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CCCHHHEEEMMMIIICCCAAALLL DDDEEEPPPAAARRRTTTMMMEEENNNTTT
DDDRRRIIILLLLLLIIINNNGGG WWWEEELLLLLL HHHIIISSSTTTOOORRRYYY
RRREEELLLAAATTTEEEDDD TTTOOO CCCHHHEEEMMMIIICCCAAALLL AAACCCTTTIIIVVVIIITTTYYY
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)
P a g e | 1
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.
P a g e | 2
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.
P a g e | 3
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.
P a g e | 4
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.
P a g e | 5
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.
Property Programmed Actual
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.
Property Programmed Actual
Density pcf 67-68 67-68
MF Viscosity , sec/ quart 45-50 48-52
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
Salinity, ppm - 600-1200
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%,
P a g e | 8
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.
Property Programmed Actual
Density pcf 68-74 68
MF Viscosity , sec/ quart 40-45 45-48
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
Salinity, ppm - 800-900
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
P a g e | 10
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
(M) LBS/CFT SEC. (CP) (CP) lbs/100ft2 Lbs/100ft2 (ml) (mm)
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
DATE PH SALINITY SAND OIL SOLID MBC HP/HT F/L Lub. Co-
eff
(ppm) % V/V % V/V %v/v (CC) (CC)
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
(M) LBS/CFT SEC. (CP) (CP) lbs/100ft2 Lbs/100ft2 (ml) (mm)
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
DATE PH SALINITY SAND OIL SOLID MBC HP/HT F/L Lub. Co-
eff
(ppm) % V/V % V/V %v/v (CC) (CC)
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
9. Casing landing Time: 06:05pm
10. Circulation Establishing Time/ Pressure (psi): 06:50PM / 300psi @ 40spm
11. Circulating Pressure (psi): 200psi @ 90spm
12. Circulated prior to cementation for (Min): 180
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: 18.05.2012
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
16. Gauging Water –
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
17. Gauging Water –
Tail Slurry - i) Formulation: Plain Water ii) Volume Prepared (Bbl): --
iii) Volume Required (Bbl): 67 iv) Volume Consumed (Bbl): --
18. Displacement-
i) Volume (calculated) Gal/Bbl/ Kl : 15480 / 387 / 70.4
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
2. Well No / LOC: - NHK#602 / HWV
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
7. Circulation Rate (gpm): 356
8. Bottom up / Cycle Time (Min): 44 / 93
9. Casing landing Time: 11:30pm
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
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: 13.06.2012
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
16. Gauging Water –
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): -
iii) Volume Required (Bbl): 25 iv) Volume Consumed (Bbl): 21
17. Displacement-
i) Volume (calculated) Gal/Bbl/ Kl : 16960 / 424 / 77.17
ii) Time: 38 mins ( 08:48am – 09:26am) iii) Pump used: MP-1+MP-2
18. Plug Caught trailing end at (Strokes): 2800
19. Plug bumped at (Strokes): 4250
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):
i) Calculated: 306 ii) Actual: 389
Tank Dip Measurements:
S/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.
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
23. Volume gained during total operation (Bbl): 117
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
26. Remarks/Observations:
i) Casing was stationary during cementing operation.
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
2. Well No / LOC: - NHK#602 / HWV
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
7. Circulation Rate (gpm): 307
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
13. Pumps for cementation (Rig pump):
i) Pump type: A 1400-PT ii) Liner Size(“): 6 ½”
iii) Gallon per stroke: 3.589 iv) Serviced on: 11.07.2012
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
16. Gauging Water –
i) Formulation: Plain water & 0.01% Defoamer ii) Volume Prepared (Bbl): -
iii) Volume Required (Bbl): 66 iv) Volume Consumed (Bbl): 59
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
19. Plug bumped at (Strokes): 2021
20. Calculated strokes for bumping plug: (100% eff) 1884 Existing Eff: 96%
21. Pump efficiency during cementation (%): 93%
22. Return volume of mud (Bbl): -
i) Calculated: 195 ii) Actual: 296
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 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
23. Volume gained during total operation (Bbl): 127
24. Average cement slurry density (lbs/cft): 118 (Pre-mixed slurry)
25. Return slurry density (lbs/cft): Not applicable
26. Remarks/Observations:
i) Casing was stationary during cementing operation.
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 | 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 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 | 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 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 | 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 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 | 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 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 | 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)
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)
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
Chief Chemist (Drilling) Chemist
For HEAD-CHEMICAL
Tested by: SNS/MB
CHEMICAL DEPARTMENT, DULIAJAN-786602, ASSAM, INDIA (Phone:91-374-2800439, Fax: 91-374-2801680/2800533, Email: [email protected])
CHEMICAL LABORATORY
(ISO 9001:2008 Certified)
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)
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)
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
Chief Chemist (Drilling) Chemist
For HEAD-CHEMICAL
Tested by: SNS/MB
CHEMICAL DEPARTMENT, DULIAJAN-786602, ASSAM, INDIA (Phone:91-374-2800439, Fax: 91-374-2801680/2800533, Email: [email protected])
CHEMICAL LABORATORY
(ISO 9001:2008 Certified)
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)
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)
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
Chief Chemist (Drilling) Chemist
For HEAD-CHEMICAL
Tested by: SNS/MB
CHEMICAL DEPARTMENT, DULIAJAN-786602, ASSAM, INDIA (Phone:91-374-2800439, Fax: 91-374-2801680/2800533, Email: [email protected])
CHEMICAL LABORATORY
(ISO 9001:2008 Certified)
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)