OIL AND NATURAL GAS CORPORATION LIMITED Plan (Domestic Exploration

ONGC�s Mid Term Appraisal of 10th Plan

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OIL AND NATURAL GAS CORPORATION LIMITED

Mid Term Appraisal Of 10th Plan (Domestic Exploration and Production Activities)

1. Introduction 1.1 The 10th Five Year Plan Programme of ONGC was submitted to MOPNG and Planning Commission in November 2001 along-with the Annual Plan 2002-03. The 10th Plan exploration and exploitation programme of ONGC reflects the ability and resolve of the company to pursue the E&P objectives in the changing environment and in tune with its long-term business goal to maximise contribution towards the national energy requirement. The 10th Plan Outlay is Rs. 33419 Crore for domestic E&P activities of ONGC also Rs.13550 Crore for overseas ventures of OVL. 1.2 The 10th Plan program encompasses the oil and gas field development strategy of ONGC during Plan period considering the status of different fields and schedule of implementing of additional development inputs. The formula1ion of the exploration programme for the 10th Plan period was based on the following considerations:

• The prospectivity perception of the domestic acreages and their potential levels • Acreage specific exploration programme under various dispensations due to the changed

scenario on account of the Govt. of India's policy initiatives under NELP regime as against the earlier practice of sector-wise/basin-wise exploration programme formulation.

The hydrocarbon demand scenario in the country necessitated acceleration of the reserves accretion from the producing basins, extension of the exploratory activities to the poorly explored, logistically difficult and frontier areas. Key sectors were identified in different basins of the country for enhancing the pace of accretion by fast track appraisal of leads obtained, exploring the large prospects and opening up of frontier areas including deep waters. 1.3 The projections of crude oil and natural gas production for the 10th Plan period were based on the major identified initiatives like Redevelopment of Mumbai High, integrated development of Heera field, additional development of Neelam field, implementation of 15 IOR schemes, finalisation of EOR pilots, commercialisation of successful EOR pilots, development of marginal fields, integrated development of Tripura gas field and initiation of production from KG Offshore. 1.3.1 Redevelopment of Mumbai High: Mumbai High field has been on production for more than 25 years and produced around 310 MMt of crude oil. During its peak production phase, the field has produced around 18-20 MMt of oil per year. The field production has declined since 1990-91. The plan for redevelopment of Mumbai High North & Mumbai High South has been approved for implementation at a cost of Rs. 2929.40 Crore and Rs. 5255.97 Crore in Dec. '2000 and Oct. '2001 respectively. The scope of work includes infill drilling, installation of process platforms, well platforms, clamp-on structures, new pipelines and modifications on existing platforms. The Incremental production envisaged is 60.76 MMt crude oil and 15.48 BCM natural gas by 2030.



1.3.2 Improved Oil Recovery Programme & EOR: In addition to the two EOR Projects in Balol and Santhal fields approved by Government, Improved Oil Recovery Programme was approved by ONGC Board for 12 other major fields viz. Heera, Neelam, Gandhar, North Kadi-Phase-I, Jotana, Sobhasan, Santhal Infill, Kalol, Sanand Extended Polymer, Lakwa -Lakhmani, Geleki and Rudrasagar. This programme will increase the Global Recovery Factor by an average of 4%. The Balol and Santhal projects have been completed in 2001-02. Two other projects Sanand Extended Polymer and Santhal Infill completed in 2002-03 whereas Additional Development Heera Pt-1 completed in November 2003. The details of major projects and the current status is appended as Appendix-I and II. The Redevelopment of Mumbai High and the IOR/EOR Programme has successfully arrested the declining trend in the crude oil production faced during the 9th Plan period. The crude production went up from the level of 24.71 MMT in the terminal year of 9th Plan to 26.06 MMT in the second year of the 10th Plan (2003-04). Besides the Redevelopment and IOR/EOR programme envisaged at the time of formulation of 10th Plan, during the first two year of plan period, three major development schemes viz., Development of D-1 Prospects, Development of Bassein (Vasai) East Field and Integrated Development of G-1 & GS-15 fields, one value addition project i.e., C2-C3 Recovery from LNG Petronet, Dahej and one replacement project of Mumbai-Uran Trunk Pipeline (MUT) to maintain the steady & non-interrupted flow of crude from Mumbai offshore to Uran- onshore terminal is also approved by ONGC Board. These development projects will also start contributing to production from 2005-2006. 1.4 Initiatives for Upgradation & Modernisation: In the 10th Plan, an outlay of Rs. 2285 Crore has been kept for upgradation, refurbishment and replacement of plant and equipment including rigs, upgradation of production & exploration technology. Token amounts are provided for Infocom and diversification. ONGC Initiated in a focused manner for acquiring the state of art technology and equipment, refurbishment and overhauling of existing aged equipments & facilities and implementation of Infocom projects. ONGC has also acquired advanced interactive workstation to create full-fledged 3-D data processing centre and Virtual Reality Centres. Other innovative measures undertaken include usages of Extended Reach and horizontal drilling, 4-D seismic, cross well tomography and using gels and polymers for water shut off jobs. In order to enhance drilling capabilities, two own rigs Sagar Vijay & Sagar Bhusan have been upgraded Out of 12 onland drilling rigs planned to be re-furbished through BHEL in phase-I, 5 rigs have been completed and 1 rig is in progress. 12 rigs will be re-furbished during 2004-05 in phase-II. 20 drilling rigs (10 rigs each In 2005-06 & 2006-07) have been planned to be re-furbished in phase-III. Out of 19 w/o rigs planned for refurbishment during 2003-05, 5 w/o rigs have been refurbished and 1 rig is under progress. The corporation has taken up company wise ERP solution on SAP /R3 Platform for Optimization and standardization of business processes, Moving up the Value chain Higher Productivity, Cost Reduction, Improving Efficiency, Lowering Inventory and Increasing Customer Satisfaction. 1.5 Integration/Diversification/Acquisition activities: Globally, all major Oil & Gas Companies are vertically integrated on the hydrocarbon value chain; this is the only paradigm to secure sustained growth in this high-risk high-cost high-technology business.



Revenue streams in the upstream business are highly volatile, and no company, for that matter, no country can control the geo-political situation in oil & gas section. The fortunes of sectoral companies are unpredictable; all major world-scale Oil & Gas companies are, therefore, vertically integrated. Competitive pressures have maximum impact on costs, and therefore, mergers and acquisitions have become the name of the game in all businesses, world-wide. Towards the first step for integration, marketing Rights for transportation fuels was obtained from GoI in May 2002; the rights are subject to organizing assured sourcing of products. In mid-June 2002, ONGC was asked to go ahead with rehabilitation of Mangalore Refinery & Petrochemical Ltd (MRPL), a joint venture company on the verge of being referred to the BIFR. Negotiations for (i) acquisition of one partner's entire stake (@ Rs 2 per share of face value of Rs 10), and (ii) restructuring of debt with 22 lenders (debt- equity improved from 9.15% to 2.5%) were completed in six weeks, an unprecedented feat in a transparent process. Now MRPL is ONGC's subsidiary (71.4 % equity). ONGC has also acquired 23% equity in Mangalore-Hasan-Bangalore Pipeline (MHBPL), designed to carry MRPL's products to the heart of the Karnataka market. The C2-C3 & LPG Recovery project from LNG was approved by ONGC Board on 29th December 2003 at a cost of Rs.900.92 Crore. The project envisages setting up a unit to recover 566574 TPA of C2-C3 and 347065 TPA of LPG from LNG at Dahej. The scheduled completion of the project is June'2006. Projects initiated for creating new value-added products (Aviation Turbine Fuel) from the fractionators is progressing well, along with projects for enhancing current productions. 2. BACKGROUND OF 10th EXPLORATION PROGRAMME- DOMESTIC ACREAGES: The broad policy guidelines and milestones for the E&P upstream sector, as brought out in the 'India Hydrocarbon vision-2025' provided the broad framework for formulating the Tenth five-year plan. The main issues as brought out in the document are:

• Maximizing exploration and exploitation efforts in the producing basins, • Spreading exploration into non producing/frontier basins, • Appraising all the sedimentary basins within a time frame,

2.1 COMPONENTS OF 10th PLAN EXPLORATION PROGRAMME: In the backdrop of the emerging NELP regime and the need for evolving an acreage specific exploration programme, detailed micro-planning was carried out for each acreage i.e. PEIs and MLs as well as NELP-II blocks applied and the open acreages, taking into account the prospectivity analysis and attendant risk perception to deduce the exploration input requirement during 10th plan. Based on the this work out, the Exploration programme of ONGC was quantified and grouped into two broad components viz, Firm programme and Upside programme, the later in view of the uncertainty on acreage availability to ONGC during the 10th plan period.

• The envisaged firm programme for exploration includes: • The input in PEL acreage's up to the current cycle, • ML acreages and



• NELP-II blocks. The programme within these areas was considered as firm, as the availability of these acreages with ONGC during the plan period was ensured, as per the existing licensing policy of the government.

• The upside programme was worked out by adding 50% of the indicative inputs in the PEL acreages held by ONGC beyond their current cycle and the open acreages in the various basins, to the firm programme in order to account for a most likely acreage availability scenario for ONGC during the course of the 10th plan period (pending the announcement of Relinquishment Policy by GOI during that time).

3. RATIONALE AND STRATEGY FOR 10th PLAN EXPLORATION PROGRAMME: 3.1 Producing basins:

• Consolidating on the known play systems- field growth and lead perusal. • Establishment of new plays in the known sectors and • Extension of exploratory activities to less explored/new sectors.

3.2 Enhancing tempo of Deep-water Exploration:

• Deep water sector was accorded priority, to receive a quantum jump in exploration programme, in view of higher degree of expectations, with twin objectives:

• To intensify the exploration in the sectors with successful outcome arising out of short- term strategy.

