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1. oldal
U N I T C O N V E R S I O N SWritten by Gabor Nemeth
Conversion from metric to Conversion from English to CalculationsEnglish unit metric unit
Metr.symbol Multiply by Eng.name Eng.symbol Multiply by Metr.symbol Metr.quantity Eng.result Eng.quantity Metr.resultmm 0.03937 inches in 25.4 mm 1 0.03937 1 25.4m 3.28084 feet ft 0.3048 m 1 3.28084 1 0.3048m 1.09361 yards yd 0.9144 m 1 1.09361 1 0.9144km 0.621373 miles(land) mile(st) 1.60934 km 1 0.621373 1 1.60934l 0.264178 gallons(US) gal(US) 3.78533 l 1 0.264178 1 3.78533l 0.219976 gallons(UK) gal(UK) 4.54596 l 1 0.219976 1 4.54596l 0.0353147 cubic feet cu.ft 28.3168 l 1 0.0353147 1 28.3168
Write the appropriate quantity into this column, and read the result in the cell close by
I4
Write the appropriate quantity into this column, and read the result in the cell close by
2. oldal
Conversion between metric units Calculations"A" "B" "C" "D" "E" "F"
Metr.symbol Multiply by Metr.symbol Metr.symbol Multiply by Metr. Symbol "A"quantity "C"result "D"quantity "F"resultbar 100 kPa kPa 0.01 bar 1 100 1 0.01bar 0.1 MPa MPa 10 bar 1 0.1 1 10N 0.102 kg kg 9.80665 N 1 0.102 1 9.80665daN 1.02 kg kg 0.980665 daN 1 1.02 1 0.980665N.m 0.102 kg.m kg.m 9.80665 N.m 1 0.102 1 9.80665
1 33.8 1 -17.22222
Conversion between british units Calculations"A" "B" "C" "D" "E" "F"
Eng.symbol Multiply by Eng.symbol Eng.symbol Multiply by Eng.symbol "A"quantiy "C"result "D"quantity "F"resultin 0.0833333 ft ft 12 in 1 0.0833333 1 12ft 0.333333 yd yd 3 ft 1 0.333333 1 3yd 0.0005682 Mile (stat) Mile (stat) 1760 yd 1 0.0005682 1 1760yd 0.0004929 Mile (naut.) Mile (naut.) 2029 yd 1 0.0004929 1 2029sq in 0.0069444 sq ft sq ft 144 sq in 1 0.0069444 1 144sq ft 0.111111 sq yd sq yd 9 sq ft 1 0.111111 1 9sq yd 0.0002066 acre acre 4840 sq yd 1 0.0002066 1 4840acres 0.0015625 sq mile(stat) sq mile(stat) 640 acre 1 0.0015625 1 640cu in 0.0005787 cu ft cu ft 1728 cu in 1 0.0005787 1 1728gal(US) 0.1336777 cu ft cu ft 7.48068 gal(US) 1 0.1336777 1 7.48068cu ft 0.1781113 bbl bbl 5.614467 cu ft 1 0.1781113 1 5.614467gal(US) 0.0238095 bbl bbl 42 gal(US) 1 0.0238095 1 42oz 0.0625 lbs lbs 16 oz 1 0.0625 1 16lb 0.0005 sh. tn sh. tn 2000 lbs 1 0.0005 1 2000gal/ft 0.1336777 cu.ft/ft cu.ft/ft 7.48068 gal/ft 1 0.1336777 1 7.48068cu.ft/ft 0.1781113 bbl/ft bbl/ft 5.614467 cu.ft/ft 1 0.1781113 1 5.614467gal/ft 0.0238095 bbl/ft bbl/ft 42 gal/ft 1 0.0238095 1 42ppg 7.48068 pcf pcf 0.1336777 ppg 1 7.48068 1 0.1336777
1 0 1 01 0 1 01 0 1 01 0 1 01 0 1 0
0C 9/5*0C+32 0F 0F 5/9*(0F-32) 0C
G37
Write the appropriate quantity into this column, and read the result in the cell close by
I37
Write the appropriate quantity into this column, and read the result in the cell close by
G46
Write the appropriate quantity into this column, and read the result in the cell close by
I46
Write the appropriate quantity into this column, and read the result in the cell close by
3. oldal
KICK SHEET / driller's method in metric units /Written by Gabor Nemeth
WELL: DATE:
Well data Mud pump dataHole size 8.5 in Pump Pump1.output Pump2.output
Original mud density cap. 0.0162 0OMD 1490 Present pump output in use 0.0162
Casing shoe data 9 Slow Pump Pressures/SPP/Size 9.625 in 9 pump1. pump2.Yield pres. 47300 kPa 118.42105 15 0 kPa 0 kPaM.depth 1900 m 118.42105 20 0 kPa 0 kPaTV.depth 1900 m 25 0 kPa 0 kPa
Hole depth 30 2800 kPa 0 kPaM.depth 3600 m 35 0 kPa 0 kPaTV.depth 3600 m 40 0 kPa 0 kPaTVD of bit 3600 m Present Slow Pump Pressure and SCRP.of LOT 30 2800 kPaat surface 12000 kPa MW.LOT-Mud weight during test 1240.00
W.o-gradient of mud in testsurface pressure with original mud W.o=MW.LOT * 9,81/1000 12.16 kPa/m
MW.max-maximum mud weight fbd-formation breakdown gradientMW.max=FBD * 1000/(9,81 * TVDcsgshoe) fbd=FBD/TVDcsg.shoe 18.48 kPa/mMW.max 1884 W.1-gradient of original mud
W.1=OMD * 9,81/1000 14.62 kPa/m
Pre-recorded data Pump strokes TimeLength m Volume/pump cap. Pump strs/SPM
Surface line 50 0.009 0.45 28 str. 1 min.DP.1 3340 0.0091 30.39 1876 str. 63 min.DP.2 0 0 0.00 0 str. 0 min.HWDP 0 0 0.00 0 str. 0 min.
