CHEMICAL DEPARTMENT - oilweb.oilindia.in Report NHK 602.pdf · CHEMICAL DEPARTMENT ... CEMENT...

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WELL NO: NHK # 602

LOCATION: HWV

AREA: DEOHAL

RIG : S-6 FIELD : NAHARKATIA TYPE OF WELL : DEVELOPMENT PLANNED DEPTH : 2665 M DRILLED DEPTH : 2670M SPUDDING-IN DATE : 26.04.2012 NO. OF DAYS REQUIRED FOR DRILLING : 73 NO. OF DAYS REQUIRED FOR PRODUCTION TESTING : 7 TOTAL NO OF DAYS REQUIRED FROM SPUDDING-IN TO RIG DOWN : 88 DATE OF RIG DOWN : 21.07.2012

Report by:

(Dipankar Dutta)

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CONTENTS

� HIGHLIGHTS.

� BRIEF WELL HISTORY.

� CHRONOLOGY OF EVENTS.

� MUD SUMMARY.

� MUD PARAMETERS MAINTAINED.

� HYDRAULICS DATA.

� CHEMICAL COST ANALYSIS (WITH PIE DIAGRAM).

� CONSUMPTION & COST OF CEMENTING CHEMICALS.

� WELL CEMENTATION CHECK LISTS.

� DEVIATION PROFILE/COURSE OF THE HOLE.

� CALIPER LOG (GRAPH).

� PLOT OF DAYS VS DEPTH.

� CBL LOG OF LOC: HWV

� DEPTH, DATA AND DRILLING POLICY.

� SIDE WALL CORE ANALYSIS REPORT.

� CEMENTING POLICIES.

� POLLUTION WATER ANALYSIS REPORTS.

� ANY OTHER RELEVANT REPORTS.

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HIGHLIGHTS

LOC: HWV (Well No. NHK # 602)

A DEVELOPMENT AND DEVIATED WELL OF DEPTH 2670M (TARGET DEPTH WAS

2665M) WITH FOUR STAGE CASING COMPLETION. THIS WELL WAS DRILLED AS

A REPLACEMENT WELL OF NHK#285.

THE WELL WAS SPUDDED ON 26.04.2012.

WHILE DRILLING AT DEPTH OF 94M, OBSERVED SEVERE NOISE FROM DRAW

WORKS. ATTENDED DRAW WORKS FOR 04 DAYS AND RECTIFIED THE

PROBLEM.

AT DEPTH OF 915M THAT IS JUST AFTER 1ST ISOLATION CEMENTING,

OBSERVED GAS BUBBLES COMING OUT FROM THE ANNULUS OF 13 3/8''CSG X

20'' CSG AT CELLAR PIT. MAXIMUM GAS READING SHOWS 32% LEL. PUMPED

CEMENT SLURRY AND 100PCF MUD TO THE ANNULUS, BUT FAILED. HOWEVER,

GAS READING VALUES DECREASED TO 4%-3% LEL.

AGAIN AFTER 2ND ISOLATION CEMENTING AT DEPTH OF 2037M, OBSERVED

CELLAR PIT GAS READING MAXIMUM UPTO 50% LEL. PUMPED 120PCF CEMENT

SLURRY AND 120PCF MUD TO THE ANNULUS, BUT FOUND NO IMPROVEMENT.

GAS WAS COMING OUT FROM THE 20”CSG VS 13 3/8” CSG ANNULUS TILL NOW.

WHILE RAN IN TCR BIT DURING OIL STRING DRILLING, STRING GOT STUCK AT

2417M. WORKED ON STRING IN THE RANGE 60T-145T WITHOUT SUCCESS.

SPOTTED 50BBLS OF LWC WITH 5% PIPELAX AND ALLOWED TO SOAK. IN THE

MEAN-TIME ATTENDED DRAW WORKS. WORKED ON STRING UPTO 160T AND

FREED THE SAME.

TOTAL MUD CHEMICALS COST INCURRED RS. 3340838.69/- AND COST PER

METER RS. 1251.25/-.

TOTAL 73 DAYS REQUIRED FOR COMPLETION OF DRILLING.

TOTAL 88 DAYS REQUIRED FROM SPUDDING-IN TO RIG DOWN.

CALIPER ANALYSIS SHOWED OF THE 8.5” HOLE WAS 97.38% IN TRUE GAUGE

RANGE (8.5”-9.5”).

LOGS RECORDED IN OIL STRING STAGE:

� DLL-MSFL-GR-SP-CAL-IDT

� LDL-CNL-GR-SP-CAL

� CST log

SHUT IN THE WELL WITH PERFORATED BULL NOSE TUBING AT 2603M AND

DECLARED RIG-DOWN ON 21.07.2012.

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WELL COMPLETION REPORT LOC: HWV (NHK # 602)

INTRODUCTION & GEOLOGICAL PROSPECTS: The replacement location HWV for NHK#285 falls in the Deohal-Lohali structure, which

is a composite faulted anticlinal structure at the Barail level, compartmentalized into

three fault blocks viz. Lohali, Deohal and East Deohal by two north-south trending faults

and is bounded by a common major EW to ENE-WSW trending fault towards the south.

The Deohal and East Deohal blocks are the central and eastern fault blocks of the area

respectively having an areal extent of around 19sq. km at Barail Third Sand level. The

Barail Third Sand is the primary reservoir of the area and has been established as NAG

(Non Associated Gas) reservoir. The well NHK#285 had been a very good gas producer

well in Deohal area and it was under production till 14.07.2011. Problem occurred in the

well NHK#285 when a leakage from the well head fittings was observed above the

master valve and the master valve of the well was immediately closed. Further

examinations revealed that there was a no. of deep impressions of damage (spots) on

the well head and the displacement of the 2 9/16” Master Valve Bonnet Flange from its

body in downward direction was observed. Gas was leaking from the displaced portion.

It was then decided to kill the well and change the Master Valve on safety consideration.

Simultaneously, Loc: HWV is planned to be drilled as a deviated well and place the well

as close as possible against the producing Barail 3rd Sand of NHK#285.

The depth of the Barail 3rd Sand (tested) at NHK#285 is 2427.0m-2447.0m. As per the

deviation plan, the replacement well will be placed 15m away from NHK#285, at 2427m

Barail 3rd Sand.

The objective depth of the well was: 2665m (MWD) / 2550m (TVD)

CONDUCTOR STAGE:

Hole Size: 26 inch

Interval: (0-122) m

The well was spudded on 26.04.2012 and 26” conductor stage of the well was drilled

down to 122m. The hole was then cleaned thoroughly and cased with 20” casing with

shoe at 115.73m. It was then cemented using 1200 sacks of API Class-G rebagged

Dalmia cement of average slurry density 114.6pcf on 03.05.2012.

FLUID DISCUSSION

Mud Type: Spud mud

A Pre-hydrated (7-8) % Bentonite suspension of density 66pcf spud mud was used to

drill 26” hole section. MF viscosity was generally controlled at a range of around 60

sec/quart. The spud mud was tailored without any inhibition.

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Property Programmed Actual

Density (pcf) 66 66

MF Viscosity (sec/ quart) 55-60 60

Rheology:

Adequate hole cleaning was achieved at these values and no problems were

experienced while drilling. As a precaution, Hi- Viscous pills were pumped for effective

hole cleaning.

API Fluid loss:

For this section API fluid loss does not have any significant role towards the stability of

the hole. No fluid loss control additives were incorporated in the mud system.

Solids control:

The solid control equipments used were two LMSS of screen size 24x28 each,

Desander and Desilter. The functions of all solid control equipments were satisfactory.

The sand trap was dumped as and when required.

1ST ISOLATION STAGE:

Hole Size: 17 ½ inch

Interval: (122-915) m

After allowing the cement to set and necessary well head hook-up, arranged for and ran

in 17 ½” new bit and felt cement top at 109m. Circulated and cleaned cement from

109m to 122m and drilled ahead to 165m (KOP). Circulated and pulled the dull bit out of

hole. Made up new bit (1-2-7) with mud motor and tested the same at surface. Found

malfunctioning of MM. Waited for MM to reach well site for around 03days. MM reached

site and tested the same at surface. MM found ok and drilled ahead to 345m with

orientation hook up. Changed hook up and drilled down to 602m with building hook up.

Drilled ahead to 915m with holding hook up and terminated 1st Isolation stage drilling.

Circulated and conditioned the mud thoroughly prior to open hole survey. Pulled bit out

of hole and Well logging recorded HRI-DFL-GR-SP log and SDL-DSN-GR-CAL-IDT log

in two successive runs. Logger’s depth was 914m and BHT was found to be 110 degF.

Ran in with same bit having stabs at 0, 9, 18m to bottom freely. Circulated thoroughly

and pulled bit out of hole. Again Schlumberger recorded DLL-MSFL-GR-SP-CAL log

and SDL-DSN-IS-GR log in two consecutive runs. Loggers’ depth was 915m. Ran in bit

to bottom freely. Circulated and pulled out bit. Lowered 13 3/8” casing and landed with

shoe at 912.64m and float collar at 900.53m. The casing was then cemented on

18.05.2012 using 1800 Sacks of Class-G NS Dalmia cement with average slurry

densities of 104pcf and 114pcf for Lead and Tail slurries respectively. Plug bumped at

3853strokes against calculated strokes of 3722 (Eff.- 96.6%) with bumping pressure of

2700psi. BPV holding OK. Cement slurry surfaced in return of density 98pcf.

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FLUID DISCUSSION

Mud Type: Dispersed Mud System

The mud from the previous section was pretreated for possible cement contamination

with sodium bicarbonate and used for drilling of this section. The mud density and MF

Viscosity were maintained in the range of 66-67pcf and 48-55 sec respectively.


Density pcf 66-67 66-67

MF Viscosity , sec/ quart 50-55 48-55

Fluid loss, cc <15 12-23

PV , cp - 5-11

YP , lbs/ cft - 10-28

Gel 0/15 min, lbs/ cft - 3-24/32-90

pH - 9.0-10.0

Salinity, ppm - 800-1200

Sand % - 0.1-0.8

Rheology & API Fluid Loss:

The Rheological and fluid loss properties were maintained by incorporating CMC(HVG),

CMC(LVG) etc. Linseed Oil was used as lubricant during deviation drilling. Good hole

cleaning was maintained throughout the drilling of this section and for effective hole

cleaning, hi-viscous pills were pumped. No caving or sloughing was observed over

shakers. pH range was 9.0-10.0 for optimum performance of chemicals and non-

abrasion of tubular.

Solids Control:

The solid control equipments used were two LMSS of screen size 24x28 each,

Desander and Desilter. These screens were able to control the solids component within

the acceptable limit. Also the mud was diluted constantly with water and sand traps

were dumped during trips for lowering the solid content.

2ND ISOLATION STAGE:

Hole Size: 12 ¼ inch

Interval: (915-2037) M

After allowing the cement to set, while worked on well head, observed gas bubbles

coming out from the annulus of 13 3/8''X 20'' CSG with maximum gas reading of

32%LEL. Decided & put cement slurry using 15 bags of cement in the annulus but

found no improvement. Prepared and pumped 100pcf mud to the annulus in stages and

found gas reading reduced to 3%LEL. Decided to work on well head and after

necessary well head hook-up, arranged for drilling the 2nd isolation stage of the hole.

Ran in 12 ¼” new bit and felt cement top at 900m (F/C). Circulated and cleaned cement

from 900m to 915m and drilled ahead to 919m. C & C mud. Conducted PIT @100psi

(EMW=72pcf), found holding OK. Circulated and pulled out the dull bit. Made up new bit

and drilled ahead to 950m with holding hook up. Well was handed over to NEWSCO

people for deviation drilling. Changed hook up and drilled down to 1654m with deviation

P a g e | 6

hook up (at 1636.40m, 21.30deg – N43degW). Circulated and pulled out bit upto 854m

due to local Bandh. Operation remained suspended for next two days and no crew at

site. Operation resumed on 2nd June’12 and drilled down to 1785m with same bit and

deviation hook up. Circulated and pulled out dull bit. Ran in new 1-2-7 bit and drilled

down to 2037m. Terminated 2nd Isolation stage drilling. Circulated and conditioned mud

thoroughly prior to open hole survey. Pulled bit out of hole and handed over the well to

Schlumberger. During drilling of the 2nd Isolation stage, annulus of 13 3/8" vs 20" casing

was filled up with 100pcf mud and dry Barytes intermittently.

