60 28280.79
MMSCM
PHYSICAL TARGETS NATURAL GAS PRODUCTION
Table C2
10 MUMBAI HIGH 4233.22 3498.29 3097.83 2666.68 2342.21 15838.23
11 HEERA NEELAM 1126.45 1027.45 1016.24 966.85 868.29 5005.28
12 BASSEIN & SATELLITE 10536.95 10586.65 10867.95 11058.44 11442.40 54492.39
13 NEW & MARGINAL FIELDS 2974.64 3824.43 4170.67 6266.37 5791.61 23027.74
14 EOA 626.20 621.70 1724.50 1694.00 12987.00 17653.40
OFFSHORE 19497.47 19558.53 20877.20 22652.34 33431.50 116017.03
(A) TOTAL ONGC 25266.18 25471.54 26669.43 28214.56 38676.10 144297.82
1 PANNA ‐ MUKTA 796.80 786.40 796.80 791.76 801.60 3973.36
2 TAPTI 890.40 826.80 826.00 701.52 518.40 3763.12
3 RAVVA 180.00 100.00 120.00 40.11 620.00 1060.11
4 PY‐3 32.44 34.16 26.20 19.73 15.76 128.29
5 CB‐OS2 82.50 57.50 37.50 45.12 47.50 270.12
6 PRAMODA / S.PRAMODA (CB‐ON‐7) 0.15 0.11 0.08 0.06 0.05 0.46
7 CB‐ON‐02 3.57 1.07 1.20 1.38 1.53 8.74
8 RJ‐ON‐6 102.68 102.68 102.68 102.68 102.68 513.40
9 RJ‐ON‐90/1 24.90 43.80 45.90 39.71 36.00 190.31
(B) JV(ONGC SHARE) 2113.44 1952.52 1956.36 1742.07 2143.52 9907.91
TOTAL (A+B) 27379.62 27424.07 28625.79 29956.63 40819.62 154205.73

Sl. No. AREA/ TERMINAL 201213 201314 201415 201516 201617 12th Plan
1 EX URAN 4100.00 3900.00 3900.00 3509.59 3200.00 18609.59
2 EX HAZIRA 9936.75 10241.21 10545.22 10475.15 10351.57 51549.89
3 Suvali + New Terminal 669.72 581.72 578.01 2912.53 2844.68 7586.65
4 EOA 604.20 599.70 1552.50 1525.00 12827.00 17108.40
OFFSHORE 15310.67 15322.63 16575.73 18422.26 29223.25 94854.53
5 ASSAM 267.25 272.93 269.29 267.20 260.65 1337.31
6 TRIPURA 1428.88 1827.56 1827.56 1832.66 1827.46 8744.11
ASSAM & TRIPURA 1696.13 2100.49 2096.84 2099.85 2088.11 10081.42
7 AHMEDABAD 125.00 100.00 84.00 71.00 59.00 439.00
8 MEHSANA 40.10 27.37 0.00 67.47
9 ANKLESHWAR 430.54 289.24 209.57 195.77 241.27 1366.39
MMSCM
Table C3
PHYSICAL TARGETS NATURAL GAS SALES
10 CAMBAY 4.14 3.81 4.02 3.95 3.44 19.36
11 RAJASTHAN 15.00 15.00 15.00 15.00 15.00 75.00
WESTERN ONSHORE 614.78 435.42 312.58 285.72 318.72 1967.22
12 RAJAHMUNDARY 1039.00 831.00 676.00 541.00 430.00 3517.00
13 CAUVERY 1429.00 1389.00 1355.00 1275.00 1187.00 6635.00
RAJAHMUNDRY & KAVERY 2468.00 2220.00 2031.00 1816.00 1617.00 10152.00
TOTAL ONSHORE 4778.91 4755.91 4440.43 4201.57 4023.82 22200.64
(A) TOTAL ONGC 20089.58 20078.54 21016.15 22623.83 33247.07 117055.17
1 PANNA ‐ MUKTA 752.80 741.79 750.52 746.27 756.89 3748.27
2 TAPTI 853.54 790.20 789.33 664.82 482.02 3579.91
3 RAVVA 168.00 98.42 117.22 37.31 561.36 982.31
4 PY‐3 24.16 23.40 17.33 13.38 78.28
5 CB OS‐2 70.00 45.01 25.00 32.60 35.06 207.67
6 PRAMODA / S.PRAMODA (CB‐ON‐7) 0.11 0.08 0.06 0.05 0.31
7 CB‐ON‐02 4.00 1.07 1.20 1.38 1.53 9.18
8 RJ‐ON‐6 103.00 102.71 102.70 102.71 102.85 513.97
(B) JV(ONGC SHARE) 1951.34 1803.47 1809.46 1602.49 1953.15 9119.91
TOTAL (A+B) 22040.92 21882.01 22825.61 24226.32 35200.21 126175.08

