CHARTER HIRING OF TWO (02) OR MORE MLT BMC JACK UP RIGS FOR THREE (03) YEARS

INSTRUCTIONS FOR FILLING & SUBMITTING FILE "ANNEXURE III STANDARD TECHNICAL SPECIFICATIONS"

Sl No. Bidder Noted and Confirms that

1 All the Worksheets herein this File, together forms the Techncial Requirement of ONGC Select

2 No contents of this File is to be altered, modified, deleted or omitted, except where instructed specifically. Select

3 Bidder to fill its offer details at Column D, E, F and G of the Worksheet named 'Exhibit A(ii)-Tech Specs' herein. Select

4 Offer details filled in the Column D, E, F, G are correct and supported by the documentary evidence. Select

5 Bidder to submit the documents as indicated in Column H of the Worksheet named 'Exhibit A(ii) - Tech Specs' herein. Bidder to also fill the page number of the submitted document, against the respective items of Exhibit A(ii) - Tech Specs. Bidder further confirms to maintain same Name and Format for the supporting documents, as mentioned in Column H. (for further details please refer the word file named 'Instructions for Technical Bid ' of the Tender) Select

6 Only Documents, submitted in pre-defined Name(s) as per word file named 'Instructions for Technical Bid ' of the Tender, shall be considered for Technical Evaluation of the Bid. Select

7 In case any of the equipment is offered under Modification as per Clause 3.6 of TBEC, Bidder to fill the details as per the proposed modifications and the same should be duly supported with the Documents as per relavent BEC Clause. Select

8 Bidder confirms and undertakes that all the documents in the support of its offer has been submitted in line with the procedure enumerated in the file "Instructions for Technical Bid " and the conditions therein, as per the tender. Select

9 Note: Following changes has been made in the Technical Specification w.r.t. Empanelment tender (Highlightes in the respective sheets): (a) Annexure-III, Exhibit A(ii)-Tech Specs, Sl. No- 47. Water Maker: (b) Annexure-III, Exhibit A(ii)-Tech Specs, Sl. No- 14. Accommodation: (c) Annexure-III, Exhibit A(ii)-Tech Specs, Sl. No- 22. Crane: (d) Annexure-III, Exhibit A(ii)-Tech Specs, Sl. No- 21. Rig Power and Power Management (e) Annexure-III, Exhibit A(iii)-Schedule of responsibility, Sl. No. 1 to 6 & 15.

SCOPE OF WORK Scope of Work Agreed, unconditionally Select

300’ Independent leg Cantilever Type Jack-up rig

I. To provide complete drilling rig and equipment confirming to the broad and general standards as mentioned in the technical specifications of the tender at File Annexure-III Standard Technical Specifications (Exhibit A(ii)) of the tender document.

II. To provide capable and experienced rig crew personnel as per 4.2 in Annexure-II of tender document in accordance with the list provided at File Annexure-III Standard Technical Specifications (Exhibit-B) ‘List of Crew ‘of the tender document.

III. The ‘Scope Of Work’ to be carried out in accordance with the various articles at File Annexure-III Standard Techncial Specs including Schedule of Responsibilities at File Annexure-III Standard Techncial Specs (Exhibit A(iii)) of the tender and to take up the job mentioned as under:-

300’ Independent Leg Cantilever Type Jack-up rig for Drilling Exploratory/ Development, Directional, High angle wells up to depth of 6000 Mtrs including short drift side track, drain hole, multilateral hole drilling, Re-entry in the well and well control in anywhere in Indian offshore.

SPECIFICATIONS OF 300’ INDEPENDENT LEG CANTILEVER TYPE J/UP RIG

Sl No. Technical Specification Details to be filled by Bidder Reference / Remarks

1 Type of Rig The Jack-up Rig(s) is/are to be of Cantilever type, Self-elevating, Independent legs, which can operate round the year in weather conditions prevailing in West-coast and East-coast offshore India. Meteorological and Oceanographic parameters, based on data available with ONGC are given at Exhibit A(ii) -Appendix-2. (Bidder to submit certificate by the Underwriter / Marine Warranty Surveyor as mentioned in BEC to affect that offered Rig meets the parameters at Annexure III Exhibit A(ii) -Appendix-2. Contractor

Date of construction

MODU Code As per MODU Certificate

Load Line Draft

Operating Draft

Design Criteria

Certificate by the Underwriter / Marine Warranty Surveyor as mentioned in BEC to affect that offered Rig meets the parameters at Annexure III Exhibit A(ii) -Appendix-2. Select Document-5, Page No……...

Limiting Factor :

Any damage to legs or vessels recorded in past and any repairs/rectification carried out

2 Design of Rig MLT-116 / BMC-300 or Equivalent Design of Rig

3 SPUD CAN Spud Can pressure with full pre load should not exceed 39 Ton/Sq Meter Confirm that the Spud Can pressure with full pre load should not exceed 39 Ton/Sq Meter: Select Document-5, Page No……..

Details of Spud Can Pressure (MT/Sq Meter) Document-5, Page No……..

Spud Can Dimensions

4 Operating Water Depth Capability Minimum Operating Water Depth: 30 feet Maximum Operating Water Depth: 300 feet No weightage will be given for lower or higher Water Depth Capability. Minimum Operating Water Depth (ft) Document-5, Page No……..

Maximum Operating Water Depth (ft)

5 Drilling Depth Capability Rig(s) should be capable of drilling exploratory/ development, high angle wells up to a depth of 6,000 metres and for work over operations including short drift side-track, long-drift side-track, drain hole & multi-lateral hole drilling, re-entry in the well and well control. Drilling Unit: Contractor confirms categorically that all the offered equipment’s are compatible with the drilling depth rating of the rig Select Document-5, Page No……..

(a) Depth rating of rig

Hoisting equipment

(a) Mast (Derrick)

(b) Load capacity Document-5, Page No……..

Racking capacity

Last inspection on

(c) Draw works Document-5, Page No……..

(d) Crown Block Document-5, Page No……..

(e) Traveling Block Document-5, Page No……..

Drilling line Document-5, Page No……..

Rotating equipment Document-5, Page No……..

(a) Rotary table

6 Illumination Illumination of light on various places on the rig should be as per API RP 14F standard. Illumination of light on various places on the rig are as per API RP 14F standards Select Document-5, Page No……..

7 Leg Length Total useable leg length below the hull should be minimum 350 feet (a) Useable leg length below the Hull (Feet) Document-4, Page No…….. Document-5, Page No……..

(b) Total leg Length (Feet)

(c) Drill Slot Dimensions (Feet)

(d) Distance between Aft (Port & Star board) Leg centers (Feet)

(e) Distance between Forward and Aft (Port / Star board) Leg centers (Feet)

(f) Distance between Aft (Port / Star board) Leg centers and Hull Stern Edge (Feet)

8 Jetting System The rig should be equipped with low pressure and high pressure of leg jetting system. High pressure system should be of minimum 1500 psi and the jetting lines should be of same pressure rating. High Pressure (psi) (Specify Pressure rating)

Low Pressure (psi)

Confirm that the pressure rating of jetting lines are similar to high pressure rating Select

9 Variable Load (excluding hook load) Variable load capacity, should be minimum 1600 Metric Tons (3527 Kilo pounds) during Drilling Conditions / Operations. The variable load capacity during jacking, Afloat, & Storm conditions shall be governed by the Marine Operating Manual approved by the respective Classification Agency of the offered rig. Bidder to submit the Marine Operating Manual for the offered rig along with the Bid. The Variable Load offered should be at Maximum footing reaction / bearing pressure (Spud-Can) allowable as per design for the Drilling Unit, during drilling conditions / operations. Note: The Variable Load capacity of rig should be such that there is no offloading of Contractor’s material while rig is in Jacking mode or Afloat. In case of any offloading, same shall be at the contractor’s account. Variable load in Metric Tons/Kips (excluding hook load) Select

(a) During Drilling Conditions / Operations Document-5, Page No…….. Document-4, Page No……..

(b) During Jacking/Afloat condition Document-5 &4, Page No……..

(c) During Storm condition

The variable load capacity during jacking, Afloat, & Storm conditions shall be governed by the Marine Operating Manual approved by the respective classification agency of the offered rig. Select

Bidder submitted the Marine Operating Manual for the offered rig along with the Bid. Select

The Variable Load offered should be at Maximum footing reaction / bearing pressure (Spud-Can) allowable as per design for the Drilling Unit, during drilling conditions / operations. Select

Confirm that there will not be any offloading of Contractor’s material while rig is in Jacking mode or Afloat at the time of rig move. In case of any offloading, same shall be at the contractor’s account. Select

10 Cantilever Movement Minimum longitudinal movement of cantilever should be such that centre of rotary table can be extended 45 ft. from the stern of the rig. Minimum transverse movement of the substructure should be such that center of rotary table can be skidded 12 ft port & starboard side from center line of the rig. Rotary Centre line movement from Stern of the SHELL

i) LONGITUDINAL (feet) Document-5, Page No…….. Document-4, Page No……..

ii) TRANSVERSE FROM CENTRE LINE (feet)

Distance rotary table center to the edge of the outer side of the rig floor (feet)

11 Jacking System Rack & pinion type. The rig should have capacity to jack up with full variable load permissible during afloat/ moving and Contractor should submit documentary evidence to this effect. Mooring Winches should be in operating condition. 1) Jacking system Document-5, Page No…….. Document-4, Page No……..

Pinions capacity during

c) Jacking/Operation

d) Emergency jacking

e) Wedges if any

2) Derrick Skidding system

3) Preload requirement/Capacity

b) Anchor Wire Line

d) Other equipment

ii) Towing arrangement (describe)

e) Mooring Winches are in operating condition Select

f) Rig should have capacity to jack up with full variable load permissible during afloat/ moving Select

g) Contractor should submit documentary evidence to this effect Select Document-5, Page No……..

12 Cellar Deck and Texas Deck: • Cellar Deck • Texas Deck Note: Both the decks should be available on the rig Cellar deck Select Document-5, Page No……..

Details of Cellar Deck

Texas Deck Select

Confirm that both the decks are available on the rig Select

13 Raw Water Tower Pumps: Deep well Pumps at Raw Water Tower of adequate capacity. i) Make Document-5, Page No……..

Capacity per day

Capacity per day

Capacity per day

14 Accommodation Air-conditioned accommodation for not less than 90 persons. Office: Company-man, Geologist and Chemist shall each be provided with computer (with Internet Connectivity) and printer including consumables like cartridges and stationery. Contractor to ensure availability of minimum 2Mbps bandwidth for ONGC. Quarters compliments (No. of men) Document-4, Page No…….. Document-5, Page No…….. Document-5, Page No……..

Office accommodation

Office: Company-man, Geologist and Chemist shall each be provided with computer (with Internet Connectivity) and printer including consumables like cartridges and stationery. Select

Contractor to ensure availability of minimum 2Mbps bandwidth for ONGC. Select

15 Pollution Control Equipment Suitable Sewage Treatment Plant meeting required standards for the treated affluent discharge. Make Document-5, Page No……..

Certified functional by

16 Mud Pumps 2 Nos. Triplex Mud Pumps each rated for minimum 1600-1700 HP with pressure rating of 5000 psi complete with suitable supercharging pumps and two no. GE752 or equivalent electric motors and suitable pulsation dampeners. Contractor has to provide 5 1/2”, 6”, 6 ½” & 7” Liner along with Mud Pumps. Note:- Contractor has to ensure the availability of rated pressure of 5000 psi lines and manifolds. Pumps should be capable of pumping @ 1100 GPM at rated working pressure of respective liner sizes. Contractor to submit the data sheet of the Mud Pumps. Rig should be equipped with strainer on suction side of Mud Pumps. Total No. of Mud Pumps Select Document-4, Page No…….. Document-5, Page No……..

1) Mud Pump 1 2 3 4

Available Liner and Piston sizes in Inch 5½” 6” 6 ½” 7”

Discharge (GPM) as per Liner Size(s)

Max. Pressure (psi), as per liner Size(s)

Details of Pulsation Dampeners

Details of Supercharger Pumps

Provision of Suction Strainer and Dampeners Select Select Select Select

Mud Pump Data Sheet submitted Attach at Document 10

2) Rotary Hoses Details:

Pressure Rating

End Connections

3) Contractor has to ensure the availability of rated pressure of 5000 psi lines and manifolds. Pumps are capable of pumping @ 1100 GPM at 3980 psi Select

4) Contractor has to provide 5 1/2”, 6”, 6 ½” & 7” Liner along with Mud Pumps. Select

17 Mud Mixing System: The system should consist of the following: - (a) Mud Mixing System consisting of 2 Nos. Low Pressure Hoppers and electric motor driven suitable centrifugal pumps with separate suction and discharge lines from / to each mud tank. (b) Jet shearing device The shearing unit shall be independent from the mixing hopper. It shall work on the principle of Centrifugal mechanism. The shearing unit shall have feed pump and shall be able to shear the mud independently from tank to tank. The shearing unit must have replaceable shearing sleeves. The pumps shall be equipped with mixer which shall have inbuilt rotor and screen. (High shear and emulsion type) The shearing unit shall process a minimum 250-350 GPM handling capacity. It shall maintain the pressure of 40Psi. Unit shall be VFD/ Electrical driven. (c ) Slug tank (d) Chemical mixing tanks (e) Suitable transfer pumps (f) Total mud volume capacity excluding Base oil tank and sand trap should be Minimum 1750 bbls. (g) All mud tanks to be provided with mud agitators, bottom guns and drill water, Seawater & base oil supply lines. (h) There should be independent lines for chemical loading (hopper lines) and mud transfer. (i) Area of sack room should be sufficient enough to accommodate minimum 35 MT chemicals and must be equipped with Forklift. a) Mud Mixing System consisting of 2 Nos. Low Pressure Hoppers and electric motor driven suitable centrifugal pumps with separate suction and discharge lines from / to each mud tank. Select Document-4, Page No…….. Document-5, Page No……..

b) Jet Shearing Device as per specs required Select

c) Slug Pit (bbl)

d) Chemical Mixing Tanks (bbl)

e) Provision of Transfer Pumps Select

f) Mud Tanks 1 2 3 4

Volume (BBLS) Note: Vol. in Bbls

Agitator Select Select Select Select

Mud guns Select Select Select Select

Mud Tanks 5 6 7 8

Volume (BBLS) Note: Vol. in Bbls

Agitator Select Select Select Select

Mud guns Select Select Select Select

Total mud tank capacity (inclusive of slug pit & chemical mixing tank) excluding base oil tank and Sand Trap (bbls)

(g) All mud tanks are provided with mud agitators,bottom guns, Drill water, Sea Water and base oil Supply Lines Select

(h) There should be independent lines for chemical loading (hopper lines) and mud transfer Select

(i) Area of sack room should be sufficient enough to accommodate minimum 35 MT chemicals and must be equipped with Forklift. Select

18 Mud Processing Equipment (a) A suitable number of Scalping type Shakers and gumbo removal. (b) A minimum of three (3) Nos. Shale Shakers equipped should be able to run at min 7G continuously and must have a deck angle adjustment range of minimum 5 degree and/or a G-force booster system along with replacement Screens (API Screen No 20 to 325 as per API RP 13C designation). Each Shaker should be capable of handling a minimum of 350 GPM using API No. 120 screens when running 12.0ppg water based mud. The Shale shakers must be Linear / Balanced Elliptical / Progressive Elliptical / Tuned Elliptical Motion shale shakers of NOV Brandt/ Thule/Derrick/ MI Swaco/ Axiom make only. Screen sizes should be available from API Screen No 20 to 325 (API 20, 40, 50, 60, 80, 100, 120, 140, 170, 200, 230, 270 & 325) SHALE SHAKERS 1 2 3 4

(a) Scalping type/Conventional type Shale Shakers and gumbo removal. Document-5, Page No……..

Mfgr. Select Select Select Select

(b) Linear / Balanced Elliptical / Progressive Elliptical / Tuned Elliptical Motion shale shakers Document-5, Page No……..

Mfgr. Select Select Select Select

Each Shaker should be capable of handling a minimum of 350 GPM using API No. 120 screens when running 12.0ppg water based mud Select

Minimum G Force ' G'

The above shale shakers will be provided with replacement API Screen No 20 to 325 as per API RP 13C designation Select

c) Screen Washer: High Pressure, low volume water spray system or base oil spray system along with portable tank and pressure gauze monitoring. High Pressure Low Volume Water Spray System or base oil spray system along with portable tank and pressure gauze monitoring Select Document-5, Page No……..

(d) Mud Cleaner, capacity 800-1000 GPM equipped with De-sander and De-silter. NOV Brandt/ Thule/Derrick/ MI Swaco/ Axiom make only Mud Cleaner equipped with De-sander and De-silter Document-5, Page No……..

Capacity (GPM) In GPM

(e) Degasser, capacity 800-1000 GPM Degasser Document-5, Page No……..

(f) Mud Gas Separator (Poor Boy Degasser) Mud Gas Separator (poor-boy degasser) Document-5, Page No……..

(g) Centrifuge: Two Nos. Mud Centrifuge with fully variable speed independent main drive and back drive motors and a maximum G force of 1900G or more and with : Bowl size – 14 inch to 18 inch Bowl speed (rpm) – 3000 or more (variable) Feed Volume –240 GPM or more OR Two mud Centrifuges for low gravity solid control and barite recovery with minimum Bowl diameter of 14”, variable bowl speed of 3000 rpm or more (hydraulic / electric drive), Feed rate of about 240 GPM and a maximum G force of at least 1900G. Two Nos. Mud Centrifuge with fully variable speed independent main drive and back drive motors and a maximum G force of 1900G or more OR Two mud Centrifuges for low gravity solid control and barite recovery with a maximum G force of at least 1900G Select Select Document-5, Page No……..

Bowl size (Inches)

Bowl speed (rpm) 3000 or more (variable)

(h) Mud Lab & Mud testing equipment (as per Exhibit A(ii) - Appendix 8-I) Details of Mud testing equipment as per Exhibit A(ii) - Appendix 8-I Select

(i) Facilities for handling SOBM: (as per Exhibit A(ii) - Appendix 8-J) Base Oil storage capacity – 800 bbls (minimum) (i) Facilities for handling SOBM as per Exhibit A(ii) - Appendix 8-J Select Document-4 &5, Page No……..

Base oil storage capacity (bbls) Vol. in bbls

(j) Brine filtration unit Brine Filtration Unit as per specification at Exhibit A(ii) - Appendix 7 Select Document-5, Page No……..

k) Spares of mud handling equipment and shale shaker screen must be of OEM Make. k) Spares of mud handling equipment and shale shaker screen must be of OEM Make. Select

19 Trip Tank: One trip tank of adequate capacity, complete with centrifugal pump and mud level indicator readable from the driller’s station, sensitivity ½ bbl Trip Tank Document-4&5, Page No……..