SLB recorded DLL-MSFL-GR-SP-CAL and CDT-CNT-DSI-IDT log in two consecutive

runs. Logger’s depth was 2039.50m and BHT was found to be 56 deg C. Ran in same

bit with stabs at 4m & 13m to bottom freely. Circulated thoroughly and pulled bit out of

hole. Again WLD recorded GR-Temperature log. Ran in same bit with stab at 0m, 9m &

18m to bottom freely. Circulated and pulled out bit. Lowered 9 5/8” casing and landed

with shoe at 2029.28m and float collar at 2017.22m. The casing was then cemented on

12.06.2012 using 1300 Sacks of Class-G Ex Dalmia cement with average slurry

densities of 101pcf and 114.2pcf for Lead and Tail slurries respectively. Plug caught TE

at 2800stks and bumped at 4250stks (against calculated 4070stks) with bumping

pressure of 2500psi (eff. 95.76%). BPV holding OK. WOC.

FLUID DISCUSSION

Mud Type: Dispersed Mud System

The mud from the previous section was pretreated for possible cement contamination

with sodium bicarbonate and used for drilling of this section. The mud density and MF

Viscosity were maintained in the range of 67-68pcf and 48-52 sec respectively.


Density pcf 67-68 67-68


Fluid loss, cc <10 8.4-29.0

PV , cp - 6-10

YP , lbs/ cft - 8-16

Gel 0/15 min, lbs/ cft - 2.5-9/42-54

pH - 8.5-10.0


Sand % - 0.1

Rheology & API Fluid Loss:

The Rheological and fluid loss properties were maintained by incorporating CMC(HVG),

CMC(LVG), PAC(R) etc. Linseed Oil and LWC were used as lubricant during deviation

drilling. Good hole cleaning was maintained throughout the drilling of this section and for

effective hole cleaning, hi-viscous pills were pumped. No caving or sloughing was

observed over shakers. pH range was 8.5-10.0 for optimum performance of chemicals

and non-abrasion of tubulars.

P a g e | 7

Solids Control:

The solid control equipments used were Desander, Desilter and two LMSS of screen

sizes in the order- 28X50, 28x38 & 24X28. These screens were able to control the

solids component within the acceptable limit. Also the mud was diluted constantly with

water and sand traps were dumped during trips for lowering the solid content.

OIL STRING STAGE:

Hole Size: 8 ½ inch

Interval: (2037-2670) M

Since gas bubbles were coming out from the annulus of 13 3/8''csg X 20'' csg

continuously, decided and pumped 26bbls of 120pcf cement slurry to the same annulus.

Found no improvement. Prepared and pumped 120pcf mud to the annulus

intermittently. Gas reading reduced from maximum value of 50%LEL to 15%LEL.

Completed necessary well head hook-up with safety precautions and arranged for

drilling the oil string stage of the hole. Ran in 8 ½” new bit with rotovert and felt cement

top at 2014m (F/C at 2017m). Circulated and pulled rotovert out of hole. SLB recorded

CBL-VDL-GR-CCL-USIT log in the range 850m-2014m. Found cement bonding poor to

moderate.

Ran in 8 ½” bit and cleaned cement, drilled out F/C and shoe. Drilled fresh formation

down to 2041m and took PIT @440psi with corresponding EMW of 78pcf. Circulated

and pulled bit out of hole. Again WLD recorded CBL-VDL-GR-CCL log in the range of

602m-2037m and found cement bonding poor to moderate. Ran in PDC bit and drilled

ahead to 2300m. Circulated and pulled out PDC bit. WLD recorded IDT-GR log and

found inclination of 0.93 deg. Further drilled down to 2495m with the same PDC bit.

Circulated and pulled PDC bit out of hole. During pulling out, observed tight spots

@2390m, 2380m, 2353m and also observed wet pull. Found 2nos of nozzles plugged.

Ran in new TCR bit with stab at 18m and got held up at 2420m. Reamed down Kelly

length. While picking up, the string got stuck at 2417m. Worked on string in the range

60T-145T without success. Spotted 50bbls of LWC with 5% pipelax covering 325m in

the annulus and kept 11bbls inside string. Allowed to soak for 6 hours keeping the string

under compression of 45T. Attended Draw works. Later on, worked on string and freed

the same at 160T. Circulate out LWC and pulled out bit inside shoe. Attended Draw

works and pulled bit out of hole. Changed hook up and ran in same bit without stabilizer

to 2377m freely. Reamed down to bottom (2495m) and dilled ahead to 2670m (TD).

Circulated and conditioned mud thoroughly and handed over the well to SLB for open

hole survey. SLB recorded DLL-MSFL-GR-SP-CAL-IDT log and LDL-CNL-GR-SP-CAL

log in two successive runs. Logger’s depth was 2676.2m and BHT was found to be 60

deg C. Circulated and conditioned mud and SLB recorded CST log :A=30, R=28

(including 1 MC), L=2. Made a hole probing trip with same hook-up prior to lowering of 5

½” casing. Lowered 5 ½” csg and cemented the same with shoe at 2666.34m (Float

collar at 2654.47m) using 800 Sacks of class-G Dalmia blended cement (DO-60: 0.6%,

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DO-65: 0.4% & Silica Fume: 5%) with pre-mixed slurry density of 118pcf by using

cementing unit and rig pump on 11.07.2012.

FLUID DISCUSSION

Mud Type: Semi Dispersed Mud System

This section was drilled with Bentonite-barytes mud treated with PAC(R), PAC(UL),

Resinex etc. Mud weight was maintained as 68pcf and MF viscosity ranges from 45-48

sec/quart was maintained in this section. No caving or sloughing was observed over

shakers.

Rheology & Lubricity:

The Rheological properties were maintained properly. Linseed oil and LWC were used

as lubricants. Drilling Detergent was used during drilling of clay formation. The pH of the

mud system was maintained in the range of 9.0-9.5 for optimum performance of the

chemicals. Formalin was also used as the Bio-polymers are easily susceptible for

bacterial degradation.


Density pcf 68-74 68


Fluid loss, cc 7-5 4.0-12.8

PV , cp - 06-16

YP , lbs/ cft - 08-18

Gel 0/15 min, lbs/ cft - 01-03/06-45

pH - 9.0-9.5


Sand % - 0.1

Oil % - 1.0-4.0

Solid % - 2.0-10.0

HP-HT F/L, cc - 11.6

L/C - 0.131-0.183

API Fluid Loss:

The Fluid loss management was done initially with the addition of PAC (R) and later on

PAC (UL) was also incorporated in the mud system as filter loss control agent. Resinex

was also added to minimize fluid loss.

Solids Control:

The solid control equipments used were Desander, Desilter and two LMSS of screen

sizes in the order 28X50, 28X50 & 28x38. These screens were able to control the solids

component within the acceptable limit. Also the mud was diluted constantly with water

and the sand trap was dumped occasionally during trips to keep the total solids under

control.

P a g e | 9

PRODUCTION TESTING:

After completing drill pipe breaking and well head hook-up, lowered rotovert down to top

of F/C (2654m). Circulated and conditioned mud. Pulled rotovert out of hole. SLB

recorded CBL-VDL-GR-CCL-USIT log in the range 2654.2m-1745m. Cement bonding

found to be good to moderate. Ran in open ended tubing to top of F/C and changed

over the well fluid to water completely. Pulled out open ended tubing upto 1505m and

conducted hermitical test upto 2800psi, but failed due to some problem in pressure

testing unit. Pulled open ended tubing out of hole. Ran in perforated bull nose tubing

down to 1507m and conducted hermitical testing upto 4000psi, found ok. Ran in

perforated tubing down to 2603m. The well kept shut in. Further production testing to be

carried out by workover outfit.

The well was declared Rig Down on 21.07.2012.

CHEMICAL COST ANALYSIS: The total mud chemicals cost incurred in this well was found to be 3340838.69/- and cost per meter was found to be Rs 1251.25/-

CHEMICALS COST % OF TOTAL COST

Basic Chemicals 1263101 38.34

Rheology Control Additives 37105 1.13

Fluid loss reducer 698053.5 21.18

Mud lubricants 1076603 32.67

Others 219886 6.68

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CHRONOLOGY OF LOC- HWV

DATE DEPTH LAST 24 HRS DETAILS

26-Apr-12 11 Arranged for and spudded the well at 4am and drilled down to 11m

27-Apr-12 57 Attended DWS. Resumed drilling from 11m to 57m

28-Apr-12 94 Drilled from 57m to 85m. Circ and POOH bit. Attended D/Works. RI bit to bottom and drilled down to 94m. Found unusual noise from D/Works. POOH bit. Presently attending D/Works.

29-Apr-12 94 Attending D/works.

30-Apr-12 94 Attending D/works.

1-May-12 94 Attending D/works.

2-May-12 94 Attended D/works and rectified the same. Arranging to RI bit

3-May-12 122 RI bit to bottom. Circ and drilled from 94m to 122m. C & C mud. Made a wiper trip. C & C mud. POOH bit. Arranging for RI 20" casing.

4-May-12 122

Cemented 20" csg with shoe at 115.73m using 1200 bags of re bag Dalmia cement. Average slurry density 114.6 pcf. Displaced the slurry with 115 bbls of mud keeping 5m under-displaced. Return slurry surfaced density was 110 pcf. WOC. Working on well head.

5-May-12 122 Working on well head.

6-May-12 165 Completed working on well head. RI 17 1/2" bit and tagged cement top at 109m (csg shoe at 115m) . Circ & cleaned cement. Drilled down from 122m to 165m (KOP). Circulating prior to deviation drilling.

7-May-12 165 C & C mud. POOH bit. Hooked up MM & tested at surface, found malfunctioning. RI OE DP up to 84m. Waiting for MM to reach well site.

8-May-12 165 Waited for MM. POOH OE DP. RI 17 1/2" bit upto bottom. C & C mud. PO bit inside shoe. Waiting for MM

9-May-12 165 Waited for MM. RI 17 1/2" bit upto bottom freely. C & C mud. PO bit inside shoe. Waiting for MM

10-May-12 177 MM reached wellsite. Arranged for and tested the same at surface, found ok. RI 17 1/2" bit with MM to bottom. Circ and drilled from 165m to 177m.

11-May-12 345 Drilled from 177m to 345m with SS reading. C&C mud. POOH bit. RI bit with building hook up to 22m.

12-May-12 545 RI bit with building hook up to bottom freely. Circ and drilled from 345m to 545m with SS readings. At 476m, 13deg- N78degW

13-May-12 602 Drilled down from 545m to 602m with SS reading. C & C mud. POOH bit. Arranging to RI bit with holding Hook Up.

14-May-12 803

RI bit with holding hook up to bottom freely. Circ and drilled from 602m to 803m with SS reading (Terminated first isolation stage drilling). Circulating prior to short trip. At depth 776m, 26 deg -N71degW.

15-May-12 915 Decided to drill further. Resumed drilling and drilled from 803m to 915m with SS reading. Observed bit taking torque. C & C mud. POOH bit. RI new bit with holding hook up to 105m

16-May-12 915

RI new bit from 105m to bottom. Encountered tight spot at 882m. Scrapped and freed the same. Terminated first isolation drilling. C & C mud. POOH bit prior to OH survey. WLD recorded HRI-DFL-GR-SP and SDL-DSN-GR-CAL-IDT logs in two consecutive runs. Loggers depth=914m and BHT: 110 deg F. Arranged for and RI bit with stab at 0, 9, 18m upto 63m

17-May-12 915

RI bit with stab at 0, 9, 18m from 63m to bottom freely. C & C mud. POOH bit. SLB recorded DLL-MSFL-GR-SP-CAL and SDL-DSN-IS-GR logs in two consecutive runs. Loggers depth=915m. Arranging for RI bit

18-May-12 915 RI bit to bottom freely. C & C mud. POOH bit. Arranged for and RI 13 3/8" csg upto 92m.