Table C4
Sl. No. AREA/ TERMINAL 201213 201314 201415 201516 201617 12th PLAN
URAN
1 LPG 435.00 435.00 440.00 435.00 430.00 2175.00
2 C2‐C3 510.00 510.00 510.00 510.00 510.00 2550.00
3 LAN 266.00 266.00 269.00 270.00 250.00 1321.00
SUB TOTAL 1211.00 1211.00 1219.00 1215.00 1190.00 6046.00
HAZIRA
1 LPG + PROPANE 638.00 651.00 643.00 619.00 572.40 3123.40
2 ARN 1427 00 1462 00 1442 00 1377 00 1253 60 6961 60
PHYSICAL TARGETS VALUE ADDED PRODUCTS
KT
2 ARN 1427.00 1462.00 1442.00 1377.00 1253.60 6961.60
3 SKO 170.00 174.00 172.00 164.00 149.60 829.60
4 HSD+ ATF 18.00 18.00 18.00 17.00 15.40 86.40
SUB TOTAL 2253.00 2305.00 2275.00 2177.00 1991.00 11001.00
ANKLESHWAR
1 LPG 23.02 21.14 19.39 17.64 15.54 96.73
2 NGL / NAPTHA 13.54 12.43 11.41 10.38 9.14 56.90
SUB TOTAL 36.56 33.57 30.80 28.02 24.69 153.63
TATIPAKA
1 NAPTHA 19.80 19.80 19.80 19.80 19.80 99.00
2 SKO 4.20 4.20 4.20 4.20 4.20 21.00
3 HSD 22.40 22.20 22.20 22.20 22.20 111.20
4 FUEL OIL/ RCO/LSHS 14.00 13.80 13.80 13.80 13.80 69.20
SUB TOTAL 60.40 60.00 60.00 60.00 60.00 300.40
CAUVERY
1 NAPTHA 15.60 20.52 16.72 14.44 12.16 79.44
2 SKO 2.60 3.51 2.86 2.47 2.08 13.52
3 HEAVY CUT / LSHS 1.80 2.16 1.76 1.52 1.28 8.52
SUB TOTAL 20.00 26.19 21.34 18.43 15.52 101.48
TOTAL ONGC 3580.96 3635.76 3606.14 3498.45 3281.21 17602.51

Sl. No. AREA
K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS K.M. WELLS
1 AHMEDABAD 88.16 53 80.95 52 75.95 49 75.95 49 75.95 49 396.96 252
2 MEHSANA 118.69 85 91.50 61 52.50 35 48.00 32 48.00 32 358.69 245
3 ANKLESHWAR 76.09 33 83.70 38 45.05 17 30.03 12 19.40 6 254.26 106
4 CAMBAY 9.22 10 12.70 9 13.20 9 8.00 6 8.00 6 51.12 40
5 ASSAM 85.50 26 95.90 28 95.00 28 90.20 26 89.50 26 456.10 134
6 TRIPURA 22.90 8 28.35 9 21.30 7 12.03 4 9.15 7 93.73 35
7 RAJAHMUNDARY 30.00 10 12.80 4 17.80 6 12.30 6 15.50 7 88.40 33
8 CAUVERY 21.55 10 29.40 12 27.55 11 27.55 11 27.05 11 133.10 55
ONSHORE 452.102 235 435.30 213 348.35 162 304.06 146 292.55 144 1832.35 900
9 MUMBAI HIGH 148.30 54 139.30 49 15.00 6 302.60 109
10 HEERA NEELAM 16.80 5 17.60 8 13.20 6 47.60 19
11 BASSEIN & SATELLITE 86.23 31 56.66 3 98.77 28 7.70 2 21.95 6 271.30 70
12 EOA 5.00 2 25.00 10 25.00 10 55.00 22
TOTAL OFFSHORE 251.332 90 218.56 62 151.97 50 32.70 12 21.95 6 676.50 220
TOTAL ONGC 703.434 325 653.86 275 500.31 212 336.76 158 314.50 150 2508.86 1120
Table C5
PHYSICAL TARGETS DEVELOPMENT DRILLING
201213 201314 201415 201516 201617 12th PLAN