Trip tank complete with Centrifugal pump & Mud Level indicator readable from Driller’s station Select

20 Top Drive System Electric “Top Drive System” with all accessories including pipe handler. Capacity minimum 500ST, Torque rating continuous 40,000 ft-lbs minimum. Maximum Speed Rating should be 200 RPM or more. Speed at continuous torque of 40,000 ft-lbs should be 100 rpm or more. Details of Top Drive System – Electrical Document-5, Page No……..

a) Manufacturer

c) Capacity (ST)

d) Torque rating

i) Continuous ft-lbs at RPM

ii) Intermittent ft-lbs at RPM

e) Maximum Speed (RPM)

f) Speed (RPM) at continuous torque of 40,000 ft-lbs

h) Power requirement Power Source

i) Inside BOP : Rating

i) Upper (psi) - 10K

ii) Lower (psi) - 10K

j) Pipe Handler details

Tonnage Capacity

Torque (ft-lbs)

21 Rig Power and Power Management The rig should have Power Packs having minimum power of 6000 HP. (Excluding power of emergency generator) Rig should have any of the following power management system (i) AC-SCR (ii) AC-VFD Contractor should clearly mention the type of power management system available on the Rig. In case of AC-SCR, minimum power available at Bus bar should not be less than 5400 HP Reduction of carbon Footprint: 1. The engines and alternators should be new or capital overhauling should not be pending as per norms of OEM 2. Contractor should provide the maintenance schedule as recommended by OEM to OIM and submit the report of the timely maintenence as per schedule to the Company-Man. 3.The Power pack (Rig Engines) shall be equipped with system that shall provide real time engine parameters like HSD consumption, load factor, power factor & running hours for each individual engine. System should be equipped for real time monitoring of HSD consumption for the miscellaneous equipment also. It should also have real time monitoring system for at least SOx (sulphur oxides) and NOx (nitrogen oxides). The system shall provide the required real time data to rig instrumentation system and shall be available to ONGC from Rig instrumentation system in WITSML format. 4. Genset (Optional) to be installed with suitable capacity to supply power during idling period with an intention to optimize carbon footprint. Emergency Generator: Rig Power and Power Management

No. of Engines Document-4, Page No…….. Document-5, Page No……..

No. of Alternators

Power available at bus bar

Power management system: Select

If AC-SCR, is the SCR system compatible with the installed power packs Select

The engines and alternators are new or capital overhauled not pending as per norms of OEM Select

Emergency Generator

22 Cranes 2 or 3 Deck-cranes of adequate boom length & lifting capacity which can cover complete deck area / drill floor etc. Minimum, rated capacity of Port side crane should be 30 MT and Star Board Crane should not be less than 20 MT. The rated capacity of a crane is the maximum load that the crane can handle during loading and unloading from an OSV. Contractor should indicate the capacity of crane at each of the location i.e., Port, Starboard etc., Being a safety critical equipment, all the pedestal cranes on-board the drilling unit must be constructed under API Specification 2C and covered under Cargo Gear Register. In case the cranes are not part of Cargo Gear Register, the Contractor shall carry out and submit Annual inspections according to API RP 2D by a Qualified Crane Inspector and the respective inspection company should be approved by the relevant flag state under which the asset is registered. Cranes Document-4, Page No…….. Document-5, Page No……..

1. Location Port Side Startboard side other

Load Capacity Select Select Select Select

Portside Crane>= 30 MT Select

Starboard Crane>= 20 MT Select

The rated capacity of a crane (Off board capacity) is the maximum load that the crane can handle during loading and unloading from an OSV Select

All cranes on-board the drilling unit covered under Cargo Gear Register Select

In case the cranes are not part of Cargo Gear Register, the Contractor shall carry out and submit Annual inspections according to API RP 2D by a Qualified Crane Inspector and the respective inspection company should be approved by the relevant flag state under which the asset is registered. Whether Certificate submitted? Select

23 Casing Policy The Casing Policy to be used is 30”/26” (connector casing) x 20”/18.5/8” x 13.3/8” (61 ppf, 68 ppf) x 9.5/8” (43.5 ppf, 47 ppf & 53.5 ppf) casing up to surface and 7” (23 ppf, 26 ppf & 35 ppf) and 5” (15 ppf & 18 ppf) as Liner (all sizes included). Rig is equipped to handle the casings and Drill string as mentioned Select

24 Drill String/Tubular Goods Exhibit A(ii) - Appendix 6 Details to be provided at Exhibit A(ii) - Appendix 6 Select

25 Drilling Jar: (Make : NOV / Schlumberger /ITS/Dailey): One No. of double acting Hydro mechanical / Hydraulic Drilling Jars suitable for use in Drilling 17 ½”/12 ¼”, 8 ½” and 6” hole each. (min. upstroke length 12” and down stroke length 7”). Drilling Jar:

Make/Model Select Select Select Select

Confirm that the Jars will be supplied as per tender specification Select

Note: ID for 8” jar shall be 3” or more Select

26 Substitutes All Substitutes matching to Contractor’s drill string, fishing tools and Contractor supplied equipment and for bits, as per the Casing Policy to be used. Complete list of Substitutes to be submitted along with Technical bid Cross over subs, Bit Sub and pup joints (Detailed list to be submitted) Select List to be attached at Document-10

Confirm categorically to provide all Cross over subs matching to Contractor drill string, fishing tools, and contractor-supplied equipment and for bits as per casing policy to be used. Select

27 Pipe for cleaning 20”x30” annulus 140 m of tubular pipe to clear cement between 20"x30" annulus immediately after 20"cementing job. Pipe for cleaning 20”x30” annulus Contractor confirms tubular pipe for clearing cement between 20"x30" annulus immediately after 20"cementing job. Select

28 Handling Tools Exhibit A(ii) - Appendix 6 Details provided at Exhibit A(ii) - Appendix 6 Select

29 Hydraulic Cat-head Drillco Ezy-Torque or equivalent, complete with motor etc. Hydraulic Cat Head Unit : Document-5, Page No…….

30 Pile Hammer For driving 30” & 26” Conductor. Pile Hammer to drive 30" & 26" Conductor Select Document-5, Page No…….

31 Blow-out Preventer The Rig should be equipped with sour treated/ H2S trim BOP of the following sizes (Make: Cameron/NOV-Shaffer/NOV-T3/WOM/Hydril) :- (a) 21 ¼ " x 2,000 PSI Stack, consisting of – i) One Annular BOP ii) One Double OR Two Single ram BOP (with one blind / blind shear ram and one pipe ram) Bottom most connection of said BOP should match the Wellhead connection, i.e. 21 ¼ “X 2,000 psi API 6A Flange. Note: 20-3/4”-3M Ram BOP's along with the suitable adaptor (20-3/4”- 3 M X 21-1/4”- 2 M) to match the wellhead connection i.e. 21 ¼ “X 2,000 psi API 6A Flange is acceptable. Blow out Preventer stack : (Make: Cameron/NOV-Shaffer/NOV-T3/WOM/ Hydril) (H2S Trim) (a) 21 ¼ " x 2,000 PSI Stack, consisting of – i) One Annular BOP ii) One Double OR Two Single ram BOP (with one blind / blind shear ram and one pipe ram) Bottom most connection of said BOP should match the Wellhead connection, i.e. 21 ¼ “X 2,000 psi API 6A Flange Select Document-5, Page No…….

(b) 13.5/8” x 10,000 psi Stack consisting of :- (i) One 13.5/8” x 5,000 psi Annular BOP (ii) One Single and one Double 13.5/8” x 10,000 psi Ram type preventer with shear rams capable of shearing 5 ½” ‘S’ grade, 21.9 ppf drill pipe. (b) 13.5/8” x 10,000 psi Stack consisting of :- (i) One 13.5/8” x 5,000 psi Annular BOP (ii) One Single and one Double 13.5/8” x 10,000 psi Ram type preventer with shear rams capable of shearing 5 ½” ‘S’ grade, 21.9 ppf drill pipe. Select Document-5, Page No…….

If BOPs are older than 5 years then the same should have re-certification and the certification should be valid throughout the entire period of contract. Contractor to submit copy of recertification from any of the above listed manufacturer or the respective authorized facilities for all the BOPs offered at the time of third party inspection by ONGC nominated third party inspection agency. If BOPs are older than 5 years then the same should have re-certification and the certification should be valid throughout the entire period of contract. Contractor to submit copy of recertification from any of the above listed manufacturer or the respective authorized facilities for all the BOPs offered at the time of third party inspection by ONGC nominated third party inspection agency. Select

(a & b) Provide complete BOP stack Diagram and details as required at Table-1 @ Appendix-1 Select Details to be provided at Appendix-2(a) and stack diagram to be included at Document-10

(c) Rigs should have additional Cross-over Spools/DSAF so as to match 5,000 psi and 10,000psi Well-heads and 13.5/8” x 10,000 psi BOP Stack, viz :- (i) 13.5/8”x 5,000 psi API 6A Flange Well-head. (ii) 11” x 5,000 psi API 6A Flange Well-head. (iii) 11” x 10,000 psi API 6A Flange Well-head. All the DSAF/Spools should have valid Certificate of Conformance by API 16A certified agencies for respective equipment. (c) Rigs should have additional Cross-over Spools/DSAF so as to match 5,000 psi and 10,000psi Well-heads and 13.5/8” x 10,000 psi BOP Stack, viz:-

All the DSAF/Spools should have valid Certificate of Conformance by API 16A certified agencies for respective equipment. Select

(d) Nut Splitter and Hydraulic Flange spreader for BOPs and Well Heads of sizes as mentioned in the relevant clauses of the Technical Specifications, to avoid hot jobs in zone 'Zero'. (d) Nut Splitter and Hydraulic Flange spreader for BOPs and Well Heads of sizes as mentioned in the relevant clauses of the Technical Specifications, to avoid hot jobs in zone 'Zero' Select

(e) Hydraulic Torque Wrench complete with suitable attachments and power pack for tightening and loosening different type of studs of API Flange, BOP stack, Well Head, X-Mas tree and Choke & Kill manifold etc. (e) Hydraulic Torque Wrench complete with suitable attachments and power pack for tightening and loosening different type of studs of API Flange, BOP stack, Well Head, X-Mas tree and Choke & Kill manifold etc. Select

(f) Spacer Spools: To enable drilling / work-over jobs on platform, the rig should be equipped with two spacer spools viz: - -21¼” x 2,000 psi-4.25 mts & 1 mts each -13-5/8” x 10,000 psi-3.65 mts. & 0.83 mts each. Spools should have valid Certificate of Conformance by API 16A certified agencies for respective equipment. (f) Spacer spool

Length 4.25m & 1m 3.65m & 0.83m

Spools should have valid Certificate of Conformance by API 16A certified agencies for respective equipment. Select

(g) Diverter System – 29 ½”/30" Diverter systems complete with necessary Flanges/Reducers to be used with 30” and 26” Pipe. OR KFDJ 37 ½”/ 49 ½”. Contractor to submit copy of Certificate of Conformance for all the diverter BOP/KFDJ type diverter systems. (g ) Diverter System:

H2S Trim Select

Flanges / Reducers for 30” and 26” connector Casing: Select

Contractor to submit copy of Certificate of Conformance for all the diverter BOP/KFDJ type diverter systems. Select

(h) Maintenance of BOP equipment is the responsibility of the Contractor at its cost. (h) Maintenance of BOP equipment is the responsibility of the Contractor at its cost. Select

(i) Additional Ram Assembly: i) For 21 1/4-2M Ram BOP: 13-3/8" & 5-1/2” ii) For 13 5/8-10M Ram BOP: 9-5/8”, 7”, 5-1/2”, 5”, 3½”, 2-7/8”, 2-3/8” ram and Variable Ram (2-7/8” – 5”) & (4-1/2” – 7”) ram size and dual ram 2 7/8” x 2 7/8” should be provided along with Preventer. Rig should have test mandrel for main drill string (5 ½” and 3 ½”) ram size. Rig should have test stump facility. (i) Additional Ram Assembly: i) For 21 1/4-2M Ram BOP: 13-3/8" & 5-1/2” ii) For 13 5/8-10M Ram BOP: 9-5/8”, 7”, 5-1/2”, 5”, 3½”, 2-7/8”, 2-3/8” ram and Variable Ram (2-7/8” – 5”) & (4-1/2” – 7”) ram size and dual ram 2 7/8” x 2 7/8” should be provided along with Preventer. Select

Rig should have test mandrel for main drill string (5 ½” and 3 ½”) ram size. Select

Rig should have test stump facility. Select

(j) Rig should be equipped with well control equipment which are sour treated conforming to NACE-MR-01-75 standard / H2S trimmed. (k) 10,000 psi WP Choke & Kill Manifold with minimum 4 nos. of Chokes, out of which two should be Hydraulic and two should be manual & complete with Choke & Kill lines along with Remote Choke Control Panel. C& K Manifold should be certified as per API 16C recommendation. Contractor to submit copy of Certificate of Conformance from OEM or API 16C authorized agency for respective equipment. Choke/Kill manifold :

H2S Trim Select

Contractor to submit copy of Certificate of Conformance from OEM or API 16C authorized agency for respective equipment. Select

Chokes: 1 2 3 4

H2S Trim Select

Type Manual Manual Hydraulic Hydraulic

Kill & Choke Valves (main stack) 1 2 3 4

H2S Trim Select

Type Manual Manual Hydraulic Hydraulic

Remote Choke Control Panel Select

No. of Side Outlets

Contractor to submit copy of Certificate of Conformance from OEM or API 6A authorized agency for respective equipment. Select

Kill & Choke Hose : API 6A flange connection of the hose should meet NACE MR0175 standard. The Product should be stamped as per API 16C. Select

(l) BOP Pressure Testing Unit, capable of testing 10,000 psi. (l) BOP testing equipment, chart recorder & tools Select

13-3/8” & 9-5/8” Cup Tester Select

(m) BOP Hydraulic Control Unit for operating all BOPs, diverter system, Hydraulic Choke & Kill line Valves. The rig should be equipped with two nos. of BOP Remote Control Panels located at drill floor & Tool Pusher’s office. The control system should be certified as per API 16D recommendations. Contractor to submit copy of Certificate of Conformance from OEM or API 16D authorized agency for respective equipment. (m) BOP control system Manufacturer:

No. of Accumulator Bottles

Charge Pressure

Rated Volume each bottle

Usable Volume each bottle

Total volume to open and close all preventors

Operating Pressure

Surplus Volume %

BOP Remote Control Panel Location :

Drill Floor Select

Tool Pusher office Select

Other Location Select

Whether BOP control system meets API regulations Select

(n) B.O.P. Handling System: Rig should be equipped with required handling system for safe handling of contractors BOP stack. Contractor to submit copy of Certificate of Conformance from OEM or API 16D authorized agency for respective equipment. Select

(n) B.O.P. handling system Select

(o) BOP Test plug: Rig contractor shall provide the BOP test plug for all BOP sizes/ type offered by Rig for BHEL make well heads( Part no test plug is attached) Select

32 Fishing Tools Exhibit A(ii) - Appendix 8-A Fishing Tools: Contractor confirms to provide all the tools as per Exhibit A(ii) - Appendix 8-A Select

Contractor to submit complete list of fishing tools & accessories along with Technical bid Select List to be attached at Document-10

33 Taper Mill Exhibit A(ii) - Appendix 8-A Ref. Item 32 Fishing Tools Taper Mill Contractor confirms to provide Taper mill as per Exhibit A(ii) - Appendix 8-A NA

34 7” Shooting Nipple Exhibit A(ii) - Appendix 8-C 7” Shooting Nipple Contractor confirms to provide 7" Shooting Nipple as per Exhibit A(ii) - Appendix 8-C Select

35 Multi-String Cutter Multi-string Cutter should be provided for 30” (26”), 20” (18.5/8”), 13.3/8”, 9.5/8” & 7" Casing. Multi-String Cutter To cut 30"(26"), 20"(18-5/8"), 13-3/8", 9-5/8” & 7" Casing Select

36 Bit Breakers Exhibit A(ii) - Appendix 8-D Bit Breakers Contractor confirms to provide Bit breakers as per Exhibit A(ii) - Appendix 8-D Select

37 Lubricants Exhibit A(ii) - Appendix 8-E Lubricants Contractor confirms to provide Lubricants as per Exhibit A(ii) - Appendix 8-E Select

38 Communication Equipment The Contractor must provide following communication equipment :- (a) Non-directional Beacon (NDB) - 1 No. (b) Aero VHF Base – 2 Nos. (c) Aero VHF handheld – 1 No. (d) Video conferencing system – IP based OR any other VC platforms like MS Teams, Zoom Video Conferencing, Webex etc agreeable to ONGC with 52” Monitor & all accessories. (e) GMDSS Equipment’s as per @ Appendix-3 for MODU Code compliance. (f) E-mail. (g) Rig should have Drilling Instrumentation System so that the drilling data is made available to the designated place of ONGC. Contractor has to ensure that drilling instrumentation system should have Port to provide Surface data in WITSML format as and when desired by ONGC. The same instrumentation server shall supply data to the clients. The detail of the drilling instrumentation System is enclosed as @ Appendix-4. Communication Equipment: Details of Each equipment as per the following category: Document-5, Page No…….

(a) Non-directional Beacon (NDB) – 1 No.

(b) Aero VHF Base – 2 Nos.

(c) Aero VHF handheld –1 No.

(d) Video conferencing system – IP based OR any other VC platforms like MS Teams, Zoom Video Conferencing, Webex etc agreeable to ONGC with 52” Monitor & all accessories Select

(e) GMDSS Equipment’s as per @ Appendix-3 for MODU Code compliance Select

Name of Equipment

(g) Drilling Instrumentation System as per specification @ Appendix-4 Select

39 Coring Tools Exhibit A(ii) - Appendix 8-F Coring Tools: Contractor confirms to provide Coring Tools as per Exhibit A(ii) - Appendix 8-F Select

40 Helipad Helipad suitable for taking off and landing of S-61 or MI-8 helicopters, in compliance with latest DGCA Rules and Guidelines, including but not limited to the Peripheral lights, Touch Down(TD)/Positioning Marking(PM) & H lights. Contractor to confirm that Helideck is compatible for night landing for medical evacuation. Contractor shall maintain Helideck as per DGCA Latest regulations / guidelines. Helipad: Helicopter Deck Size

Helipad suitable for taking off and landing of S-61 or MI-8 helicopters, in compliance with latest DGCA Rules/Guidelines including but not limited to the Peripheral lights, TD/PM & H lights. Select

Contractor to confirm that Helideck is compatible for night landing for medical evacuation. Select

Contractor shall maintain Helideck as per DGCA Latest regulations / guidelines. Select

41 Safety Equipment and Fire Fighting Equipment All necessary fire fighting and safety equipment as per the SOLAS and IMO regulations should be on board. Contractor should clearly specify in detail about the fire fighting equipment and safety equipment on board. Safety Equipment and Firefighting equipment: Complete Details to be submitted Select Details to be attached at Document-10

Does it confirm to IMO/SOLAS regulations: Select

42 Life Saving Equipment: Rig should be equipped with – Life rafts, Life boats, Rescue boats, Life Vests, Ring Life Buoys. Life Saving Equipment

3. Rescue Boats

5. Ring Life Buoys

Does it confirm to IMO/SOLAS regulations: Select

43 Compliances of Different Regulatory Body Exhibit A(ii) - Appendix 8-G Compliances of Different Regulatory Body Contractor confirms to comply as per Exhibit A(ii) - Appendix 8-G Select

44 Miscellaneous (i) Inside BOP and FOSV, (rated 10,000 psi) for 5 ½”, 5” and 3 ½” drill pipe string. Miscellaneous: (i) Inside BOP 5-1/2" 5" 3-1/2"

Pressure rating

Pressure rating

(ii) Wire line winch for carrying out directional surveys. (ii) Wire line winch :

(iii) Drilling Instrumentation system Exhibit A(ii) - Appendix 4 (iii) Drilling Instrumentation system Contractor confirms to provide drilling instrumentation system as per enclosed at Exhibit A(ii) - Appendix 4 Select

(iv) All other miscellaneous equipments required for Rig and drilling operations. Exhibit A(ii) - Appendix 8-H (iv) All other miscellaneous equipments required for Rig and drilling operations including tools at Exhibit A(ii) - Appendix 8-H Select

Details of Storage Equipment Details of Storage Equipment:- Document-4, Page No……. Document-5, Page No…….