P a g e | 11

19-May-12 915

Cemented 13 3/8" csg with shoe at 912.64m (FC@ 900.53m) using 1800 bags of API class G NS Dalmia cement. Avg cement slurry density was 104pcf for lead and 114pcf for tail. Displaced the slurry with 387bbls of 67pcf mud. Plug got bumped at 3853 strks against calculated 3722 strks at 2700psi with pump eff of 96.6%. Cement slurry of 98pcf surfaced in return. BPV holding ok. WOC

20-May-12 915 Working on well head.

21-May-12 915

Working on Wellhead. Observed gas bubble coming out from the annulus of 13 3/8''X 20'' CSG. Decided & put 15 bags of cement slurry in the annulus but found no improvement. Presently waiting for decision. *Gas reading- Maxm-32% LEL, Min-10% LEL. **Prepared 80bbls of 85pcf mud.

22-May-12 915 Arranged for and pumped 45bbls of 100pcf mud in stages to the annulus of 13 3/8" casing vs 20" casing. Well under observation. *Gas Reading: Max 12% LEL, Min 3% LEL.

23-May-12 915 Worked on wellhead. Arranging to RI bit. Gas reading: Max=3% LEL, min=1% LEL. * Pumped mud of density 100pcf to cellar in stages

24-May-12 915

Worked on wellhead. RI 12 1/4" bit and tagged cement top at 900m (FC). C & C mud, cleaned cement from 900m to 902m. Further cement cleaning is in progress. * Gas reading: Max=3% LEL, Min=1% LEL. **Topped up 13 3/8" csg vs 20" csg annulus with 100pcf mud intermittently

25-May-12 919

Cleaned cement from 902m to 915m. Drilled fresh zone down to 919m. C & C mud. Conducted PIT @100psi (EMW=72pcf), found holding OK. Circ & POOH bit. RI new bit with holding hook-up to bottom freely. Circulating prior to resume drilling. *Gas reading: Max=4% LEL, Min=1% LEL. **Topped up 13 3/8" csg vs 20" csg annulus with 100pcf mud intermittently.

26-May-12 961

Circ and drilled from 919m to 950m. C & C mud, POOH bit. Well handed over to NEWSCO people. Arranged for and RI bit with new deviation hook up and MM to bottom freely. Circ and drilled from 950m to 961m. *Gas reading: Max=3% LEL, Min=1% LEL. **Topped up 13 3/8" csg vs 20" csg annulus with 100pcf mud intermittently.

27-May-12 1223 Drilled from 961m to 1223m with MM and deviation hook up. *Gas reading: Max=2% LEL, Min=1% LEL. **Topped up 13 3/8" csg vs 20" csg annulus with 100pcf mud intermittently.

28-May-12 1495 Drilled from 1223m to 1495m with MM and deviation hook up. *Gas reading: Max=2% LEL, Min=1% LEL. **Topped up 13 3/8" csg vs 20" csg annulus with 100pcf mud intermittently.

29-May-12 1579

Drilled from 1495m to 1579m with MM and deviation hook up. Considering bit-hours, decided to PO bit. C & C mud. POOH bit. RI new bit up to 12m. *Gas reading: Max=3% LEL, Min=1% LEL. **Topped up 13 3/8" csg vs 20" csg annulus with 100pcf mud intermittently.

30-May-12 1579

Attended DWs. RI new bit with deviation hook up from 12m to 1163m. Circulating for gel breaking. *Gas reading: Max=4% LEL, Min=1% LEL. **Topped up 13 3/8" csg vs 20" csg annulus with 100pcf mud intermittently.

31-May-12 1654

Resumed RI bit from 1163m to bottom freely. Circ and drilled from 1579m to 1654m with deviation hook up. C & C mud. PO bit upto 854m due to bandh. Waiting for further instructions. *Gas reading: Max=2% LEL, Min=1% LEL. **Topped up 13 3/8" csg vs 20" csg annulus with 100pcf mud intermittently.

1-Jun-12 1654 Operation suspended due to Bandh. No crew at site since 5pm on 31.05.2012. *Gas reading: Max=3% LEL, Min=1% LEL.

2-Jun-12 1654 Operation suspended due to Bandh. Crew reach site today morning. *Morning gas reading: 2%LEL.

3-Jun-12 1785

Started engines & established circ for gel breaking with bit at 854m. RIH bit to bottom freely. C & C mud. Resumed drilling & drilled from 1654m to 1785m with deviation hook-up. *Gas reading: Max: 2%LEL, Min:1%LEL.

P a g e | 12

4-Jun-12 1953

Drilled from 1785m to 1953m with deviation hook-up. Presently circulating prior to PO bit for bit change. *Gas reading: Max: 2%LEL, Min:1%LEL.

5-Jun-12 1953 C & C mud. POOH bit. Arranged for and RI new 1-2-7 bit upto 209m. *Gas reading: Max: 2%LEL, Min:1%LEL.. ** Filled up 13 3/8" vs 20" casing annulus with 100 pcf mud and dry barytes intermittently.

6-Jun-12 2037

RI new 1-2-7 bit with deviation hook up from 209m to bottom freely. Circ and drilled from 1953m to 2037m. At 2019.95m, 5.80 deg: N-81 deg-W *Gas reading: Max: 2%LEL, Min:1%LEL.. ** Filled up 13 3/8" vs 20" casing annulus with 100 pcf mud and dry barytes intermittently.

7-Jun-12 2037

Terminated second isolation stage drilling. C&C mud, Made a free short trip up to 13 3/8" csg shoe. C&C mud. PO bit up to 180m prior to OH survey. *Gas reading: Max: 2%LEL, Min:1%LEL.. ** Filled up 13 3/8" vs 20" casing annulus with heavy weight mud and dry barytes intermittently.

8-Jun-12 2037 POOH bit. SLB recorded DLL-MSFL-GR-SP-CAL and CDT-CNT-DSI-IDT log in two consecutive runs. Arranged for and RI bit with SDMM up to 910m. Gas reading:Max:2%, Min:1%(LEL)

9-Jun-12 2037 RI bit with SDMM from 910m to bottom freely. C&C mud, POOH bit. WLD recorded GR- temperature log. Arranged for and RI bit with stab @ 4m &13m up to 35m. Gas reading:Max:2%, Min:1%(LEL)

10-Jun-12 2037

RI Bit with stab at 4m & 13m down to bottom freely. C & C mud. POOH bit. Arranged for and RI bit with stab at 0m, 9m & 18m to bottom freely. Circulating prior to PO for RI 9 5/8" casing. Gas reading:Max:2%, Min:1%(LEL)

11-Jun-12 2037 C & C mud, POOH bit. Arranged for and RI 9 5/8" csg upto 257m. Gas reading:Max:2%, Min:1%(LEL)

12-Jun-12 2037 RI 9 5/8" csg from 257m and landed with shoe at 2029.28m (FC @ 2017.22m). Established circulation and presently circulating prior to cementing.

13-Jun-12 2037

Cemented 9 5/8" csg with shoe at 2029.28m & F/C at 2017.22m using 1300bags of Ex-Dalmia blended cement. Avg. c/slurry density L=101pcf & T=114.2pcf. Displaced the slurry with 424bbls of 68pcf mud. Plug caught TE at 2800stks and bumped at 4250stks (against calculated 4070stks) with bumping pressure of 2500psi (eff. 95.76%). BPV holding ok. WOC. Working on well head.

14-Jun-12 2037 Working on well head. *Gas reading 1%LEL.

15-Jun-12 2037

Worked on well head. Arranged for and cemented 20" csg Vs 13 3/8"csg anulus with 26bbls of class G Dalmia cement with a slurry density of 120pcf (GW treated with 2% NaCl). WOC. Recorded gas reading max- 31% LEL and min-1%LEL. Waiting for further decision

16-Jun-12 2037 Arranged for and pumped 15bbls of 120pcf mud to the annulus of 20" csg vs 13 3/8" casing in stages. Well is under observation. Gas Reading: Max:40%LEL, Min:1% LEL

17-Jun-12 2037 Well is under observation. Pumped 11bbls of 120pcf mud to the annulus of 20" csg vs 13 3/8" casing in stages.Gas Reading: Max:50%LEL, Min:5% LEL

18-Jun-12 2037 Well is under observation. Pumped 16bbls of 120pcf mud to the annulus of 20" csg vs 13 3/8" casing in stages.Gas Reading: Max:41%LEL, Min:7% LEL.

19-Jun-12 2037 Well is under observation. Pumped 09bbls of 120pcf mud to the annulus of 20"csg X 13 3/8" casing in stages. *Gas Reading: Max:30%LEL, Min:4% LEL.

20-Jun-12 2037 Working on well head. Pumped 02bbls of 120pcf mud to the annulus of 20"csg X 13 3/8" casing in stages. *Gas Reading: Max:35%LEL, Min:8% LEL.

21-Jun-12 2037 Working on well head. *Gas Reading: Max:26%LEL, Min:5% LEL.

22-Jun-12 2037 Completed working on well head. Arranged for & RI 8 1/2" bit with rotovert up to top of FC (2017m). C & C mud. PO rotovert up to 591m prior to cased hole survey. *Gas Reading: Max:15%LEL, Min:4% LEL.

P a g e | 13

23-Jun-12 2037

POOH rotovert. SLB recorded CBL-VDL-GR-CCL-USIT log in the range 850m-2014m.Arranged for and RI 8 1/2" bit down to 2014m. Circ and cleaned cement down to 2014.77m. *Gas Reading: Max:11%LEL, Min:2% LEL.

24-Jun-12 2041

Cleaned cement from 2014.77m to 2037m. Drilled fresh zone down to 2041m. C & C mud. Conducted PIT @ 440psi (EMW=78pcf), found holding. Circulated and PO bit upto 103m prior to cased hole survey. Gas reading: Max=11% LEL and min=2% LEL

25-Jun-12 2074

POOH bit. WLD recorded CBL-VDL-GR-CCL log in the range of 602m-2037m. RI 8 1/2" PDC bit with stab at 18m to bottom. Circ and drilled down from 2041m to 2074m. Gas reading: Max=7% LEL and min=1% LEL

26-Jun-12 2222 Drilled down from 2074m to 2222m. Gas reading: Max=5% LEL and min=1% LEL

27-Jun-12 2300 Drilled down from 2222m to 2300m. C& C mud. Made a free short trip upto shoe (9 5/8"csg shoe). Presently circulating prior to PO bit for OH survey. Gas reading: Max=5% LEL and min=1% LEL

28-Jun-12 2300

C & C mud. POOH bit. WLD recorded IDT-GR log and found inclination of 0.93 deg. Arranged for & RI PDC bit with same hook-up down to 189m. Attended & moved csg line. Gas reading: Max=15% LEL and min=2% LEL.

29-Jun-12 2423 RI PDC with stab at 18m down to bottom freely. Circ and drilled down from 2300m to 2423m.Gas reading: Max=13% LEL and min=5% LEL.

30-Jun-12 2461 Drilled from 2423m to 2461m. *Gas reading: Max=11% LEL and min=2% LEL.

1-Jul-12 2495

Drilled from 2461m to 2476m. C & C mud prior to PO bit. Decided to drill further and drilled down to 2495m. C & C mud. PO bit up to 1986m (inside shoe). During PO bit observed tight spots @2390m, 2380m and 2353m. Attended D/works. Further PO bit up to 1228m for bit change.*Gas reading: Max=7% LEL and min=1% LEL.

2-Jul-12 2495 POOH bit from 1228m. Observed wet pull during PO bit. Found 2nos of nozzle plugged. Attended D/Works. RI new TCR bit down to 1968m. *Gas reading: Max=5% LEL and min=1% LEL.

3-Jul-12

2495

RI new TCR bit from 1968m and got held up at 2420m. Reamed down kelly length. During picking up, string got stuck at 2417m. Worked in the range of 60T-145T. Found no success. Decided and spotted 50bbls of LWC with 5% pipelax covering 325m in the annulus and kept 11bbls inside string. Allowed to soak for 6 hours keeping string under compression of 45T. Repaired D/works up to 4am. Presently working on stucked string. *Gas reading: Max=5% LEL and min=1% LEL.