Sl.No BASINS
2D 3D 2D 3D 2D 3D 2D 3D 2D 3D 2D 3D
1 CAMBAY 110.0 424.0 0.0 360.0 0.0 360.0 0.0 360.0 0.0 360.0 110.0 1864.0
2 RAJASTHAN 30.0 0.0 50.0 0.0 50.0 0.0 20.0 0.0 0.0 0.0 150.0
3 GULF OF CAMBAY (SW) 0.0 0.0
WESTERN ONSHORE 110.0 454.0 0.0 410.0 0.0 410.0 0.0 380.0 0.0 360.0 110.0 2014.0
4 UPPER ASSAM & NAGALAND 120.0 129.0 600.0 95.0 130.0 281.0 0.0 60.0 50.0 0.0 900.0 565.0
5 CACHAR 40.0 125.0 240.0 250.0 0.0 200.0 0.0 0.0 0.0 0.0 280.0 575.0
6 TRIPURA 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0
ASSAM AND ASSAM ARAKAN 160.0 254.0 840.0 345.0 130.0 481.0 0.0 60.0 50.0 0.0 1180.0 1140.0
7 BENGAL (ONSHORE) 212.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 212.0
8 BENGAL (SW) 0.0 0.0
9 PURNEA 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0
10 MAHANADI (ONSHORE) 0.0 0.0
11 MAHANADI (SW) 0.0 0.0
12 MAHANADI (DW) 4000.0 0.0 0.0 2000.0 0.0 0.0 0.0 0.0 4000.0 2000.0
13 ANDAMAN (DW) 3310.0 2000.0 500.0 0.0 0.0 0.0 0.0 0.0 0.0 5310.0 500.0
MBA 3310.0 212.0 6000.0 500.0 0.0 2000.0 0.0 0.0 0.0 0.0 9310.0 2712.0
14 KRISHNA GODAWARI (ONSHORE) 0.0 200.0 0.0 200.0 0.0 200.0 0.0 200.0 0.0 800.0
15 KRISHNA GODAWARI (SW) 0.0 4991.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 4991.0
16 KRISHNA GODAWARI (DW) 0.0 300.0 0.0 500.0 0.0 0.0 0.0 0.0 0.0 800.0
KRISHNA GODAWARI 0.0 0.0 0.0 5491.0 0.0 700.0 0.0 200.0 0.0 200.0 0.0 6591.0
17 CAUVERY (ONSHORE) 255.0 0.0 450.0 0.0 100.0 0.0 300.0 0.0 100.0 0.0 1205.0
18 CAUVERY (SW) 0.0 400.0 0.0 400.0 0.0 0.0 0.0 0.0 0.0 800.0
19 CAUVERY (DW) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0
CAUVERY 0.0 255.0 0.0 850.0 0.0 500.0 0.0 300.0 0.0 100.0 0.0 2005.0
20 HIMALYAN FORELAND / GV 400.0 0.0 100.0 0.0 0.0 0.0 0.0 0.0 500.0 0.0
21 VINDHYAN & GONDWANA 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0
GVK (FRONTIER) 0.0 0.0 400.0 0.0 100.0 0.0 0.0 0.0 0.0 0.0 500.0 0.0
Q LAND 0.0 0.0
22 MUMBAI (SW) 75.0 0.0 1800.0 0.0 0.0 0.0 1200.0 0.0 1000.0 0.0 4075.0
23 KUTCH & SAURASHTRA (SW) 2200.0 3040.0 0.0 86.0 0.0 1000.0 1000.0 1000.0 1000.0 500.0 4200.0 5626.0
24 KERALA KONKAN (SW) 3000.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 3000.0 0.0
25 DEEP WATER (WC) 6690.0 3180.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 9870.0 0.0
WESTERN OFFSHORE 8890.0 3115.0 6180.0 1886.0 0.0 1000.0 1000.0 2200.0 1000.0 1500.0 17070.0 9701.0
(A) SUB TOTAL ONSHORE 270.0 1175.0 1240.0 1405.0 230.0 1191.0 0.0 940.0 50.0 660.0 1790.0 5371.0
(B) SUB TOTAL OFFSHORE 12200.0 3115.0 12180.0 8077.0 0.0 3900.0 1000.0 2200.0 1000.0 1500.0 26380.0 18792.0
(C ) TOTAL ONGC : (A) +(B) 12470.0 4290.0 13420.0 9482.0 230.0 5091.0 1000.0 3140.0 1050.0 2160.0 28170.0 24163.0
0.0
(D) DEEP WATER (WC+EC) 10000.0 0.0 9180.0 800.0 0.0 2500.0 0.0 0.0 0.0 0.0 19180.0 3300.0
NELP (I+II+III+IV)
(E) INDICATIVE (FUTURE ACREAGE) 0.0 0.0
(F) TOTAL(FIRM + INDICATIVE) 12470.0 4290.0 13420.0 9482.0 230.0 5091.0 1000.0 3140.0 1050.0 2160.0 28170.0 24163.0
201314 201415 201617201516
PHYSICAL TARGETS SEISMIC SURVEY
Table: C6
12th PLAN201213