1. Drilling Water

2. Fresh(Potable)Water

4. Dry bulk storage :

Cement ( Neat & Blended): Note: If volume of Cement storage tank is given in terms of weight unit, then take conversion factor of 94 lbs/cft.

Silo No. 1 (cft)

Silo No. 2 (cft)

Silo No. 3 (cft)

Silo No.4 (cft)

Barite: Note: If volume of Barite storage tank is given in terms of weight unit, then take conversion factor of 143.5 lbs/cft.

Silo No. 1 (cft)

Silo No. 2 (cft)

Silo No. 3 (cft)

Silo No.4 (cft)

6. Dry Sack Storage

7. Storage place for general cargo, tubular (Casing/Drill Pipe/Drill Collar), Electro Logging Unit and Mud Logging Unit Select

45 Rig should be equipped with Detection equipments to detect Combustible & sour gases as per international practices. Rig should be equipped with Detection equipments to detect Combustible & sour gases as per international practices. Select

46 Ventilation and Air-conditioning System Rig should be equipped with suitable ventilation and air-conditioning system. Rig should be equipped with suitable ventilation and air-conditioning system. Select

47 Reduction in use of Plastic bottles Water-maker: Contract shall provide Fresh water & Drinking water at the rig. a) Water-maker(s) of minimum Total capacity 65 M. Tons per day including fresh water of salinity less than 500 ppm. b) For Drinking water, RO to be installed at the different locations of accommodation (preferably one at each floor). Contractor has to ensure provisioning of adequate quantity of drinking water for human consumption at rig at all times. Note: i) Contractor’s responsibility is to provide water maker/operational RO of capacity as per Sr. No. 47 (a) & (b). Acceptance of Fresh water as per 47(a) shall be on basis of Salinity only, and rejection by ONGC on basis of any parameter other than Salinity shall not be construed as shortfall. ii) Water maker shall produce min 65MT fresh water/day subject to storage capacity and variable load conditions of the rig. All water requirements of the rig shall be met by the above system. In case, required quantity is not fulfilled by the above system, then the difference of required and available fresh water will be provided by ONGC on chargeable basis without any profit margin (quantity of shortfall to be calculated on monthly basis). Recovery Charges for providing water shall be as per latest recovery rates circulated by ONGC Supply Base as per rig deployment in west /east coast. iii) In case, requirement of ONGC is more than 65 MT at any given point of time and contractor is not able to fulfill the requirement due to water maker capacity, then difference of required and available fresh water will be provided by ONGC on non-chargeable basis. iv) Measurement system for Fresh Water: Rig Should have a system for real time measurement of Fresh water stock at storage tanks through electronic level instruments. The system should indicate the total Fresh water stock at the Rig at a control panel/HMI by processing of data from individual storage tanks. Rig should have flow meter at the outlet of Water makers for accounting of Fresh water generation at the Rig. Measurement system should generate Fresh water consumption reports with digital date & time stamps for daily, weekly and monthly consumption. Rig should have measurement system for Fresh water intake from supply vessel through suitable flow meters & report generation for total intake from supply vessel for each instance. The control panel/HMI should feed Fresh Water storage & consumption parameter real time data to RTDMA/SCADA of the Rig. Water-maker 1 2 3 4 TPI Report Document-5, Page……….

Capacity in Metric Ton per day

48 Cementing Unit As per Exhibit A(ii) - Appendix 9 Cementing Unit As per Exhibit A(ii) - Appendix 9 Select

Provide the List of operational spares for cementing unit for 01 year as per OEM recommendations Select Details to be attached at Document-10

49 Rig should be equipped with – Rig should be equipped with

(i) Transfer hoses on both port and starboard side and its replacements (i) Transfer hoses on both port and starboard side and its replacements Select

(ii) Mooring lines and its replacements (ii) Mooring lines and its replacements Select

(iii) Oil and Gas burner boom assembly on port and star board side as per specifications enclosed at Exhibit A(ii) - Appendix 5. (iii) Oil and Gas burner boom assembly on port and star board side as per specifications enclosed at Exhibit A(ii) - Appendix 5 Select

50 All the Rig Equipment like Draw-works, Mud Pumps, Main Generator Sets, Main Engines etc. should be in perfect working condition and should be capable of operating on its full rated capacity. All the Rig Equipment like Draw-works, Mud Pumps, Main Generator Sets, Main Engines etc. should be in perfect working condition and should be capable of operating on its full rated capacity. Select

51 Spare parts for contractor provided tools and equipment of replacement of contractor provided equipment / tool are to be provided by the contractor. Spare parts for contractor provided tools and equipment of replacement of contractor provided equipment / tool are to be provided by the contractor. Select

52 Total Bulk Capacity Total Bulk capacity available for storage of barite and cement, in the respective designated storage areas, should not be less than 5000 cft. The said Bulk capacity should be excluding the capacity of any surge tanks. Total Bulk Capacity (Cement + Barite) in cft

Total Bulk capacity available for storage of barite and cement, in the respective designated storage areas, should not be less than 5000 cft. The said Bulk capacity should be excluding the capacity of any surge tanks. Select Document-4, Page…… TPI Report Document-5, Page……

53 ONGC intends to deploy proposed rigs on existing platforms in West-coast of India, where the pug marks of the previously deployed rigs are existing. Major types of rigs which have been deployed in the past on various platforms, which have left corresponding pug marks, are having broad dimensions as under :- ONGC intends to deploy proposed rigs on existing platforms in West-coast of India, where the pug marks of the previously deployed rigs are existing. Major types of rigs which have been deployed in the past on various platforms, which have left corresponding pug marks, are having broad dimensions as per Item 53. Select

Maximum spud can diameter – 56 Ft.

54 In case the offered Rig(s) is/are of types/designs other than indicated above, the technical assessment and confirmation of M/s. DNV-GL NDA, Dubai or M/s Aqualis Offshore will be obtained by the bidder for compatibility with anyone of the above existing and previously deployed Rigs and suitability for deployment in Mumbai Offshore fields. Technical assessment and confirmation from M/s. DNV-GL NDA, Dubai or M/s Aqualis Offshore should be enclosed with the Technical Bid. Confirmation of M/s. DNV-GL NDA, Dubai or M/s Aqualis Offshore enclosed Select Document-5, Page……

General Information

i) Overall appearance of Vessel and Equipment

ii) Past operating performance of the rig

iii) Past Safety record of the rig and personnel

iv) Sources of above data

55 Acceptance of different Appendices of Annexure III. Exhibit A Contractor accepts the following:

(i) Exhibit A(iii)-Schedule of Responsibilities (SOR) Select

(ii) Exhibit B-List of crew Select

(iii) Exhibit C-Short Deployment Rate Select

(iv) Exhibit A(ii) - Appendix 2-Environmental Parameters Select

(v) Exhibit A(ii) - Appendix 10 - Cementing Unit Inspection Procedure Select

(vi) Exhibit A(ii) - Appendix 11 -SOW TPI Select

(vii) Exhibit A(ii) - Appendix 12-Physical and Medical Fitness criteria Select

(viii) Exhibit A(ii) - Appendix 13-Well Bore clean up tool Select

(ix) Exhibit A(iv) - Non-Availability Deduction Select

(x) QCBS Worksheet of this Excel File has been printed and signed by the Authorized Signatory Select

(xi) Contractor to submit standard equipment list in IADC format of the offered rig equipment and capabilities once contract is awarded. Select

Exhibit A(ii) - Appendix-1

Size Mfgrs. & type Rating Response Gallons to Close Gallons to Open Closing Ratio Opening Ratio

Exhibit A(ii) - Appendix-2

Exhibit A(ii) - Appendix-3

DETAILS OF COMMUNICATION/NAVIGATION EQUIPMENT COMPLIANCE OF JACKUP RIGS

I. MAIN RADIO STATION

Sl No. EQUIPMENT QUANTITY REMARKS

1 VHF/DSC 2 NOS WITH BOTH ANTENNAA

2 INMARSAT-C 2 NOS. WITH GPS KIT+LRIT COMPLIANT

3 MH/HF-DSC+SSB 1 NOS. WITHOUT NBDP KIT

4 BATTERY CHARGER 1 NO WITH VOLT/AMP METER + AUDIO ALARM

5 RADIO BATTERIES 24 V-200 AH 1 SET (HEAVY DUTY AND M.F)

6 DEDICATED INDIVIDUAL POWER SUPPLIES FOR ALL EQUIPMENT 1 NO

7 MH/HF- DSC +SSB +NBDP 1 NO OPTIONAL (THIS CAN BE CONSIDERED IN PLACE OF ONE INMARSAT-C AT SR. NO. 2 ABOVE)

8 GMDSS CONSOLE 1 NO

II. BRIDGE/CONTROL ROOM:

Sl No. EQUIPMENT QUANTITY REMARKS

1 NAVTEX RECEIVER 1 NO.

4 TWO WAY GMDSS WALKIE/TALKIES 2 NOS.

7 GPS FOR POSITION FEED 1 NO.

III. LIFE BOAT:

Sl No. EQUIPMENT QUANTITY REMARKS

1 TWO WAY GMDSS WALKIE/TALKIES 2 NOS. (ONE FOR EACH LIFE BOAT)

2 RADAR TRANSPONDERS-SART 2 NOS. (ONE FOR EACH LIFE BOAT)

Exhibit A(ii) - Appendix-4

Drilling Instrumentation System on Rig

1 System Design & Operation Philosophy:

i. Drilling Instrumentation consists of the parameters required by the Driller, Chemist and Geologist at the time of Drilling , Tripping, Cementing and Well Control. ii. The system shall be Server based compatible for data transfer from the Rig Instrumentation Server to any other system deployed by ONGC in WITSML Format. The same Rig Instrumentation Server to supply DATA to clients at the Driller’s cabin, Tool Pusher, Chemist & Geologist. iii. The PLC/DAQ will send data to Drilling Instrumentation Server and Discrete Digital Display Unit (DDDU) (Drillwatch or equivalent) on the rig floor. iv. DATA and/or trend graphs of all selected parameters are to be displayed on 15-inch Color LCD TFT Touch Screen Monitor for Driller in the Driller’s Cabin. v. Dedicated Data Base Management System (DBMS) viz., DB2, Oracle, MS SQL, etc., shall be used as backend software.

vi. Tamper proof data base with password protection. vii. Data extraction and backup facility. viii. In the event of failure of Drilling Instrumentation Server, current drilling parameters data should be available to the driller through Discrete Digital Display Unit (DDDU). ix. In the event of failure of PLC/DAQ the following current drilling parameters should be available to the driller on the driller’s panel to continue with drilling operations. a. Hook Load & Weight on Bit, through Hydraulic Weight Indicator. b. Stand Pipe Pressure, through Hydraulic Pressure Gauge. c. Tong Torque, through Hydraulic Gauge. d. Pump SPM1, SPM2, SPM3 and total strokes through Digital Gauge. e. Return Flow %, through Digital Gauge. x. Rig with mechanical brake system to be equipped with digital auto driller for constant weight on bit/ ROP & differential pressure. xi. All sensors of rig instrumentation should be calibrated annually or earlier by OEM/ competent Third party. xii. Screen size of the Rig Sense unit display monitor in company man office should be of minimum 26”.

2 Parameters for Display:

The system shall Display the drilling parameters on Discrete Digital Display Unit for viewing continuously in a fixed window on the Driller’s panel.

Sl. No. Parameter Required display

i. a. Hook load LCD, Digital

b. W.O.B. LCD, Digital

ii. a. Stand Pipe Pressure LCD, Digital

b. Casing Pipe Pressure LCD, Digital

iii. Tong Line Pull LCD, Digital, with High set point, Audio & Visual alarm.

iv. a. SPM#1 LCD, Digital

b. SPM#2 LCD, Digital

c. SPM#3 LCD, Digital

d. SPM #1 + #2+#3 LCD, Digital

e. Total Strokes up to 3 Pumps LCD, Digital

f. Pump#1 ( Fill) LCD, Digital

g. Pump#2 ( Fill) LCD, Digital

h. Pump#3 ( Fill) LCD, Digital

v. a) RPM, Rotary Table LCD, Digital (Single display should show which ever is active)

b) RPM, Top Drive

vi. a) Rotary Torque, Rotary Table LCD, Digital (Single display should show which ever is active)

b) Top Drive Torque

vii. a) ROP LCD, Digital

b) Hole Depth LCD, Digital

c) Bit Position LCD, Digital

viii. a) Loss/Gain Volume LCD, Digital, Loss & Gain set points with Audio & Visual alarm

b) Tank Volume1 to 6 Selectable LCD, Digital

c) Total tank volume LCD, Digital, with Tank selection status

ix. Return Flow LCD, Digital & High Low set points with Audio & Visual Alarm,

x Trip Tank Volume LCD, Digital & High Low set points with Audio & Visual Alarm,

xi Total Gas 0 to 100% by Volume in air.

xii H2S 0 to 20 PPM by Volume in air.

Note: a. Provision for the following features  Bit Weight Zero Set  Loss/Gain Zero Set  Tank Select  Total Strokes Reset Alarm set points are to be displayed in digital form when being set without obscuring the current reading.

3 Printing Device

Colour Ink Jet Printer for taking Printouts in A3 Size Sheets in the following modes. To be installed with Workstations. GRAPHICAL PRINTOUTS i. Selected Parameters are to be recorded. ii. Feature of Time Base and Parameter Range selection. The Print Out should show the time on hourly basis and Parameter Range on each page. The Time selection feature should facilitate the Printout to cover 24 hours of drilling activity in user selectable A3 or super B sheets. iii. The Print Outs should cover the normal Print Area of the paper. Well Name and Date to be printed in every sheet. Date format shall be dd-mmm-yyyy or Month-dd-yyyy.

4 Parameter to be Measured & Sensor Details:

Sl. No Parameters Sensor Type Description Quantity

1 Hook load Hydraulic, E80 Hydraulic Electronic Pressure to current transducer 0 to 1000 1 No. 1 No.

2 Stand Pipe Pressure. Electronic &Hydraulic 1. Direct mount on standpipe, electronic sensor suitable for 2 inch WECO Union Female Sub & Hammer Lug Nut Type 1502. Range for SPP-1, 0 to 5000 PSI.. 2. Piston Separator 1:1(Suitable for 2 inch WECO Union Female Sub & Hammer Lug Nut Type 1502) on stand pipe & Pressure to current transducer 0 to 5000 PSI to be installed in the driller’s panel. For SPP-2. 1 Set 1 Set

3 Casing Pipe Pressure Electronic Direct mount on standpipe, electronic sensor suitable for 2 inch WECO Union Female Sub & Hammer Lug Nut Type 1502. Range 0 to 10000 PSI. 1 Set

4 Tong Line Pull Hydraulic Hydraulic Tension Cylinder & Pressure to current transducer to be mounted in driller’s console. 0 to 20000 Pounds pull. 1 Set

5 SPM Proximity Sensor Proximity Sensor 3 Nos

6 RPM, Rotary Table Proximity Sensor Proximity Sensor 1 No

7 ROP/Ton mile/ Depth/Block Speed/ Block Position/Pipe Tally Proximity Sensor Optical encoder. Suitable for mounting on draw-works counter shaft. 1 No

8 Rotary Torque, Hall Effect Sensor Hall Effect Sensor. Input Range 0 to 1000 Amps. Output 4 to 20mA OR 0 to 2.9 V. 1 No

9 Mud Pit Level Ultrasonic Sensor Ultrasonic Sensor (5 No Mud Tank + 1 No for Trip Tank). Range 0 to 10 feet. 6 Nos.

10 Return flow Paddle type Ultrasonic Sensor or any other type based on reliable technology. Range 0 to 48 inches. 1 No

11 Mud-In conductivity Electronic Range 0 to 200 millisimense/cm. Range 0 to 200 millisimense/cm. 1 No

Mud-Out conductivity

12 Mud-In density Electronic Electronic Output. Range 5 to 22 PPG.. Electronic Output Range 5 to 22 PPG. 1 No

Mud-Out density

13 Mud-In Temperature Electronic RTD, Electronic Output Range 0 to 100 Deg Celsius. RTD, Electronic Output Range 0 to 100 Deg Celsius. 1 No

Mud-Out Temperature

14 Total Gas Infrared 0 to 100% by Volume in air. 1 No

15 H2S Catalytic 0 to 20 PPM by Volume in air. 1 No

Contractor to install IP based Digital CCTV camera. The access for the cameras shall be available at OIM/company man office. Live Feed for helideck/main deck will be given to radio room & Monkey board to driller’s cabin. Also the functionality/additional port shall be available to share live video footage to ONGC Base. The Specifications of IP based CCTV camera is as under: 1. Explosion -Proof Fixed IP (IECEx/ ATEX/PESO) camera: Min 1/2.8" CMOS Sensor, Min 2 MP Resolution, 30x Optical Zoom, with Wiper, IP67, ONVIF Compliant, H.265/264 Compliant. 2. Weather-Proof Fixed IP camera: Min 1/2.8" CMOS Sensor, Min 2 MP Resolution, 5-50mm +/-5mm motorized varifocal, IP67, ONVIF Compliant, H.265/264 Compliant. 3. Weather-Proof PTZ IP camera: Min 1/2.8" CMOS Sensor, Min 2 MP Resolution, 30x Optical Zoom, with Wiper, IP67, ONVIF Compliant, H.265/264 Compliant. 4. Video Management cum recording server software specifications • The IP Video Management Software should allow Live Viewing, Recording and Management solution of Network Video surveillance systems. • VMS Software should be ONVIF S, G, and T Profile Compliant. • Should record H265, H.264, MPEG4 or MJPEG in at minimum 5 fps to 30 FPS at minimum CIF to Full HD (1080p)

Contractor to install IP based Digital CCTV camera at the below-mentioned locations.:

S.N Location Qty OF CAMERA (Minimum) Weather proof/ Ex-Proof Hazardous Zone type Type of Camera

1 Monkey board 1 Ex-Proof Zone 2 Fix

2 Rig Floor 1st camera 1 Ex-Proof Zone 2 Fix

3 Rig Floor 2nd camera 1 Ex-Proof Zone 2 Fix

4 Below rig floor 2 Ex-Proof Zone 1 Fix

5 Shale shaker area 1 Ex-Proof Zone 1 Fix

6 Sack Store 1 Weather-Proof safe area Fix

7 Cement room 1 Weather-Proof safe area Fix

8 Mud pump room 1st camera 1 Weather-Proof safe area Fix

9 Mud pump room 2nd camera 1 Weather-Proof safe area Fix

10 Mud pit room 1 Ex-Proof Zone 1 Fix

11 Engine Room 1st camera 1 Weather-Proof safe area Fix

12 Engine Room 2nd camera 1 Weather-Proof safe area Fix

13 Compressor Room 1 Weather-Proof safe area Fix

14 Auxiliary Room 1 Weather-Proof safe area Fix

15 MCC Room & SCR Room 2 Weather-Proof safe area Fix

16 On Port Side Jack House for Main Deck 1 Weather-Proof safe area PTZ

17 On Control Room Top for Main Deck 1 Weather-Proof safe area Fix

18 On Control Room Top for Helideck 1 Weather-Proof safe area Fix

19 Start Board Side for Boat Handling 1 Weather-Proof safe area PTZ

20 Port Side for Boat Handling 1 Weather-Proof safe area PTZ

21 On FWD Jack-house 1 Weather-Proof safe area Fix

22 HVAC compressor room 1 Weather-Proof safe area Fix

Total camera 24

Exhibit A(ii) - Appendix-5

OIL & GAS BURNER

Oil & Gas Burner for complete & smokeless burning of the products of the test well on offshore rigs, with the following facilities:

a) Should have minimum three burner heads mounted on boom.

b) Combined oil capacity of three heads should be 9,000 BOPD.

c) Total gas capacity should be 60 MMSCF/DAY

d) Oil burning should be through full atomization of fluid to be disposed off for efficient combustion at varying flow rates / pressures with minimum backpressure. Dropping of liquid below the burner is not acceptable.

e) LPG/Propane ignition pilot system with spark plug facility to be provided near burner heads & gas line outlet to ignite oil & gas efficiently with control at the base of burner. Pilot to be fully protected from water (cooling spray).

f) Oil & gas pipe line should be suitable for sour service as per NACE specs MR-01-75 (latest edition).