260 0.00401 1.04 64 str. 2 min.0 0 0.00 0 str. 0 min.
Drill string volume (surface to bit) 31.89 1968 str. 66 min.OH - without string 0 0.03661 0.00 0 str. 0 min.
260 0.0152 3.95 244 str. 8 min.0 0 0.00 0 str. 0 min.
HWDP-OP.hole 0 0 0.00 0 str. 0 min.DP.1-Op.hole 1440 0.02345 33.77 2084 str. 69 min.Open hole volume (bit to shoe) 37.72 2328 str. 78 min.
0 0 0.00 0 str. 0 min.0 0 0.00 0 str. 0 min.
HWDP-Csg 0 0 0.00 0 str. 0 min.DP.1-Csg 1900 0.02503 47.56 2936 str. 98 min.DP.2-Csg 0 0 0.00 0 str. 0 min.Total ann.volume (bit to surface) 85.28 5264 str. 175 min.Total mud volume in the hole 117.16 7232 str. 241 min.Active surface volume 150.00 9259 str. 309 min.
The driller's method of killing a well kick is accomplished in two circulation cycles. In the first circulation cycle, the influx is circulated out of the hole with original mud by keeping the Pdp on steady. After the annulus is clear of invading fluid, the well is closed in. The mud weight is adjusted to required density. In the second circulation cycle, the original mud is circulated out of the hole with new kill mud. Until the kill mud does not reach the bit, the Pcsg is kept constant. When the kill mud is at the bit, maintain the calculated Final Circulation Pressure, till the kill mud reaches the surface. Disadvantages of the method are the high annulus pressure / in case of gas kick / and the two circulations.
E9
The SCR being half or less of drilling pump rate. Establish it at the: -50% of drilling pump rate, -33% of drilling pump rate, -25% of drilling pump rate, For the following reasons: -Mud velocity in the annulus is reduced to the extent that cuttings are not transported to the surface anymore; this reduces the chance that the chokes get plugged while killing. Annular mud velocity must be less than 15 m/min. -The chokes, wheter adjustable or manual, can operate in the proper orifice range. -It allows the operator more time to react when well killing or mechanical problems develop. -It allows the crew more time to mix the kill mud.
F9
Slow rate circula-tion pressure has to be established: -at the beginning of each shift, -after each BHA changing, -after each mud property changing, -after each mud pump repairing, -after each 100 m drilling.
4. oldal
Total volumetotal volume in hole+active surface volume 267.16 16492 str. 550 min.NOTE: basic data readable data calculated dataKick data
SIDPP-Shut in drill pipe pressure 3500 kPaSICP-Shut in casing pressure 5000 kPaGain-Pit gain 1.80
Fill in ONLY the blue & yellow cells with data and the program will calculate by itself !!!
m3
KMD=OMD+(102 * (SIDPP+SP)/TVD bit kg/m3
(dw x (KMW-OMW))/(dw-KMW) kg/m3
dw-Barite density kg/m3
m3
Infl.at shoe
Infl.at surface
Infl. in air
KM at bit
KM at shoe
KM at surface
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
11000
12000
static and circulating pressure behaviour /metric units/
strokes
pre
ss
ure
/k
Pa
/
E64
It depends on company regulation, but recommended to calculate with the pressure due to Trip Margin
E100
Open choke while bringing up pump speed to slow circulating rate. Increase pump rate slowly and hold Pcsg constant until the pump rate reaches the slow circulating rate and after hold Pdp on steady.