Sl. No. BASINS
K.M. Wells K.M. Wells K.M. Wells K.M. Wells K.M. Wells K.M. Wells
1 CAMBAY 75.97 36 62.65 27 52.50 25 57.00 25 42.30 20 290.42 133
2 RAJASTHAN 3.70 2 3.70 2 4.00 2 2.00 1 13.40 7
3 GULF OF CAMBAY (SW) 4.80 2 4.80 2 9.60 4
WESTERN ONSHORE 80.77 38 71.15 31 56.20 27 61.00 27 44.30 21 313.42 144
4 UPPER ASSAM & NAGALAND 56.21 17 50.82 15 47.22 13 41.01 13 41.00 12 236.26 70
5 CACHAR 6.90 3 6.50 2 9.50 3 3.00 1 2.50 1 28.40 10
6 TRIPURA 25.50 10 34.40 11 31.10 10 34.10 11 40.25 13 165.35 55
ASSAM & ASSAM ARAKAN 88.61 30 91.72 28 87.82 26 78.11 25 83.75 26 430.01 135
7 BENGAL (ONSHORE)+PURNEA 8.00 3 11.70 4 8.80 5 8.00 3 5.00 3 41.50 18
8 BENGAL  (SW)
9 MAHANADI   (SW)
10 MAHANADI  (DW) 31.00 8 3.00 1 7.00 2 7.00 2 48.00 13
11 ANDAMAN (DW) 6.00 2 3.30 1 5.00 2 4.00 2 18.30 7
MBA 39.00 11 20.70 7 12.10 6 20.00 7 16.00 7 107.80 38
12 KRISHNA GODAWARI (ONSHORE) 36.20 12 37.00 10 37.00 10 30.00 8 26.50 7 166.70 47
13 KRISHNA GODAWARI (SW) 43.77 11 33.80 8 36.80 9 38.60 10 37.00 9 189.97 47
14 KRISHNA GODAWARI (DW) 43.20 9 40.60 9 21.20 4 4.50 1 109.50 23
KRISHNA GODAWARI 123.17 32 111.40 27 95.00 23 68.60 18 68.00 17 466.17 117
15 CAUVERY (ONSHORE) 56.25 15 39.70 10 40.20 10 39.70 10 31.70 8 207.55 53
16 CAUVERY  (SW) 7.20 2 7.20 2 14.40 4
17 CAUVERY (DW) 11.00 2 11.00 2 22.00 4 44.00 8
CAUVERY 67.25 17 50.70 12 62.20 14 46.90 12 38.90 10 265.95 65
18 HIMALYAN FORELAND / GV 1.15 2.35 1 5.00 1 4.50 1 13.00 3
19 VINDHYAN  & GONDWANA 6.25 2 1.00 1 2.60 1 9.85 4
GVK (FRONTIER) 7.40 2 3.35 2 2.60 1 5.00 1 4.50 1 22.85 7
20 MUMBAI (SW) 68.80 21 34.00 14 33.16 12 36.45 13 32.70 14 205.11 74
21 KUTCH & SAURASHTRA  (SW) 16.35 5 28.40 8 21.10 7 14.00 4 3.00 1 82.85 25
22 KERALA KONKAN   (SW)
23 DEEP WATER (WC) 17.00 4 6.50 1 6.00 1 29.50 6
WESTERN OFFSHORE 85.15 26 79.40 26 60.76 20 50.45 17 41.70 16 317.46 105
(A) SUB TOTAL ONSHORE 272.43 98 249.82 83 232.62 79 221.81 74 195.75 66 1172.43 400
(B) SUB TOTAL OFFSHORE 218.92 58 178.60 50 144.06 38 108.25 33 101.40 32 751.23 211
(C ) TOTAL ONGC : (A) +(B) 491.34 156 428.42 133 376.68 117 330.06 107 297.15 98 1923.65 611
(D) DEEP WATER (WC +EC) 85.20 19 77.600 18 53.000 10 12.000 4 21.500 6 249.30 57
(E) INDICATIVE
(F) TOTAL (INDICATIVE+FIRM) 491.34 156 428.42 133 376.68 117 330.06 107 297.15 98 1923.65 611
Table: C7
201516 201617 12th PLAN201314 201415
PHYSICAL TARGETS EXPLORATORY DRILLING
201213