Burner boom to support heads, provide safe walkway to approach burner head, and support all piping for oil, gas, water, air & LPG and should have the following :

a) Boom length 60 ft minimum and should be suitable to fold 90 deg Vertically/ horizontally to facilitate boat operation during well testing.

b) Should have built in hand rails and steel grating walkway for safe access of people to burner head (chains not acceptable)

c) Should be rugged enough to withstand 150 KMPH wind speed in hanging position.

d) The flow line piping for oil, gas and air should be of following size and end connections, as per NACE MR-01-75 (latest edition).

Flow line Size End Connection Oil 3" 3" WECO Fig 602 Female Gas 3" 3" WECO Fig 602 Female Water 3” 3" WECO Fig 602 Female Air 2" / 3” 2” WECO Fig 206 Female / 3”WECO Fig 602 Female (In case 3” 6O2 end connections are provided for the Air line, then suitable change over to convert the end connection to 2”WECO Fig 206 Female should be provided)

(e) Oil flow lines to have 3" x 1500 PSI WP check valve and airline to have 2" x 500 PSIWP check valve at the end of the burner boom.

(f) Suitable accessories including slings, base plate, kingpost & tie rods should be supplied for installation of burner.

(g) The pilot ignition startup switch boxed in fireproof and explosion proof case with supply cable of 100' length compatible with power supply of rig and fitted with fuse etc.

(a) 2”- 10K 1502 Upstream lines including Flexible line (Coflex / Coflexip hose) to connect Flow Head & Choke Manifold (Total about 50m)

(b) 3”- 5K 602 Downstream lines to connect both oil & gas lines of the burners with the well test separator including Oil & Gas diverters.

Exhibit A(ii) - Appendix-6

TUBULARS & HANDLING TOOLS

Sl No. Technical Specification Details to be filled by Bidder Reference/ Remarks

24 Drill String/ Tubular Goods & Handling Tools: The Rig should be equipped with Drill String & handling tools as following: (a) Drill Pipe

(a) Drill Pipes : (i) 5 ½”: 21.9 ppf , Grade `S’, - 4000 Mtrs. OD of Tool Joint should be 7” (ii) 5” : 19.5 ppf, Grade –‘S’- 1500 Mtrs. iii) 3½” Drill pipe: 13.3 ppf, Grade ‘S’ - 1500 metres (iv) 2 3/8” Drill pipe: 6.65 ppf, Grade ‘G’ - 800 metres (v) 5 ½” DP Pup joint – 5 ft, 10 ft & 15 ft – one No. Each ( Grade –S, 21.9 PPF-7” Tool Joint OD) (vi) 5” DP Pup joint – 5 ft, 10 ft & 15 ft – one No. Each (Grade –S, 19.5 PPF) All Drill pipes shall be in Range-II, new/premium class. In case of hard banded tool joints, tool joints should have hard banding of non-abrasive, non-tungsten carbide material String strainers for all Drill Pipe sizes to be provided. Size 5-1/2" 5" 3-1/2" 2-3/8"

Quantity (in meters) 4000 1500 1500 800

Range II II II II

Drill Pipe Elevator 5-1/2" 5" 3-1/2" 2-3/8"

Last Inspection & by whom

Drill Pipe Slips 5-1/2" 5" 3-1/2" 2-3/8"

Last Inspection & by whom

Pneumatic/Hydraulic Drill Pipe Spinning Wrench

5 ½” DP Pup joint – 5ft, 10ft & 15ft – one No. Each ( Grade –S, 21.9 PPF-7” Tool Joint OD) Select

5” DP Pup joint – 5ft, 10ft & 15ft – one No. Each ( Grade –S, 19.5 PPF) Select

All Drill pipes shall be in Range-II, new/premium class. Select

In case of hard banded tool joints, tool joints have hard banding of non-abrasive, non-tungsten carbide material Select

String strainers for all Drill Pipe sizes to be provided. Select

(b) Spiral Drill Collars: 8” / 8 ¼” OD : 12 Joints 6 ¼”/6 ½” D : 24 Joints 4 ¾” OD : 24 Joints 3 ½” OD : 6 Joints Spiral Drill Collars

Quantity (joints) 12 24 24 6

Spiral Spiral Spiral Spiral Spiral

Drill Collar Elevators / Lifting Sub 8"/ 8-1/4" 6-1/2"/ 6-1/4" 4-3/4" 3-1/2"

Last Inspection & by whom

Last Inspection & by whom

(c ) Heavy Weight Drill Pipe: 6-5/8” O.D. Spiral: 20 Joints (65-75 ppf) 5 ½” OD. Spiral: 30 Joints OD of Tool Joint should be 7” (55-62 ppf) 5" OD, Spiral: 15 Joints (50 ppf) 3½”OD, 24 Joints (26-30 ppf) Note: HT 55 connection for 5-1/2” HWDP is acceptable if 5-1/2” Drill pipe of same HT 55 connection is provided. Heavy Weight Drill Pipe

Quantity (Joints) 20 30 15 24

Connection 5-1/2" FH 4-1/2" IF 3-1/2" IF

Spiral Spiral Spiral Spiral

Heavy weight Drill Pipe Elevator 6-5/8"

Last Inspection & by whom

Heavy weight Drill Pipe Slip 6-5/8"

Last Inspection & by whom

Note: 1. Tolerance limits of each element of the above Drill String(s) should be as per the API Standard for Pipe Inspection 2. Contractor shall maintain the specific tolerance limits of all the above Drill String(s) elements within the range as per the A PI Standard for Used Pipe Inspection API RP 7G-2 at any point in time the Contract is effective 3. If directed by the Operator, Contractor shall use drill pipe casing protectors of approved type. Kelly sub-protectors are not required as Kelly is not the part of specs. 4. All tubulars are to be NDT inspected as per DS-1, Category 5, prior to acceptance of the rig. Note: Contractor confirms that 1. Tolerance limits of each element of the above Drill String(s) is as per the API Standard for Pipe Inspection. Select

2. Contractor shall maintain the specific tolerance limits of all the above Drill String(s) elements within the range as per the API Standard for Used Pipe Inspection API RP 7G-2 at any point in time the Contract is effective. Select

3. If directed by the Operator, Contractor shall use drill pipe casing protectors of approved type. Kelly sub-protectors are not required as Kelly is not the part of specs. Select

4. Contractor shall get all tubulars NDT inspected as per DS-1, Category 5, prior to acceptance of the rig. Select

Inspection schedule on all Tubular, when last inspected and by whom Select

28 All handling tools like Elevator, Spiders, Slips, Tongs, Power Tongs, Pipe Spinners, Hydraulic casing tong (5” to 13 3/8” size range), Safety Clamps, Elevator Links, etc. for Contractor’s Drill String, above mentioned Casing (at SL. No. 23 of Exhibit A(ii)) including • CUL Bushing for all sizes of casing as per casing policy at sr. no. 23 matching to the rotary table installed on rig • Spider elevator-350 T • Stabbing board & Single joint elevator for 13 3/8”, 9 5/8”, 7” & 5" casing • Handling Tools like Latch type elevator for 2-3/8”, 2-7/8”, 3 ½” & 4 ½” EUE Tubing • Slip type elevators for 2 3/8”, 2 7/8”, 3 ½” and 4 ½” non-upset tubing • Slips & Hydraulic tubing tong for 2-3/8”, 2-7/8”, 3 ½” & 4 ½” Tubing along with manual tubing tong of 2-3/8”, 2-7/8”, 3 ½” & 4 ½” tubing • Slip type elevator for 5” casing Iron Roughneck with remote/manual controls Complete list of handling tools to be submitted along with Technical bid. However, it should be amply clear that all the tools required to handle Contractor’s tubulars and Operator’s tubulars mentioned herein, is sole responsibility of the Contractor and shall not be limited to the list provided by the Contractor. Elevator Links

Last Inspection & by whom

Last Inspection & by whom

Confirm providing all required Tubing Handling Tools for 2-3/8”, 2-7/8”, 3 ½” & 4 ½” size Select

Casing Handling Tools

Casing Size Single Elevator Side Door Elevator Slips Tong

30" Casing Select Select Select

26" Casing Select Select Select

20" Casing Select Select Select Select

18-5/8" Casing Select Select Select Select

13-3/8" Casing Select Select Select Select

9-5/8" Casing Select Select Select Select

7" Casing Select Select Select Select

5" Casing (Slip type elevator) Select Select Select Select

Casing Hydraulic Power Tong

CUL Bushing for 30”, 26” and 20” connector & all sizes of casing as per casing policy at sr. no. 23 matching to the rotary table installed on rig Select

9 5/8” & 13 3/8” Spider Elevator/Slips for 350 ton/500 ton load Select

Stabbing Board Select

Iron Roughneck Select

List of Handling tools with accessories enclosed is indicative, Contractor confirm to provide all the tools as per item 28 Select

Complete list of handling tools submitted along with Technical bid. Select Complete List to be Enclosed at Document-10

Exhibit A(ii) - Appendix-7

Brine Filtration Unit

1. Rig is to be equipped with a Brine filtration system to clean the brines of solids, waste and sludge prior to pumping to well as clean the received brines from well to desired level of brine quality for future use.

2. The Type of Brine Filters to be installed are: Bag type Filter Unit for upstream coarse filtration up to 25 Micron: Qty - 1 No. Cartridge type filter Unit for filtration of Brine from 10 Micron to 2 Micron: Qty - 1 No. Specification of the Cartridge type filter Unit a) Filter Housing – Designed as per ASME Sec VII Div I b) Vessel material – Stainless Steel 316 Grade. c) Filter housing design - For Quick changing of filter cartridge d) Filter Media-Polypropylene pleated cartridge e) Vessel flow capacity-10-18 bbl/min f) Inlet / Outlet Diameter - 4” Pipe g) Operating Pressure - Suitable up to 10 bar operation

3. Contractor has to install and maintain the Brine filtration units along with operational spares and filters (consumables) as per the operational requirement. 4. The minimum number of filters in terms of bags and cartridges may be maintained at any given times are as given below. Sr No Filter bags/ Cartridges No. 1 Filter bag – 25 micron 10 2 Filter cartridges –10 micron 200 3 Filter cartridges –2 micron 200

Exhibit A(ii) - Appendix-8

Sl No. Miscellaneous

A Fishing Tools: The Rig should be equipped with Fishing tools, (Make : NOV/ Weatherford/ Schlumberger/ Baker Hughes/Logan) Following Fishing Tools for Contractor’s Tubular for various hole sizes (26”, 17½”, 12 ¼”, 8 ½”, 6”) and casings (20", 13-3/8", 9-5/8", 7" and 5") a. Over shots (i) (Full Strength to catch all sizes of string with oversize guides and extension subs), (ii) 8-1/8" Slim Hole overshot for 7" OD tool joint of 5-1/2" DP, with oversize guide and extension sub), b. Junk Subs, c. Reverse Circulating Junk Baskets, d. Bumper sub, e. Junk Mills, f. Magnets, g. Safety Joints, h. Fishing Jars, i. Surface Jar j. Fishing Tools for work over: Die collar and Male Tap for 3 ½” & 2 7/8” tubing (Inside 9 5/8” & 7” Casing) k. Casing Spear for 20”, 13 3/8”, 9 5/8”, 7” and 5" casing shall be provided by the Contractor. 9 5/8” Casing Spear should be provided with Pack off Assembly. l. Ditch magnet to be provided in the flow channel. m. Impression blocks for 8-1/2”, 12-1/4” & 17-1/2" hole sizes.

n. Taper Mill: (i) Mill Size OD-12-1/4” Fishing Neck OD (max)- 8” Top Conn.-6-5/8” Reg Pin (ii) Mill Size OD-8 3/8” Fishing Neck OD (max)- 5 ¾” Top Conn.-4 ½”Reg Pin (iii) Mill Size OD-5 7/8” Fishing Neck OD (max) - 4 1/4” Top Conn.-3 ½”Reg Pin Min. length of Fishing Neck for all Taper Mill- 12” o. Flat bottom Mill : Mill Size OD-4-1/8” Complete list of fishing tools & accessories to be submitted along with Technical bid at Exhibit A(ii) - Appendix-13 (c).

B Taper Mill: Shifted to Fishing Tools @ A.

C 7” Shooting Nipple: Compatible with wireline BoP At least one side outlet with WECO hammer union connection fig. 1502. Certificate of Conformity for minimum WP Rating of 3000 psi by Third Party Certifying Agency. Certificate of compliance for API and NACE Industry standard by Third Party Certifying Agency.

D Bit Breakers & Bit Gauges Bit Breakers for 26”, 23”, 17½”, 12¼”, 8½”, 6” and 4-1/8” Bits. Rig should have 1 set of No-Go gauge for PDC bit and Go gauge for TCR bit of all hole sizes (17-1/2", 12-1/4", 8-1/2", 6") according to API spec 7-1.

E Lubricants All lubricants for the Contractor’s equipment and Contractor’s hired equipment will be supplied by the Contractor at its cost, including for Cementing Unit.

F Coring Tools 1 set of 6¾” x 4” x 60 ft Core barrel along with handling tools, stabilizers and all accessories. a) Inner Barrel : Fibre glass/Aluminum, b) 2 sets of Inner barrel should be available on the rig: c) 2 nos of 8 15/32” Core bit of medium hard formation: d) Core Bit connection should match the core barrel:

G Compliances of Different Regulatory Body Requirements Contractor has to comply the following 1. Contractor to submit all relevant documents required under Schedule IV and other applicable rules for obtaining to operate for compliance of Petroleum & Natural Gas (Safety in Offshore Operations) Rule 2008 issued by MOP&NG, India being regulated by Oil Industries Safety Directorate (OISD) at least 45 days prior to acceptance of the rig by ONGC. 2. MODU Safety Certificate from concerned classification society 3. Rig should be equipped with AIS (Automated Information System) (ODAG) 4. Rig should be equipped with CCTV at Helideck 5. International Oil Pollution Prevention (IOPP) Certificate to be taken

6. Sewage Pollution Prevention (SPP) Certificate to be taken 7. Rig should be capable to handle MOEF guidelines for drill cuttings disposal 8. Helideck should be in compliance with latest DGCA Rules and Guidelines. 9. Contractor to comply verification of fitness of offshore drilling rigs as per OISD guidelines note on Rule-30 on “Verification of fitness of offshore installation” pertaining to offshore drilling rigs, available on OISD website www.oisd.gov.in. 10. Contractor also to comply latest applicable guidelines issued by OISD for operating the rig in Indian water.

H (i) Drift Indicator (Totco 0-16 degree) with baffles plates and complete with wire line retrieving tool.

(ii) Calibrated Flow Meters for diesel, Drill and Potable water.

(iii) Welding Gen Sets, Gas Cutters, Torches and accessories.

(iv) Cargo nets, cargo boxes, personnel baskets, towing lines, hoses for transferring barites, cement, potable water, drill water, diesel etc as required should be provided

(v) Wiper for 2 7/8”, 3 ½” & 4 ½” tubing.

(vi) Hole Opener: (For soft formation and equivalent to Bit IADC code 1-1-1) with detachable Bull Nose of suitable length and compatible threaded connection. 26” – 1 No. 23” – 1 No

(vii) Rotating Scrapper: Contractor to provide rotating scrappers that has the capability to drill and scrap the well in the same run. Rotating Scrapper is to be maintained for: a. 9 5/8” casing ( 1 no ) – 47ppf to 53.5ppf b. 7” Casing ( 1 no) -29ppf to 35ppf.

(viii) Spiral Blade Stabilizers for Hole Sizes as follows- a.Full Gauge integrated type String Stabilizers - 01 each for hole size (i) 26" (ii)17 ½”, (iii) 12 ¼”, (iv) 8 ½”, (v) 6” (Box x Pin) b.Full Gauge integrated type Near bit Stabilizers - 01 each for hole size (i) 17 ½”, (ii) 12 ¼”, (iii) 8 ½”, (iv) 6”, (v) 5" (Box x Box) c.Under Gauge (1/4") integrated type String Stabilizers - For 6” hole size (Box x Pin). d.Under Gauge (1/4") integrated type Near bit Stabilizers -For 6” hole size (Box x Box) e.Under Gauge (1/8") integrated type String Stabilizers - For 6” hole size (Box x Pin). f.Under Gauge (1/2") ") integrated type String Stabilizers - 01 each for hole size (i) 17 ½”, (ii) 12 ¼”, (iii) 8 ½” (Box x Pin) g.Under Gauge (1/2") integrated type Near bit Stabilizers - 01 each for hole size (i) 17 ½”, (ii) 12 ¼”, (iii) 8 ½” (Box x Box) Note: (i) For 17 ½” Hole Size: 6 5/8” API regular connection, 8” OD fishing neck X 2 13/16” ID for drilling 17½” hole, with mirror smooth surface finish and hard facing of tungsten carbide blocks embedded in tungsten carbide matrix or equivalent. (ii) For 12 ¼” Hole Size: 6-5/8” API regular connection, 8” OD fishing neck X 2-13/16” ID for drilling 12¼” hole, with mirror smooth surface finish and hard facing of tungsten carbide blocks embedded in tungsten carbide matrix or equivalent. (iii) For 8 ½” Hole Size: 4-1/2” IF connection, 6½” OD fishing neck X 2-13/16” ID for drilling 8 ½” hole, with mirror smooth surface finish hard facing of tungsten carbide blocks embedded in tungsten carbon matrix or equivalent. (iv) For 6” Hole Size: 3-1/2” IF connection, 4¾” OD fishing neck X 2-1/4” ID for drilling 6” hole, with mirror smooth surface finish and hard facing of tungsten carbide blocks embedded in tungsten carbide matrix or equivalent. (v) All above stabilizers must be 4 slight spirals integral and sufficient bladed length of double tapered at both leading and trailing ends. Stabilizers should have sufficient opening/ annular clearance with taper blade on stabilizer body.

(ix) Circulating Sub: 9 5/8” BTC PIN X 5 ½” FH BOX 13 3/8”BTC PIN X 5 ½” FH BOX

(x) Drill Cutting Storage space: Rig to be equipped with unit having cuttings storage/ handling/ processing space (sufficient to accommodate two containers of approx. size h: 2.5 m * l: 2.5 m * w: 2 m) for transportation of cuttings to shore during pay zone drilling.