4-Jul-12 2495

Worked on string and freed the same at 160T. Established circulation and circulated thoroughly. Decided to PO and PO bit inside shoe, Scrapped tight spots encountered during PO. Attended DW and PO bit upto 1070m. Gas reading max=5%

5-Jul-12 2495 POOH bit from 1070m. RI same bit with new BHA (without stab) down to 2377m. Reamed from 2377m to 2465m. Gas reading: max=7%, min=2%.

6-Jul-12 2596 Reamed from 2465m to 2495m. Circ and drilled from 2495m to 2596m. Gas reading: max=9%, min=2%.

7-Jul-12 2670

Drilled down from 2596m to 2670m. Terminated Oil string drilling stage. C & C mud. Made a free short trip upto 9 5/8" csg shoe. C & C mud. PO bit upto 974m prior to OH survey. Gas reading Max=5%LEL, Min=1%LEL

8-Jul-12 2670

POOH bit from 974m. SLB recorded DLL-MSFL-GR-SP-CAL-IDT log and LDL-CNL-GR-SP-CAL log two consecutive runs. Loggers depth 2676.2m. BHT=60 degC. Arranged for and RI bit down to 2013m for circulating prior to CST log. * gas reading = max 7%. Min = 2%

9-Jul-12 2670

RI bit from 2013m to bottom freely. C & C mud. POOH bit. SLB recorded CST log, A=30, R=28 (including 1 MC), L=2. Arranging to RI bit for circulating prior to lowering 5 1/2" csg. *Gas reading = max 5%LEL. Min = 1%LEL.

P a g e | 14

10-Jul-12 2670

Arranged for and RI bit with same hook up to bottom freely. C & C mud. PO bit up to 113m prior to lowering of 5 1/2" casing. *Cellar pit gas reading: Max: 7% LEL, Min: 2% LEL

11-Jul-12 2670

POOH bit. Arranged for and lowered 5 1/2" casing and landed with shoe at 2663.34m (FC at 2654.47m). Established circulation @100psi at 30 SPM. Circulating prior to cementing. *Cellar pit gas reading: Max: 6% LEL, Min: 2% LEL

12-Jul-12 2670

Cemented 5 1/2" casing with shoe at 2666.34m ([email protected]) using 800bags of Class-G blended Dalmia cement. Prepared 118pcf pre-mixed slurry in surface tanks by using cementing unit and rig pump. Pumped 80bbls of 68pcf freshly prepared mud followed by 40bbls of plain water treated with 1% ASPP and 40bbls of 95pcf weighted pre-flush. Pumped pre-mixed slurry by rig pump. Displaced slurry with 169bbls of mud. Plug caught TE at 1232 stks and bumped at 2021stks against calculated stks of 1884 with bumping pressure of 2800psi. Pump Eff:93%. BPV holding OK. WOC. DP breaking is in progress. *Cellar pit gas reading: Max: 5% LEL, Min: 2% LEL

13-Jul-12 2670 DP breaking is in progress. *Cellar pit gas reading: Max:4% LEL, Min: 1% LEL

14-Jul-12 2670 DP breaking is in progress. *Cellar pit gas reading: Max:4% LEL, Min: 1% LEL

15-Jul-12 2670 Completed DP breaking. Working on well head. *Cellar pit gas reading: Max:4% LEL, Min: 1% LEL

16-Jul-12 2670 Completed working on well head. Arranged for an RI rotovert down to 200m. *Cellar pit gas reading: Max:5% LEL, Min: 1% LEL. ** 2% KCl Solution Salinity = 14,000ppm

17-Jul-12 2670 RI rotovert down to 2654m (Top of FC). C & C mud. PO rotovert up to 787m. *Cellar pit gas reading: Max:4% LEL, Min: 1% LEL..

18-Jul-12 2670

POOH rotovert. SLB recorded CBL-VDL-GR-CCL-USIT log in the range 2654.2m to 1745m. Arranged for and RI OE tbg down to top of FC (2654m) and changed over to water completely. Arranging for PO OE tbg. *Cellar pit gas reading: Max:3% LEL, Min: 1% LEL..

19-Jul-12 2670

PO OE tbg upto 1505m. R/up X mass tree. Comducted hermatical test upto 2800psi but failed due to problem in pressure testing unit. R/dn X mass tree. POOH OE tbg. Arranged for and RI perforated bull nose tbg dn to 398m. *Cellar pit gas reading: Max:4% LEL, Min: 1% LEL..

20-Jul-12 2670

RI perforated bull nose tbg down to 1507m. R/up X-mass tree. Conducted hermatical test upto 4000psi. Found holding ok. Waiting for gravel packing job by service provider. Celler pit gas reading: max=3%LEL, min=1%LEL

21-Jul-12 2670 Waiting for gravel packing job by service provider. Celler pit gas reading: max=4%LEL, min=1%LEL

22-Jul-12 2670 Declared rig-down. But later on, decided to RI perforated bull nose tbg down to bottom. Arranged for and RI tbg from 1507m to 2603m. Shut in well. Further rigging down is in progress.

P a g e | 15

MUD SUMMARY OF LOC. HWV

Date of spudding: 26.04.2012

Date of Oil string cementation: 11.07.2012

Date of rig down: 21.07.2012

STAGE

MUD

PARAMTERS

CONDUCTOR

(0-122)m

Ist

ISOLATION

(122-915)m

IInd

ISOLATION

(915-2037)m

OIL STRING

(2037-2670)m

MUD WEIGHT (lbs/cft)

MF VISCOSITY (sec)

AV (Cp)

PV (Cp)

YP (lbs/100sq ft)

0’ GEL

15’ GEL

API F/LOSS (cc)

SHEATH (mm)

SALINITY (ppm)

pH

SAND (%)

OIL (%)

Solid (%)

MBC (cc)

HP/HT F/Loss(cc)

Lubricity Coefficient

66

60

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

66-67

48-55

13-19

5-11

10-28

3-24

32-90

12-33

1.0-2.0

800-1200

9.0-10.0

0.1-0.8

Trace

6.0

6

-

0.238

67-68

48-52

10-16

6-10

8-16

2.5-9

42-54

8.4-29

1.0-2.0

600-1200

8.5-10.0

0.1

1.0

4.0

4.0

-

0.223-0.344

68

45-48

10-25

6-16

8-18

01-03

06-45

4.0-12.8

1.0

800-900

9.0-9.5

0.1

1.0-4.0

2.0-10.0

5.5-6.0

11.6

0.131-0.183

Type of Mud Bentonite

suspension

lightly treated

with Caustic

Soda.

Bentonite

suspension

lightly treated

with CMC

(HVG), CMC

(LVG),

C/Soda,

Drilling

Detergent and

Linseed Oil.

Bentonite mud

treated with

CMC (HVG),

CMC (LVG),

C/Soda,

PAC®, Drilling

Detergent,

LWC and

Linseed Oil.

Bentonite Barites

(semi dispersed)

mud treated with

C/Soda, PAC®,

PAC(SL), Resinex,

Linseed Oil,

Drilling Detergent,

LWC, Formaline

etc.

P a g e | 16

MUD PARAMETERS MAINTAINED LOC- HWV

1ST ISOLATION STAGE DATE

DEPTH

MUD WEIGHT

MF VISC.

AV PV YV 0/15'/30'/60

' GEL F/LOSS SHEATH

(M) LBS/CFT SEC. (CP) (CP) lbs/100ft2 Lbs/100ft2 (ml) (mm)

07.05.2012 165 66 55 19 5 28 24/36 33.0 2.0

10.05.2012 295 67 55 14.5 6 17 10/90 27.0 2.0

12.05.2012 545 67 50 13 8 10 3/32 15.2 1.0

15.05.2012 915 67 52 17 11 12 6/36 12.0 1.0

16.05.2012 915 67 48 15 10 10 8/55 13.0 1.0

17.05.2012 915 67 48 13 8 10 7/54 13.4 1.0

1ST ISOLATION STAGE

DATE PH SALINITY SAND OIL SOLID MBC HP/HT F/L Lub. Co-

eff

(ppm) % V/V % V/V %v/v (CC) (CC)

07.05.2012 9 800 0.8 - - - - -

10.05.2012 10 800 0.8 trace 6.0 6.0 - -

12.05.2012 8.5 1000 0.1 - - - - -

15.05.2012 9 1000 0.1 - - - - 0.2

16.05.2012 9 1200 0.1 - - - - -

17.05.2012 9 1200 0.1 - - - - -

RESISTIVITY DATA:

Rm= 2.93 at 71.2 degF

Rmf=2.60 at 71.6 degF Rmc=3.10 at 71.7 degF

2ND ISOLATION STAGE

DATE DEPTH

MUD WEIGHT

MF VISC.

AV PV YV 0/15'/30'/60

' GEL F/LOSS SHEATH


24.05.2012 919 67 52 10 6 8 2.5/84 29.0 2.0

27.05.2012 1280 67 52 14 8 12 9/56 13.0 1.5

28.05.2012 1560 67 50 12 7 10 4/42 12.0 1.0

02.06.2012 1654 67 48 10 6 8 8/54 20.0 1.0

04.06.2012 1981 67 45 11 3 16 2/22 11.5 1.0

06.06.2012 2037 67 48 16 10 12 2/33 8.4 1.0

09.06.2012 2037 68 47 12 9 6 2/42 8.4 1.0

20.06.2012 2037 68 50 14 10 8 2/20 16.0 1.0

2ND ISOLATION STAGE


eff


24.05.2012 10.0 600 0.1 - - - - -

27.05.2012 8.5 800 0.1 - - - - 0.245

28.05.2012 9.0 1000 0.1 - - - - -

02.06.2012 9.0 1000 0.1 - - - - -

04.06.2012 9.0 1000 0.1 - - - - -

06.06.2012 9.0 1000 0.1 1.0 4.0 - - 0.223

09.06.2012 9.0 1000 0.1 - - - - 0.344

20.06.2012 10.5 1000 0.1 - - - - -

RESISTIVITY DATA:

Rm= 2.76 at 74.0 degF

Rmf=2.38 at 74.7 degF

Rmc=3.12 at 74.9 degF

P a g e | 17

MUD PARAMETERS MAINTAINED LOC- HWV

OIL STRING STAGE

DATE DEPTH MUD

WEIGHT MF VISC. AV PV YV

0/15'/30'/60' GEL

F/LOSS SHEATH


25.06.2012 2158 68 46 10 6 8 1/45 12.8 1.0

26.06.2012 2260 68 48 20 12 16 2/34 8.4 1.0

26.06.2012 2260 68 47 19 12 14 1/32/39/52 7.8 1.0

03.07.2012 2417 68 45 15 9 12 1/6 5.4 1.0

05.07.2012 2510 68 45 21 12 18 2/10/14/17 4.8 1.0

06.07.2012 2670 68 47 25 16 18 3/13 4.0 1.0

07.07.2012 2670 68 45 21.5 16 11 2.5/15 6.4 1.0

OIL STRING STAGE


eff


25.06.2012 9.0 850 0.1 1.0 2.0 5.5 - 0.146

26.06.2012 9.0 900 0.1 - - - - -

26.06.2012 9.0 900 0.1 - - - - -

03.07.2012 9.5 900 0.1 - - - - 0.131

05.07.2012 9.0 900 0.1 4.0 6.0 6.0 11.6 0.183

06.07.2012 9.0 800 0.1 - - - - -

07.07.2012 9.0 800 0.1 4.0 10.0 6.0 - -

RESISTIVITY DATA:

Rm=1.89 at 72.6 degF

Rmf=1.80 at 71.2 degF

Rmc=2.17 at 71.0 degF

P a g e | 18

HYDRAULICS DATA OF LOC:HWV

12 1/4" HOLE

DATE DEPTH (m)

BIT SIZE (inch)

NOZZLE SIZE (INCH)

Liner (INCH)

STROKE LENGTH (inch)

VOL/STK (gal)

SPM GPM SPP (psi)

eff.

03.06.12 1846 12 1/4 18/32 X 3 7 10 4.162 90 356 950 95

JET VEL (FT/SEC)

BHHP SHHP RATIO ANNULAR VELOCITY (FT/MIN) PRESSURE LOSS AT BIT

(PSI)

OH/DC OH/DC OH/DP CSG/DP

184 68 236.5 0.29 122 97 84 81 270

8 1/2" HOLE

DATE DEPTH (m)

BIT SIZE (inch)

NOZZLE SIZE (INCH)

Liner (INCH)

STROKE LENGTH (inch)

VOL/STK (gal)

SPM GPM SPP (psi)

eff.