E103
Until this stroke, hold the Pdp on steady by adjustable choke. If kill mud is not ready, circulate with this Pdp and Pcsg until the kill mud gets ready to pump into the hole.
E104
Until this stroke hold the Pcsg on steady by adjustable choke and from now hold the Pdp again on steady till Pcsg becomes to ~zero
5. oldal
NOTE: basic data readable data calculated dataCalculations
P.omd-hidrostatic pressure of the original mudP.omd=(OMD * TVD * 9,81)/1000 52621 kPaP.form-formation pressure P.form=SIDPP+P.omd 56121 kPaH.f-lenght of influx at bottom H.f=G/V.ab 118 mr-ratio between bottom hole and surface volumes r=V.ab/V.as 0.61K-ratio between depth and specific gravity 0.72d1-original mud specific gravity 1.49 kg/lM.A.C.P.-max.annulus casing pressure M.A.C.P.=Yield pres.* 0,80 37840 kPaP.Amax.-max. annulus pressure
8498 kPaH.s-lenght of influx at surface H.s=P.form/P.Amax * (K * r * H.f) 342 mV.gas-volume of influx at surface V.gas=H.s * V.as/1000 8.56Strokes of V.gas Strokes of V.gas=V.gas/pump input 528 str'sD.influx-density of influx D.influx=OMD-((SICP-SIDPP) * 1000/(9,81 * H.f) 199Possible Kick Type Gas
1848 kPa5492 kPa
MAASP+=(OMD-D.influx) * H.s * 0,052 4998 kPaMAASPgs-if the gas reached the surface(MAASPmax.)
12338 kPa1500 kPa
Rgm-gas migration 103 m34272 kPa
1.85Max.pit gain-pit gain when influx reached the surfaceMax.pit gain=0,158984*4*root2(P.form(psi)*G(bbl)*Vas(bbl/ft))/OMW(ppg)) 12
Fill in ONLY the blue & yellow cells with data and the program will calculate by itself !!!
Dp-pressure changing issued from mud density changingDp=((KMD-OMD) * 9,81 * csg.shoe depth)/1000MAASP KMD MAASP KMD=MAASPOMD-delta p.MAAS+-you can increase the MAASP if the gas reached the surface
MAASPgs=MAASPOMD+MAASP+= (MAASPmax.)DSICP- SICP changing based on a certain time.
Rgm=DSICP/W1New Pshoe New Pshoe=((OMW * TVDshoe * 9,81)/1000+SICP+DSICPV1=Volume of mud to be bled off due to New PshoeV1=((Phidr+SIDPP) * Gain)/(Phidr+SIDPP-DSICP) m3
m3
Start Infl.at shoe Infl.at surface Infl. in air KM at bit KM at shoe KM at surface0 2328.3950617284 4735.69667459291 5264.01234567901 7232.32098765432 9560.71604938272 12496.3333333333
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
11000
12000
13000
14000
15000
6300 6300 6300 6300
2986 2986 2986
5000 5000
8498
3500 3500
1548
0
73
40
73
40
12
33
8
73
40
73
40
73
40
54
92
Analysis of driller's method /metric unit/
Pdp
Pcsg
MAASP
strokes
Pre
ss
ure
s /
kP
a/
G118
There are five main possibilities to assamble the drillstring: - DC1-DC2-HWDP-DP1-DP2 - DC1-HWDP-DP1-DP2 - DC1-DC2-DP1-DP2 - DC1-DP1-DP2 - DP1-DP2 Since the DP2 never enters into the open hole, we can leave it out of consideration. The length of influx at bottom depends on the relation of drill-string and bottom hole. It means about thirty-two vari- ations to calculate the length of influx at bottom This program takes all of the main variations into conside-ration.
F120
See on "K" diagram
F128
If density of influx is: - 180 - 360 kg/m3 = gas - 600 - 839 kg/m3 = oil -1030 - 1438 kg/m3 = saltwater
F137
If the procedure is paused for any time(before the influx is circulated above the shoe), the Pcsg will increase due to gas migration. In this case read and record the Pcsg increasing into the cell close by.