Sl. No. Type of Wells
WELLS WELLS WELLS WELLS WELLS WELLS
Sub Total 0 17
1 0 44 51 39 15 149
2 INDICATIVE 0 10 35 50 55 150
Sub Total 0 54 86 89 70 299
TOTAL 0 54 86 89 70 316
UPSIDE
201516 201617 12th PLAN
EXPLORATORY WELLS
DEVELOPMENT WELLS
Table: C8
PHYSICAL TARGETS CBM Wells
201213 201314 201415

Sl. No. BASINS 201213 201314 201415 201516 201617 12th PLAN
1 WESTERN ONSHORE 24.00 25.00 23.00 21.00 18.50 111.50
2 ASSAM & AAFB 23.00 27.50 20.50 21.00 18.00 110.00
3 KG (ON+SW) 45.00 37.00 35.00 48.00 42.00 207.00
4 CAUVERY (ON+SW) 14.00 14.00 18.00 22.00 18.00 86.00
5 FRONTIER 0.00 0.00 0.00 0.00 0.00 0.00
Table: C9
PHYSICAL TARGETS ACCRETION TO INITIAL INPLACE HYDROCARBONS RESERVES (IIH)
MMToe
6 WESTERN OFFSHORE & GULF OF CAMBAY
(SW)
68.00 53.00 48.00 40.00 39.00 248.00
7 MBA 1.50 0.00 3.00 1.00 1.00 6.50
SUB TOTAL (ON+SW) 175.50 156.50 147.50 153.00 136.50 769.00
8 DEEP WATER (WC) 0.00 0.00 5.00 0.00 5.00 10.00
9 DEEP WATER (EC) 110.00 99.00 42.00 20.00 30.00 301.00
10 TOTAL DW 110.00 99.00 47.00 20.00 35.00 311.00
11 TOTAL ONGC 285.50 255.50 194.50 173.00 171.50 1080.00

Sl. No. BASINS 201213 201314 201415 201516 201617 12th PLAN
1 WESTERN ONSHORE 3.90 7.90 7.00 6.40 5.70 30.90
2 ASSAM & AAFB 7.20 9.10 7.40 7.40 6.95 38.05
3 KG (ON+SW) 14.25 10.50 10.10 17.30 16.10 68.25
4 CAUVERY (ON+SW) 5 00 4 10 5 60 7 10 5 30 27 10
Table: C10
PHYSICAL TARGETS ACCRETION TO RECOVERABLE HYDROCARBONS RESERVES (UR)
MMToe
4 CAUVERY (ON+SW) 5.00 4.10 5.60 7.10 5.30 27.10
5 FRONTIER 0.00 0.00 0.00 0.00 0.00 0.00
6 WESTERN OFFSHORE & GULF OF
CAMBAY (SW)
19.00 19.60 18.00 16.40 15.60 88.60
7 MBA 0.90 0.00 1.00 0.60 0.60 3.10
SUB TOTAL (ON+SW) 50.25 51.20 49.10 55.20 50.25 256.00
8 DEEP WATER (WC) 0.00 0.00 2.00 0.00 2.00 4.00
9 DEEP WATER (EC) 36.00 22.50 18.50 10.00 13.00 100.00
10 TOTAL DW 36.00 22.50 20.50 10.00 15.00 104.00
TOTAL ONGC 86.25 73.70 69.60 65.20 65.25 360.00

12th PLAN TARGETS
Financial Summary Sheets & IR Statement
(Tables D 1 to D 3)