• To expand the activities to new sectors simultaneously making foray into the super and ultra deep waters

3.3 Yet to establish Basins:

• Focus on the acreage where in spite of elusive commercial success, knowledge building needs continuation for a breakthrough. The basins under this category are Mahanadi, Satpura, South Rewa, Vindhyan, Kutch (Mesozoic sequence), Kerala-Konkan and Himalayan Foothills.

• In the 'teaser' basins of Bengal and Rajasthan, continued intellectual efforts in basin evaluation to be maintained in order to register a breakthrough.

The exploration. of non-conventional hydrocarbons is critical not only to supplement the conventional hydrocarbons but also to cater to the possible upsurge in energy demand on account of rapid industrialisation. 4. REVIEW OF THE EXPLORATION PROGRAMME IMPLEMENTATION DURING 2002-04: 4.1 Acreage holding scenario:

• With the adoption of Relinquishment policy, in respect of the nomination acreages held by the NOCs, by the Govt. of India, ONGC had to surrender 25% of the original area, while entering into the regnant cycle. This has led to considerable reduction in the nomination acreages held by the Company.

• However, during the period from 1.4.2002 to 1.4.2004, ONGC either on sole risk or in consortium with other companies has been awarded 24 blocks (223363 sq. km.), during NELP-III&IV rounds,



where ONGC is the operator. Additionally, 7 CBM blocks (2779 sq. km.) have also been awarded to ONGC (sole rick and consortium) during CBM NELP -I & II rounds.

• The comparison of the acreage holding scenario of ONGC as on 1.4.2002 and 1.4.2004, considering nomination and NELP acreages is as under:

Year Number of blocks Area(Sq .km.)

PEL NELP ML CBM PEL NELP ML CBM 1.4.2002 131 23 205 0 188685 318368 9525 0 1.4.2004 119 44 239 5* 145743 464788 10688 1562*

* 2 Additional CBM blocks also awarded for which PEL has been applied. 4.2 Exploration programme Implementation: The scenario of exploration programme implementation during 2002-04 reflects over achievement in respect of 3D seismic data acquisition, as indicated below:

2D (GLK/LK) 3D (Sq Km) Exploratory Wells Inplace Accretion (Mmtoe)

BE Actual BE Actual BE Actual BE Actual 2002-03 15135 21059 6556 8639 153 150 121.7 128.1 2003-04 14690 5993 14784 19891 172 124 134.55 104.78 Total 29825 27052 21340 28530 325 274 256.25 232.88

During 2002-03 (BE) & 2003-04(BE) it was envisaged to acquire 29825 GLK/LK of 2D and 21340 Sq. Km. of 3D seismic data. Against this 2D data acquired was 27052 GLK/Lk while 3D data acquired was 28530 Sq. Km. The cumulative achievement of 2D seismic is 90.7% of BE targets whereas in 3D seismic it was 133.7% . The planned 2D data acquisition during 2002-03 in the NELP-III blocks in deep water, could not be taken up since the blocks were awarded to ONGC during February 2003. The same has been prioritised during 2003-04 and 2004-05. In the 10th Plan it was envisaged to drill 561 exploratory wells (Firm Programme). During the first two years of the 10th Plan, against BE target of 325 exploratory wells, 274 wells were drilled. 4.3 Basin wise planned vs. actuals of the physical programme during 2002-03 and 2003-04 are placed at Appendix-III (A) and III (8). 4.4 Exploration objective fulfillment: 4.4.1 Producing Basins: In the seven producing basins, during 2002-04, 12417 GLK/LK of 2D, 13113 Sq. Km. of 3D seismic data were acquired and 265 exploratory welis were dried against a target of 6305 GLK/ IK of 2D, 8346 Sq. Km. of 3D and 292 exploratory wells. This has led to in-place hydrocarbon accretion of 233 MMt of O+OEG, agalnst a target of 256.25 MMt, during 2002-04. New areas taken up: During 2002-04, several new areas were taken up for exploration in the producing basins both for establishing the extension of known plays and for testing new plays, as mentioned below:



Cambay Basin:

• Assessing Mesozoic prospectivity In Rajpardi area and West of Baola. • Oligo-Mlocene prospectivity in Navasari area, in South Cambay basin. • Exploration spread to Degam area, leading to oil strike in Degam-1 in Oligocene sequence.

Rajastan Basin:

• Tested Goru and Pariwar play in S. Kharatar area, leading to significant gas strike in Chlnnewala Tibba.

A&AA Basin:

• Exploration spread to Eastern Tripura- initiated the seismic data acquisition. • Exploratory drilling taken up in sector-Vc in Northern Cachar.

K.G. Basin:

• Exploration spread to Vizag high area in northern part of K.G. shallow water area to establish Gondwana prospectivity.

Cauvery Basin:

• Exploration spread to Gulf of Mannar to establish extension of Nannilam play and test additional Tertiary turbidite plays.

• Panruti and Udaiyur in Ariyalur - Pondicherry and Nammeli in Tranquebar sub-basin Mumbai Offshore:

• Exploration spread to South Ratnagiri, in the form of seismic surveys and exploratory drilling, leading to establishing significant lead in Panna formation and Oligocene carbonates.

• Exploratory drilling in Shelf margin depression (SM-86) area. New prospects taken up and Hydrocarbon Strikes made: During 2002-04, 51 new prospects were drilled in different basins. 12 new hydrocarbon finds were made during first two years of the 10th Plan which are mentioned below:

Sl. No. Basin Well Find

1. A&AA Banamali Oil

2. A&AA Laipling Gaon Oil

3. Rajasthan Chinnewala Tibba Gas

4. Western Offshore Vasai West Oil & Gas

5. K.G Offshore GS-KW Oil & Gas

6. K.G. Offshore GS-49 Gas



7. A&AA East Lakhibari Oil & Gas

8. Western Offshore NMT (North East of Mid Tapti)

Gas

9. Krishna Godavari Offshore G-4 Gas

10. Krishna Gadavari Onshore Sitarampuram Oil & Gas

11. Western Onshore Degam Oil

12. A&AA Sonamura Gas

The details of these hydrocarbon finds made during 2002-04 are placed in Appendix-IV. 4.5 Hydrocarbon leads obtained: Cambay Basin:

• Gas bearing Mehsana sands were discovered for the first time in Mansa field in the well Mansa-25, providing a significant lead in the eastern basin margin.

• Two wells drilled in the Nardipur Low adjoining Umbodra field, on the interpreted K-IX channel brought out by 3D interpretation, proved oil bearing thus validating the model. This important lead has given an impetus to hitherto poorly explored K-IX sand in the Nardipur Low area.

• Kalol III+IV sand was found oil bearing in three wells drilled in the south-western part of Nawagam field as an additional pay discovered in the field.

• Oil find in the well Gandhar -532, drilled on the western rising flank of Tankari Low has opened up a large area for exploration.

• Southwest wards extension of oil/gas bearing Jambusar Sands was proved by the well Jambusar-26, leading to exploration expansion.

A&AA Basin:

• The well KG-S produced commercial hydrocarbons from LBS-1 and is presently under testing in LBS-2, opening further areas for exploration.

• The well PD-4 produced commercial hydrocarbons from Tura and Sylhet, providing impetus for exploration of Pre-Barails in the area.

• The well RO-40 produced commercial hydrocarbons from Upper Bhuban sands, thereby opening up the area south of the well for further exploration.

Mumbai Offshore:

• A deliberate attempt was made to probe the structural play in the Eastern Homocline area. Well B 182A-1 drilled in this set-up proved to be oil bearing within Lower Bassein, thereby opening the area for exploration.

• B 172-7 was drilled to explore the Mukta, Bassein and Panna Fm. Mukta Fm. proved to be oil bearing for the first time in B172 structure. Its bearing on hydrocarbon accumulation in the area is being pursued.

• RSER: Hydrocarbon shows obtained in the Oligo-Miocene and Eocene sequence has provided lead for further exploration in a new play.



• R4N: It was drilled to explore the Eocene carbonates in a structural play and Panna clastics associated with inversion within the Vijaydurg graben. The well has indicated oil and gas from Panna Fm.

• C37-4: Located in the Tapti-Daman sector, flowed gas from Mahuva Fm. 4.6 New plays tested: A&AA Basin:

• The Gondwana sandstone was a new play tested in the well East Lakhibari-1 and established presence of oil.

K.G. Basin:

• Syn-rift sediments in the western part of Gudivada graben and Sub-conformity trap below Mio-

Pliocene unconformity in Sitarampuram area • Mio-Pilocene channel fan complex in K.G. deep water

Mumbai Offshore basin:

• Lower Bassein play in the Heera-Panna-Bassein sector (Vasai West, B 182A). • Eocene-Oligocene carbonate wedge-out play in the DLS prospect in BH-DCS sector. • Shelf edge carbonates build-up in Ratnagiri sector. • Eocene carbonates as structural play due to Inversions within Vijaydurg graben in Ratnagiri

sector. 4.7 Lead pursuing efforts Cambay and Rajastan Basins:

• Efforts have been expended to pursue the leads obtained in the basin with acquisition of 3D seismic and firming up of exploratory locations in Chinnewala Tibba, Degam, Nawagam-Sadra and Manso.

• Integrated interpretation in the Warosan Low and its flanks for Mandhali prospects and locations firmed up.

• Reinterpretation of 2D and 3D seismic data for delineation of Wadasma new pay. A&AA basin:

• The lead established by the well BM-4 in the Banamali area, in 2001-2002, was followed up and locations were released.

• In the East Lakhibari, three locations were released, based on the integrated G&G studies. • In Laipling-gaon area, two exploratory locations were released in the light of the find established. • The recent Sonamura find is presently under assessment.

K.G. Basin:

• Appraisal drilling taken up in Penumadam, Kavitam, GS-KW and Rangapuram to pursue the leads obtained.

• GD-1-2 currently under drilling to consolidate the lead provided by GD-1-1.