25.06.12 2158 8 1/2 13/32 X 6 7 10 4.162 108 427 850 95

29.06.12 2438 8 1/2 13/32 X 6 6 1/2 10 3.589 100 341 1000 95

06.07.12 2596 8 1/2 14/32 X 3 6 1/2 10 3.589 100 341 1000 95

JET VEL (FT/SEC)

BHHP SHHP RATIO ANNULAR VELOCITY (FT/MIN) PRESSURE LOSS AT BIT

(PSI)

OH/DC OH/DC OH/DP CSG/DP

212 110 254 0.43 419 - 266 229 362

169 56 238 0.23 334 - 212 199 231

291 166 238 0.69 334 - 212 199 686

P a g e | 19

CHEMICAL COST ANALYSIS LOC- HWV

Chemicals Unit Unit

rate(Rs) Planned Chemical

Actual chemical

consumption

Plannedcost (Rs)

Actual cost (Rs)

BARYTES MT 6949.93 1600 104 11119888 722792.72

BENTONITE MT 3637.90 450 135 1637055 491116.5

CAUSTIC SODA KG 37.84 5000 1300 189200 49192

CMC(H) KG 74.21 4000 500 296840 37105

GUAR GUM KG 72.55 500 0 36275 0

CL-20 KG 18.47 13000 0 240110 0

CMC(L) KG 60.21 4900 2500 295029 150525

PAC® KG 193.96 9000 1550 1745640 300638

PAC (UL) KG 146.93 4500 850 661185 124890.5 POTASSIUM CHLORIDE KG 50.91 2000 1500 101820 76365

RESINEX BAG 976.00 650 125 634400 122000

LWC KL5 1620.00 200 11.806 324000 19125.72 DRILLING DETERGENT DR 1284.85 100 60 128485 77091

EP-LUBE LIT 66.29 20000 0 1325800 0

LINSEED OIL LIT 98.37 15000 10750 1475550 1057477.5

SOD BICARBONATE KG 23.57 700 200 16499 4714

FORMALINE KG 16.79 2000 430 33580 7219.7

PIPELAX LIT 83.66 2000 450 167320 37647

CFLS KG 48.74 8000 0 389920 0

OCTYL ALCOHAL KG 129.61 850 130 110168.5 16849.3

20928764.5 3294748.94

REMARKS:

1. LOC:HWV was a development well of depth 2670m.

2. The planned chemical cost has been taken from SAP system (as no data available in periodical review of chemicals).

3. The cost per meter is found to be Rs. 1251.25/-.

REASONS FOR HIGH COST OF THE WELL:

1. Few remarkable reasons for high cost of the well can be explained as follows:-

2. Very long section of Deviation drilling increased the consumption of Lubricants.

3. Because of gas leakage in 20" csg vs 13 3/8" csg annulus, 100pcf and later on 120pcf mud was prepared and kept in stock for emergency use.

4. During Oil string drilling, string got stuck at 2417m. Freed the same by spotting 50bbls of LWC.

P a g e | 20

CHEMICAL COST ANALYSIS

COST % OF TOTAL COST

BASIC CHEMICALS 1263101 38.34

RHEOLOGY CONTROL ADDITIVES 37105 1.13

FLUID LOSS REDUCER 698053.5 21.18

MUD LUBRICANT 1076603 32.67

OTHERS 219886 6.68

CONSUMPTION AND COST OF CEMENT CHEMICALS LOC – HWV

CHEMICALS UNIT UNIT RATE **PLANNED CHEMICAL

PLANNED COST

ACTUAL CONSUMPTION

ACTUAL COST

HR-4 KG 173.49 1200 208188 125 21686.25

HR-12 BAG 8,071.74 15 121076.1 0 0

ASPP KG 75.31 500 37655 300 22593

TEEPOL L 36.21 250 9052.5 50 1810.5

TOTAL COST= 375971.6 46089.75

**PLANNED CHEMICALS' RECORD TAKEN FROM SAP SYSTEM.

P a g e | 21

WELL CEMENTATION CHECK LIST TYPE OF JOB: CONDUCTOR

1. Date: 03.05.2012

2. Well No / LOC: - NHK#602 / HWV

3. Depth (Mtr): 122

4. Average Hole Size (“): 26

5. Casing Size(“)/Shoe/F/Collar (Mtr): 20 / 115.73 / --

6. Hole Volume after Landing Casing (Bbl): ---

7. Circulation Rate (gpm): ---

8. Bottom up (Min): -- / ----

9. Casing landing Time: 01:50pm

10. Circulation Establishing Time/ Pressure (psi): 02:35pm / no record

11. Circulating Pressure (psi): ---

12. Circulated prior to cementation for (Min): 95min

13. Pumps for cementation (Rig pump):

i) Pump type: A-1400 PT ii) Liner Size (“): 7

iii) Gallon per stroke: 4.162 iv) Serviced on: 03.05.2012

v) Pump efficiency (with super charger): P1- 95% P2- 95%

14. Pre flushes:

i) Formulation: Plain Water ii) Volume (Gal): 1200

iii) Pumping Time: 05mins (04:11pm – 04:16pm) iv) Pump Used: MP-2

15. Cement Used:

i) Type: Re-bag Dalmia ii) Formulation: Neat

iii) Percentage of grout: 50% iv) quantity (MT/Bags): 42 / 1200

v) Pumping time: 41mins (04:16pm – 04:57pm) vi) Pump Used: MP-2

16. Gauging Water –

i) Formulation: 0.1% HR-4 ii) Volume Prepared (Bbl): 200

iii) Volume Required (Bbl): 115 iv) Volume Consumed(Bbl): 103

17. Displacement-

i) Volume (calculated) Gal/Bbl/ Kl : 4600 / 115 / 20.93

ii) Time: 19mins (05:02pm – 05:21pm) iii) Pump used: MP-2

18. Average cement slurry density (lbs/cft): 114.6 pcf

19. Recommended slurry density: 114 pcf

20. Return slurry density (lbs/cft): 110pcf

P a g e | 22

WELL CEMENTATION CHECK LIST TYPE OF JOB: 1st ISOLATION

1. Date: 18.05.2012

2. Well No / LOC: NHK#602 / HWV

3. Depth (Mtr): 915m

4. Average Hole Size (“): 17.50”

5. Casing Size (“)/Shoe/F/Collar (Mtr): 13 3/8” / 912.64m / 900.53m

6. Hole Volume after Landing Casing (Bbl): 714.6

7. Circulation Rate (gpm): 356

8. Bottom up Time (Min): 36


10. Circulation Establishing Time/ Pressure (psi): 06:50PM / 300psi @ 40spm

11. Circulating Pressure (psi): 200psi @ 90spm

12. Circulated prior to cementation for (Min): 180


i) Pump type: A 1400-PT ii) Liner Size (“): 7”


v) Pump efficiency (with supercharger): P1- 96% P2-96.2%

14. Pre flushes:

i) Formulation: 1%ASPP+0.5%Teepol ii) Volume (Gal): 2000

iii) Pumping Time: 06min (11:49pm-11:55pm) iv) Pump Used: MP2

15. Cement Used:

A. Lead Slurry

i) Type: NS-Dalmia Cement ii) Formulation: Neat

iii) Percentage of grout: 76% iv) quantity (MT/Bags): 38.5/1100

v) Pumping time: 30min (11:55pm-12:25am) vi) Pump Used: MP2

B. Tail Slurry-

i) Type: NS-Dalmia Cement ii) Formulation: Neat

iii) Percentage of grout: 50% iv) quantity (MT/Bags):24.5/700

v) Pumping time: 20min (12:25am-12:45am) vi) Pump Used: MP2


Lead Slurry - i) Formulation: 1.64%Bentonite+0.26%HR-4 ii) Volume Prepared (Bbl): 250

P a g e | 23

iii) Volume Required (Bbl): 178 iv) Volume Consumed (Bbl): 166


Tail Slurry - i) Formulation: Plain Water ii) Volume Prepared (Bbl): --

iii) Volume Required (Bbl): 67 iv) Volume Consumed (Bbl): --

18. Displacement-


ii) Time: 37min (01:00am-01:37am) iii) Pump used: P-1 & P-2

19. Plug Caught trailing end at (Strokes): Not recorded

20. Plug bumped at (Strokes): 3853

21. Calculated strokes for bumping plug: (100% eff): 3722 Existing Eff: 96.2%

22. Pump efficiency during cementation (%): 96.6

23. Return volume of mud (Bbl):

i) Calculated: 388 ii) Actual: 470

Tank Dip Measurements: Sl/

No

Tank

Vol

Suc-1 Suc-2 Desander Sto-1 Sto-2 Sto-3 Slug

Total Vol/in. Vol/in. Vol/in. Vol/in. Vol/in. Vol/in. Vol/in.

2.2 3.16 1.78 3.16 3.16 3.16 0.96

1 Before

pumping

C/slurry 143 190 98 208 100 120 40 899

2 After pumping

C/slurry 171 250 141 250 243 243 71 1369

3 After

displacement 119 164 96 205 164 133 71 952

24. Volume gained during total operation (Bbl): 53

25. Average cement slurry density (lbs/cft):

i) Lead slurry: 104

ii) Tail slurry: 114

26. Return slurry density (lbs/cft): 98

27. Remarks/Observations:

i) Casing was stationary during cementing operation.

ii) One plug was used during cementation.

iii) Free fall of cement slurry was observed for 05mins and return came after 03mins of

displacement started.

iv) Displacement started after 15min of completing cements slurry pumping.

v) BPV holding ok.

vi) Active tanks cleaned on 16.05.2012.

P a g e | 24

WELL CEMENTATION CHECK LIST TYPE OF JOB: 2nd ISOLATION

1. Date: 13.06.2012


3. Depth (Mtr): 2037

4. Average Hole Size (“): 12.25

5. Casing Size(“)/Shoe/F/Collar (Mtr): 9 5/8 / 2029.28 / 2017.22

6. Hole Volume after Landing Casing (Bbl): 828


8. Bottom up / Cycle Time (Min): 44 / 93


10. Circulation Establishing Time/ Pressure (psi): 12:30am / 600psi @ 30spm

11. Circulating Pressure(psi): 300 psi @ 75spm

12. Circulated prior to cementation for (Min): 300


i) Pump type: A-1400 PT ii) Liner Size(“): 7


v) Pump efficiency(with super charger): P1- 95% P2- 95%

14. Pre flushes:

i) Formulation: 1%ASPP ii) Volume (Gal): 2000

iii) Pumping Time: 5min (07:48am – 07:53am) iv) Pump Used: MP-2

15. Cement Used:

A. Lead Slurry

i) Type: Class G Ex-Dalmia ii) Formulation: 0.6% DO-60

& 0.4% DO-65

iii) Percentage of grout: 76% iv) quantity (MT/Bags): 36.4 / 1040

v) Pumping time: 26mins (07:54am – 08:20am) vi) Pump Used: MP-2

B. Tail Slurry-

i) Type: Class G Ex-Dalmia ii) Formulation: 0.6% DO-60

& 0.4% DO-65

iii) Percentage of grout: 50% iv) quantity( MT/Bags): 9.1 / 260

v) Pumping time: 15mins (08:20am – 08:35am) vi) Pump Used: MP-2


A .Lead Slurry-

i) Formulation: 1.97%Bentonite ii) Volume Prepared (Bbl): 250

iii) Volume Required (Bbl): 152 iv) Volume Consumed(Bbl): 141

B. Tail Slurry –

P a g e | 25

i) Formulation: NIL ii) Volume Prepared (Bbl): -


17. Displacement-


ii) Time: 38 mins ( 08:48am – 09:26am) iii) Pump used: MP-1+MP-2

18. Plug Caught trailing end at (Strokes): 2800


20. Calculated strokes for bumping plug: (100% eff):4070 Existing Eff: 95

21. Pump efficiency during cementation (%): 95.76

22. Return volume of mud (Bbl):


Tank Dip Measurements:

S/No

Tank

Vol


Total Vol/in Vol/in. Vol/in. Vol/in. Vol/in. Vol/in. Vol/in.