Table: D1
S.No Activity Unit 201213 201314 201415 201516 201617 12th Plan
1 Seismic Survey Rs Crore 1719.64 2467.00 888.76 661.94 555.58 6292.93
2 Exploratory Drilling Rs Crore 7667.50 10917.58 9647.76 8242.34 8186.64 44661.82
3 Development Drilling Rs Crore 5830.57 8058.39 6472.31 3245.46 2898.69 26505.43
4 Capital Projects  & Purchases Rs Crore 15606.70 13316.53 15552.83 17206.91 17580.54 79263.52
5 R&D and Institutes Rs Crore 245.93 409.78 430.27 451.78 474.36 2012.11
6 JV Domestic Rs Crore 1322.98 867.54 444.96 603.42 578.50 3817.39
7 Integration Rs Crore 671.98 126.00 605.00 0.00 0.00 1402.98
Total Plan Outlay Rs Crore 33065.31 36162.81 34041.89 30411.86 30274.31 163956.18
PLAN OUTLAY   SUMMARY

Table D2
S.NO. PARTICULARS 201213 201314 201415 201516 201617 TOTAL  12th Plan
A REVENUES:
1 SALES REVENUE
Capital Projects  & Purchases 57,622.23 57,941.00 55,701.39 50,681.57 49,176.56 271,122.75
R&D and Institutes 15,709.04 14,379.21 15,085.05 16,067.64 23,336.62 84,577.57
L.P.G 3,681.10 3,131.90 3,121.29 3,034.23 2,886.72 15,855.23
Naphtha 5,852.62 4,890.39 4,830.44 4,645.60 4,240.49 24,459.53
C2‐C3 1,983.45 982.27 982.27 982.27 982.27 5,912.53
SKO 595.14 497.77 490.51 467.53 425.37 2,476.30
RCO 34.40 28.84 28.12 27.69 27.25 146.31
OTHERS 0.00 676.07 674.99 675.88 672.40 2,699.33
PROFIT OIL SURRENDER ‐2,877.32 ‐2,599.47 ‐2,368.88 ‐2,029.15 ‐1,635.01 ‐11,509.82
SUB TOTAL (1)) 82,600.65 79,927.98 78,545.18 74,553.24 80,112.66 395,739.72
2 OTHER REVENUE
OTHER INCOME 1,481.17 2,063.72 2,063.72 2,063.72 2,063.72 9,736.05
INTEREST INCOME 1,602.19 993.89 1,061.20 1,134.23 1,213.47 6,004.97
DIVIDEND RECEIPT 555.00 440.50 440.50 440.50 440.50 2,317.00
SUB TOTAL (2)) 3,638.35 3,498.11 3,565.42 3,638.45 3,717.69 18,058.02
TOTAL REVENUE A (1+2) 86,239.01 83,426.09 82,110.60 78,191.69 83,830.34 413,797.73
B EXPENDITURE:
1 OPERATING EXPENDITURE 15852.23 15,680.15 16,464.16 17,287.37 18,151.74 83,435.65
2 PURCHASE OF CONDENSATE 307.29 324.05 340.25 357.26 375.12 1,703.97
3 STATUTORY CHARGES
CESS 6,388.15 7,166.57 6,906.69 6,295.02 6,062.99 32,819.42
ROYALTY 10,600.17 10,041.38 9,195.92 8,548.07 8,693.39 47,078.93
SALES TAX 404.60 415.48 379.03 335.64 311.77 1,846.52
EXCISE DUTY 377.94 231.40 230.42 226.74 219.19 1,285.68
OCTROI/ BPT 434.88 533.45 522.02 468.56 437.54 2,396.46
OTHERS & SERVICE TAX
SUB TOTAL (B3) 18,205.73 18,388.29 17,234.08 15,874.02 15,724.88 85,427.01
4 LOAN REVALUATION 0.00 0.00 0.00 0.00 0.00 0.00
5 RECOUPED COSTS / DDA 21,035.87 23,157.56 22,233.57 22,406.31 22,730.62 111,563.94
6 INTEREST PAYMENTS:
CENTRAL GOVT / OIDB 0.00 0.00 0.00 0.00 0.00 0.00
OTHERS (INCL. SHORT TERM  LOAN) 0.00 575.68 682.40 512.42 19.09 1,789.59
SUB TOTAL (B5) 0.00 575.68 682.40 512.42 19.09 1,789.59
7 PRIOR PERIOD ADJUSTMENTS 0.00 0.00 0.00 0.00 0.00 0.00
TOTAL EXPENDITURE B
(1+2+3+4+5+6)
55,401.11 58,125.73 56,954.47 56,437.38 57,001.45 283,920.15
C P.A.I.B.T. (AB) 30,837.89 25,300.35 25,156.13 21,754.31 26,828.90 129,877.58
D PROVISION FOR TAX 10,005.35 8,208.70 8,161.91 7,058.19 8,704.64 42,138.78
E PROFIT AFTER TAX (CD) 20,832.54 17,091.65 16,994.22 14,696.12 18,124.26 87,738.80
TWELFTH PLAN (201217) TARGETS
INTERNAL & EXTERNAL BUDGETARY RESOURCES (IEBR)
STATEMENT 1 PARTI  ( IEBR for PLAN )