(xi) External casing cutter (Cold cutter) for cutting and beveling 13 3/8" and 9 5/8" casing with pneumatic or hydraulic drive options.

I Mud Lab & Mud testing equipment - Rig should have an air conditioned mud laboratory with all drilling fluid testing apparatus as described below and a desk top computer with drilling fluid reporting system along with printer. a) Fann VG meter with thermo cup b) Airplane kits with Oil – water retort apparatus. c) H2S Detection kit. d) Hamilton batch mixer. e) Methylene blue test kit. f) Mud balance. g) Lab Centrifuge h) Marsh Funnel with Measuring Cup. i) Digital Balance 300 gm, readability 0.01gm j) Hot plate with magnetic Stirrer k) Test kit for SOBM system (ES Meter, HPHT fluid loss apparatus, 50 ml retort, Pressurized Mud balance, Lab reagents) l) Refractor for glycol measurement m) PHPA determination kit n) U V Spectrophotometer for oil content determination in effluent & cuttings. o) Hydrometer (Full range to measure densities between 0.6 to 1.1 g/ml) and glass thermometer as per ASTM D1298. p) Glassware, Spares and Lab Reagents for Mud/ BrineTesting

J Facilities for handling SOBM: Base Oil storage capacity – 800 bbls (minimum) The elastomer of the rig should be suitable for SOBM as per standard industry practice. Rigs should be equipped with Verti G Cutting Drier capable of reducing oil on cuttings to less than 10%. - Cuttings handling capacity – Min 60 Tons/hr.) - G Force upto 400 - Screw conveyor (Minimum size requirements - 4 Mtrs L) - Monopump for Cutting drier 01 no with broad specs as follows: • Explosion proof body • Maximum speed (rpm) – 450 • Flow rate (max) – 40 m3 /hr (water) • Drive system : Variator with motor Other SOBM requirements: - Drains from the rig floor to be installed leading up to holding Pit/Tanks. - Pressure washers and Mud vacuum for SOBM cleaning - Mud savers - Flow Meter to record receipt of Base oil & SOBM.

Exhibit A(ii) - Appendix-9

The Cementing Unit shall be Inspected/Tested as per procedure attached herein at Exhibit A(ii) - Appendix-10

Mfgr.: Dowell Schlumberger / BJ / Halliburton

Diesel / Electric driven horizontal twin pump cementing unit with RCM / PSM or equivalent recirculating system having minimum 8 bbl slurry tub capacity and complete with all accessories including:

(a) Cementing unit should have two triplex pumps capable of developing a maximum discharge of 12 bpm with both triplex pumps and should be able to develop a maximum pressure of 10000 psi with either of the triplex pump. Cementing Unit should be rated for preparing 8.3 ppg to 22 ppg slurry at mixing rate 12 BPM to 3 BPM.

(b) Two Centrifugal Mixing Pumps having close-in pressure of 100-150 psi minimum and maximum discharge rate of 10 BPM per pump. Both Centrifugal pumps should be independent driven. Second mixing pump can be provided on a separate skid.

(c) Slurry re-circulating centrifugal pump / Booster centrifugal pump, rated working pressure 30-60 psi & maximum flow rate 20-22 BPM

(d) Cementing batch mixer: Twin of capacity 50 bbls X 2 Nos = 100 bbls with all relevant hoses, spares and accessories rated to prepare Cement Slurry up to 22 PPG. Make: Dowell Schlumberger / BJ / Halliburton or equivalent having following minimum detailed specifications.

The unit shall be Skid Mounted designed to operate in oilfield environment, circulate slurries while adding additional sacked chemicals/additives with dedicated mixing bowl & hopper arrangement, bulk supply line from main silos and cement slurry delivery line prior to pumping to high Pressure pumping Cementing units.

Centrifugal Pumps for each tank to handle/mix Cement slurry density up to 22 PPG and rated to give flow rate of 20 BPM and pressure 60 psi.

Shall be equipped with one Engine /Electric Motor, rated for minimum 250 HP (for single engine type prime mover. In case of electric motors, total sum of HP of different motors should be 250). It is to power for running of Mixing/ Recirculating centrifugal pumps and mixing tank agitators (extended up to bottom of batch mixer tank).

Mixing system shall contain independent slurry mixer of vortex (inclined eductor) Type/PSM type / RCM type with recirculation piping, Bulk cement intake piping and a diffuser to remove the air entrained in the bulk supply of cement to cementing unit. Additional Hopper arrangement for mixing cement additives on top of Batch Mixer.

Dead volume of Cementing batch mixer should not be more than 10 bbls.

(e) Provision for data recording / acquisition system up to 8 parameters to display, record pressure, flow rate, density etc. provision to down load to PC / Laptop with necessary software. Cementing unit shall be capable of transmitting data in WITS/ WITSML format in Real time to DAQ (Data Acquisition System) and data should be available at Rig sense.

(f) Cement surge tank of 70-80 cu.ft. capacity having load cell with Analog/ Digital weight indicator.

Silos for Cement & Barytes should have load cells with Analog/ Digital weight indicators.

(g) Contractor should supply minimum operational spares for cementing unit (most important are Triplex pump Fluid end, Mixing pumps, Booster pumps, high pressure LT-valves (as standby), high pressure LT-valves repair kit etc) for one year as per OEM recommendations (A list should also be provided at Document 7). Drilling contractor shall always maintain inventory of minimum one year operational spares as per the recommendation of cementing unit manufacturer [Supported by a list of items provided].

The Contractor should provide all special tools and equipment, as recommended by the OEM, required for the maintenance of the cementing equipment. (A list should be provided at Document 7)

The Contractor should provide one set each of the hard and soft copies of all the equipment Operation and maintenance Manuals and the Parts Catalogues etc. at rig.

(h) Option with ONGC to operate through own or third-party personnel. The cost of providing Cementing Operator, cement, cement additives, retainer to be borne by ONGC.

(i) Cementing Head:

One No each of cementing head & circulating head along with HP manifold with 2 nos. LT valves of the following sizes:

2. 13 3/8”- rated 4500 psi or higher– Dual Plug, Quick latch type Cementing head of reputed International make

3. 9 5/8” –rated 6000 psi or higher – Dual Plug, Quick latch type Cementing head of reputed International make.

4. Circulating head : 13 3/8” / 9 5/8”- 01 each ( BTC Thread) and 20" /30" – 1 no. with Leopard Connection. 20”Csg x Drill Pipe Stinger Head (min rated 1500 PSI) with suitable C-Plate for running in stringer Drill Pipes.

(j) Cross Overs: ( For Liner Cementing Head)

5 ½” FH/HT-55 Pin x 4 ½” IF Box -2 Nos each

4 ½” IF Pin x 5 ½” FH/HT-55 Box – 2 Nos each

(Min ID 2.75 Inch with 30 to 45 degree taper) Crossover should be compatible with available drill pipe string with 4-1/2" IF connection)

1. All working pressures are in cold working pressure with water.

2. Butterfly valves at Cementing Unit and Cement Batch Mixer should be pneumatic (actuator) type, with controls at respective console panel of Cementing Unit and Cement Batch Mixer.

(k) The contractor must have to provide copies of the treating iron certificates for all the items of High pressure manifold, Valves, lines etc. connected /part of cementing unit and keep the treating iron certification valid all the times as per the recommendation of the OEM.

(l) Maintenance of the cementing unit will be full responsibility of the drilling contractor.

Exhibit A(ii) - Appendix-10

CEMENTING UNIT INSPECTION PROCEDURE

Triplex Pump (No-load Run)

• Circulate water from the displacement tank, via Triplex pump-1, HP manifold and through bleed line back to the displacement tank. Ensure the variable choke in bleed line is fully open.

• With overpressure shut down set to 1000 psi (69 bar). Run the engine at idle speed for 2 min. Engage first gear and increase engine speed to full throttle and pump for 1- 2 minutes. Continue this procedure for each gear and record rates and pressures for each stage. Do not exceed 8.5 bpm.

• Carry out similar procedure for the Triplex pump-2,

Triplex Pump-1 Triplex Pump-2

Gear # Engine RPM Rate (BPM) Pressure (PSI) Engine RPM Rate (BPM) Pressure (PSI)

Idle Speed N/A N/A N/A N/A

1 (Full throttle)

2 (Full throttle)

3 (Full throttle)

4 (Full throttle)

5 (Full throttle)

Values of the Engine parameters (of triplex pumps) at full RPM

Parameter Expected Range Triplex Pump-1 Triplex Pump-2

Engine Oil Press 50-80 psi

Engine Coolant Temp <210 ºF (<99 ºC)

Transmission Oil Press 160 – 225 psi

Transmission Oil Temp 180–225ºF (82–107ºC)

Power End Lube Oil Press 65 – 125 psi

Power End Lube Oil Temp <180ºF (82ºC)

Pressure Test of Triplex pumps:

• Low pressure test: Raise the pump pressure up to 200 to 300 psi (For both triplex pumps)

• Higher pressure test (Triplex pump-1): Raise the pump pressure up to 10,000 psi,

• Higher pressure test (Triplex pump-2): Raise the pump pressure up to 5,000 psi.

• Check and run both the pumps together to achieve discharge of minimum12 bpm.

Mix Water Pump (Low Pressure)

• Circulate water from displacement tank, via Primary mix water pump, through mixing manifold into mixing tub. Ensue slurry chief knife gate is fully closed.

• Transfer water (using front engine) into the mixing tub by briefly opening each valve on the mixing manifold.

• Record discharge pressure and rate for the following combinations.

• Carry out similar procedure for the Secondary mix water pump (using rear engine).

Valve Combination Primary mix water pump Secondary mix water pump

Discharge rate Pressure (PSI) Discharge rate Pressure (PSI)

Both Valves Closed (Min.press.range: 100-150 psi)

Thin-up Valve Open

Both Valves Open

Pressurizing Pump (Booster Pump)

• Circulate water from displacement tank via Front pressurizing pump, front and rear triplex pumps, HP manifold through the return bleed off line back to the displacement tank. Close the Slurry Recirculation Valve.

• Engage the front pressurizing pump. Start the front engine and bring it to full throttle.

• Open the Slurry Recirculation Valve and shift both triplex pumps to gravity feed.

• With the slurry tub almost full, shift pressurizing pump suction from displacement tanks to mixing tub. Continue circulation for few minutes noting discharge pressure at the pump. Close the Slurry Recirculation Valve and record Closed-in Pressure.

• Shift both triplex pumps to pressurized feed. Observe that the slurry tub level decreases while water returns to the displacement tanks.

• Carry out similar procedure for the Rear pressurizing pump.

Note: Booster pump rated working pressure should be in the range of 30-60 psi and maximum flow rate in the range of 20-22 bpm

Slurry Recirculation Valve position Acceptable Range Discharge pressure (Front Pressurizing Pump) Discharge pressure (Rear Pressurizing Pump)

Open 55 - 75 psi

Close 70 - 80 psi

Mixing Simulation Test

• Set overpressure shut downs to 3500 psi for both pressurizing (Triplex) pumps.

• Recirculate water through the Slurry Chief into the mixing tub using the front pressurizing pump.

• Use the rear pressurizing pump to recirculate the averaging tub and pressurize the triplex suctions.

• Using both triplex pumps, pump out of the averaging tub back to the displacement tank. Establish a rate of 4 bpm for 15 min. Slowly close the choke until 3,000 psi is reached, continue for 15 min.

• Manually operate knife gate to check operation and opening/ closing in the correct direction.

• Set Slurry King Control to automatic. Raise and lower density set point to check operation and knife gate opening / closing in the correct direction.

• Observe and record the following parameters of the triplex pumps after 30 min.

Parameter Front Pump Rear Pump

Engine Oil Pressure (PSI)

Engine Coolant Temperature (°C)

Transmission Oil Pressure (PSI)

Transmission Oil Temperature (°C)

Converter Lock Up Pressure (PSI)

Power End Oil Pressure (PSI)

Power End Oil Temperature (°C)

Knife gate Indicator Test

• Check the knife gate working under no-load condition, i.e. while operating knife gate from the control panel, it should go in and out. Proper closing and opening is to be checked on the console.

• Observe Hydraulic System pressure

Cement Batch Mixer

No-load Run Test

• Circulate water from the batch tanks, via front centrifugal pump, LP manifold back to the batch tank.

• Select first gear and increase engine speed to full throttle. Pump for 1 to 2 minutes before engaging any hydraulics. Observe and record hydraulic pressures for each pump and agitator.

• Record the Engine RPM both in Idle Speed and full throttle speed: ____________ / _____________

Parameter at Full RPM Expected Range Value

Engine Oil Pressure 50-80 psi (3.4 – 5.4 Bar)

Engine Coolant Temperature <210 ºF (<99 ºC)

Hydraulic Oil Temperature 140-270 ºF

Compressed Air Pressure 80-120 PSI

Hydraulic System Test

• To test Hydraulic system #1, circulate water from batch tank-1 via the CP-1 pressurizing pump, LP manifold back batch tank-1. Note the discharge pressure

• Engage the rear pressurizing pump. Start the rear engine and bring it to full throttle. Engage the CP-1 Pump

• Observe the batch tank level. Continue circulation for several minutes noting discharge pressure at the pump. Record Circulating Pressure (acceptable range 45-55 psi for discharge valve in open position and in the range of 60- 70 psi for discharge valve in close position).

• Start Agitator # 1 (AG-1) by turning the hydraulic needle valve on the control console. Slowly turn it fully in and check if the Agitator in tank#1 is turning slowly. Throttle up the engine and check speed of Agitator # 1.

• To test Hydraulic System # 2, follow the similar steps (for CP-2 & AG-2).

• Keep running both agitators for several minutes and check for noise and vibration.

• Circulate both pumps for several minutes and circulate water from Tank # 1 to Tank # 2. Observe the engine and hydraulic parameters.

• Establish feed from Batch mixer to the cement unit and vice a versa.

Hydraulic Pressure Expected Range Hydraulic System# 1 Hydraulic System# 2

Circulating Pump (CP) 500-2300 PSI CP-1: ……………. psi CP-2: ………….. psi

Agitator (AG) 100-1800 PSI AG-1: ……………. psi AG-2: ………….. psi

Note:-Above Tables to be duly filled by the contractor & verified by TPI during Inspection for Acceptance.

Exhibit A (ii) - Appendix-11

SCOPE OF WORK: FOR OFFSHORE RIG INSPECTION

ONGC may offer different types of Charter Hire/ONGC offshore rigs for inspection like Slot type Jack-up, Mat supported type Jack-up, Cantilever type Jack-up, Platform rigs, Drill Barge, Semi-submersible and Drill ship. TPI has to carry out final inspection to ensure the readiness of the Rig, prior to acceptance of the rig for commencement of operations with the following scope of work –

1 To physically verify, test and check the rig equipment in conformity with the Tender/Contract Specification of the Rig.

2 Assessment of equipment condition and standard of maintenance, in accordance with API standards; the equipment manufacturer's specifications and recommendations.

3 Opening of all major items of equipment for internal inspection for the purpose of a detailed examination of gear teeth, bearings, chains and ancillary parts for excessive wear, damage, cracks and other defects and for the measurements of clearances. Drilling Contractor will open and prepare the items for inspection wherever required.

4 Conducting function testing, pressure testing, Endurance testing, load testing and insulation resistance checks for all equipment on board the drilling unit, as applicable. Drilling contractor will conduct the test, as per OEM guidelines or as per TPI inspector, as applicable.

5 A check that the proper safety devices are installed and are working correctly to prevent accidents and equipment failures.

6 Evaluation of effectiveness of the Preventive Maintenance System.

7 The inspection will broadly cover the following areas/equipment, but not limited to, (a) Drilling equipment including traveling equipment, load carrying components, Draw works and Drill-line anchor, Rotary table, Derrick substructure, Auxiliary equipment like casing Stabbing board, Drilling instrumentation, Wire line unit, etc. (b) Drill string and Handling equipment, Substitutes, Fishing Tools, Communication Equipment, Burner booms, Cementing Unit etc. (c) Mud system consisting of mud pumps, high pressure piping, Solid Control Equipment, Mud pits and Centrifugal pumps, Bulk system etc. (d) Well control equipment including BOP Control system, blow-out Preventers etc. (e) Electrical equipment includes all AC Motors, all DC Motors, Engines & Generators, Transformers, Air Compressors etc. (f) Barge/Marine equipment. (g) Safety equipment. (h) To verify/ check safety, cleanliness, working environment and housekeeping on offered drilling unit as per international practices.

8 Competency certification i.e. Experience and Qualification of the Key personnel proposed to be deployed on the respective rigs.

9 Verify / check all statutory certificates and valid HSE management system as per ISO: 9001, ISO: 14001 & ISO: 45001 in respect of the Drilling unit.

10 Fit for purpose verification as per “Rule 30” for OISD & other guidelines of OISD.

11 Discuss the final draft Inspection report with consent of ONGC. To submit the final Inspection Report (soft copy) within 3 days from “closeout meeting” and one hard copy of the comprehensive Audit Report within 15 days. Reports shall comprise findings / remarks against each clause of technical specification as indicated in the TPI Report template (As per Exhibit A), being provided by ONGC.

Exhibit A(ii) - Appendix-12

PHYSICAL AND MEDICAL FITNESS CRITERIA

(Ref Note 3, Exhibit -B)

Physical Fitness Criteria:

This would be the first line of screening to ensure that a person with a physical deficiency, although otherwise healthy, will not be permitted to work at offshore as they could be a liability to safe working and evacuation condition. Personnel with the following defect will be considered as unfit:

a) One eyed person

b) Person with missing limb

c) Amputees(long bone/Girdle/Subtotal hand or Foot)

d) Spinal deformity – Kyphosis/Scoliosis/greater than 20 degree

e) Inequality in length of lower limb greater than 5 centimetre.

Medical Fitness Criteria:

This would be second line of screening to ensure that a healthy employee is allowed to work at offshore. Medical conditions which would debar an individual from being fit for offshore are given below:

Active tuberculosis (TB), healed TB subject to fitness by treating doctor

Lung disease with peak flowmetry less than 40%.

Post lobectomy/ pulmonectomy

Stroke with residual deformity

Recurrent vertigo/Meniere’s disease

Chronic liver disease (Decompensated)

Chronic renal failure (on dialysis)

Bleeding disorders & patients on anti- coagulant

Patients on bi ventricular pacemaker/ combo devices

CAD with significant LV dysfunction

Cardio-myopathies

Major Valvular disorder

Psychotic history

Suffering from major depressive mood disorder

Panic attacks interpersonal dysfunction

Patients on psychotropic drugs

Substance abuse.

All post-operative cases till certified by treating surgeon.

Large hydrocele

Ankylosing spondylitis with restrictive mobility of spine.

Chest expansion less than 3 cm

Polyarthrities of rheumatologic origin, involving large joints

Degenerative lumber spine disease

Spinal canal disease with claudication

Any bony disease or traumatic disorder significantly affecting job performance.

Active Rheumatoid Arthritis (RA) or RA with deformities

Total deafness in one ear

Bilateral sensory neural Hearing Loss (SNHL) greater than 80%

Noise induced hearing loss greater than 50dB in both ears.

All types will be treated as unfit unless fitness for offshore duty is certified by Oncologist.

All types of infectious skin disease will be treated as unfit unless fitness for offshore duty is certified by Dermatologist.