1 Before

pumping

C/slurry 138 189 106 227 139 60 - 859

2 After

pumping

C/slurry

169 249 142 227 215 246 - 1248

3 After

displacement 138 196 109 227 215 246 - 1131


24. Average cement slurry density (lbs/cft):

i) Lead slurry (lbs/cft): 101 pcf (Recommended: 102pcf)

ii) Tail slurry (lbs/cft) : 114.2 pcf (Recommended: 114pcf)

25. Return slurry density (lbs/cft): Not applicable



ii) Cementing was done using one plug.

iii) BPV holding OK.

iv) During free fall of cement slurry, mud return was observed in the mud nullah for

06mins.

v) Displacement started after 13min of completing cements slurry pumping.

vi) Mud return came after 02mins of displacement started.

vii) Active tank cleaned on 10.06.2012

P a g e | 26

WELL CEMENTATION CHECK LIST TYPE OF JOB: OIL STRING

1. Date: 11.07.2012


3. Depth (Mtr): 2670m

4. Average Hole Size (“): 8.5”

5. Casing Size (“)/Shoe/F/Collar (Mtr): 5 ½” / 2666.34m / 2654.47m

6. Hole Volume after Landing Casing (Bbl): 499


8. Bottom up time (Min): 43

9. Casing landing Time: 03:15am

10. Circulation Establishing Time/ Pressure (psi): 03:50 am / 150 psi @ 40spm

11. Circulating Pressure (psi): 200 psi @ 90spm

12. Circulated prior to cementation for (Min): 300min


i) Pump type: A 1400-PT ii) Liner Size(“): 6 ½”


v) Pump efficiency(with supercharger): P1 -95% P2- 96%

14. Pre flushes:

i) Formulation: Plain water treated with 1% ASPP followed by 95pcf weighted preflush

ii) Volume (bbl): 40bbls water + 40bbls weighted mud

iii) Pumping Time: 16min (11:59am-12:15pm) iv) Pump Used: MP-1

15. Cement Used:

i) Type: API Class G Ex-Dalmia ii) Formulation: DO-60: 0.6%,

DO-65: 0.4% & Silica Fume: 5%

iii) Percentage of grout: 43.1% iv) quantity (MT/Bags): 28 / 800

v) Cement Mixing time (pre-mixed): 57min (12:25pm-01:22pm)

vi) Pumping time: 16min (08:10pm-08:50pm) vii) Pump Used: Cementing Unit & MP#2


i) Formulation: Plain water & 0.01% Defoamer ii) Volume Prepared (Bbl): -


P a g e | 27

17. Displacement-

i) Volume (calculated) Gal/Bbl/ Kl: 6760 / 169 / 30.76

ii) Time: 18min (01:50pm-02:08pm) iii) Pump used: MP-1 & MP-2

18. Plug Caught trailing end at (Strokes): 1232


20. Calculated strokes for bumping plug: (100% eff) 1884 Existing Eff: 96%

21. Pump efficiency during cementation (%): 93%

22. Return volume of mud (Bbl): -


Tank Dip Measurements:

Sl/No

Tank

Vol


Total Vol/in. Vol/in

.

Vol/in. Vol/in. Vol/in. Vol/in. Vol/in.

2.2 3.16 1.78 3.16 3.16 3.16 0.96

1

Before

pumping

C/slurry 130 212 137 243 123 151 33 1029

2

After

pumping

C/slurry

167 240 135 240 240 240 63 1325

3 After

displacement 158 227 133 202 212 200 66 1198


24. Average cement slurry density (lbs/cft): 118 (Pre-mixed slurry)

25. Return slurry density (lbs/cft): Not applicable



ii) Cementing was done using one plug.

iii) 80bbls of 68pcf freshly prepared mud was pumped before pumping preflush.

iv) Displacement started after 12minutes of completing cements slurry pumping.

v) During free fall of cement slurry mud return was observed in the mud nullah for 05

minutes.

vi) Mud return came after 02 minutes of Displacement.

vii) BPV holding OK.

viii) Active tank cleaned on 08.07.2012

P a g e | 28

DEVIATION PROFILE/COURSE OF THE HOLE

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CALIPER LOG (GRAPH)

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PLOT OF DAYS VS DEPTH

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CBL LOG OF LOC: HWV

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P a g e | 40

P a g e | 41

OIL INDIA LIMITED DEVELOPMENT GEOLOGICAL NOTE NO: 1168

NHK WELL NO.* (LOC. HWV): DEPTH DATA AND DRILLING POLICY

(DEOHAL AREA, HUGRIJAN ML) (DEVIATED)

REFERENCE i) Dev. G. Note No. 1145 (Loc. R) of December, 2011

ii) D (E&D)’s Letter No. E&D/2.2-464, dated 28.12.2011

Formations Depth (m bdf) (Approx.)

Depth (TVD) (Approx.) Remarks

All/Dhek Surface Surface

Based on evidence from neighbouring wells

Girujan 1750.0 1636.0

Tipam 1850.0 1736.0

Barail Argillaceous 2415.0 2301.0

Arenaceous 2545.0 2431.0

The expected lithology of the formations to be encountered in this well, based on evidence of neighbouring wells, is indicated in Figure-2.

CASING POLICY

Depth (m)

Hole Size (inch)

Casing Cement

Size (inch) Amount (m) Type

upto

150 26 20 0 – 150 94 PPF X K-55 X BTC Surface

1000 17.1/2 13.3/8 0 – 1000 68 PPF X N-80 X BTC Surface

2150 φ 12.1/4 9.5/8 0 – 2150 47 PPF X N-80 X BTC 150 m inside 13⅜″ casing shoe

2670 8.1/2 5.1/2 0 – 2665 20 PPF X N-80 X BTC 150 m inside 9⅝″ casing shoe

GEOLOGY :

The replacement location Loc. HWV (Loc. R) for NHK-285 falls in the Deohal-Lohali structure, which is a composite faulted anticlinal structure at the Barail level, compartmentalized into three fault blocks viz. Lohali, Deohal and East Deohal by two north-south trending faults and is bounded by a common major EW to ENE-WSW trending fault towards the south. The Deohal and the East Deohal blocks are the central and eastern fault blocks of the area respectively having an areal extent of around 19 sq km at Barail Third Sand level. The Barail Third Sand is the primary reservoir within the Barail Formation of the area and has been established as a NAG reservoir. The well NHK-285 had been a very good gas producer well in Deohal area and it was under production till 14.07.2011. Problem occurred in well NHK-285 on 14.07.2011, when a leakage from the wellhead fittings was observed above the master valve and the master valve of the wellhead was immediately closed. Further examination revealed that there were a number of deep impressions of damage (spots) on the wellhead and displacement of the 2.9/16” Master Valve Bonnet Flange from its body in downward direction was observed. Gas was observed to be leaking from the displaced portion. It was then decided to kill the well and change the master valve on safety consideration. Presently, effort is on to kill the well. Simultaneously, Loc. HWV is planned to be drilled as a deviated well from the existing plinth of NHK-552, place the well as close as possible against the producing Barail 3

rd sand of NHK-285 and complete it as a replacement

well of NHK-285. For information, the depth of the Barail 3

rd sand (tested) at NHK-285 is

2427.0- 2447.0 m with perforations in the ranges of 2430.0- 2435.0 m and 2436.0- 2442.0 m. As per the deviation plan the replacement well will be placed 15 m away from NHK-285, at 2427-m Barail 3

rd sand level.

SURFACE : POSITION

Well NHK-552 (Surface) to Loc. HWV (Surface) is 15 m towards 186°-00’-00’’ true bearing (refer Figure-1). [X: 3265231.923, Y: 1082280.769]

SUB SURFACE :

POSITION

Loc. HWV (Surface) to Loc. HWV (Sub-surface) is 602.48 m towards 296°-30’-24’’ true bearing, i.e. 15 m away from the position of NHK-285. [X: 3264682.80, Y: 1082527.62]

ELEVATION : GLE: 117.09 m. (As per NHK-552). Deviation correction (MWD - TVD) = 113.63 m.

OBJECTIVE DEPTH : 2665 m. ** (MWD) / 2550 m TVD

P a g e | 42

Note: Depending on situations, the surface, 13.3/8” and 9.5/8” casing setting depths may be reduced to 100 m, 800 m and around 1800 m respectively.

* Well number will be advised later. m BDF = Meter Below Derrick Floor, TVD = True Vertical Depth. ** The objective depth may need to be revised based on actual drilling evidence nearer the time. φ The 9 5/8” casing setting depth may be decided based on the actual drilling evidence.

MUD POLICY

Depth (m)

Hole Size (inch)

Mud

Weight (lbs/cft)

M. F. Visc. (sec)

Filt (API) (cc)

Mud Type

150 26 66 55 – 60 -- Fresh water Bentonite suspension

1000 17.1/2 66 – 67 50 – 55 < 15 Fresh water Bentonite mud treated with CMC (HVG) and lubricants

2150 φ 12.1/4 67 – 68 45 – 50 < 10 Fresh water mud treated with F/L control agent and lubricants

2670 8.1/2 68 – 74 # 40 – 45 5 – 7

Fresh water mud fully treated with F/L controller, rheology modifier, lubricants etc.

# Mud weight may need to be changed based on actual drilling evidence.

DEVIATION PLAN

i) Kick off at 200 m. ii) Build-up angle at a rate of 2° per 30 m towards 296°-30’-24’’ true bearing

until a drift angle of 23.53° is attained at around 553 m. iii) Maintain the drift angle of 23.53° and direction towards 296°-30’-24’’ true

bearing down to around 1643 m. iv) Cement 13.3/8″ casing with shoe at around 1000 m within the 23.53° holding

section. v) Drop the angle at a rate of 1.5° per 30 m till about 602 m total horizontal

displacement is achieved at around 2114 m and drill a vertical hole down to 2150 m.

vi) Limit the target area within 30 m radius vii) Cement 9.5/8″ casing with shoe at around 2150 m and drill a vertical hole

below.

BOTTOM HOLE TEMPERATURE

Based on the bottom-hole temperature, recorded during BHP operations at well NHK-285, geothermal gradient works out to be 17.5°C/km (65°C at 2335 m TVD).

FORMATION PRESSURE

i) SBHP recorded on 23.04.2010 at well NHK-285 in 2427-m Barail 3

rd Sand was

239.6 kg/cm2 at mid-perforation depth 2436 m TVD, which is about 4 kg/cm

2

below hydrostatic.

ii) FBHP recorded on 15.07.2010 at well NHK-285 in 2427-m Barail 3rd Sand was

237.3 kg/cm2 at mid-perforation depth 2436 m TVD, which is about 6 kg/cm

2

below hydrostatic. iii) Overall BHP data suggests that the reservoir pressure has depleted in the

producing Barail 3rd Sand and the Formation pressure is expected to be nearly

hydrostatic within all Formations in this well.

iv) BOP protection and degassing equipment to be installed at the well-site and BOP drill to be performed at regular intervals.

v) Arrangements for preparation of heavy weight mud at short notice are to be made available at the well-site.

COMPLICATIONS & LOSS

CIRCULATION

i) While trying to kill the well NHK-285 recently, gushing out of gas and water

around the cellar and the well plinth was observed, which was suspected to be due to communication between 5 ½’’ and 9

5/8” casing and leakage through 9

5/8” casing. All necessary precaution to handle the possible gas charged zones/ sands within the shallower sections must be taken while drilling.

ii) Though no mud loss was observed within Alluvium, Girujan, Tipam and Barail

formations in the neighboring wells, care to be taken while drilling this well for any mud loss.

iii) Sufficient quantities of loss circulation material to combat mud loss need to be

stored at well-site. Care/vigilance is also required for any induced loss while carrying out isolation/ oil-string cementation job.

SAMPLE COLLECTION

Below 150 m.

P a g e | 43

GAS LOGGING Below 13.3/8″ casing shoe.

(G K SHARMA) CHIEF GEOLOGIST (D/O) For HEAD (OPERATIONS)

For GENERAL MANAGER (G&R)

Duliajan: 29/03/2012

FLUSH SAMPLE

Depth Range (m) Interval (m) Purpose

150-1750 1750-2400 2400-2550

2550-Objective

10 5 3 2

Logging only

150-2400 2400-Objective

10 6

Petrology, Paleontology, source rock analysis and storage

Samples close to all the formation tops are to be retained at 6 m interval till the wireline surveys are over.