Cauvery Basin:

• Significant success obtained in Kanjrangudi-3 with establishment of hydrocarbons in Bhubanagiri and Nannilam plays.

• Appraisal drilling taken up in Kuthalam, Vijaypuram, Kamalapuram, Tiruvarur. Mumbai offshore:

• Bassein East: In addition to the known pays in the wells of Bassein East, additional pays were encountered in the well BSE-6 at deeper levels which flowed gas.

• B28-4: Located to the SW of Vasai West in the Heera- Panna- Bassein sector to explore hydrocarbon potential of Mukta, Bassein & Panna Fm, the well flowed oil and proved the extension of the Panna oil bearing trend of B 149 towards south.

4.8 Field growth established.

• Cambay / basin: Pool extensions were established in Mandhali and Linch sand units in the Jotana-Warosan-Unch area, Kalol and Mehsana sands in the Nandasan area, Kalol IX and X sands in the Ahmedabad-Nandej-Nawagam-Wasna-Sadra area, Kalol IX sand in Nardipur Low southwest of Limbodra field, Wadu pay in the northern part of Wadu field, Kalol VII and VIII sands In Gamij area, S-I pay in southwestern part of Jambusar field

• A&AA basin: Pool extensions were established in Nambar, Khoraghat, Changmaigaon, Gojalia, Panidihlng, Rokhia-Konaban

• K.G. Basin: Significant field extensions were established at Pasarlapudi, Kesavadasupalem, Gopavaram, Rangapuram, Kavitam, Penumadam, Endamaru, and Kaikalur, in the on land and GS-KW & G-1 in the offshore.

• Cauvery basin: New pools were established in Kamalapuram, Vijayapuram and Tiruvarur fields. In Vijayapuram, Kamalapuram and kanjirangudi fields significant field extensions were established

• Mumbai Offshore: Established extension of Bassein field in the west 4.9 Reserve accretion:

• Tenth Plan in-place hydrocarbon Accretion target is of the order of 570 MMToe. During the first two years, the actual accretion is 233 MMTOE, against the target of 256 MMtOE for these two years. Target for 2004-05 (BE) has been kept as 148.4 MMToe.

• Similarly against the Ultimate ReseNe accretion target of 147.13 MMToe for the total Tenth plan period, the actual achievement during 2002-04 has been 74.39 MMToe and accretion of 40 MMtoe has been planned during 2004-05.

Target (BE) Achievement Year

IIH UR IIH UR 2002-03 121.7 30.01 128.10 40.73 2003-04 134.55 30.90 104.78 33.67 Total 256.25 60.91 232.88 74.40



4.10 Deep Water Exploration:

• A major thrust was given to deepwater exploration at the time of formulation of 10th Plan and it was envisaged to drill 34 exploratory wells (firm programme) in deepwater areas during 10th Plan period.

• ONGC currently holds 29 deepwater PEL acreages, of which 20 have been awarded under the four rounds of New Exploration Ucensing Policy (NELP).

• During first two years (2002-04) of lOth Plan, ONGC has acquired 8485 LK of 20 and 9684 sq. km. of 3D seismic data and 5 wells have been drilled, against the 2002-04 target (BE) of 13365 LK of 20, 1573 sq. km. of 30 and 19 exploratory wells.

• To give Impetus to deepwater exploration, project Sagar Sammriddhi was launched in August 2003. This project, the biggest ever-deepwater exploration campaign by a single operator anywhere in the world is progressing with 3 drill ships, Belford Dolphin, Discoverer Seven Seas and ONGC's own rig Sagar Vljay.

• The deep-water exploratory well GD-1-2 (water depth -751 m) on the GD structure was completed during 2003-04. In addition, under the campaign 'Sagar Sammriddhi', ONGC has already drilled two wells namely G-4 -2 In a water depth of 430 m in the East Coast, through in-house drill ship "Sagar Vijay� and GK-DW-A-1 in bathymetry of 1860 m in the Arabian Sea with chartered hire rig Belford Dolphin.

• The well G-4-2 proved to be gas bearing and the estimated initial in place volume of gas is about 22 BCM. Three more wells namely, DWRO-1-A in the west coast at a water depth of 1090 m by Belford Dolphin and KD-2-1 by Discoverer Seven Seas at a water depth of 1463 m and GD-2-1 by in-house drill ship "Sagar Vijay� at a water depth of 650 m in East Coast were under drilling as on 1.04.2004.

• The current emphasis is on pre-drill risk reduction measure through validation of the interpretation carried out in house by internationally reputed consultants namely M/s Landmark M/s Paradigm and M/s Jason. M/s Triton has been engaged as consultant for deepwater drilling.

4.11 Exploration focus in Yet-to-establish basins:

• During 2002-04, the tempo of exploration in the yet-to -produce basins viz. Kutch offshore, Kerala-Konkan, Mahanadi and Bengal was enhanced, so as to bring out the GME cycle operative and establish breakthrough.

• During these two years, 4966 LK of 2D, 5732 Sq. km. of 3D seismic data were acquired and 2 exploratory well was drilled in these basins against the 2002-04 (BE) target of 8700 LK of 2D, 2579 Sq. km. of 3D and 13 exploratory wells.

• Several interesting hydrocarbon ploys have been identified based on the geoscientific data acquired and the analysis carried out/under progress, which will form the basis for intensification of exploration in these basins in the remaining period of the plan period.

4.12 Exploration in the Frontier Onland basins:

• During 2002-04, exploration activities continued in the frontier onland basins viz. Ganga Valley, Himalayan Foreland, Satpura and Vindyan basins. 1186 GLK of 2D seismic data was acquired against the 2002-04 (BE) target of 1455 GLK.

• Two exploratory wells viz. Kharkhari-1 in Satpura basin and Sundernagar-1 in Himalayan foreland basin were drilled during 2002-04.

• A special group evaluates the optimal requirement of knowledge building exploration inputs in various less explored frontier basins in the country to promote those basins for commercial exploration activities. The data acquisition programme such activities has been identified.



4.13 Efforts for CBM Exploration:

• Following the establishment of CBM gas production for the first time in India from a well in Jharia in Parbatpur block during the previous years and introduction of CBM policy by Government of India, ONGC has further consolidated the CBM exploration. Production testing of another well Jharia-4 is in progress to assess its production potential.

• Out of the two blocks awarded to ONGC-CIL consortium for CBM exploration and exploitation in the previous years, pre drill G & G activities have been completed in Jharia block. Nine pilot wells have been released and eight bore holes and two exploratory locations have been firmed up in Parbatpur area. Pre drill EIA studies have been completed.

• Execution of planned work.«; is in progress in the two blocks, one each in Bokaro and North Karanpura, awarded under CBM policy-1 jointly to ONGC and Indian Oil Corporation Ltd. In the both the blocks, G&G studies have been completed. In Bokaro block two exploratory and eight bore hole locations have been released out of which three bore holes have been completed and two are in progress. Two exploratory and nine borehole locations have been released in North Karanpura block, out of which drilling of three bore holes has been completed. Work on one bore hole is in progress.

• In the second round of bidding for CBM Gol has invited bids on 23rd May 2003 for nine blocks for CBM exploration and exploitation. After detailed analysis of the Blocks offered, ONGC submitted bids for six Blocks and has been awarded five Blocks, four on sole risk basis and one in consortium with GSPCL.

• ONGC presently holds nine CBM Blocks and has established itself as the leading company for CBM exploration in the country, of which 7 blocks have been obtained through CBM-NELP (PEL obtained for 5 blocks). The blocks awarded under the CBM NELP rounds are as follows:

Blocks / Area Awarded to

ONGC & Consortium

Existing Blocks / Area with

ONGC

No. Km2 No. Km2 CBM Policy-I 2 435 2 435 CBM Policy-II 5 2344 3 1,127 Total for CBM Policy

7 2779 5 1562

5. THRUST AREAS IDENTIFIED FOR ACCELERATION OF EXPLORATION Cambay Basin:

• Recent leads obtained along the eastern basin margin in Mansa, Limbodra, Gamij etc reaffirm this as a priority sector.

• Success at Degam -1 and Gandhar - 532 puts the flanks of Tankari and Broach depressions in high priority.

• Terrace features in and around Jambusar area. • The flanks of known fields e.g. Kalol, Wadu, Wasna, Nawagam and Sadra continue to prove the

extension of the established plays resulting in field growth. This remains an important sector for quick assessment of field growth. Rising flanks of Nardipur and Warosan Lows remain in focus considering the recent leads obtained therein.

• The deeper prospects in the Wamaj Low and over the Kalol high are future targets and are being covered by 3D seismic survey for a better sub-surface image.



• Considering the series of success in Oligo-Miocene prospects in the CB-OS-2 block, Olpad-Dandi-Kim area has attained a special thrust for probing similar structures in the onland part. Accordingly, 3D seismic data is being acquired in the entire area for a focused exploration.

Rajasthan Basin:

• The hydrocarbon find in Lower Goru and Pariwar play in Chinnewala Tibba in the western part of Jaisalmer-Mari high has only confirmed the thrust assigned to this sector. This sector attains the highest priority and is being covered by 3D seismic survey.

• Exploration for new plays in Cambrian and Permo-Triassic sequences (though got delayed pending environmental clearance for the site) remains a high priority.

A&AA basin:

• Banamali- Laipling-gaon -Kuargaon for explorationof Barail plays, • Panidihing-Disangmukh area for exploration of Pre-Barail plays • East Lakhibari-Merapani Sectors for Sylhet and Kopili plays • South of Nambar for Bokabil, Kopili and Syhet plays • Manikyanagar-Sonamura and Tichna-Gojalia for Bokabil and Bhubal plays

K.G. Basin:

• Major emphasis on the shallow offshore area (GS-29, GS-15 and GS-KW) to explore Mio-Pliocene sequences.