Retinal detachment

Diabetic retinopathy of proliferative variety

Hypertensive retinopathy – grade III & IV

Colour blindness of any type

One eyed person

Macular degeneration (Central type)

Uncontrolled glaucoma with field changes

High myopia or Hypermetropia of minus or plus 4 or more

Night blindness

Fitness criteria for physical endurance and life-style diseases

Disease Parameter Unfit Regular Medical Regular Medical Supervision needed Supervision not needed

Obesity BMI 40 35.0 TO 39.9 Less than 35

Diabetes HbA 1c 9.0% 7.0 to 8.9 Less than 7

CAD LVEF Less than 40% 41% to 45% Above 45%

COPD PFT FEV1<50% FVC<60% of Predicted

ADDITIONAL MEDICAL AND PHYSICAL FITNESS CRITERIA FOR OFFSHORE GOING FEMALE EMPLOYEES

The female employee will be treated unfit if she has anyone of the following condition.

A. Conditions related to the Child birth (Pregnancy)

Sl.No. Condition/Unfit criteria Investigations required Examination

1 Complete antenatal period (Pregnancy) Pregnancy card test, USG abdomen (Obstetric) By specialist doctor qualified with MD/MS/DNB in Gynaecology & Obstetrics or Diploma in Gynaecology & Obstetrics where above degree holder specialist is not available

2 Up to six months of delivery (Child Birth)

3 Upto six weeks from the date of miscarriage (Abortion) or Medical termination of Pregnancy (MTP) Pelvic USG

4 History of any major surgery in reference to obstetrical condition As advised by Specialist

B. Other disorders of females (gynecological conditions):-

• All Gynecological conditions will be treated as unfit unless fitness for offshore duty is certified by qualified Gynecologist.

Exhibit A(ii) - Appendix-13

Sr. No. Well bore clean up tool specifications (WBCU) for 9 5/8” and 7” casing

A The contractor shall provide the complete set of WBCU tools. Each set shall have back up tool. Well bore clean up tool specifications (WBCU) for 9 5/8” and 7” casing.The following are the Wellbore Cleanup equipment technical specifications.

1. Casing scrapper tool a. To ensure effective scrapping operation in various casing sizes b. To work effectively in variety of fluid types c. Incorporate rotating or non-rotating spring blades to provide 360° coverage when stationary d. No bolts or fixings that can become loose down hole, resulting in lost components. e. Robust design for blade retention f. Capable of rotation at minimum of 90 rpm. g. Capable of pumping through at rates >20 bpm h. Capable of operating effectively at annular velocities of ≥250ft/min. i. Possess axial and torsional ratings equivalent to or greater than the work sting used to run equipment in hole. j. The equipment shall be Heavy Duty' casing cleaning tools that can be used in combination with a bit or mill to drill out cement plugs and/or cementing accessories.

2.Casing Brush Tool: a. To ensure effective operation in various casing sizes. b. To work effectively in variety of fluid types. c. Incorporate rotating or non-rotating spring brush to provide 360° coverage when stationary. d. Robust design for blade retention. e. Capable of rotation at minimum of 90 rpm. f. Capable of pumping through al rates >20 bpm g. Capable of operating effectively al annular velocities of >250ft/min. h. Possess axial and torsional ratings equivalent to or greater than the work string used to run equipment in hole.

3.Wellbore Filtration Tool: a. Ensure effective debris extraction in various casing sizes in a single trip. b. Work effectively in variety of fluid types. c. Isolate the annulus around the tool by use of a rubber diverter cup or alternative to ensure 100% debris extraction. d. Ensure that the well is not swabbed or surged while R/I or POOH whether full or not. e. Facility to easily and quickly inspect the contents to determine well cleanliness on the drill floor (or at the well site) f. Allow rotation of string when in hole. g. A mechanism like rupture disc or a modulating valve or suitable alternative to relieve pressure in the event the tool plugs up. h. Capable of circulating through the tool i. Capable of pumping through at rates >20bpm j. Capable of effective filtration up to depths of up to 6000m k. Possess axial and torsional ratings equivalent to or greater than the work string used to run equipment in hole.

4.Downhole magnets: a. Ensure effective operation in various casing sizes b. Work effectively in variety of fluid types. c. One piece main mandrel d. Capable of rotation al minimum of 90 rpm e. Capable of pumping through at rates >20 bpm f. Capable of operating effectively al annular velocities of >250ft/min g. Possess axial and torsional ratings equivalent to or greater than the work string used to run equipment in hole h. Contractor is to quote capacity / strength of magnet (kg of ferrous material recovered) i. Tool should be capable of being cleaned on surface safely (i.e. safe manual removal of ferrous material)

5.Full gauge Stabilizers/ Drift Sub: a. Ensure ability to drift various casing sizes b. Work effectively in variety of fluid types c. Capable of rotation at maximum of 80 rpm d. Possess axial and torsional ratings equivalent to or greater than the work string used to run equipment in hole.

Wellbore clean out tool equipment -General Condition a. Contractor to provide connection of tool joint in line with the drill string in use. Contractor to provide any additional crossover sub required if any. b. For each tool the contractor should specify the operating parameters, tool specifications and any special handling instruction complete with tool schematics c. The contractor shall be fully responsible for the equipment provided. The design and construction must be in line with any relevant industry standards and recommended practices such API RP7G. d. Contractor to provide two sets (i.e. 1 Primary + 1 Back up) of wellbore clean up equipment and services. e. Contractor shall ship WBCO tools to the rig in assemblies

Exhibit A (iii)

SCHEDULE OF RESPONSIBILITIES FOR DRILLING EQUIPMENT MATERIALS, SUPPLIES AND SERVICES

Sl No. Description Provided by At Cost of

ONGC Contractor ONGC Contractor

1 Fresh water for drilling/cementing and wash down of Contractor’s equipment as per requirement mentioned at Sl No. 47 of Exhibit A (ii) ✓ ✓

2 Drinking Water as per requirement mentioned at Sl No. 47 of Exhibit A (ii) ✓ ✓

3 Fresh Water in excess of requirement mentioned at Sl No. 47 of Exhibit A (ii) ✓ ✓

4 If water maker is producing less than the required quantity of Fresh water as mentioned at Sl No. 47 of Exhibit A (ii) ✓ ✓

5 Diesel fuel for all equipment of the drilling unit and mud , subject to condition at Sl No.6 below ✓ ✓

6 Diesel fuel for all equipment of the drilling unit except mud, in excess of quoted quantity as per schedule of rates, calculated on quarterly basis ✓ ✓

7 Thread dope for Company’s tubular equipment. ✓ ✓

8 Oil for mud or completing well oil emulsions & other special drilling and completion fluids. ✓ ✓

9 All drilling fluids and additives. ✓ ✓

10 All cement, mud, chemicals and additives ✓ ✓

B. TRANSPORTATION

1 All marine transportation required for Contractor’s and Company’s equipment, supplies, fuel, drill water, potable water, consumables and personnel between Company’s shore base and Drilling Unit, subject to A 4 above. ✓ ✓

2 Supply vessel for Company’s & Contractor’s requirement in the area of operation including standby vessel for safety of well, crew and Drilling Unit during operations. ✓ ✓

3a Air/Sea Transportation of the Contractor’s personnel as per Serial No. 1-25 and 27 of Exhibit-B between the Company’s shore base/nearest National Airport Whichever is nearer to Drilling Unit and Drilling Unit and back, subject to the conditions therein Exhibit-B. ✓ ✓

3b Air/Sea Transportation of the Contractor’s personnel as per Serial No. 26 of Exhibit-B between the Company’s shore base/nearest National Airport, whichever is nearer to Drilling Unit and Drilling Unit, to & fro, subject to the conditions therein Exhibit-B, in crew change Chopper/Boat only, if available. ✓ ✓

4 Marine transportation if required for offloading Contractor’s shore base supplies and equipment from Drilling Unit after commencement of contract and for loading shore base supplies and equipment up to termination of contract. ✓ ✓

5 Air transportation of the contractor’s personnel as per Exhibit-B between rig to shore base in case of medical emergencies provided the emergency is certified by the rig medical doctor and company Tool Pusher ✓ ✓

6 Transportation of Marine/ Warranty/ Class Surveyor/ Naval Inspectors/ ISO Auditors, after the Commencement of the Contract (max two at a time) ✓ ✓

7 Contractor may have personnel in excess of crew listed at Exhibit-B for which the request from the Contractor will be considered on its merit by the ONGC, if considered necessary. The additional personnel so agreed will be transported by boats/helicopter by the Operator on chargeable basis to the Contractor. ✓ ✓

8 Drill strings inspected by a recognized inspection agency mutually acceptable by both parties prior to the first Well unless inspected within last six months in previous contract, and thereafter every six months or 50,000 feet of drilling, whichever occurs first, in line with the Model Contract Clause 4.1(c).Transportation of Drill String by boat, to the base, if required due to Variable Load constraint only. This shall require prior Approval of ONGC. ✓ ✓

9 For all purposes other than mentioned at 1-8 above, on request of the Contractor, ONGC may provide logistics for personnel and supplies, including chopper services, subject to availability, on chargeable basis to the Contractor. ✓ ✓

1 Identifying, marking and surveying the drilling locations. ✓ ✓

2 Work boats for towing the Drilling Unit between locations. ✓ ✓

3 Work boats for all other purposes (wherever applicable and if requested by Contractor, subject to availability) Otherwise providing OSV shall be the responsibility of the Contractor at its cost ✓ ✓

D. MAINTENANCE SUPPLIES & SPARES

1 Repairs, parts & operating supplies for Company’s equipment. ✓ ✓

2 Repairs, parts for Contractor’s equipment including BOP ✓ ✓

E. WELL EQUIPMENT

1 All casing & tubing to be used in wells. ✓ ✓

2 Any well guards, platforms or similar structure. ✓ ✓

3 Well location marker buoys. ✓ ✓

4 Special size tools for Company’s special casing. ✓ ✓

5 Drill stem and formation testing tools and services. ✓ ✓

6 Bits and Directional deviation tools, equipments and services. ✓ ✓

7 All production and completion equipments other than as set out Technical Specifications at Annexure-III Exhibit A of tender document. ✓ ✓

F. THIRD PARTY DRILLING SERVICES

1 Diving equipment and services essential for drilling operations only [subject to Article 3.5 of Annexure-II of tender document. ✓ ✓

2 Cementing services and personnel ✓ ✓

3 Electric Logging Unit and services ✓ ✓

4 Geological and Mud Engineering Services. ✓ ✓

5 Mud logging Unit and related services. ✓ ✓

6 Weather forecasting services, if required by the Company ✓ ✓

1 All permits and licenses for Radio. ✓ ✓

2 All permits and licenses required for drilling site and to permit access thereto and egress there from required. ✓ ✓

3 Seabed inspection of location. ✓ ✓

4 Additional welders required by Company. ✓ ✓

5 Additional third party contractor personnel including meals, transportation and accommodation required by Company. ✓ ✓

6 Location approval or any other similar formality from Contractor’s underwriters. ✓ ✓

7 Security & Naval Defense Clearance of Contractor’s personnel & Rig & Equipment from Ministry of Home Affairs & Defense. ✓ ✓

8 Weather forecasting services ✓ ✓

H. MISCELLANEOUS

1 Lubricants, Grease, Hydraulic operating fluids and additives for the drilling unit and all Contractor’s equipment in accordance with manufacturer’s specification and recommendation. ✓ ✓

2 All personnel, safety equipment (except standby vessel) for Contractor’s and other personnel. ✓ ✓

3 Mud pumps piston and liners. ✓ ✓

4 Labour on the Drilling Unit to load and unload all Contractor’s and Company’s equipment, materials. ✓ ✓

5 Expenses of supply and auxiliary vessel mooring lines at the drilling unit including towing bridles, pendant wires and shackles etc. ✓ ✓

6 Overtime beyond normal Work Schedule, meal and accommodation for personnel when required by Company for any reason including transportation delays. ✓ ✓

7 Underwriter’s representatives for Drilling Unit move required by Contractor/Contractor’s underwriters. ✓ ✓

8 Office for Contractor’s personnel and materials at Company’s shore base. ✓ ✓

9 All Radio communication equipment’s. ✓ ✓

9A Usage of INMERSAT, FAX, MINI-M TELEPHONE by Operator & It’s representative (Excluding Service charges) ✓ ✓

9B Bandwidth for video conference ✓ ✓

10 Cementing unit and Cement mixing pumps rental charges even if service is performed by Company other than that supplying the Cementing Unit. ✓ ✓

11 Repair, maintenance, cost of spares and modifications to Cementing Unit. ✓ ✓

12 Location survey and marine survey, if any required in addition to being carried out by Company, by Contractor/Contractor’s underwriters. ✓ ✓

13 Transfer hoses on both starboard and port side and its replacements. ✓ ✓

14 Mooring lines and its replacements. ✓ ✓

15 (i) Contractor to provide boarding & lodging of 10 (ten) personnel of Operator and/or its third-party on board the Drilling Unit per day at its own cost (average quantity to be calculated on monthly basis). If at the end of month, average no of personnel per day exceeds 10, then, ONGC will pay US$ 10 per day per person and in case a person does not stay overnight on Drilling Unit and takes only meal (s), then US$ 4 (United States Dollars four only) shall be payable for individual meal, but not exceeding US$ 10 per day per person Note: All rates are exclusive of GST and 3 Individual meals are equivalent to 1 Full meal ✓ ✓

(ii) Dry fruit packets (40 gram Almonds, 40 gram Cashew nuts, & 20 gram resins per person per day for stay on board rig to company personnel ✓ ✓

16 Medical services (first aid only) on board the Drilling Unit for all Company and Company’s third party personnel. ✓ ✓

17 All equipment and services not specified herein. ✓ ✓

18 OISD and other mandatory regulatory compliances ✓ ✓

19 Police verification of contractor’s manpower ✓ ✓

20 COVID-19 kit for the Contractor’s manpower to follow government guidelines. ✓ ✓

21 Cost of any medical test / treatment incurred, Board and Lodging of Contractor’s personnel during any quarantine period, as per SOP’s followed by ONGC in view of ongoing pandemic or any unforeseen situation. ✓ ✓

22 Provide Galley Equipment and Dish Washer to ensure hygienic handling of Kitchen activities. Operation & Maintenance of the same all Galley Equipment. ✓ ✓

The following is the minimum crew requirement. Contractor may have more personnel in excess of the following crew list, if considered necessary for which their request will be considered on its merits by ONGC. Those personnel shall be transported by boats/helicopter by Operator on chargeable basis to Contractor. However, Marine/ Warranty / Class Surveyor/ Naval Inspectors / ISO Auditors, after the Commencement of the Contract, (maximum two at a time) shall be transported by helicopter at no cost to the Contractor.

Sr. No. Personnel Minimum present on board at any time for 2 shift operations

1. Drilling Superintendent (Rig Manager) (on rig / base as required) 1

2. Tool Pusher 1

3. Tour Pusher /Night Tool Pusher 1

5. Asst. Driller 2

6. Derrickman 2

7. Rig/Floorman/Roughnecks 8

8 Crane Supervisor 1

9 Crane Operator 2

10 Roustabouts 10

11 Chief Mechanic 1

12 Chief Electrician 1

16 Storekeeper 1

18 Radio Operator 1

19 Barge Engineer 1

20 Safety Officer 2

21 Electrician 1

23 Electronics Engineer (Optional) Select

24 Solid Control Engineer 1

25 Additional Personnel 4

26 Specialist/ Expert/ Contractor's Senior Management, for 'Improving Rig Performance', subject to the conditions at Note below. (Optional) Select

27 HSE Manager (on rig/base as required) (Can manage more than 1 rig) 1

(a) The Key personnel i.e. OIM (Offshore Installation Manager) Drilling Superintendent, HSE Manager, Tool Pusher, Tour Pusher, Driller, Asstt. Driller, Chief Mechanic, Chief Electrician, Radio Operator, Barge Engineer, Electronics Engineer and Safety Officer must have at least three years offshore experience in their respective position, out of which, at least one year should be on the Jack up rigs and should be fluent in English.

(b)The details of all personnel i.e bio-data, proof of qualification etc., should be submitted and got approved by Company before commencement of the work.

(c) In case of key personnel, if the contractor intends and proposed to promote such personnel to the next higher post, may do so, provided such personnel are exposed and given vigorous on the job training to take up the responsibility of the next higher post. In case Derrickman, who have put in a minimum of four ( 4) years offshore experience in the respective post and if the Contractor intends and proposed to promote such personnel to the next higher post, may do so, provided such personnel are exposed & given vigorous on the job training for at-least six (6) months to take up the responsibility of the next higher post. Contractor shall be required to submit each case along with the recommendations of ONGC Tool Pusher for approval of ONGC. However, such approvals shall be subjected to review by ONGC based on the performance of the individual on the promoted post. However, if the performances of promoted personnel does not found to be satisfactory, ONGC reserves the right to ask the contractor for the change or revert back to the original position. Drilling Superintendent, Tool Pusher, Tour Pusher, Driller, Asstt. Driller should possess valid IWCF / IADC Well Sharp Certificate from IWCF/IADC accredited well control training centre at appropriate level.

(d) Medic should have at least three years’ experience as a registered medical practitioner and be a MBBS degree holder.

(e) Solid Control Engineer with minimum two years’ experience should be provided to run the Centrifuge and Cutting Drier.

(f) Electronics Engineer is optional. Contractor has to indicate the requirement of the Electronics Engineer at the time of bidding stage. If it is required, the helicopter charges will be borne by ONGC.

(g) Catering Persons- 14. Short deployment Rate of $10 shall be deducted for each absent catering personnel.

(h) After commencement of the contract, first Sign-Off of each crew member (Onboard as on the date of Commencement), limited to the numbers listed at Exhibit-B and with Approved CV, including 14 Nos of catering persons, shall be transported by Boat / Helicopter on non-chargeable basis.

(i) Drilling Superintendent (Rig Manager) shall be allowed 30 days leave over a period of Contract i.e., 3 years, subject to suitable replacement and with approval of CV by ONGC.

(j) Contractor to plan the deployment of Additional personnel mentioned at item 25 as per the operational requirement, to ensure uninterrupted operations.

(k) Crane Operator should have API RP-2D certification and must have at least two years offshore experience as a crane operator.Crane Supervisor should have API RP-2D certification and must have at least three years offshore experience as a crane operator.

(l) Any rig crew (preferably deck crew) meeting the experience & qualification criteria of crane operator may be utilized for crane operations by the contractor as per operational requirement. This shall require prior approval of OIM, ensuring all safety requirements, at the risk of contractor. However this shall not be construed as replacement of regular crane operator(s). ONGC Company man to be intimated appropriately for such usage.

(m) The 2nd Safety Officer with at least one year offshore experience in their respective position on the Jack up rig is acceptable subject to meeting all other qualification criteria.

2 Training to the Crew Personnel

a) All the crew members including catering personnel should have undergone BOSIET - Basic Offshore Safety Induction and Emergency Training (with EBS) approved by OPITO, which should cover all the trainings, including the Elementary First Aid. No personnel is allowed to go on offshore rigs without undergoing out the above training. Additionally, they should also have undergone training for safety while working in areas with hazard of H2S presence. b) Barge Master should have undergone Helicopter Landing Operation Training (HLO). c) Crane operator /Crane Supervisor/ Roustabout should have undergone HLA / OHETMC training d) All the offshore going crew, including catering crew, should have IADC Rig pass certification. e) HSE Manager and Safety Officer should have valid NEBOSH (National Examination Board in Occupational Safety and Health) International Technical Certificate in Oil and Gas Operational Safety/ NEBOSH HSE Certificate in Process Safety Management. Note - HSE Certificate in Process Safety Management. shall be accepted after NEBOSH discontinues issuing International Technical Certificate. f) OIM should have undergone Major Emergency Management - Initial Response Training (MEMIR) approved by OPITO.