WIRELINE SERVICES

i) 17½” Hole: DIL/HRI/DLL-MSFL-GR-SP-CAL, CDL-CNL-GR-CAL and Sonic surveys at first isolation stage.

ii) 12¼” Hole: DLL-MSFL- GR-SP -CAL, SDLT-DSNT- SGR/GR-CAL, Sonic, Side-wall coring, CBL-VDL-GR-CCL, FMI (provisional), MDT (provisional), surveys at second isolation stage.

iii) 8½″″″″ Hole : DLL-MSFL-SP-GR-CAL, SDLT-DSNT- SGR/GR -CAL, DSI/ WSTT, CMR (provisional), FMI (provisional), MDT (provisional), VSP, Side-wall coring, CBL-VDL-GR-CCL and USIT (provisional) surveys are to be carried out at the final depth.

The wireline log requirement is tentative and actual logs to be recorded will be decided nearer the time.

WELL COMPLETION

AND PRODUCTION TESTING

Conventional production testing will be carried out in this well. However, the

following equipment may be kept ready.

i) Surface equipment: 5000 psi X-mas tree.

ii) Boiler and gas flaring arrangement to be made at suitable place at well-site.

iii) NPU/CTU may be required for unloading well.

iv) Make necessary arrangement for wellhead pressure test upto 4000 psi and

oil-string casing hermetical test upto 4000 psi prior to production testing.

GENERAL REMARKS

i) The 13⅜″ & 9⅝″ casings may be tested upto 1500 psi and 3500 psi respectively.

ii) BOP to be tested upto 350 psi (minimum) after 20” casing completion 1500 psi (minimum) after 13.3/8” casing completion and upto 3500 psi (minimum) after completion of 9.5/8” casing respectively.

iii) Leak off test (LOT) to be carried out after cementation of 13⅜” and 9⅝” casings.

iv) The chemical ramp of at least 600 sq. ft. with proper shed will be required for keeping adequate quantities of barites at well-site.

v) Kill pump with adequate capacity should be available at well-site.

Note: 1. Depending on situations, in case the 20” casing set at 100 m, then kick-off point (KOP) will be at around 150 m.

2. In case 9.5/8” casing needs to be set at 1800 m, directional drilling to be completed within 1800 m, with high DLS (Dog leg severity).

P a g e | 44

DEVIATION PLAN

LOCATION: HWV

Planned Direction: 296°-30’-24’’ true bearing. Kick Off Point: 200 m

Sl MWD C/Length D/Angle A/D. Angle TVD CD THD

No.

(m)

(m)

(Deg)

(Deg)

(m)

(m)

(m)

1 200.00 0.00 200.00 0.00 0.00

2 210.00 10 0.67 0.34 210.00 0.06 0.06

3 240.00 30 2.67 1.67 239.99 0.87 0.93

4 270.00 30 4.67 3.67 269.93 1.92 2.85

5 300.00 30 6.67 5.67 299.78 2.96 5.82

6 330.00 30 8.67 7.67 329.51 4.00 9.82

7 360.00 30 10.67 9.67 359.08 5.04 14.86

8 390.00 30 12.67 11.67 388.46 6.07 20.93

9 420.00 30 14.67 13.67 417.61 7.09 28.02

10 450.00 30 16.67 15.67 446.50 8.10 36.12

11 480.00 30 18.67 17.67 475.08 9.11 45.23

12 510.00 30 20.67 19.67 503.33 10.10 55.33

13 540.00 30 22.67 21.67 531.21 11.08 66.40

14 553.02 13 23.53 23.10 543.19 5.11 71.51

15 1642.94 1090 23.53 23.53 1542.48 435.13 506.64

16 1650.00 7 23.18 23.36 1548.97 2.80 509.44

17 1680.00 30 21.68 22.43 1576.70 11.45 520.88

18 1710.00 30 20.18 20.93 1604.72 10.72 531.60

19 1740.00 30 18.68 19.43 1633.01 9.98 541.58

20 1770.00 30 17.18 17.93 1661.55 9.24 550.82

21 1800.00 30 15.68 16.43 1690.33 8.49 559.30

22 1830.00 30 14.18 14.93 1719.31 7.73 567.03

23 1860.00 30 12.68 13.43 1748.49 6.97 574.00

24 1890.00 30 11.18 11.93 1777.84 6.20 580.20

25 1920.00 30 9.68 10.43 1807.35 5.43 585.63

26 1950.00 30 8.18 8.93 1836.98 4.66 590.29

27 1980.00 30 6.68 7.43 1866.73 3.88 594.17

28 2010.00 30 5.18 5.93 1896.57 3.10 597.27

29 2040.00 30 3.68 4.43 1926.48 2.32 599.58

30 2070.00 30 2.18 2.93 1956.44 1.53 601.12

31 2100.00 30 0.68 1.43 1986.43 0.75 601.87

32 2113.63 14 0.00 0.34 2000.00 0.13 602.00

Total horizontal displacement of 602 m to be achieved at around 2114 m (MWD). Deviation correction (MWD - TVD) = 113.63 m.

P a g e | 45

Chem. Lab/Core/SWC (Rep)/02

Side Wall Core Analysis Report

Reference No: Chem Lab / Core /SWC (Rep)/14/2012-13 Date: 12/07/2012

GENERAL MANAGER (G&R)

OIL– Duliajan.

Attention: D. Deka, Sr. Geologist (D/O)

Ref: Memo No. GM (G&R)/ HWV/09.07.2012

Location: HWV Well No: NHK # 602

Sample Received on: 09.07.2012. at 1-10 PM No. of Samples: 27

Analyzed by: BS/SRB/GS/HD (U.Chaliha.)

Copy: SG (D/O), CC (D&W/O), file (Core Data), file (Core Lab). Suptdg. Chemist

Enclosure: Sample Pot: 27 nos. For Chief Chemist (R)

Chromatogram Strip: 15 nos. For Head Chemical

Sl

No.

Depth,

(m)

Sample

Weight, (gm)

% of Oil by

volume/ weight

(cc/100gm)

Porosity

(%)

Fluid Saturation

(% Pore Volm)

Carbonate

Content (as

CaCo3 ) %

Remarks

1 2617.0 3.648 0.365 31.115 2.342 0.584

1) 12 no

Chromatogram strips

were sent earlier with

priority sample

report.

2 2610.0 4.194 0.291 27.927 2.127 1.156

3 2574.5 6.176 0.018 Loose Sample 0.922

4 2571.0 5.865 0.019 32.100 0.114 1.057

5 2568.0 5.184 0.043 31.525 0.273 1.125

6 2564.0 7.951 0.042 31.051 0.255 0.482

7 2560.0 6.268 0.035 31.787 0.205 1.134

8 2558.0 4.313 0.052 31.116 0.326 0.640

9 2553.0 10.319 0.032 31.155 0.194 1.033

10 2529.5 5.603 0.119 Loose Sample 1.291

11 2527.5 4.554 0.073 31.381 0.433 0.939

12 2525.0 4.424 0.025 31.801 0.147 1.131

13 2523.0 5.007 0.067 32.011 0.390 0.553

14 2517.0 5.177 0.064 26.684 0.486 0.939

15 2511.0 3.860 0.547 29.490 3.739 1.853

16 2342.5 6.171 0.270 31.227 1.653 0.567

17 2331.0 3.863 0.403 29.563 2.754 1.154

18 2307.5 4.079 0.681 23.996 5.382 0.583

19 2256.5 4.209 0.739 30.805 4.721 0.556

20 2232.5 5.552 0.400 Loose Sample 1.067

21 2231.0 5.157 0.517 29.473 3.407 0.893

22 2195.0 3.831 0.290 29.577 1.937 1.069

23 2184.5 5.368 0.166 31.495 1.075 0.490

24 2155.0 6.096 0.164 28.807 1.106 0.770

25 2151.0 5.866 0.133 27.789 0.955 0.586

26 2135.0 4.391 0.405 30.149 2.656 1.151

27 2050.0 4.362 0.127 32.351 0.740 1.337

CHEMICAL DEPARTMENT, DULIAJAN-786602, ASSAM, INDIA (Phone:91-374-2800439, Fax: 91-374-2801680/2800533, Email: [email protected])

CHEMICAL LABORATORY

(ISO 9001:2008 Certified)

P a g e | 46

Ref.no.: Chem/Ana/PW/0396/DJN/12. Date: 08.06.2012.

Chief Chemist - Drilling Operation. Attn.: Mr.Dipankar Dutta, Chemist-in-charge (LOC-HWV).

Sub: POLLUTION WATER ANALYSIS REPORT.

Ref.: Your letter no. 40, of date: 06.06.2012.

Characteristics Unit

Desirable limit as per State

PollutionControl Board of Assam.

Sample No 1 Sample No 2

Appearance - Clear Turbid.

Temperature Deg. oC < 40 -

pH - 5.5 - 9.0 7.51

Chloride (as Cl-) mg/l 1000 (max.) 12

Phenolic compounds mg/l 1.0 (max) 0.0720

Sulphate mg/l 1000 (max) 74

Chromium (as Cr+6) mg/l 0.1 (max) 0.0089

Total Dissolved Solids mg/l 2100 (max) 128

Suspended Solids mg/l 100 (max) 64

Oil and grease mg/l 10 (max) Nil.

Sample details :- Sample no.1: Pit water sample collected from Pit of LOC: HWV on 05.06.2012 and was received at our Lab. on 06.06.2012. (Well status: IInd Isolation Drilling, Well depth: 1981m).

(S.Bora.)

Tested by : AKB/K.Gogoi. Chemist (Lab)

For Chief Chemist(Lab)


CHEMICAL LABORATORY


P a g e | 47

Ref.no.: Chem/Ana/PW/0451/DJN/12 Date: 28.06.2012

Chief Chemist - Drilling Operation

Attn.: Mr.Dipankar Dutta, Chemist-in-Charge, Loc. HWV

Sub: POLLUTION WATER ANALYSIS REPORT.

Ref.: Your memo no.51 dated 26.06.2012

Characteristics Unit

Desirable limit as per State

PollutionControl Board of Assam.

Sample No. 1 Sample No. 2

Appearance - Clear Turbid.

Temperature Deg. oC < 40 -

pH - 5.5 - 9.0 7.2

Chloride (as Cl-) mg/l 1000 (max.) 8.5

Phenolic compounds mg/l 1.0 (max) 0.4541

Sulphate mg/l 1000 (max) 67

Chromium (as Cr+6) mg/l 0.1 (max) 0.0611

Total Dissolved Solids mg/l 2100 (max) 260

Suspended Solids mg/l 100 (max) 128*

Oil and grease mg/l 10 (max) Nil.

Sample details:- Sample no.1: Pit water sample collected from pit of Loc.HWV on 25.06.2012 and was received at our Lab. on 26.06.2012 ( Well status: Oil String Drilling, Depth : 2158 m.)

* Not within desirable limit

(S.Bora)

Tested by : RS/ PKS Chemist (Lab)

For Chief Chemist (Lab)


CHEMICAL LABORATORY


P a g e | 48

Ref.no.: Chem/Ana/Misc/516/DJN/12 Date : 17.07.2012

Chief Chemist (Drilling Operations )

Attn.: Mr.Dipankar Dutta,Chemist ; Loc.HWV

Sub: 2% KCl SOLUTION ANALYSIS REPORT

Ref.: Your memo no.60 dated 16.07.2012

Characteristics Unit Sample No. 1 Sample No. 2

Appearance - Turbid

pH - 6.78

Salinity (as NaCl ) mg/l 13,400

Carbonate mg/l Nil.

Bicarbonate mg/l 30.5

Potassium (K+) mg/l 7200

Samlpe details :- Sample no.1: KCl solution (2%) sample collected from Loc. HWV on 14.07.12 and

received in the analytical laboratory on 16.07.2012.

N.B.: Parameters are tested as per requirement mentioned in the memo.

Tested by : RS/ PKS

( S.Bora)

Chemist(Lab)

For Chief Chemist (Lab)


CHEMICAL LABORATORY


P a g e | 49

CEMENT SLURRY FORMULATION FOR LOC : HWV (Conductor)

Ref:Chem/Cmtg/Conductor/01/12-13. Date: 05.04.2012.