• Amalapuram block identified for focused exploration based on the leads obtained recently in PSD-36, SR-2 and GM-3&4.

• Based on the lead obtained in Kesavadaspaplem-6&7, coastal tracks of Island and amalapuram blocks have been identified as a focused area for exploration of Matsyapuri play.

• Tirupati play in Kavitam and Penumadam area. • Northern part of West Godavari sub basin and Kaza-Kaikalur high to chase the leads obtained

recently. Cauvery Basin:

• Gulf of Mannar sector: Deliberate thrust in this Frontier sector during last 2 years to realize the potential including the extension in the deep water areas. Visualized extension of Nannilam and Kamalapuram play to this sector.

• Tranquebar sector: Significant success achieved in exploration for Andimadam oil & gas play in Kuthalam- Kali areas. Play extension being pursued in NW rising flank of Tranquebar sub-basin.

Mumbai Offshore Basin:

• Tapti-Daman sector: Strati/ Structural prospects of Mahuva, Daman and Mahim clastics; Eocene carbonate wedges/mounds along East-Daman carbonate bank; Isolated Palaeocene Dolomitic Carbonate over Basement High.

• Heera-Panna-Bassein: Focusing Bassein Lower pay along the Rift shoulder areas on either side of central graben covering B157, Vasai West, B182A and down to Ratnagiri areas; Inversion structures in the Central graben and other Palaeo lows covering Bassein East and East of Neelam; Strati-structural play within Bassein, Mukta and Miocene build-up along the upthrown



side of Diu fault; Strati-structural play within Panna Formation, specially in the area girdling the Basement Highs

• Bombay High-DCS: Wedgeout prospects of Palaeogene carbonate along Bombay pericline; Miocene Reefal plays along shelf margin and along Diu fault; Structural plays of Palaeogene and Miocene carbonates; Clastic play within Panna formation along the rising flanks of southern palaeo-sink, basement spurs.

Deep water sector:

• Mio-Pliocene play in K.G. deep offshore in G-4, KD, GO and off Yanam (KG-DWN- 98/4 and KG-DWN-98/5 area).

• Oligo-Miocene play in Mahandi deep water. • Mesozoic play in Kerala-Konkan. • Tertiary carbonate play in Kutch sector.

Yet to establish basins:

• Bengal and Mahanadi offshore: • Large turbidite plays. • 3D seismic data acquired in Bengal and Mahanadi shallow offshore indicates significant geo-

bodies with good potential. 3D seismic under acquisition in Mahanadi deep water. • Potential evaluation in this new sector promises exciting breakthrough in next 2-3 years. • Kutch shallow offshore: Mesozoic play in shallow water • Kerala-Konkan: Eocene carbonate and Mesozoic play

6. DEVELOPMENT DRILLING: During 10th Plan 622 development wells were projected. During the first two years of 10th Plan 387 development wells were drilled against BE target of 372 wells. During 2004-05 BE 182 development wells are planned. 7. PRODUCTION OF CRUDE OIL, NATURAL GAS AND VALUE ADDED PRODUCTS: Crude Oil: The 10th plan target for crude oil production was 130.026 MMT. The cumulative achievement in respect of first 1wo years (2002-03 BE & 2003-04 BE) is 52.062 MMT which is 99.6%. There was a shortfall of 0.326 MMT during 2003-04, the reasons for shortfall are:

• Increase in water cut and seizure of wells in Gandhar, Ankleshwar, Jambusar, Sisodra, Motwan and Dabka.

• Environment problems in Assam and ASEB power disruptions. • Less contribution from EOR wells of Santhal and Balol fields in Mehsana Asset. • Rapture in the MUT trunk pipeline.

Gas Production: The 10th Plan target for gas production was 112.10 BCM. The cumulative achievement during first two years is 47.56 BCM which is 101.16% of 2002-04 (BE) targets.



Natural Gas Sales: The 10th Plan target for gas sales was 90.136 BCM. The cumulative achievement in respect of first two years of 10th plan is 38.51 BCM which is 100.81% 2002-04 (BE) target. Value Added Products: The 10th Plan target for value added products was 15156 KT. The cumulative achievement in respect of first two years of the 10th plan is 7422 KT which is 110% of the total 2002-04 (BE) target. 8. INITIATIVE TAKEN TO ENHANCE PRODUCTION OF OIL & GAS: As mentioned earlier Improved Oil Recovery (lOR)/ EOR in 15 major fields are under different stages of Implementation. Further six new IOR schemes have been started in onshore areas namely Linch, Nadasan in Mehsana Asset, Ungala in KG Asset and Narimanam, Kovilkalappal, Nannilam in Karaikal Asset. In addition to above, ONGC has taken/is taking various actions for maintaining/augmenting the crude oil and natural gas production as mentioned below, apart from focusing on optimisation of artificial lift, additional perforation/re-perforation, and work-overt stimulation of wells:

• In an effort to reduce cost of offshore well servicing work-over with modular rig was conceived and Rig Sundowner -VI has commenced operations from 8.6.2003 at IK Platform. The work-over operations by this concept are not only cost effective but also independent of pugmark of jack up rigs and seabed survey. Also no docking constraints envisaged with this concept.

• Solid Expandable Tubular (SET) is a new technology being adopted in Mumbai Offshore for cost effective side tracking of wells in L-III middle layer. These wells save time taken to drill/sidetrack in L -III middle layer.

• Self Diverting Acid (SDA) like Visco-elastic Diverting Acid (VDA), Insitu Cross-linking Acid Development Agent (ISCADA) etc. jobs are being taken up as a new pilot introductory technology in wells of Mumbai High field to improve oil production.

• Application of gel/polymer technology to control production of excess water and gas. • Specialized drilling techniques like horizontal drilling, drain hole drilling, side tracking,

Extended Reach Drilling (ERD) and multilateral drilling are being adopted to improve well productivity.

• Polymer flooding in Sanand field of Ahmedabad Asset. • Alkali-Surfactant EOR pilot in Kalol field of Ahmedabad Asset. • Alkali-Surfactant-Polymer (ASP) EOR pilot in Jhalora and Viraj field of Ahmedabad asset, Lakwa

field of Assam asset and in S3-1 and 54-3 of Ankleshwar asset. • Rigless workover jobs through Coil Tubing Unit (CTU). • Workover jobs without killing pay zones (using clean plug). • Laboratory studies for EOR processes like SWAG, WAG, ASP, Air injection, MEOR as pilots have

been completed for a number of fields and feasibility studies are in progress. • Miscible gas injection in GS-12 sand of Gandhar field. • Water Alternating Gas (WAG) injection pilot project at GS-4, GS-9, and GS-11 sand at Gandhar

field of Ankleshwar Asset. • Putting newer fields on stream as quickly as possible by drawing technological schemes of

development and its implementation. Three-pronged strategy is being adopted for small/marginal field development as under:

o In-house development.



o Alliance with profit sharing with other E&P companies. o Through service contract.

9. REALISATION OF POTENTIAL FROM SMALL/MARGINAL FIELDS In-house Development: Three offshore fields viz. G-1, D-1 and Vasai East are considered under in-house development. The development scheme for 0-1 is under execution. Schemes for development of Vasai East and integrated development of G-1 & GS-15 have been approved by ONGC board on 22.04.2003. Revised FR for integrated development of G-l & GS-15 was approved in PAC meeting held on 25.3.2004. Development of marginal fields through outsourcing: In the first phase of the offer tenders were invited for 16 onshore marginal fields and eight fields namely West Becharaji, Khambel, Hirapur, S. Patan, Kamboi in Cambay basin and Laxmijan, Bihubar and Barsilla in Assam were awarded. Final contract for six fields- West Becharaji, Khambel, Hirapur in Cambay basin and Laxmijan, Bihubar and Barsilla in Assam were signed on 28.04.04. ONGC board has also approved outsourcing of 19 identified marginal offshore fields of Western Offshore on seNice contract for which process is in progress. 10. STEPS TAKEN TO REDUCE GAS FLARING: As per normal production practice, associated gas is produced along with crude oil as a by-product. The produced gas is first utilised for meeting internal requirements and the balance gas is offered/supplied to GAIL for further transportation, distribution and marketing. Low pressure associated gas/balance available gas th6t cannot be supplied to consumers or due to adverse techno-economic has to be necessarily flared. This is done as gas cannot be normally stored, neither can it be allowed to escape in the atmosphere without being burnt. Flaring of such gas therefore cannot be avoided. There is, however, no flaring of non-associated (free) gas except technical flaring. In order to ensure that there is no flaring of gas other than flaring due to technical reasons, various gas flaring reduction schemes were formulated, some of which have already been implemented while others are at various stages of implementation. On account of various initiatives taken to reduce gas flaring, gas flaring in ONGC has been considerably reduced from a level of 6% of production in 2001-02 to 3.5% of production in 2003-04. In order to reduce flaring of gas from isolated/marginal fields, ONGC has been empowered by MOP&NG for direct marketing of gas upto 1.0 LCMD from each of such fields provided GAIL is not able to identify consumers in these areas within six months time. Further gas supply agreement with Assam Gas Company Limited (AGCL) was signed on 23.01.04 for supply of 30,000 SCMD gas from isolated fields of Khoraghat and Namber in Assam under direct marketing. The importance of reducing gas flaring is well accepted in ONGC. Efforts to reduce gas flaring are a continuous process and ONGC is taking/planning further measures for additional gas collection/compression facilities.



It is pertinent to mention here that with the implementation of various gas flaring reduction schemes. ONGC's installation at Uran Terminal and Heera Offshore platform have achieved zero gas flaring status. Special drive has also been undertaken to achieve zero gas flaring at all installation by 2005-06. 11. PLAN OUTLAY & EXPENDITURE: The basis of 10th Plan revolved fundamentally around certain critical assumptions made at the time of formulation e.g. crude price of 18 $/bbl, Exchange rate of 47.5 Rs. /$, successes in ongoing exploration efforts, Intensive upgradation of old installations. Facilities and equipment and all these to primarily be funded through own internal resources. Considering the above the Plan outlays for 10th Plan were constrained to a base level if the primary assumptions were followed. After the formulation of the 10th Plan several major changes have come into being - Global, sectoral and within the company.