3 Fitness Certificate

All Offshore going personnel should have valid Fitness Certificate based on ONGC Medical and Physical Fitness Criteria (as per list attached at Exhibit A(ii) - Appendix 12 of the tender document, issued by the Registered Medical Practitioner with minimum qualification of MBBS. The validity of such certificate is two years from the date of issue. Contractor shall ensure to maintain valid Certificates for each individual onboard, and should present the same for verification by ONGC, anytime during the tenure of the Contract. Contractor to submit the Fitness Certificate issued post NIT date, at the time of submission of CV for Approval by ONGC, during Mobilization period.

4 The Duty Pattern of the all offshore going crew personnel (including catering crew)

i. The Duty Pattern of the crew personnel, shall be mutually agreed and signed between Operator and the Contractor in the “Bridging Document”, post LOI, in line with the OISD Rules / Guidelines for ‘Hours of Work and Rest’. ii. If duty days of any crew member(s) exceeds by 7 days beyond the agreed Duty Pattern in the Bridging Document, the Contractor shall be liable to bear cost of Air transportation of those crew members. iii. Any shortfall in deployment of any of the crew personnel, due to above situation shall attract Short Deployment Rates as per Exhibit - C.

5 Conditions for deputing Specialist/ Expert/ Contractor's Senior Management Personnel

i) Specialist/ Expert/ Contractor's Senior Management personnel, like Software Engineer, HSE Specialist, Operation Manager, Motivators, Directors etc., can be deputed by the Contractor for 'Improving Rig Performance'. ii) Any such deputation by the Contractor shall be solely at the risk and cost to the Contractor without any liability to ONGC, except provided specifically under the contract. iii) Specialist/ Expert/ Contractor's Senior Management shall be transported by ONGC, in crew change Chopper/Boat only, if available, along with other crew as at 1-25 above. However, if Contractor transports such Personnel on Chopper other than crew change Chopper, ONGC shall provide transport, but chargeable to the Contractor. iv) Only one Specialist/ Expert/ Contractor's Senior Management personnel shall be allowed in 1 crew change and maximum two (2) Specialist/ Expert/ Contractor's Senior Management can remain onboard at any point in time. v) No Regular Crew as mentioned at 1-25 above shall be allowed under Item 26.

6 Visit of Rig Manager and HSE Manager onboard the Rig

i) Rig Manager should visit onboard the Rig preferably for 5 nights per month totaling minimum 15 nights per financial quarter. ii) USD 1200 per short night will be deducted in case Rig Manager stays less than 15 nights onboard per financial quarter or pro rata thereof. iii) HSE Manager should visit onboard the Rig preferably for 3 nights per month totaling minimum 9 nights per financial quarter. iv) USD 1500 per short night will be deducted in case HSE Manager stays less than 9 nights onboard per financial quarter or pro rata thereof. v) HSE Manager can manage more than 1 rig for single contractor. vi) Deduction for short stay for Rig Manager and HSE Manager shall not be made for reasons attributable to ONGC. vii) In case partial financial quarter situation arises due to start / end of the contract falling in middle of a financial quarter then the rig visits shall be on prorate basis.

Short Deployment Rates for Rig Crew Personnel

Sl No. Category Min. Crew on board Short Deployment Rates in US $ (per person)/Day

1 Drilling Superintendent (Rig Manager) 1 (on rig/base as required) 1200

2 Tool Pusher 1 500

3 Tour Pusher /Night Tool Pusher 1 500

4 Driller 2 300

5 Asst. Driller 2 200

6 Derrickman 2 100

7 Rig/Floorman/Roughnecks 8 100

8 Crane Supervisor 1 100

9 Crane Operator 2 100

10 Roustabouts 10 100

11 Chief Mechanic 1 500

12 Chief Electrician 1 500

13 Welder 1 100

14 Motorman 2 100

15 Mechanic 2 100

16 Storekeeper 1 100

17 Medico 1 100

18 Radio Operator 1 100

19 Barge Engineer 1 500

20 Safety Officer 2 500

21 Electrician 1 100

23 Electronics Engineer 1 500

24 Solid Control Engineer 1 200

25 Additional Personnel 4 100

26 Specialist/ Expert/ Contractor's Senior Management, for 'Improving Rig Performace' 1 NIL

27 HSE Manager 1 (on rig/base as required) 1500

Non-Availability of Rig Equipment (s)

Non-availability of following listed equipment and/or expiry of COC/any other certificate required to be maintained as per the provisions of the Contract, but not leading to shut down of Rig operations under Clause 3.4.4 of the Contract, shall be considered sub-optimal performance, in normal or standby mode. Following equipment minimum required as per contract should be maintained by the Contractor at any point of time. In case of non-availability of such equipment as per minimum, not leading to shutdown, shall attract equipment Non-Availability Deductions, as per table below:

Sl No. Description of Item Non-Availability Deduction Rates in USD $/Day Remarks

1 Mud Pump (Min. required as per contract) 100 The Non-Availability Deduction mentioned are for each item.

2 Crane (Min. required as per contract) 100

3 Mud Processing Equipment. As per Exhibit A(ii) Sl no. 18 50

4 Mud testing Equipment (As per Exhibit A(ii) - Appendix 8-I) 20

5 Drilling Instrumentation System : Non-Availability Deduction shall be applicable in case the following drilling parameters are not available at Drillers Console, Display Monitor at Company Man office, and Drilling Parameter Recorder as per Exhibit A(ii) - Appendix-4 50 The Non-Availability Deduction mentioned are for each parameter.

6 Iron Rough Neck 100

7 For any equipment(s) not having valid certification, if required to be maintained as per the provisions of the Contract 100 For each equipment

Note: 1) The above Non-Availability Deduction shall not be applicable in case of rig under EBDR Clause 3.4.4. of GCC. 2) The Non-Availability Deduction shall be applicable due to non-availability each day, irrespective of the no. of hours. 3) Waiver of Non-Availability Deduction has to be taken by the contractor on format provided at Exhibit A(v) when required for planned maintenance.

(Format for seeking waiver of Deduction for equipment non-availability)

Request for Waiver of Non-Availability Deduction (Against Exhibit A (iv))

Equipment (s) Name:

Brief of Works Planned

Undertaking by the Contractor:

The requested waiver is at sole risk and cost of the contractor and shall be limited to the date requested.

Requested by (OIM/RM) Recommended by Approved

Name & Signature (Onboard ONGC representative) (ONGC RM)

Note: This waiver is only for equipment under Exhibit A(iv)

Yes New NOV Brandt Select

No Premium Thule Mud Centrifuge with fully variable speed independent main drive and back drive motors and a maximum G force of 1900G or more

New Rig Derrick Mud Centrifuges for low gravity solid control and barite recovery with a maximum G force of at least 1900G Water Maker Type

Select 8" MI Swaco Select

Electrical 8-1/4" Axiom Heat

Hydraulic Select N/A Select RO

Select 6-1/2" Select Yes

Available 6-1/4" NOV No

Not Available Weatherford Not Applicable

Manual Schlumberger

Hydraulic Baker Hughes

Select NOV /Weatherford/ Schlumberger /Baker Hughes Select

Select Select Select Select

MT (Metric Ton) Agreed NOV Brandt Yes

ST (Short Ton) Not Agreed Thule Not Applicable as all cranes on-board the drilling unit covered under Cargo Gear Register

Derrick At the time of TPI

Port Side MI Swaco

Starboard Side Acceptable Axiom

Other Not acceptable NOV Brandt/ Thule/Derrick/ MI Swaco/ Axiom

0 Select Schlumberger

1 Yes will be submitted at the time of TPI ITS

3 NOV/Schlumberger/ITS/Dailey

Tender No. / Bid ID ZW3KC26002 Annexure- V: B

Name of Work Charter hiring of two (02) or more MLT/BMC Jack up Rigs for three (03) years from Empaneled Vendors

Name of Bidder/ Bidding Firm/ Company

Sr. No. Commercial BEC/ ITB/ GCC Requirements Description of Undertaking / Confirmation / Submission of Documents ONGC's expected response Bidder's response Compliance status Reason for non-compliance, if any

1 BEC Clause B.2 I/We confirm that following vital commercial conditions should be strictly complied with failing which the bid will be rejected. Yes

BEC Clause B.2.1.1 I/We hereby confirm thatBid will not be considered for evaluation where bidder /supporting company/ ultimate controlling company/ JV partner is undergoing an Insolvency Resolution Process under the Insolvency & Bankruptcy Code, 2016 (or any amendments thereof) or, in case of an international bidder, is undergoing any proceedings for resolution of bankruptcy /insolvency by concerned court/authority of relevant jurisdiction, as on actual techno-commercial bid opening date. Yes Deviation bid, recheck your response

BEC Clause B.2.1.1 I/We hereby confirm that In case a bidder /supporting company/ ultimate controlling company /JV partner/Consortium Partner is undergoing or gets admitted to an Insolvency Resolution Process under the Insolvency & Bankruptcy Code, 2016 (or any amendments thereof) or in case of an international bidder, is undergoing or gets admitted to any proceedings for resolution of bankruptcy /insolvency, or is declared as bankrupt/insolvent by concerned court/authority of relevant jurisdiction, prior to or during Tender evaluation stages, then such bids will be rejected. Note: Rejection of bid in case Supporting company/ ultimate controlling company shall be applicable wherever bidding entity seek the support (Technical or Financial) in the tender Yes Deviation bid, recheck your response

BEC Clause B.2.2.0 I/We hereby confirm that the bid along with all appendices and copies of documents (except copies of the documents required in physical form) have been invariably submitted through GePNIC-CPPP (https://etenders.gov.in), before the scheduled date and time for the tender closing. Yes Deviation bid, recheck your response

BEC Clause B.2.2.0 I/We hereby confirm that all the documents uploaded have been digitally signed by the authorized signatory of the bidder. Yes Deviation bid, recheck your response

BEC Clause B.2.2.0 I/We hereby confirm that the password protected e-bids (Techno-commercial / Price bids), which require the password to open the file, will not be considered. Yes Deviation bid, recheck your response

BEC Clause B.2.2.0 I/We hereby confirm that the Techno-commercial bid contains all details without indicating prices of the quoted items, however, a suitable response has been selected of the given options against each item of the format at Appendix- IV A (Bidders Response Sheet) to indicate that there is a quote against that item in the Price Bid/BOQ. Yes Deviation bid, recheck your response

BEC Clause B.2.2.0 I/We hereby confirm that Price bid contains only the prices duly filled in the on-line price format of GePNIC-CPPP (https://etenders.gov.in) and have necessarily used the same excel sheet for price bid. Yes Deviation bid, recheck your response

BEC Clause B.2.2.0 I/We hereby confirm that the price bids submitted in physical form against e-procurement tenders shall not be given any cognizance. Yes Deviation bid, recheck your response

BEC Clause B.2.2.0 I/We hereby confirm that I/We have submitted following documents in physical form, in a sealed envelope super-scribed as “Physical documents against e-procurement Tender Reference Number………….., Tender ID………….., due on ………… To be opened by Tender Opening Officers at 15.30 Hrs, on due date for opening of bid” Yes / No Not complied, unless not applicable

BEC Clause B.2.2.0 I/We hereby confirm that documents required in physical form shall reach to the purchaser’s office on or before 15:00 Hrs. of the closing date specified for submission of bid through GePNIC-CPPP and also confirm that wherever any other time for receipt / opening of documents have been specified in the tender document, same has been appropriately indicated/followed in place of 15.00 Hrs / 15.30 Hrs. Yes Deviation bid, recheck your response

BEC Clause B.2.2.0 I/ We hereby confirm that bidders are required to only upload scanned copies of Power of Attorney, Integrity Pact, MOU (as applicable) along with techno-commercial bids in the e-tender portal and not required to submit physical copies / originals. However, ONGC reserves the right to seek any documents including these documents uploaded in e-tender portal, in physical form in original/ notarized true copy, during the processing of tender and execution of contract. Yes Deviation bid, recheck your response

BEC Clause B.2.3.0 I/We hereby confirm unconditional acceptance of General Conditions of Contract at Annexure II, Special Conditions of Contract at Annexure III and Instruction to Bidders at Annexure I as well as the instructions contained in website https://etenders.gov.in. Yes Deviation bid, recheck your response

BEC Clause B.2.3.1 Deleted- Not Applicable

BEC Clause B.2.3.1 Deleted- Not Applicable

BEC Clause B.2.4.0(a) I/We hereby confirm that I/We have submitted “Bid Securing Declaration" Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(b) I/We hereby confirm that I/We have submitted offer in e-form through GePNIC-CPPP. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(c) I/We hereby confirm that my/ our offer is not made by Agents /Consultants/ Retainers/ Representatives/Associates of foreign principals. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(d) I/We hereby confirm unconditional validity of the bid for 60 days from the date of opening of bid. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(e) I/We hereby confirm that prices are firm during entire duration of the contract and/or not with any qualifications. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(f.i) I/We hereby confirm that my/our offer conforms to ONGC’s ‘online price bid format’ as given in the GePNIC-CPPP. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(f.ii) I/We hereby confirm that my/our Offer conform filling of all relevant fields in the online bidding format for the items quoted by me/us. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(g) I/We hereby confirm to the mobilisation period indicated in the bid. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(h) I/We hereby confirm to the contract period indicated in the bid. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(i.i) I/We hereby confirm that I/We have submitted Integrity Pact along with the bid, duly signed by the same signatory who has signed the bid (Refer clause No. 13.1(f) of Annexure-I). Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(i.i) I/We hereby confirm that my/our offer shall be rejected due to Non-submission of Integrity Pact, duly signed by the same signatory who has signed the bid, even after giving an opportunity after opening of techno-commercial bids. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(i.ii) I/We hereby confirm that my/our offer is not violating the provisions of Integrity pact. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(j) Deleted- Not Applicable

BEC Clause B.2.4.0(k) I/We hereby confirm that I/we have submitted a copy of valid registration certificate under GST Legislation of India. Yes / No Not complied, unless not applicable

BEC Clause B.2.4.0(k) I/ We hereby confirm that we are a foreign bidder and GST registration certificate is not available at the time of submission of bid and I / We hereby confirm that shall submit GST registration certificate at least two weeks before submission of first invoice. Yes / No Not complied, unless not applicable

BEC Clause B.2.4.0(l) I/We hereby confirm that I/We have submitted an undertaking to provide all the necessary compliances/Invoice/ documents required under GST legislation for enabling ONGC to avail Input tax (GST) credit (Not applicable for the bidder who are under composition levy). Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(m.i) I/We hereby confirm that I/We have submitted undertakings as per Appendix- BP1, BP2 and BP3 on acceptance of ONGC's 'Policy for Banning/provisional Suspension of Business Dealings with erring Firms’. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(m.ii) I/We hereby confirm that I/We have submitted a declaration that neither myself/ourselves, nor any of my/our allied concerns, partners or associates or directors or proprietors involved in any capacity, are currently serving any banning orders issued by ONGC debarring us from carrying on business dealings with ONGC. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(n) I/ We hereby confirm that I/ We have submitted undertaking on Limiting of charges as per Appendix- 12.5 of Annexure VI. Yes

BEC Clause B.2.4.0(o) I/We hereby confirm that I/We have submitted undertaking on the company’s letter head and duly signed by the signatory of the bid that all the documents/certificates /information submitted by me/us against the tender are genuine. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(p) I/We hereby confirm that our offer is accompanied with the undertaking/Agreements as per clause B.1.2 and B.2.17.0, if applicable. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(q) I/We hereby confirm that my/our Offer and all attached documents have been digitally signed using digital signatures issued by an acceptable Certifying Authority (CA) as per Indian IT Act 2000 by the person as per power of attorney submitted as per ITB (Refer clause No. 13.1(i) of Annexure-I). Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(r) I/We hereby confirm that i/we have not submitted Password protected e-bids (Techno-commercial / Price bids), which require the password to open the file. Yes Deviation bid, recheck your response

BEC Clause B.2.4.0(s) I/We hereby confirm that I/We have submitted declaration that neither me/us nor my/our supporting company/ultimate controlling company/JV partner/Consortium Partner (applicable only in case bidding entity seek Technical or Financial support) is undergoing an Insolvency Resolution Process under the Insolvency & Bankruptcy Code, 2016 (or any amendments thereof)/ proceedings for resolution of bankruptcy /insolvency by concerned court/authority of relevant jurisdiction in respective country. Yes Deviation bid, recheck your response

BEC Clause B.2.4.1 I/We hereby Confirm that I/We have not indicated/disclosed prices in techno-commercial (un-priced bid) and in case I/We have indicated/disclosed prices in techno-commercial (un-priced bid) or at any stage before opening of price-bid, our bids shall be evaluated without giving any cognizance to such prices. Yes Deviation bid, recheck your response

BEC Clause B.2.4.1 I/We hereby Confirm that evaluation will be done as per Price Evaluation Criteria of BEC on the basis of prices quoted in the price bid only. Yes Deviation bid, recheck your response

BEC Clause B.2.4.1 I/We hereby Confirm that if I/We have indicated/disclosed some price in techno-commercial bid (at techno-commercial stage) or at any stage before opening of price-bid, but have not indicated any price in my/our Price Bid, my/our offer shall be considered as without any price and thus shall be rejected and in no case price revealed in techno-commercial bid shall be considered for award. Yes Deviation bid, recheck your response

BEC Clause B.2.5.0 I/We hereby confirm that I/We shall bear within the quoted rates, the Personnel Tax as applicable in respect of my/our personnel and my/our sub-contractor’s personnel, arising out of this contract; the Corporate Tax, as applicable, on the income arising out of this contract. Yes Deviation bid, recheck your response

BEC Clause B.2.6.0 Deleted- Not Applicable

BEC Clause B.2.7.0 I/We hereby confirm acceptance of BEC Clause B.2.7.0 of mobilization period. Yes Deviation bid, recheck your response

BEC Clause B.2.7.0 Note I/ We hereby confirm that I/ We have submitted various schedules as per Clause No. 1.1.2 (b)- (Mobilization) of the Model Conditions of the Contract at Annexure- II of tender document. Yes Deviation bid, recheck your response

BEC Clause B.2.8.0 I/We hereby confirm acceptance of BEC Clause B.2.8.0 of Drilling Units already operating with ONGC. Yes Deviation bid, recheck your response

BEC Clause B.2.9.0 I/We hereby confirm acceptance of BEC Clause B.2.9.0 of Period of charter hire. Yes Deviation bid, recheck your response

BEC Clause B.2.9.0 I/ We hereby confirm that the contract will stand automatically extended under the same rates, terms and conditions to cover the time necessary to complete or abandon to the satisfaction of ONGC, the well in progress at the end of the term of the contract. Yes Deviation bid, recheck your response

BEC Clause B.2.10.0 (a) I/ We hereby confirm acceptance of BEC Clause B.2.10.0 (a ) with regards to EDR of rig(s) offered should be consistent with the quality score Yes Deviation bid, recheck your response

BEC Clause B.2.10.0 (b) I/ We hereby confirm acceptance of BEC Clause B.2.10.0 (b ) with regards to confirmed availability of rig (s). Yes / No Not complied, unless not applicable