Table D3
S.NO. PARTICULARS 201213 201314 201415 201516 201617 TOTAL 12th Plan
F DIVIDEND PAYMENT:
DIVIDEND PAYMENT 6,844.40 5,127.50 5,098.27 4,408.84 5,437.28 26,916.28
TAX ON DIVIDEND 1,110.33 831.81 827.07 715.22 882.06 4,366.49
SUB TOTAL (F) 7,954.73 5,959.30 5,925.33 5,124.06 6,319.34 31,282.77
G RETAINED SURPLUS (EF) 12,877.81 11,132.35 11,068.89 9,572.06 11,804.92 56,456.03
H ADD BACK:
DEPRECIATION & WRITE OFFS 21,035.87 23,157.56 22,233.57 22,406.31 22,730.62 111,563.94
DEFERRED TAX
LOAN REVALUATION 0.00 0.00 0.00 0.00 0.00 0.00
SUB TOTAL (H) 21,035.87 23,157.56 22,233.57 22,406.31 22,730.62 111,563.94
I REPAYMENT OF LOANS 0.00 0.00 0.00 0.00 0.00
J
CHANGE IN W. CAPITAL INCR /
(DECR)
1457.39 0.00 0.00 0.00 0.00 1,457.39
LOANS TO SUBSIDIARIES 7,400.00 0.00 0.00 0.00 0.00 7,400.00
K I.R. OPERATIONS (G+HIJ) 27,971.06 34,289.91 33,302.46 31,978.38 34,535.54 162,077.35
L INVESTMENT (DISINVESTMENT)
INVESTMENTS/ SHORT TERM
DEPOSITS IN TDRS
‐5,093.94 ‐1,872.90 ‐739.43 1,566.52 4,261.22 ‐1,878.52
LONG TERM INVESTMENTS
M I.R. AFTER INVEST (DISINV) (KL) 33,065.31 36,162.81 34,041.89 30,411.86 30,274.31 163,956.18
N
EXTERNAL BUDGETARY RESOURCES
(EBR)
SHORT TERM LOAN 0.00 0.00 0.00 0.00 0.00 0.00
LONG TERM LOAN 0.00 0.00 0.00 0.00 0.00 0.00
SUB TOTAL (N) 0.00 0.00 0.00 0.00 0.00 0.00
O
TOTAL INTERNAL & EXTRA
BUDGETARY RESOURCES (M+N)
33,065.31 36,162.81 34,041.89 30,411.86 30,274.31 163,956.18
P PLAN OUTLAY 33,065.31 36,162.81 34,041.89 30,411.86 30,274.31 163,956.18
STATEMENT 1 PARTII ( IEBR for PLAN )

12th PLAN TARGETS
Asset –wise Summary Physical & Financial
(Tables E 1 to E 19)

Table E1
(I)
CRUDE OIL PRODUCTION‐ONGC MMT 25.045 28.270 28.002 26.286 25.456 133.058
CRUDE OIL PRODUCTION‐ JV Share MMT 3.721 3.882 3.176 2.627 2.527 15.932
CRUDE OIL PRODUCTION‐TOTAL MMT 28.765 32.151 31.178 28.912 27.983 148.990
NATURAL GAS PRODUCTION‐ONGC MMSCM 25266.18 25471.54 26669.43 28214.56 38676.10 144297.82
NATURAL GAS PRODUCTION‐JV Share MMSCM 2113.44 1952.52 1956.36 1742.07 2143.52 9907.91
NATURAL GAS PRODUCTION‐ TOTAL MMSCM 27379.62 27424.07 28625.79 29956.63 40819.62 154205.73
NATURAL GAS SALES ‐ ONGC MMSCM 20089.58 20078.54 21016.15 22623.83 33247.07 117055.17
NATURAL GAS SALES ‐ JV Share MMSCM 1951.34 1803.47 1809.46 1602.49 1953.15 9119.91
NATURAL GAS SALES ‐ TOTAL MMSCM 22040.92 21882.01 22825.61 24226.32 35200.21 126175.08
   (b)                              WELLS Nos 325 275 212 158 150 1120
(II) PLAN OUTLAY
1
2
3
PHYSICAL :
PHYSICAL PROGRAMME AND PLAN OUTLAY    SUMMARY ASSETS