• On the Global front Oil prices have steadily remained at high levels than historical averages and than assumed for lOth Plan. Similarly Exchange rate which has seen reversal with the Rupee appreciating by Rs.2 to 2.5 against the US Dollar i.e. Rs. 47.50 1$ assumed in 10th Plan against Rs. 45-46/$ prevailing now.

• On the sectoral front Government has allowed International parity for crude price, which has benefited the company at two levels first by International pricing and secondly by sustained high International crude prices resulting in higher cash flows than planned in 10th Plan.

• At the company level there has been major reorganization and efforts to have sustained growth by having three Strategic Goals

• To double reserve accretion on Initial in-place hydrocarbons from 6 billion tonnes to 12 billion tonnes in next 20 years.

• Improve Global Recovery Factor from 28% to 40% by the year 2020. • 20 MMT per annum Equity Oil & Gas equivalent from overseas by 2020 through OVL.

During 2002-03 against an outlay of Rs. 7408 Crore, actual expenditure was Rs. 5089 Crore. Whereas in 2003-04 against BE target of Rs. 10265 Crore, the actual utilisation for the year 2003-04 is Rs. 6760.44 Crore (provisional). The activity wise expenditure is appended at Annexure-II. Reasons for less utilisation of plan outlay during 2002-04 are:

• Less utilization due to delays in hiring / mobilization owing to non-availability of charter rigs / deepwater rigs and less expenditure under capital purchases.

• Less expenditure under capital projects • Shortfall in drilling for want of environmental and security clearance. • Lower utilization in HQ expenses due to less expenditure in infocom projects than planned. • Delay in finalisation of contracts



Appendix-I

10th Plan Major Project's description Improved recovery projects: i) Mumbai High Redevelopment: Mumbai High field is the largest and most prolific field discovered so far in India. The field development has passed many challenges due to very large aerial extent, complex geology and multi-layered reservoir. A comprehensive review of the field was made in consultation with M/s Gaffney Cline & Associates and redevelopment strategy was chalked out. The proposed redevelopment programme in Mumbai High is a major step to arrest the decline and raise the recovery factor by around 5% i.e., from 25-26% to 30-31%. The redevelopment is planned in two projects namely: a) Mumbai High North Redevelopment b) Mumbai High South Redevelopment ii) Mumbai High North Redevelopment: ONGC board approved the project at a cost of Rs.2929.40 Crore. The scheme, with scheduled completion by December'2005, envisages incremental gain of 24.8 MMT of oil and 5.85 BCM of gas from 2000-2001 to 2029-30. The project envisages installation of 4 well-head platforms- nine slots each, one process platform with 1.9 MMSCMD gas compression capacity, 2,50,000 BWPD water injection capacity, drilling of 73 new wells 62 producers and 11 injectors) and 10 side track wells with associated pipelines & modifications. The scheme is being planned to be implemented by inviting 5 tenders. iii) Mumbai High South Redevelopment: The tentative cost of the project is around Rs 5255 Crore. The facilities envisaged drilling of 140 wells (133 producers + 7 injectors) including two S1 sand wells, 4 side tracks, 17 new well platform including ZA platform, 1 new process platform, bridge connected to BHS complex, submarine pielines, 8 clamp-on structures and modification and augmentation of facilities on various platform. The scheme will result in production of 35.95 MMT of additional oil and 9.63 BCM additional gas by year 2029-30. The recovery factor at the end of 2029-30 is expected to be 31.5%. iv) Heera Heera Field is situated 70 kms. South-West of Mumbai City in the Arabian Sea and 140 kms. South East of Mumbai High at an average water depth of about 50 meters. Based on geological data from exploratory wells it was proved to be one of the major hydrocarbon bearing structures in Mumbai Offshore Basin, with a number of reservoirs of commercial oil and gas accumulations in Heera field. Heera was discovered in 1990 and was developed in 1994. In order to improve the oil recovery, IOR scheme was proposed in Heera & South Heera Field. The incremental oil production is envisaged to be 3.19 MMT of oil and 0.553 BCM of gas during the period from 2003-04 to 2019-20. The project envisages installation of a 12 slot platform, drilling of 11 wells, laying of gas lift, well fluid and water injection lines and modifications at three platforms. The scheme was approved at a cost of Rs.309.08 Crore with scheduled completion of Jan'2004. v) Neelam Neelam field, located 10 km North-East of Heera and about 45 km South-West of Mumbai city, was discovered in Jan'87 in a water depth of about 60m. Neelam field covers an area of about 86 sq. kms. The



field was developed in phases and was put on commercial production in March '90. However, the full-fledged production commenced from June'94 through 11 well platforms. As per earlier development scheme it was envisaged to achieve the oil production of 29.35 MMT considering recovery factor of 26.75% till 2019-2020. A proposal for improved oil recovery in Neelam field at a capital cost of Rs.347.69 Crore was approved. The scheme proposed incremental oil & gas production of 2.06 MMT and 1.23 BCM respectively upto 2020 over and above base case. This shows increment of around 1.88% in recovery factor. The project envisages installation of 3 clamp-on structures on NLM-1, 2, 3, & 4 well platforms, up-gradation of process gas compressors, lying of pipelines and associated modifications. The scheduled completion of the project is July'2003. vi) Gandhar The field was discovered in 1984. The field has multi-layered reservoirs having oil and gas in 12 pays. Production from Gandhar fields started through Early Production System (EPS) in May 1986. IOR scheme was prepared for improving recovery, from entire Gandhar field covering an area of around 800 Sq. Kms at a cost of Rs. 473.23 Crore with an additional of inputs of 55 development wells. The IOR scheme envisages a cumulative production of 34.313 MMT of oil and condensate by 2019-20 from entire Gandhar field, out of which incremental production of 4.34 MMT of oil has been, envisaged w.e.f. 2000-01 till 2019-20 through IOR scheme. Average Recovery with lOR will be 30.13%, which shows improvement of 4.24% in recovery factor. The project comprises of drilling of 55 development wells, construction of 2 nos. of Group Gathering Stations, facilities for handling MP/LP gas at GGS-VI, up-gradation of feeder/collector pipelines, facilities for gas lift, compression facilities for low pressure gas and up-gradation of ETP. vii) North Kadi Discovered in late 1968, the North Kadi field is in the northern part of Ahmedabad - Mehsana block of Cambay basin. Hydrocarbon accumulation has been established in seven pays within lower Cambay shale. North Kadi is a major oil field in Mehsana area. The field has been developed in stages based on simulation studies carried out during the years 1981, 1987, 1989 & 1991. Based on the performance of drilled wells of earlier schemes, an IOR scheme was proposed which was approved at a cost of 62.86 Crore with scheduled completion by March'2003. The scheme envisages drilling of 33 Infill wells, Installation of Sucker Rod Pumps & Gravel Packs in all the wells, associated well fluid lines, construction of 1 GGS of 1000m3 Capacity. With the implementation of IOR scheme, improved oil recovery of about 1.09 MMT (1.7%) of OIIP will be achieved by further improving the recovery of the field from the present base case of 20.118 MMT (31.22%) to 21.215 MMT (32.93%). viii) Santhal Santhal field located in the heavy oil belt of Mehsana in Gujarat State was discovered in 1971. The field has been developed on 300m x 300m spacing, is on primary production since 1974. To augment the production rate and produce the bypassed oil, IOR scheme was approved at a cost of Rs.38.85 Crore with scheduled completion by March'2004. With the implementation of IOR scheme, by 2013, Improved Oil Recovery of about 0.326 MMT (0.6% of OIIP of 53.99 MMT) will be achieved by further improving the recovery efficiency of the field from present base case (Primary + EOR upto 2013) of 20.047 MMT (37.13%) to 20.373 MMT (37.73%). The project comprises of drilling of 23 infill wells, installation of SRP & Gravel packs, associated well fluid lines. The scheme was conceptualize to augment oil production rate and produce by passed oil by reducing the spacing of wells from 300 X 300 m to 212 X 212 m.



ix) Kalol Kalol field was discovered in 1961. Development of the field started in 1964 and consequently wells were drilled with 700 m x 700 m spacing. Even though the trial production started in 1964, full fledged development activity was undertaken in the late 80s. The improved oil recovery scheme was approved by ONGC board at a cost of Rs. 99.67 Crore with scheduled completion by March'2007. The project envisages drilling of 38 infill wells, zone transfer in 57 wells, hydrofracturing in 80 wells, change of artificial lift mode, installation of 2 compressors, power upgradation at 117 wells, installation of one heater treater at GGS-IX and associated well fluid lines. With the implementation of IOR scheme by 2020, improved oil recovery of about 2.65 MMT will be achieved by further improving the recovery efficiency of the field by 2.32 % from the present base case of 12.79 MMT (11.19 %) to 15.44 MMT (13.5 %). x) Jotana Jotana field discovered in 1977 is located 17 kms south west of Mehsana city. The field is on production since 1980. The present scheme is for improving oil recovery from Mandhali units, which comprises of more than 77% reserves. The scheme was approved by ONGC board at a cost of Rs. 53.24 Crore with scheduled completion by March'2004. The incremental gain envisaged is 0.96 MMT of oil in the period 2000-01 to 2019-20. The project comprises of drilling of 25 infill wells, modification of GGS, creating of water injection facility and the associated well fluid lines. The scheme was conceptualize to augment oil production rate. Additional oil gain envisaged from the scheme is 0.96 MMT. xi) Geleki Geleki field is situated towards the southern fringe of Upper Assam valley. Trial production began in August' 1970 and regular production started from August' 1974. The proposed project envisages maximize recovery with optimum inputs viz. drilling of 25 infill wells, 24 zone transfer, installation of 6 nos. HLW pumps and hydrofracturing in 10 wells in phased manner and creation of additional surface facilities such as ETP expansion with an anticipated cost of Rs. 343.05 Crore. The incremental recovery expected to be 3.942 MMT from 2001-02 to 2019-20. xii) Lakwa-lakhmani Lakwa field is located 32 sq. km east of Sibsagar town with its aerial extent of 70 sq. km. The field is under production since 1964. The improve recovery plan has been drawn to tap the undrained oil. The action plan envisages additional 34 infill locations (includes side tracks well), 44 zone transfer, 47 water shut off job and creation of additional surface facilities at an anticipated cost Rs. 345.10 Crore. The incremental recovery expected to be 4.941 MMT from 2001-02 to 2019-20. xiii) Rudrasagar Rudrasagar field is located south of Brahmputra river with its aerial extent of 30 sq. kms. The field is on produc1ion since 1966. To improve recovery from the field, an action plan has been drawn to maximize the recovery which invisages drilling of additional 34 infill location (includes side track wells), 10 water shut off jobs and creation of additional surface facilities such as High Pressure Gas Compressor for lift gas and ETP revamping/ expansion. The anticipated cost of the project is Rs.113. 90 Crore. Besides above schemes, during first two years of 10th Plan period the following new development, value addition and replacement projects were also approved by ONGC Board:



1. Development of D 1 Prospect D-1 oil field is located at a distance of about 200 Km SW of Mumbai city in the western offshore at the water depth of 85-90 m. A development plan was approved by ONGC Board on 25th September 2002 at a cost of Rs.310.32 Crore. The project envisages production of 4.57 MMT of oil over a period of 10 years (from 2006 to 2015). The work envisages fabrication and installation of one light weight 12 slots well cum water injection platform, Water injection capacity of 2500 m3/day, Installation of Electrical Submersible Pumps in all the producers for artificial lift, Sagar Laxmi processing facility with modifications/utility upgradation, Associated submarine pipelines and Drilling of 12 wells, 3 producers and 3 injectors each in phase-I & II. The scheduled completion of the project is March' 2005 (Phase-1) and March'2009 (Phase-II). 2. Development of Bassein East Bassein East field is located in the Heera-Panna-Bassein block, which is one of the highly explored and prospective areas of Mumbai offshore basin. The water depth over Bassein East field ranges from 40-Som. A development plan has been approved by ONGC Board on 22th April 2003 at a cost of Rs.985.17 Crore. The project envisages production of 6.185 MMT of oil and 3.175 BCM of gas over a period of 15 years. The facilities planned are 8 legged production, processing cum water injection platform bridge connected to BPA, 2 well platforms (BSEA-12 slots and BSEB-9 slots), Oil Handling Capacity �20000 BOPD, Water Handling -63000 BWPD, Submarine pipelines- 6 segments (38 Kms.). The project is scheduled for completion by March 2006. 3. Integrated Development of G-l & GS-15 Fields G- 1 structure is located in Bay of Bengal, off Amalapuram coast in Andhra Pradesh in the water depth of 267-300 m south east of existing G-15/23 offshore field. Discovery of hydrocarbon made in 1980 in this structure. GS-15 prospects are small oil & gas pools with marginal potential located in KG Offshore very near to the coast in the water depth ranging from 8 -15 m. A development plan has been approved by ONGC Board on 22th April 2003 at a cost of Rs.429.82 Crore. The project envisages production of 0.704 MMT of oil and 4.135 BCM of gas over a period of 10 years (from 2005-06 to 2014-15). The following facilities are proposed for development of the field: G-l Field:

• Drilling of 2 new sub-sea wells, Regaining of G-1-9 well • Sub Sea Manifolds and control system • 14 H x 30 kms common sub sea pipeline • Additional oil and gas processing and oil pumping facilities at onshore terminal • Pipeline to S. Yanam for transporting crude

GS-15 Structure:

• One monopod platform at GS-15- 1 with two well slots • Drilling of two new wells one each at GS-15- 1 and GS- 15-4 • 8� x 5 kms well fluid lines from GS-15-1 & GS- 15-4 to Y joint • 2� gas lift lines from onland terminal • Modifications on the existing GS-15-4 platform • Gas compression facility



4. C2-C3 & LPG Recovery from LNG, Dahej The project was approved by ONGC Board on 29th December 2003 at a cost of Rs.900.92 Crore. The project envisages setting up a unit to recover 566574 TPA of C2- C3 and 347065 TPA of LPG from LNG at Dahej. The scheduled completion of the project is June'2006. 5. Mumbai High Uran Trunk Pipeline The project was approved by ONGC Board on 29th December 2003 at a cost of Rs.2792.50 Crore as a replacement of earlier laid Mumbai-Uran Trunk line. The project envisages laying, burying, testing & commissioning of 30N Sub-marine Oil Trunk Line from MNW to Uran Shore Terminal, Laying, burying, testing & commissioning of 28" Sub-marine Gas Trunk Line from MNW to Uran Shore Terminal, Laying, testing & commissioning of Associated Feeder Lines to both Oil and Gas Trunk Lines, Hook-Up & Modification on Platform complexes and at Uran Shore Terminal, Instrumentation, Elect. System etc. and provision of 3 new MOL Pumps on NQ Complex.



Appendix-II

Progress of the Major Projects as end of March 2004:

Brief status of implementation is as under: Sl. No.

Project Approved on

Approved Cost Rs. Crore

Status of Implementation

1. Mumbai High North Redevelopment

16.12.2000 2929.40 Project is under implementation. Scheduled completion Dec. 2005. Out of 4 packages two packages MNCO & N11/N12 Platform completed. Work in progress in rest two packages. One more package is added as 3 Pipeline project and is under execution. No cost or time overrun for the project anticipated at this stage.

2. Mumbai High South Redevelopment

16.10.2001 5255.97 Project is under implementation. Scheduled completion July 2007. Out of 7 packages, two packages i.e. ZA Platform and MSCO completed. MSP process platform work is under execution with schedule completion by April 2005. After the review of the recently drilled wells, proposed platforms requirement reviewed and some platforms merged into 9 well platforms and pipeline & platform modification project. The work for the same awarded on 20.02.2004. 9 Clamp-on project added in scope of work and awarded on 14.11.2003. No cost or time overrun for the project anticipated at this stage.

3. IOR Neelam 11.01.2001 347.69 Project is under implementation. Scheduled completion July 2003. Out of 3 packages, two packages. Clamp-ons and PM&PL completed ahead of schedule on 04-05-01 and 3-11-02 respectively. Thira package Upgradation of PGC-part work i.e, overhauling & upgradation of 3 turbines completed and upgradation of D&R compressors is underway. There is no cost over run but the completion is likely to delay by 12 months as it took long time to negotiate with OEM of installed compressors.

4. IOR Gandhar 16.12.2000 473.23 Project is under implementation. Scheduled completion December 2004. Work planned in seven packages, out of which one package. Expansion of GGS-VI has been completed and process unit commissioned for package-II Construction of GGS-VII. Work on other four packages in progress. The seventh package i.e. ETP package has been deferred. All planned wells have been drilled. For the project as a whole, no cost overrun is anticipated at this stage.

5. IOR Lakwa 26.09.2001 345.10 Project is under implementation. Scheduled completion March�2007. Work on Gas Lift Compressor Plant is in progress. Package-II. Installation of three ETP-scheduled commissioning is March 2006 whereas Package-III. Installation of 10 Heater Treater is planned



for post monsoon 2006-07 and subject to review. No cost of time overrun for the project anticipated at this stage.

6. IOR Geleki 26.09.2001 390.90 Project is under implementation. Scheduled completion March 2007. Pre-award activities for Effluent Treatment Plant in progress. No cost or time overrun for the project anticipated at this stage.

7. IOR-Rudrasagar 15.09.2001 113.90 Project is under implementation. Scheduled completion March 2006. Work on Gas Lift Compressor Plant is in progress. Package II-Installation of ETP- completed as per schedule in Dec.' 2003. No cost overrun for the project anticipated at this stage.

8. D-l Prospect Dev 29.9.2002 310.32 Work awarded to M/s EIL at quoted price. Due to change in scope of work the cost has gone up.

9. G1/G15 Development

22.04.2003 429.82 Geotechnical investigation is in progress. For consultancy work awarded to M/s Intec Asia Pacific . Malaysia. NIT for onland export pipeline issued on 15.01.2004. EIA & RA studies are in progress at M/s NEERI. Nagpur.

10. Dev. of Bassein East

22.04.2003 985.17 NIT issued on 04.11.2003. The NOA date is 06 .04 .2004 wi th scheduled comple t ion by 3 1.03. 2005 (RFD).

11. Mumbai Uran Trunk Pipeline

29.12.2003 2792.50 NOA placed to M/s HHI on 9.1.2004. Pre-Engg survey for top side modifications and jacket face completed. Design Engineering is in progress.

12. C2-C3 Recovery Projects

29.12.2003 900.92 Recently approved.