BEC Clause B.2.10.0 (c) I/ We hereby confirm acceptance of BEC Clause B.2.10.0 (c ) that empaneled bidders should identify & offer pre-qualified rigs only. Yes / No Not complied, unless not applicable

BEC Clause B.2.10.0 (c) Deleted- Not Applicable

BEC Clause B.2.10.0 (d) Deleted- Not Applicable

BEC Clause B.2.10.0 (d) Deleted- Not Applicable

BEC Clause B.2.10.0 (e) Deleted- Not Applicable

BEC Clause B.2.10.0 (f) Deleted- Not Applicable

BEC Clause B.2.10.0 (g) Deleted- Not Applicable

BEC Clause B.2.10.0 (h) Deleted- Not Applicable

BEC Clause B.2.10.0 (i) Deleted- Not Applicable

BEC Clause B.2.10.0 (i) Deleted- Not Applicable

BEC Clause B.2.11.0 Deleted- Not Applicable

BEC Clause B.2.12.0 I/ We hereby confirm that I/ We have submitted undertaking on limiting charges as per format at Appendix- 12.12 of Annexure VI. Yes Deviation bid, recheck your response

BEC Clause B.2.13.0 Not Applicable Yes Deviation bid, recheck your response

BEC Clause B.2.14.0 I/ We hereby confirm that I/ We have indicated the value of the drilling unit in the price format Yes Deviation bid, recheck your response

BEC Clause B.2.15.0 I/ We hereby confirm thatbidders offering rigs to be mobilised from different zones will not be paid mobilization fee (MOB Fee) more than the amount mentioned at BEC Clause B.2.15.0. Yes Deviation bid, recheck your response

BEC Clause B.2.16.0 I/ We hereby confirm acceptance for extension of the contract, at the same rates, terms and conditions, at the option of operator, for the total unpaid period of absence or non-availability for operations of the drilling/ work over unit due to repairs, dry-dock, break-down and hull inspection Yes

BEC Clause B.2.17.0 I/We hereby confirm that my/our Offer complies with the Financial Criteria required as per BEC Clause B.2.17.0. Yes Deviation bid, recheck your response

BEC Clause B.2.18.0 I/ We hereby confirm that Indian agent is not permitted to represent more than one foreign bidder (Supplier/ Manufacturer/ Contractor) in a particular tender. In case an Indian agent represents more than one foreign bidder (Supplier/ Manufacturer/ Contractor) in a particular tender, then offers of such foreign bidders (Suppliers/ Manufacturers/ Contractors) shall be rejected in that tender. Yes Deviation bid, recheck your response

BEC Clause B.2.19.0 I/ We hereby confirm that I/ We have submitted scanned copy of Integrity Pact (which is issued along with the bidding document) duly signed on all the pages by the same signatory who is duly authorized to sign the bid digitally. All the pages of the Integrity Pact are duly signed by the same signatory. Yes Deviation bid, recheck your response

BEC Clause B. Deleted Yes Deviation bid, recheck your response

BEC Clause C.1 I/We hereby confirm acceptance of Clause C.1 of the BEC regarding Price Evaluation Criteria. Yes Deviation bid, recheck your response

BEC Clause C.1.1 I/ We confirm acceptance of Quality & Cost based selection (QCBS) Methodology BEC Clause C.1.1. Yes Deviation bid, recheck your response

BEC Clause C.1.2 I/ We confirm acceptance of BEC Clause C.1.2. Yes Deviation bid, recheck your response

BEC Clause C.2.0 I/ We confirm acceptance of BEC Clause C.2.0. Yes Deviation bid, recheck your response

BEC Clause C.3.0 I/ We confirm acceptance of BEC Clause C.3.0. Yes Deviation bid, recheck your response

BEC Clause D I/We hereby confirm Clause D of the BEC (General). Yes Deviation bid, recheck your response

Annexure- VI: Appendix-1 I/We hereby confirm that I/We have submitted duly filled Bidding Document Acknowledgement Proforma. Yes Deviation bid, recheck your response

Annexure- VI: Appendix-2 I/We hereby confirm that I/We have submitted duly filled Bid Submission Proforma. Yes Deviation bid, recheck your response

Annexure- VI: Appendix-3 I/We hereby confirm that I/We have submitted duly filled Agreement. Yes Deviation bid, recheck your response

Annexure- VI: Appendix-5 deleted-Not aplicable

Annexure- VI: Appendix-9 I/We hereby confirm that I/We have submitted duly filled Form 10F Yes / No Not complied, unless not applicable

Annexure- VI: Appendix-9A I/We hereby confirm that I/We have submitted duly filled Particulars to be furnished by foreign bidders (non-residents as per Income Tax Act, 1961) in line with Clause No. 16.1 of ITB. Yes / No Not complied, unless not applicable

Annexure- VI: Appendix- 11 I/We hereby confirm that I/We have submitted the requisite payment particulars as per clause 16.0 of Annexure-I. Yes Deviation bid, recheck your response

Annexure- VI: Appendix- 12 I/We hereby confirm that I/We have submitted UNDERTAKINGS / DECLARATIONS / CONFIRMATIONS as per Appendix-12 of Annexure VI. Yes Deviation bid, recheck your response

Annexure- VI: Appendix- 14 I/We hereby confirm that I/We have submitted Undertaking from Agent/ Consultant/ Representative/ retainer/ associate (if applicable). Yes / No Not complied, unless not applicable

BEC I/We hereby confirm acceptance of all clauses of the BEC. Yes Deviation bid, recheck your response

Note: Bidder is advised to comply with ONGC expected response requirements, failing which their bids may be rejected without any request for clarification, confirmation, or submission of deficient documents.

Name of Authorised Signatory of Bidder as per POA:

Annexure - IV - Appendix - 2

Bidder's Response Sheet

Please enter values in yellow shaded cells only.

Name of Bidder and name of Rig offered

Type of rig Charter hiring of two (02) or more MLT/BMC Jack up Rigs for three (03) years from Empaneled Vendors Tender No. ZW3KC26002

Bidder's Quotation Reference

Currency of Quote

HSN Code/ SAC Code

Table-A: Cost for Rig Hiring

1 SN Particulars Estimated Qty (a) UOM Unit Rate exclusive of GST (b) GST % (c) Amount of GST on the Unit rates (d) Unit Rate inclusive of GST (e=b+d) Total Rate inclusive of GST (f=a*e)

2 1 Mobilization Fee of rig along with all equipment and accessories as per tender document (A), if any (Lumpsum) 1 Lumpsum

3 2 Operating Day Rate (R1) 310 Days

3 Non-Operating Day Rate (R2) 38 Days

4 4 Equipment Break Down Rate (R3) 12 Days

6 5 Moving Day Rate (R4) 5 Days

6 De-mobilization Fee of rig along with all equipment and accessories as per tender document (B), if any (Lumpsum) 1 Lumpsum

Total cost for Rig Hiring (T1)=[A + {R1 (310x3) + R2 (38x3 + R3(12x3) + R4(5x3} + B]

Table-B: Cost for Diesel consumption (For Evaluation purpose only)

Price of diesel per KL intimated along with NIT by ONGC in INR (P) 112747

SN Particulars Estimated Qty (a) UOM Average Diesel consumption per day in KL (b) Total Cost for Diesel consumption (c =a*b*P)

7 Average Diesel consumption for Drilling operations: D 288 Days

8 Average Diesel consumption forWorkover operations: W 23 Days 72 Days

9 Average Diesel consumption for Rig Move operations: R 18 Days 5 Days

Total cost on account of Diesel consumption (T2)= P * (D (288x3) + W (72x3)+ R (5x3)).

i) ONGC would provide required undertaking/ certificate to contractor for availing concessional rate of customs for import of rigs/ equipment/ tools required in connection with Petroleum operations, as per BEC clause and bidder to confirm that such concessional rates have been considered in fixing the price in price bid. As per clause 15.6 of MCC, for rigs and ancillary items imported for Oil & Gas exploration & production, taken on lease by the Importer would be exempted from custom duty, subject to certain conditions. If the rig is imported on Ownership basis, Bidder is to ascertain taxes & input tax credit, based on legal provisions considering nature of transaction. The bidder is advised to check latest position in their own interst and ONGC will not bear any responsibilites for any incorrect assessment of statutory leves by bidder. Rates should be quoted accordingly.

ii) Day Rate of rig should be inclusive of rig crew day rate.

iii) Bidders should quote rates / prices strictly, as per price format.

v) In case of foreign bidders, if GST registration certificate is not available at the time of submission of bid, the bidder shall submit an undertaking to provide copy of the same at least two weeks before submission of first invoice.

vi) Bidder must indicate the value of the rig and equipment as required at Appendix-2 of the price format.

vii) Bidder shall furnish alongwith technical bid (unpriced bid), a copy of Bidder's response sheet which is a Price format with the prices duly blanked out. While submitting alongwith the techno-commercial unpriced bid, bidder shall fill up information pertaining to “Type of rig offered” & “Quoted currency” and select option ‘Quoted’ or ‘Not Quoted’ against S. No. 1 to 9 as an indication of the item having been quoted by the bidder in the priced bid. If not quoted against any item, bidder may clearly indicate as ‘Not Quoted’.

viii) Bidders should quote the prices, clearly indicating the applicable rate of GST, nature / category of service as per GST rules (under which the respective service is covered) alongwith all other taxes and duties applicable. Details of abatements / deductions available, if any, should also be indicated by bidder specifically.

ix) Price of diesel per KL in USD taken for evaluation purpose is INR 112747. Bidders to quote average diesel consumption per day which will be the basis of limiting the quarterly consumption of diesel that ONGC is going to bear the cost for. In case, bidder quote the prices of diesel per KL in any other currency, then bidder shall convert the prices of diesel from USD/KL (as intimated by ONGC) to its quoted currency by referring the Daily” Closing exchange rate published on Thomson Reuters internet site https://in.reuters.com /markets/currencies , upto three places of decimal considering date of NIT.

x) Evaluation of bids shall be as per BEC clause C).1.

xi) Non Operating Day Rate & Rig Move day rate should not exceed 95% of Operating Day Rate. Equipment breakdown rate should not exceed 60% of Operating Day Rate. Ceiling on mobilization charges shall be as per BEC clause 15. The bidder(s) must adhere to the limits of Mobilisation fee , NODR, MDR and EBDR. However, after opening of price bids, if it is observed that such charges/amount quoted are higher than the limits for above parameters, the offer (s) of such bidder (s) shall be evaluated restricting the charges/amount up to the specified limit. Contract (in case the bidder becomes L-1) shall also be awarded restricting the charges / amount up to specified limit as above.

xii) Rate of Boarding & lodging as per STCC clause no.9 shall be included by contractor in their offered price.

xiii) The average quoted diesel quantity in KL/day for Workover/Testing mode and for Rig Move mode should not be equal to or more than the average quoted diesel quantity in KL/day for Drilling mode in price format

xiv) The bidders offering rigs to be mobilised from different zones will not be paid mobilization fee (MOB Fee) more than the amount as mentioned below: (i) Rigs to be mobilized from Indian EEZ- 2.6% of the total evaluated value for 01 Rig (excluding GST) as per the offer of the bidder (ii) Rigs to be mobilized from Middle East- 5.2% of the total evaluated value for 01 Rig (excluding GST) as per the offer of the bidder (iii) Rigs to be mobilized from Singapore/Far East-7.8% of the total evaluated value for 01 Rig (excluding GST) as per the offer of the bidder (iv) Rigs to be mobilized from areas other than (i), (ii) & (iii) above- 18.1% of the total evaluated value for 01 Rig (excluding GST) as per the offer of the bidder Note: The mob fee limitation is excluding GST. The bidder(s) must adhere to the above limits. However, after opening of price bids, if it is observed that such charges/amount quoted by the bidder (s) are higher than the limit for above parameter, the offer (s) of such bidder (s) shall be evaluated restricting the charges/amount up to the specified limit. Contract (in case the bidder becomes B-1) shall also be awarded restricting the charges / amount up to specified limit as above. The bidder shall submit an undertaking in this regard along-with techno-commercial bid as per format at Annexure –VI, Appendix– ...

xv) The number of days mentioned are indicative and for evaluation purpose only which may change (increase or decrease w/o restriction) as per operational requirement. However, payment shall be made as per actual days.

xvi) All quoted cost will be converted to INR as per BEC clause C.2 for evaluation

Annexure - IV - Appendix-2

ITEM Nature / category of service as per GST rules (under which the respective service is covered) SAC Code

i) In case the bidder has Indian Agent, the details of Indian Agent may be provided as under:

Amount or % of IAC included in quoted prices

ii) Value of the rig and equipment for customs duty purpose

Annexure - IV - Appendix - 1

Please enter values in yellow shaded cells only.

Name of Bidder and name of Rig offered

Type of rig Charter hiring of two (02) or more MLT/BMC Jack up Rigs for three (03) years from Empaneled Vendors Tender No. ZW3KC26002

Bidder's Quotation Reference

Currency of Quote

HSN Code/ SAC Code

Table-A: Cost for Rig Hiring

1 SN Particulars Estimated Qty (a) UOM Unit Rate exclusive of GST (b) GST % (c) Amount of GST on the Unit rates (d) Unit Rate inclusive of GST (e=b+d) Total Rate inclusive of GST (f=a*e)

2 1 Mobilization Fee of rig along with all equipment and accessories as per tender document (A), if any (Lumpsum) 1 Lumpsum

3 2 Operating Day Rate (R1) 310 Days

3 Non-Operating Day Rate (R2) 38 Days

4 4 Equipment Break Down Rate (R3) 12 Days

6 5 Moving Day Rate (R4) 5 Days

6 De-mobilization Fee of rig along with all equipment and accessories as per tender document (B), if any (Lumpsum) 1 Lumpsum

Total cost for Rig Hiring (T1)=[A + {R1 (310x3) + R2 (38x3 + R3(12x3) + R4(5x3} + B]

Table-B: Cost for Diesel consumption (For Evaluation purpose only)

Price of diesel per KL intimated along with NIT by ONGC in INR (P) 112747

SN Particulars Estimated Qty (a) UOM Average Diesel consumption per day in KL (b) Total Cost for Diesel consumption (c =a*b*P)

7 Average Diesel consumption for Drilling operations: D 288 Days

8 Average Diesel consumption forWorkover operations: W 23 Days 72 Days

9 Average Diesel consumption for Rig Move operations: R 18 Days 5 Days

Total cost on account of Diesel consumption (T2)= P * (D (288x3) + W (72x3)+ R (5x3)).

i) ONGC would provide required undertaking/ certificate to contractor for availing concessional rate of customs for import of rigs/ equipment/ tools required in connection with Petroleum operations, as per BEC clause and bidder to confirm that such concessional rates have been considered in fixing the price in price bid. As per clause 15.6 of MCC, for rigs and ancillary items imported for Oil & Gas exploration & production, taken on lease by the Importer would be exempted from custom duty, subject to certain conditions. If the rig is imported on Ownership basis, Bidder is to ascertain taxes & input tax credit, based on legal provisions considering nature of transaction. The bidder is advised to check latest position in their own interst and ONGC will not bear any responsibilites for any incorrect assessment of statutory leves by bidder. Rates should be quoted accordingly.

ii) Day Rate of rig should be inclusive of rig crew day rate.

iii) Bidders should quote rates / prices strictly, as per price format.

v) In case of foreign bidders, if GST registration certificate is not available at the time of submission of bid, the bidder shall submit an undertaking to provide copy of the same at least two weeks before submission of first invoice.

vi) Bidder must indicate the value of the rig and equipment as required at Appendix-2 of the price format.

vii) Bidder shall furnish alongwith technical bid (unpriced bid), a copy of Bidder's response sheet which is a Price format with the prices duly blanked out. While submitting alongwith the techno-commercial unpriced bid, bidder shall fill up information pertaining to “Type of rig offered” & “Quoted currency” and select option ‘Quoted’ or ‘Not Quoted’ against S. No. 1 to 9 as an indication of the item having been quoted by the bidder in the priced bid. If not quoted against any item, bidder may clearly indicate as ‘Not Quoted’.

viii) Bidders should quote the prices, clearly indicating the applicable rate of GST, nature / category of service as per GST rules (under which the respective service is covered) alongwith all other taxes and duties applicable. Details of abatements / deductions available, if any, should also be indicated by bidder specifically.

ix) Price of diesel per KL in USD taken for evaluation purpose is INR 112747. Bidders to quote average diesel consumption per day which will be the basis of limiting the quarterly consumption of diesel that ONGC is going to bear the cost for. In case, bidder quote the prices of diesel per KL in any other currency, then bidder shall convert the prices of diesel from USD/KL (as intimated by ONGC) to its quoted currency by referring the Daily” Closing exchange rate published on Thomson Reuters internet site https://in.reuters.com /markets/currencies , upto three places of decimal considering date of NIT.

x) Evaluation of bids shall be as per BEC clause C).1.

xi) Non Operating Day Rate & Rig Move day rate should not exceed 95% of Operating Day Rate. Equipment breakdown rate should not exceed 60% of Operating Day Rate. Ceiling on mobilization charges shall be as per BEC clause 15. The bidder(s) must adhere to the limits of Mobilisation fee , NODR, MDR and EBDR. However, after opening of price bids, if it is observed that such charges/amount quoted are higher than the limits for above parameters, the offer (s) of such bidder (s) shall be evaluated restricting the charges/amount up to the specified limit. Contract (in case the bidder becomes L-1) shall also be awarded restricting the charges / amount up to specified limit as above.

xii) Rate of Boarding & lodging as per STCC clause no.9 shall be included by contractor in their offered price.

xiii) The average quoted diesel quantity in KL/day for Workover/Testing mode and for Rig Move mode should not be equal to or more than the average quoted diesel quantity in KL/day for Drilling mode in price format

xiv) The bidders offering rigs to be mobilised from different zones will not be paid mobilization fee (MOB Fee) more than the amount as mentioned below: (i) Rigs to be mobilized from Indian EEZ- 2.6% of the total evaluated value for 01 Rig (excluding GST) as per the offer of the bidder (ii) Rigs to be mobilized from Middle East- 5.2% of the total evaluated value for 01 Rig (excluding GST) as per the offer of the bidder (iii) Rigs to be mobilized from Singapore/Far East-7.8% of the total evaluated value for 01 Rig (excluding GST) as per the offer of the bidder (iv) Rigs to be mobilized from areas other than (i), (ii) & (iii) above- 18.1% of the total evaluated value for 01 Rig (excluding GST) as per the offer of the bidder Note: The mob fee limitation is excluding GST. The bidder(s) must adhere to the above limits. However, after opening of price bids, if it is observed that such charges/amount quoted by the bidder (s) are higher than the limit for above parameter, the offer (s) of such bidder (s) shall be evaluated restricting the charges/amount up to the specified limit. Contract (in case the bidder becomes B-1) shall also be awarded restricting the charges / amount up to specified limit as above. The bidder shall submit an undertaking in this regard along-with techno-commercial bid as per format at Annexure –VI, Appendix– ...

xv) The number of days mentioned are indicative and for evaluation purpose only which may change (increase or decrease w/o restriction) as per operational requirement. However, payment shall be made as per actual days.

xvi) All quoted cost will be converted to INR as per BEC clause C.2 for evaluation

Annexure - IV - Appendix-2

ITEM Nature / category of service as per GST rules (under which the respective service is covered) SAC Code

i) In case the bidder has Indian Agent, the details of Indian Agent may be provided as under:

Amount or % of IAC included in quoted prices

ii) Value of the rig and equipment for customs duty purpose