HEAD (DRILLING-SUPPORT)

1. Ref. SED(C&T)'s Memo No. : DRLG/CMTG/MEMO/1627/2012 of 04.04.2012.

2. Loc/Well No : HWV.

3. Depth : 150 m.

4. Nature of Cement job : Conductor

5. Type of Cement : Re-Bag Dalmia Cement .

6. Blended with : Nil. 7. Percentage of grout : 50%

%

Addi-

tives

W/W

Density

(lb/cft)

Setting Time at

100 °F

HP/HT

Fluid

Loss Thick-

ening

Time

Schedule

…7G(M)

Viscometer Dial Readings Rheology

n k

IST (hr:min)

FST (hr:min)

at

...C./..psi

(ml)

600 300 200 100 6 3

AV PV YV

(cp) (cp) (lb /100 sqft)

HR-4:0.05%

114 04:10 04:35 NM NM

RT 54 30 25 18 11 8 27 24 6 - -

100 °F

60 37 31 26 15 11 30 23 14 - -

Sample collected by cementing section of Drilling Deptt.

The above cement sample is recommended for conductor casing cementing job at Loc:HWV.

Note: 1.Gauging water to be treated with HR-4:0.1%

R Borkataky J Gogoi

Chief Chemist (Drilling) Chemist

For HEAD-CHEMICAL

Tested by: SNS/MB


CHEMICAL LABORATORY


P a g e | 50

CEMENT SLURRY FORMULATION FOR LOC : HWV (1st Isolation )

Ref:Chem/Cmtg /Iso/03/12-13. Date: 04.05.2012.

HEAD (DRILLING-SUPPORT)

1. Ref. SED(C&T)'s Memo No. : DRLG/CMTG/MEMO/1648/2012 of 03.05.2012.

2. Loc/Well No : HWV (1st Isolation ) .

3. Depth : 1000 m.

4. Nature of Cement job : Isolation

5. Type of Cement : N S Dalmia Cement .

6. Blended with : Nil. 7. Percentage of grout : Lead 76% & Tail 50%.

% Addi-

tives

W/W

Density

(lb/cft)

Setting Time at

140 °F

HP/HT

Fluid

Loss Thick-

ening

Time

Schedule

…7G(M)


n k

IST (hr:min)

FST (hr:min)

at

...C./..psi

(ml)

600 300 200 100 6 3

AV PV YV


LEAD Bentonite : 1.25%

HR-4 : 0.2%

102 04:45 05:15 NM NM RT 140 °F

28 19 16 12 9 7 14 9 10

- -

48 40 34 26 14 12 24 8 32

TAIL

Plain

Water 114 03:00 03:25 NM NM

RT 140 °F

58 39 32 25 15 12 29 19 20

- - 66 48 42 34 18 10 33 18 30

Sample collected by cementing section of Drilling Deptt.

The above cement sample is recommended for 1st isolation casing cementing job at Loc: HWV. Note:

1. Gauging water to be mixed with 1.64% Bentonite & HR-4:0.26% for Lead Slurry & Plain water for Tail slurry.

2. Defoamer 0.01% to be added in gauging water.

R Borkataky J Gogoi


For HEAD-CHEMICAL

Tested by: SNS/MB


CHEMICAL LABORATORY


Chem Lab/Cement/Report/1st Iso/02

P a g e | 51

CEMENT SLURRY FORMULATION FOR LOC : HWV (2nd Isolation) Ref:Chem/Cmtg /2nd Iso/03/12-13. Date: 08.06.2012. HEAD (DRILLING-SUPPORT)

1. Ref. SED(C&T)'s Memo No. :DRLG/CMTG/MEMO/1667/12 of 06.06.12

2. Type of Cement :API Class 'G' Ex Dalmia Cement

3. Blended with :DO-60 : 0.6% & DO-65 : 0.4%.

4. Depth :2150 m.

5. Nature of job :2nd Isolation.

6. Loc/Well No :HWV.

7. Percentage of grout :Lead 76%& Tail 50%

BHCT =45 °C (Tested at 60ºC) BHT = 62ºC

TG=0.9°F/100 ft ( TG based on neighbouring well no:chandmari # 1)

%

Addi-

tives

W/W

Density

(lb/cft)

Setting Time at

140 °F

HP/HT

Fluid

Loss Thick-

ening

Time

Schedule

…7G(M)


n k

IST (hr:min)

FST (hr:min)

at

...C./..psi

(ml)

600 300 200 100 6 3

AV PV YV


LEAD Bento-nite : 1.5%

102 NM NM 400 418 RT 60°C

34 20 15 11 6 4 17 14 6

- -

22 12 9 6 3 2 11 10 2

TAIL

Plain

Water 114 NM NM 60 399

RT 60°C

104 62 44 28 13 11 52 42 20

- - 44 24 16 9 3 2 22 20 4

Sample collected by Cementing Section Drillling Dept.

The above cement sample is recommended for 2nd Isolation casing cement job at Loc: HWV. Note : 1. Gauging water to be mixed with 1.97% Bentonite for Lead slurry & Plain water for Tail slurry. 2. Defoamer 0.01% to be added in gauging water.

R Borkataky J Gogoi


For HEAD-CHEMICAL

Tested by: SNS/MB


CHEMICAL LABORATORY


Chem Lab/Cement/Report/2nd Iso/03

P a g e | 52

CEMENT SLURRY FORMULATION FOR LOC : HWV (Oil String)

Ref:Chem/Cmtg / Os/10/12- 13. HEAD (DRILLING-SUPPORT)

. Ref. SED(C&T)'s Memo No :DRLG/CMTG/MEMO/1685/2012 of 29.06.2012

2. Loc/Well No :HWV

3. Nature of Cement job :5 1/2" Csg .

4.Target Depth :2670 mt

5. Type of Cement :Ex Dalmia Cement

6. Blended with :DO-60 : 0.6 %, DO-65 : 0.4% & 5 % SILICA FUME

7. Percentage of grout :43.1 %

BHCT = 53˚C( Tested at 600c)

BHT = 60 ˚C TG = 0.68ºF/100 ft (based on logging temperature).

% Addi-tives W/W

Density (lb/cft)

Setting Time at 140 °F

HP/HT Fluid Loss

Thick-ening Time

Schedule

… 7G (M)


n k

IST hr:min

FST hr:min

at ...C. /..psi (ml)

600 300 200 100 6 3

AV PV YV


NIL 118 NM NM 56 230 RT 60°C

226 130 94 54 7 5 113 96 34

0.86 0.0049

100 55 37 20 3 2 50 45 10

Sample collected by cementing section of Drilling Deptt. The above formulation is recommended for 51/2 " casing cementing job for Loc: HWV Note: 1. Plain water to be used for mixing cement slurry.

3. Defoamer 0.01% to be added with water.

0:00 0:30 1:00 1:30 2:00 2:30 3:00 3:30 4:00Time (HH:MM)

0

10

20

30

40

50

60

70

Temperature (°C)

0

1

2

3

4

5

6

7

Pressure (kpsi)

0

20

40

60

80

100

120

Consistency (Bc)

R Borkataky J Gogoi


For HEAD-CHEMICAL

Tested by: SNS/MB


CHEMICAL LABORATORY


Chem Lab/Cement/Report/OIL ST/04

Date: 09.07.2012.

P a g e | 53

09.07.2012 Oil India LimitedOil India LimitedOil India LimitedOil India Limited

Casing PolicyCasing PolicyCasing PolicyCasing Policy OIL STRING CASING POLICY NO: GM (G&R) /HWV

General Manager (OD&RS)-------------- (4)

Attention: CED (Loc. HWV)

5.½” CASING POLICY

Well No: NHK-602 (Loc. HWV)

1. Depth:

Drilling : 2670 m

Logging : 2676 m

Accepted : 2676 m

2. Float Collar not above : 2650 m

3. Cement to rise upto : 1880 m

4. Short joints at : I. 2480 m

II. 2165 m

5. Scratchers in the range : Float Collar to 1850 m

6. Centralizers in the range :

I. Float Collar to 1850 m (Every

alternate joint)

II. One inside 9.5/8” casing shoe

(S Bhardwaj)

Sr.Geologist (D/O) for Chief geologist (D/O)

for Head (Operations) for General Manager (G&R)

Note: The above depths are as per open hole wire line logs.

P a g e | 54

OIL INDIA LIMITED Date : 09.07.2012

Well No. NHK-602 (Loc. HWV)

Cementation Policy : Oilstring Cementation

Final Depth: 2670 m (Drilling); 2676.2 m (Logging)

1. Shoe at: 2674.00 m 8772.97 ft Float collar at (m) 2650.00 8694.23 ft 2. Cemt. top to reach: 1880.00 m 6167.98 ft Hole size (inch) 8.50

3. Height of cement 794.00 m 2604.96 ft Casing size (inch) 5.50

4. True gauge annular volume per feet :

0.2291

5. Cement required to fill the true gauge annulus between 8.1/2'' hole and 5.1/2" casing:

596.80 cft

6. Interval between float collar & shoe: 24.00 m 78.74 ft

7. Capacity of 5.1/2" casing:

0.1245 cft/ft

8. Cement required to fill 5.1/2" casing between float collar and shoe: 9.80 cft

OVERGAUGE CONSIDERATIONS

(Based on calipar log)

Hole size (inch) Overgauge Metre Feet Overgauge Overgauge annular volume

cft annular volume

cft/ft

9.00 141.00 462.60 0.0477 22.07

8.50 9.50 45.00 147.64 0.0981 14.48

10.00 64.00 209.97 0.1513 31.77

9. Extra cement required to fill the overgauge sections of the hole:

68.32 cft

10. Total cement required (calculated):

674.92 cft

Sr.Geologist (D/O)

for HEAD-Operation

for General Manager (G&R)

N.B :

The above depths are as per open hole wire line logs.

P a g e | 55

Ref.No. GM (G&R)/ Loc. HWV (DRAFT) Duliajan: 16.07.2012

Well No. NHK-602

(Loc.HWV)

(Deviated)

(All depths are in metres below original derrick floor)

A. BASIC DATA:

D.F. Elevation : 124.71 m asl G.L. Elevation : 117.07 m asl Deviation correction : 112.05 m

9⅝″ casing shoe at : 2028.28 m

As per Driller’s Tally 5½″ float collar at : 2654.47 m

5½″ casing shoe at : 2666.34 m

B. TESTING PROGRAMME:

The replacement well NHK-602 (Loc. HWV) for NHK-285 falls in the Deohal-Lohali structure. The well NHK-602 was drilled as a deviated well from the existing plinth of NHK-552. The well has encountered the expected Barail prospects which

were encountered in NHK-285 also. After breaking and laying down of drillpipes, the operational steps will be

as follows:

1. Make a rotovert trip down to top of float collar (2654.47 m).

2. WLD/Schlumberger to record CBL-VDL-GR-CCL & USIT (Optional) log.

3. Run in 2.7/8” OE tubing to top of float collar (2654.47 m) & change over

mud to water completely in stages.

4. Pull back tubing upto 1500 m and carry out hermetical testing of 5.1/2” casing upto ______ (To be decided by Drilling. As per DDDP, 5.1/2”

casing to be tested hermetically upto 4000 psi). POOH tubing.

5. Run in 2.7/8” OD tubing with perforated bull nose plug to 2600.0 m (F/C:

2654.57 m). Rig up X-mas tree. Rig down Out-fit.

6. Further steps to be decided for gravel pack completion in consultation with the gravel pack service provider.

C. GENERAL REMARKS:

vi) SBHP recorded on 23.04.2010 at well NHK-285 in 2427-m Barail 3rd

Sand was 239.6 kg/cm2 at mid-perforation depth 2436 m TVD, which is

about 4 kg/cm2 below hydrostatic.

vii) This is a deviated (S-bend) well with a maximum drift angle of 26.74° at

598 m (MD). The hole is nearly vertical below 2300.0 m MD.

(Nababrot Gogoi)

Dy. Suptdg. Geologist (D/O)

for Cheif Geologist (D/O)

for Head (Operations)

for GENERAL MANAGER (G&R)

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