Appendix-III-A Exploration Programme Implementation-Basin Wise( 2002-03)

2D (GLK/LK) 3D (Sq. km) Exploratory Wells BE Actual BE Actual BE Actual CAMBAY 440 1497 360 472 49 54 RAJASTHAN 300 1 1 UPPER ASSAM 100 47 280 344 21 22 ASS. ARA (CACHAR) 75 196 17 1 2 K-GODAVAR1 900 856 138 248 18 27 CAUVERY 300 416 130 289 18 19 BENGAL 100 1 TRIPURA 200 155 5 5 HF&GV 715 534 VINDH. & GOND. 14 TOTAL ONLAND 3130 3715 908 1370 114 130 MUMBAI OFFSHORE 1540 7301 1098 1098 22 15 KUTCH & SAURASH. 4000 2857 3 KERALA-KONKAN 32 1 IK-GODAVARI 192 192 3 3 CAUVERY 1035 1035 3 MAHANADI BENGAL SW 600 1119 1447 1447 1 EAST COAST DEEP WATER

842 842 3 2 WEST COAST DEEP WATER 5865 6035 2655 2655 3

TOTAL OFFSHORE 12005 17344 7269 7269 39 20 TOTAL ONGC 15135 21059 8177 8639 153 150

Accretion: Targets & Actuals

In-Place Hydrocarbon Accretion (O+OEG), MMt

2002-03 Basin X-Five Year Plan (2002-07) STP

BE Actual

Western Onshore 71.1 21.5 24.09 Western Offshore 302 55 54.95 A&AA 85.3 25.5 22.74 Krishna Godavari 64 11 11.82 Cauvery 26 8.7 14.5 Sub Total 548.4 121.7 128.1 Future Acreages 22 Total 570 121.7 128.1



Appendix-III-B Exploration Programme Implementation-Basin Wise (2003-04)

2D (GLK/LK) 3D (Sq. km) Exploratory Wells BE Actual BE Actual BE Actual

CAMBAY 670 652 360 553 47 45 RAJASTHAN 280 79 UPPER ASSAM 410 5 180 150 24 10 ASS. ARA (CACHAR) 177 30 20 3 K-GODAVARI 250 485 138 338 17 15 CAUVERY 325 405 138 331 22 17 BENGAL 1 1 TRIPURA 515 223 50 5 4 HF&GV 445 505 1 1 VINDH. , GOND.& SAT 295 133 1 TOTAL ONLAND 3190 2586 896 1470 120 94 MUMBAI OFFSHORE 3862 7798 23 21 KUTCH & SAURASH. 3000 763 3883 1 KERALA-KONKAN 1000 1 K-GODAVARI 200 150 6 3 CAUVERY 800 4 2 MAHANADI 100 402 1 BENGAL SW 958 1500 4 EAST COAST DEEP 2450 900 5119 3 2 WEST COAST DEEP 7500 7263 1068 10 1 TOTAL OFFSHORE 11500 3407 13888 18421 52 30 TOTAL ONGC 14690 5993 14784 19891 172 124

Accretion: Targets & Actuals

In-Place Hydrocarbon Accretion (O+OEG), MMt 2003-04 Basin X-Five Year Plan

(2002-07) STP BE Actual Western Onshore 71.1 18.75 28.36 Western Offshore 302 70 27.75 A&AA 85.3 23 16.49 Krishna Godavari 64 12 27.48 Cauvery 26 7.8 4.71 MBP 3 Sub Total 548.4 134.55 104.78 Future Acreages 22 Total 570 134.55 104.78



Appendix-IV

NEW FINDS DURING 2002-04 Year 2002-03:

1. Vasai West (B-22). Mumbai Offshore The discovery well B-22-5 is about 15 km west of Bassein field (water depth: 73 m) & was drilled up to 2110 m. The well flowed oil and gas from the Middle Eocene Bassein Formation (Lower & Upper) and gas from the Early Oligocene Mukta Formation. Another well SB-E was drilled to the NE & about 16.5 km from B-22-5 which flowed oil & gas from Bassein Fm.

Flow Rates Interval (m) Payzone Choke Size

Inches Oil (BPD) Cond (BPD) Gas (M3/d) 1972-56 Lr. Bassein 1/2 1774 10760 1945-43, 1942-37.5 Lr. Bassein 1/2 1050 7955 1799-87 Bassein Upp. 1/2 312 165503 1779-69, 1767-55 Mukta 1/2 82 38846

Testing Results: SB-E

2213-2201 Bassein 1/2 732 13538

2. Banamali, Assam Shelf. Assam and Assam-Arakan Basin Banamali prospect is located in the Northeast of Lakwa field and North of Safrai field in Sivasagar district of Assam. The discovery well Banamali-4, drilled down to a depth of 4200m has established hydrocarbons in Barail sands. Two objects in the Oligocene-Barail sands, have been tested of which one interval, 3990-97 m, has produced oil and gas during testing.

Testing results

Bean Size Flow Rate (m3/day) W/Cut Interval (m) Pay (mm) Oil Gas %

6 53 12233 6 5 47 9890 2 3997-90 BCS 4 30 6211 5

The areal extent of the structure is about 1.53 Sq Km. This hydrocarbon strike is significant as it has opened up the entire sector to the northeast of Lakwa field for exploration. In order to consolidate and append on this lead, four more exploratory locations have been identified for drilling and the area is also presently being covered by 3D seismic survey..



3. Laipling-Gaon, Assam Shelf, Assam and Assam-Arakan Basin Laipling-Gaon prospect is located in the North of Lakwa field in Sivasagar district of Assam and is about 20 KM ENE of Sivasagar (Sibsagar Town). The discovery well Laipiling-Gaon-1, drilled down to 3900m with an objective of Barail and Tipam sands, flowed oil and gas from Barail sands. Four objects, all in the Oligocene-Barail sands, with a cumulative thickness of 84 m have been tested as oil and gas bearing. The details are as follows:

Testing results

Interval (m) Pay Zone

(F i )

Bean Size (mm)

Gas (m3/d)

Liquidi (m3/d)

Remarks

3683-3660. LBS-I 6 17,434 113.6 Water cut 0.6%

3628-3602 LBS-II 6 40,000 81 Traces of water

3492-3473 LBS-V 6 30,000 82 -

3450-3434 LBS-VI 6 66,500 -

The areal extent of the structure is 6.0 Sq Km. This hydrocarbon strike is significant, as multiple stacked oil pools north of giant Lakwa-Lakhmani field have been established, opening up the entire sector for exploration. 4. GS-KW: (Krishna-Godavari shallow offshore basin): GS-KW is located about 4 km south-east of Kesanapalli-West oil and gas field, off the Amalapuram coast of Krishna-Godavari Basin, in the logistically difficult land-marine transition zone. The discovery well, GS-KW #1, at a water depth of 8.5m, was drilled to explore the hydrocarbon potential of reservoirs within Matsyapuri Formation and a sand layer in the interval, 2017 - 2019 m on testing produced 163 m3/d of oil and 17948 m3/d of gas through 8 mm bean. The testing result has established the extension of Matsyapuri play in the offshore area further south of Kesanapalli-West onland oil and gas field and also brings out the prospectivity of the land-marine transition zone. 5. GS-49 (Krishna-Godavari shallow offshore basin): GS-49 is located at about 8.5 km south-west of Kesavadasupalem (onland) gas field, in shallow offshore area of Krishna- Godavari basin off the Amalapuram coast. The discovery well, GS-49-2 was drilled at a water depth of 7.0 m to explore the hydrocarbon potential of Matsyapuri Formation. On initial testing five intervals, in Matsyapuri Formation produced gas as per the following details:

Testing results:

Gas Interval (m) Bean (mm)

m3/day Ft3/day Condensate

1711.0-1702.0 7 1,02,480 36,16,212 1627.0-1625.0 6 71,706 25,30,290 1498.0-1496.0 6 64,371 22,71,460 Traces



1462.5-1460.5 6 56,175 19,82,247 1362.0-1357.0 6 34,715 12,24,988 Traces

The testing result of this well has established the extension of multiple stacked gas bearing pools in Matsyapuri Formation, in onland gas field Kesavadasupalem field, to the offshore area further south-west and also highlights the prospectivity of the land-marine transition zone. 6. Chinnewala Tibba (Jaisalmer basin): The Chinnewala Tibba prospect is located in the western part of Jaisalmer Mari High around 12km north-west of Ghotaru field in Jaisalmer Basin of Rajasthan in the district of Jaisalmer bordering Pakistan. Discovery well Chinnewala Tibba-1 is the first well drilled on the prospect on an independent structural closure. The well was drilled to 2004m upto Pariwar Formation of Lower Cretaceous age. Out of four objects tested, two produced hydrocarbons.

Testing results:

Flow Rate (m3/day) Interval (m) Formation Bean Size (mm)

Gas Condensate 1901.0-09 Pariwar Fm 8 1,30,622 3.6 1685.5-89 Lower Goru Fm 6 69,127 2.4 (water: 10%)

The preliminary analysis of gas produced indicates a better quality of gas accumulation having a calorific value of the order of 7091-7109 Kcal/m3 as compared to the gas in adjoining fields of Ghotaru and Kharatar, where calorific value ranges from 1250 to 3100Kcal/m3. Year 2003-04 1. East Lakhibari, Assam Shelf Exploratory well, East Lakhibari-1 was drilled to a depth of 2547 m on a new prospect which is an up dip closure, located south west of the Borholla Field and 3.5 km west of the well, Gamariguri-1 in the Dhansiri Valley (Assam Shelf) to probe Kopili & Sylhet Formations and Basement, The Object-IV in the interval 2042.5-2044.5 m within the Sylhet Formation flowed oil @ 37.5 m3/d with little water through 5 mm bean. Additionally, gas has also been assessed based on electrolog analysis in the Kopili sand leading to the opening up of a new play in Borholla- Mekrang sector This has opened up a new area south west of the Borholla-Mekrang sector for further exploration. 2. Degam, Cambay Basin Exploratory well Degam-1 was drilled on northern rising flank of Tankari depression in the Broach block of Cambay Basin to explore Dadhar and Hazad sands. The well was drilled to a depth of 2247 m. Four objects, one in Ardol and three in Dadhar were tested by conventional method.