TableE2
(I)
CRUDE OIL PRODUCTION‐ONGC MMT 15.409 18.454 18.208 16.333 15.790 84.194
CONDENSATE RECEIPT MMT 2.461 2.588 2.611 2.845 2.671 13.177
CONDENSATE + CRUDE PRODUCTION MMT 17.870 21.042 20.819 19.178 18.461 97.371
2 NATURAL GAS PRODUCTION‐ONGC MMSCM 19497.47 19558.53 20877.20 22652.34 33431.50 116017.03
3 NATURAL GAS SALES ‐ ONGC MMSCM 15310.67 15322.63 16575.73 18422.26 29223.25 94854.53
   (b)                              WELLS Nos 90 62 50 12 6 220
(I)      PLAN OUTLAY :
1
PHYSICAL :
PHYSICAL PROGRAMME AND PLAN OUTLAY   SUMMARY OFFSHORE ASSETS

TableE3
(I)
1 CRUDE OIL PRODUCTION MMT 10.420 10.330 9.802 9.321 8.849 48.722
2 NATURAL GAS PRODUCTION MMSCM 4233.22 3498.29 3097.83 2666.68 2342.21 15838.23
3 (a) DEVELOPMENT  METREAGE (Incl NMFD) K.M. 148.30 139.30 15.00 0.00 0.00 302.60
4 (a)                              WELLS (Incl NMFD) Nos. 54 49 6 0 0 109
(b) DEVELOPMENT WELLS MH(Excl NMFD) Nos. 43 21 6 0 0 70
(II)
Total Rs Crore 7465.62 6806.81 5460.77 4384.99 2455.29 26573.48
Oil Production excludes N&MF of MH , which is shown separately in N&MF.
Development wells & Meterage at 3a&3b includes MH & NMFD of MH
PHYSICAL :
PLAN OUTLAY :
PHYSICAL PROGRAMME & PLAN OUTLAY   SUMMARY MUMBAI HIGH

TableE4
(I)
3a DEVELOPMENT  METREAGE K.M. 16.80 17.60 13.20 0.00 0.00 47.60
4 (a) DEV.  WELLS Nos. 5 8 6 0 0 19
(II)
2 a HEERA REDEVELOPMENT PART‐II Rs Crore 200.00 0.00 0.00 400.00 362.50 962.50
b NEELAM SUBSEA 3 WELLS Rs Crore 0.00 0.00 0.00 200.00 100.00 300.00
c
B‐173 SUBSEA / LOW COST P/F WITH 3
WELLS
Rs Crore 0.00 470.00 0.00 0.00 0.00 470.00
d OTHER CAPITAL Rs Crore 289.93 727.24 558.41 232.62 13.38 1821.58
Total Rs Crore 1613.28 1622.69 896.65 832.62 475.88 5441.12
PHYSICAL :
PLAN OUTLAY :
PHYSICAL PROGRAMME & PLAN OUTLAY SUMMARY HEERA & NEELAM

TableE5
(I)
3a DEVELOPMENT  METREAGE (Incl NMFD) K.M. 86.23 56.66 98.77 7.70 21.95 271.30
4 (a)                              WELLS (Incl NMFD) Nos. 31 3 28 2 6 70
(b) DEVELOPMENT WELLS (Excl NMFD) Nos. 11 3 2 2 4 22
(II)
Total Rs Crore 3007.52 2925.79 4069.12 4259.79 9730.05 23992.28
Oil Production excludes N&MF of B&S , which is shown separately in N&MF.
Development wells & Meterage at 3a&3b includes B&S and NMFD of B&S
PHYSICAL :
PLAN OUTLAY :
PHYSICAL PROGRAMME & PLAN OUTLAY SUMMARY B&S

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