On initial testing, object-Ill in the interval 1745-1755m within Dadhar Formation flowed oil @ 32 m3/day thru 5 mm bean. This testing result has provided an excellent lead for exploration of Dadhar reservoir in the northern part of Broach depression. 3. NMT. Western Offshore NMT-2 (North of Mid Tapti-2) is an exploratory well in Tapti-Daman block targeted to 2880m with the objective to explore hydrocarbon potential of Daman, Mahuva and Panna Formation. The well was drilled down to 2880m (T.D) and terminated within Panna Formation. Object-l (2013-2011m ) within Mahuva Formation, on testing, flowed gas @1,53,312 m3/d and condensate @:201 BPD (API:59.65) through 24/64" choke. 4. Sitarampurarn, KG Basin Sitarampuram-2, an exploratory well in Amalapuram Block, East Godavari sub-basin, KG basin and located at about 2.5 km south-west of Sitarampuram-1 and 2.25 km south-east of Pasarlapudi-29, was drilled to a depth of 2267 m to explore hydrocarbon potential in Matsyapuri Formation and sands in Vadaparru Shale. The well encountered multiple hydrocarbon bearing sands in Matsyapuri Formation and Vadaparru Shale within depth range of 500-2500m. Out of the five objects tested, four have produced gas as per the details given below:

OBJ INTERVAL (m) BEAN FLOW RATE OF OIL/GAS 1 2496.5-2494.5, 2490.5-2489 6 Qg: 87,651 m3/d, Qc: 5.8 m3/d II 2247-2444 6 Qg: 81,121 m3/d, Qc: 18 m3/d IV 2037-2034 6 Qg: 73,198 m3/d, Qc: 12.11 m3/d V 1896-1890 6 Qg: 82,495 m3.d, Qc: 5.10 m3/d

The testing results in this well have opened up a new fault corridor, to the south of Pasarlapudi -29 block for exploration of sands within Vadaparru Shale. Exploratory well, Sitaramapuram-3, located SW of the discovery well Sitaramapuram # 2 in Amalapuram block, KG Basin was drilled to a depth of 1653 m to test shallower sands within Matsyapuri Formation. The testing results of the two objects are given below

OBJ INTERVAL (m) BEAN (mm) FLOW RATE OF OIL/GAS

I 1600.5-1602.5 6 Qo: 23 m3/d, Qg: 45600 m3/d II 499-502, 506.5-509.5 & 515-521 6 Qg: 23067 m3/d

The sand within Matsyapuri Formation tested as object-l in Sitaramapuram #3 has provided significant exploration lead in the form of an oil strike as the earlier well Sitaramapuram # 2 produced gas from deeper objects. The gas producing sand (Object-lI) is a new pool. Along with Sitarampuram-2 in which this sand was interpreted as gas bearing on the basis of log data, this has substantiated the potential of a new sub-conformity shallow level stratigraphic play in the Island-Amalapuram block of KG Basin.



5. G-4, Krishna Godavari Deepwater. The well G-4 # 2 on G-4 prospect, drilled to a depth of 2675 m to explore the hydrocarbon potential of Pliocene sequence is located in KG offshore off the coast of Yanam within the ONGC shallow water PEL block I-G at a water depth of 428 m. The prospect is about 38 km from the land and about 10 km to the east of GS-29 oil find. Geologically the prospect is a strati-structural feature with multiple stacked sand bodies within a Pliocene channel / fan complex. In the well, G-4#2, based on the drilling and log data, 5 para-sequences having 56 m net pay have been interpreted to be hydrocarbon bearing in this well within Pliocene sequence. One object was tested and has produced gas as per details given below:

Object Interval (M) Choke (Inch) Flow Rate Of Gas

1 2133.0-2130.0

2115.5-2114.5 32/64

4,12,169m3/day FTHP - 2350 psi

Traces of sand.

The hydrocarbon bearing sands identified in the present well has given a major fillip to exploration of Pliocene and Miocene sediments to the north, north-western and eastern part of G-4 structure. Based on this exploration lead, the available geoscientific data in the area is under further analysis to assess the upside potential in the area. Additionally, four locations have been released in the similar geological set up to the west of G-4 structure to target the Mio-Pliocene sequence. 6. Sonamura, A&AA-Tripura Sonamura prospect is located about 10 km south of Rokhia-Manikyanagar field and about 5 km SSE of well Rokhia -35 in Assam Arakan Fold Belt (Tripura) basin. Rokrua-41, an exploratory well was spudded on 30.06.03 on this prospect and drilled down tc a depth of 2553 m to explore the hydrocarbon potential of Upper and Middle Bhuban Formations. The well has encountered multiple pays as in the Konaban-Manikyanagar fields in the north but found to be thicker in this prospect. The details of the testing results are given below:

Object Interval (m) Bean Size ( )

Gas (m3/d)

Condensate (m3/d)

I 2034-2037 8 1. 1 6.502 1.50

II 1886-1895 & 1898.5-1905

8 1. 35.420 1.68

I I I - IV 1766.0-1767.0 8 76.896 1.13

1775.5-1776.5,

1784.0-1785.5,

1787.0-1788.0

The result has provided a definite lead for further extending the exploration towards south, there by, making the Konaban- Manikyanagar- Sonamura trend as multiple gas plays in Western Tripura.



Annexure-I Oil and Natural Gas corporation ltd. Mid term appraisal of 10th plan (2002-07) percentage distribution

of planwise outlay & expenditure SL. NO.

ACTIVITY Tenth Plan 2002-2003 2003-04 2004-05

Percentage w.r.t. Total Outlay

Target (BE)

Actual Expenditure

Target (BE)

Target (RE)

Target (BE)

A SURVEY * 5.14 8.90 11.30 8.54 8.01 8.55

B EXPLORATORY DRILLING *

21.85 21.80 26.58 30.87 22.88 31.34

C DEVELOPMENT DRILLING

24.37 23.19 26.00 16.77 17.66 18.66

D CAPITAL ACQUISITION

42.67 38.41 29.78 39.43 25.39 32.27

E R&D7 INSTITUTES 3.96 3.07 2.37 1.77 2.07 3.07

F JV PROJECTS DOMESTIC

2.00 4.64 3.97 2.63 2.34 3.10

G JV PROJECTS OVERSEAS /DIVERSIFICATION #

21.65

H TOTAL OUTLAY 100.00 100.00 100.00 100.00 100.00 100.00

* Inclusive of CBM, Deepwater & NELP. # Excluding advances



Annexure-II

Tenth Plan

2002-2003 2003-04 2004-05 Sl.

No. Activity

Approved Outlay

Target (BE)

Actual Expenditure

Variation w.r.t. target (BE)

Reasons for shortfall if any,

Target (BE)

Target (RE)

Variation w.r.t. target (BE)

Reasons for shortfall if any,

Target (BE)

Likely % Exp During 2002-05 (Cols 5+9+ 12) as %age of (Col 3)

Balance available for the last two years of the 10th Plan (Col. 3 minus Cols.

Suggested corrective steps, if any. with justification

1 3 4 5 6 7 8 9 10 I 11 12 13 14 15

A SURVEY * 1719 14 659 22 575.06 -84 16 876.23 851.51 -24.72 855.30 132.73 -562.73

B EXPLORATORY DRILLING *

7301 97 161472 1352.55 -262.17 3168.81 2430.84 -737.97 3134.13 94.73 384 45

C DEVELOPMENT DRILLING

8145.56 1717.62 1323.30 -394.32 172 1.04 1876.44 155.46 1866.43 62.20 3079.39

D CAPITAL PROJECTS AND

14260.14 2845.45 1515.62 -1329.83 4047.66 2697.18 -1350.48 322590 52.17 6820.438

E R&D /INSTITUTES

1323 85 227.63 12053 -107.1 181.29 220.28 38.99 307.05 4894 67599

F JV PROJECTS DOMESTIC

668.29 343.66 201.90 -141.76 270.09 248.45 -21.64 310.19 113.80 -92.25

G JV PROJECTS OVERSEAS

2300 00 230000 30000 -2600

H TOTAL OUTLAY

33418.95 7408.30 5088.96 -2319.34 10265.12 10624.70 359.58 10000.00 76.94 7705.29

* Inclusive of CBM, Deepwater & NELP # Excluding advances Note:- RE for 2002-05 not yet prepared



Annexure-III

2002-03 2003-04 2004-05 S.No ACTIVITY UNIT Tenth Plan Approved Target ' Target

(BE) Actual Variatio

n w.r.t. Target

Reasons for shortfall if any

BE Actual Variation w.r.t. Target

Reasons for shortfall if any

BE

Achievements in 2002- 03 and 2003-04 and targets for 2004-05 (BE) as% age of 10th Plan Targets

General comments and suggestions

1 CRUDE OIL PRODUCTION

MMT 130.026 25.897 26.005 0.108 26.387 26.057 -0.330 26.174 60

2 NATURAL GAS PRODUCTION

MMSCM 112105 23700 24244 544 23315 23584 268 22127 62

3 NATURAL GAS SALES

MMSCM 90136 19240 19436 196 18960 19073 113 17495 62

4 VALUE ADDED PRODUCTS

KT 15156 3246 3795 549 3228 3627 400 3003 69

5 (a) DEVELOPMENT METREAGE

K.M. 1163.96 406.26 425.33 19.07 431.45 412.72 -18.73 413.16 107

(b) WELLS Nos. 622 184 190 6 188 197 9 182 91

6 (a) SEISMIC SURVEYS 2D

GLK 35286 15135 21059 5924 14690 5991 -8699 5178 91

(b) 3D SKM 34834 6556 8639 2083 14784 19891 5107 15956 128

7 (a) EXPLORATORY METREAGE

K.M. 1575.53 41881 348.19 -70.62 491.86 324.79 -16707 499.91 74

(b) WELLS Nos 561 153 150 -3 172 124 -48 178 81

8 (a) RESERVES ACCRETION IIH

MMToe 538-553 121.7 128.1 6.4 134.55 104.78 -29.77 148.4 70



(b) UR MMToe 147.13 30.01 4073 10.72 30.9 33.67 2.77 40 78

Note: Reasons for shortfall are given in the write-up. * Firm Programme only

OIL AND NATURAL GAS CORPORATION LIMITED Plan (Domestic Exploration

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