F139
IF New Pshoe>FBD, bleed of mud
I144
This diagram is based on the "Expected cir-culation status of driller's method" chart
6. oldal
NOTE: basic data readable data calculated data
Start Infl.at shoe Infl.at surface Infl. in air KM at bit KM at shoe KM at surface0 2328.3950617284 4735.69667459291 5264.01234567901 7232.32098765432 9560.71604938272 12496.3333333333
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
11000
12000
13000
14000
15000
6300 6300 6300 6300
2986 2986 2986
5000 5000
8498
3500 3500
1548
0
73
40
73
40
12
33
8
73
40
73
40
73
40
54
92
Analysis of driller's method /metric unit/
Pdp
Pcsg
MAASP
strokesP
res
su
res
/k
Pa
/
7. oldal
Start Infl.at shoe Infl.at surface Infl. in air KM at bit KM at shoe KM at surface0 2328.3950617284 4735.69667459291 5264.01234567901 7232.32098765432 9560.71604938272 12496.3333333333
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
11000
12000
13000
14000
15000
6300 6300 6300 6300
2986 2986 2986
5000 5000
8498
3500 3500
1548
0
73
40
73
40
12
33
8
73
40
73
40
73
40
54
92
Analysis of driller's method /metric unit/
Pdp
Pcsg
MAASP
strokes
Pre
ss
ure
s /
kP
a/
8. oldal
Start Infl.at shoe Infl.at surface Infl. in air KM at bit KM at shoe KM at surface0 2328.3950617284 4735.69667459291 5264.01234567901 7232.32098765432 9560.71604938272 12496.3333333333
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
11000
12000
13000
14000
15000
6300 6300 6300 6300
2986 2986 2986
5000 5000
8498
3500 3500
1548
0
73
40
73
40
12
33
8
73
40
73
40
73
40
54
92
Analysis of driller's method /metric unit/
Pdp
Pcsg
MAASP
strokes
Pre
ss
ure
s /
kP
a/
9. oldal
KICK SHEET / driller's method in field units /Written by Gabor Nemeth
WELL: DATE:
Well data Mud pump dataHole size 8 1/2 in Pump Pump1.output Pump2.output
Original mud density cap. 0.1019 bbl/str 0.098 bbl/strOMD 12.43 ppg Present pump output in use 0.1019 bbl/str
Casing shoe data 9 Slow Pump Pressures/SPP/Size 9 5/8 in 9 pump1. pump2.Yield pres. 6860 psi 388.5611 15 130 psi 110 psiM.depth 6234 ft 388.5611 20 190 psi 170 psiTV.depth 6234 ft 25 270 psi 240 psi
Hole depth 30 406 psi 350 psiM.depth 11811 ft 35 490 psi 420 psiTV.depth 11811 ft 40 560 psi 500 psiTVD of bit 11811 ft Present Slow Pump Pressure and SCRP.of LOT 30 406 psiat surface 1740 psi MW.LOT-Mud weight during test 10.35 ppg
W.o-gradient of mud in testsurface pressure with original mud W.o=MW.LOT * 0,052 0.54 psi/ft
MW.max-maximum mud weight fbd-formation breakdown gradientMW.max=FBD/(0,052 * TVDcsgshoe) fbd=FBD/TVDcsg.shoe 0.82 psi/ftMW.max 15.72 ppg W.1-gradient of original mud
W.1=OMD * 0,052 0.65 psi/ft
Pre-recorded data Pump strokes TimeLength ft Cap.bbl/ft Vol.bbl Volume/pump cap. Pump strs/SPM
Surface line 164 0.017 2.79 27 str. 1 min.DP.1 10958.01 0.017445 191.16 1876 str. 63 min.DP.2 0 0 0.00 0 str. 0 min.HWDP 0 0 0.00 0 str. 0 min.
853.02 0.007687 6.56 64 str. 2 min.0.00 0 0.00 0 str. 0 min.
Drill string volume (surface to bit) 200.51 1968 str. 66 min.OH - without string 0 0.070187 0.00 0 str. 0 min.
853.02 0.029138 24.86 244 str. 8 min.0.00 0 0.00 0 str. 0 min.
HWDP-OP.hole 0 0 0.00 0 str. 0 min.DP.1-Op.hole 4724.41 0.044954 212.38 2084 str. 69 min.Open hole volume (bit to shoe) 237.24 2328 str. 78 min.
0 0 0.00 0 str. 0 min.0 0 0.00 0 str. 0 min.
HWDP-Csg 0 0 0.00 0 str. 0 min.DP.1-Csg 6233.60 0.047983 299.11 2935 str. 98 min.DP.2-Csg 0 0 0.00 0 str. 0 min.Total ann.volume (bit to surface) 536.34 5263 str. 175 min.Total mud volume in the hole 736.85 7231 str. 241 min.Active surface volume 943.49 9259 str. 309 min.
The driller's method of killing a well kick is accomplished in two circulation cycles. In the first circulation cycle, the influx is circulated out of the hole with original mud by keeping the Pdp on steady. After the annulus is clear of invading fluid, the well is closed in. The mud weight is adjusted to required density. In the second circulation cycle, the original mud is circulated out of the hole with new kill mud. Until the kill mud does not reach the bit, the Pcsg is kept constant. When the kill mud is at the bit, maintain the calculated Final Circulation Pressure, till the kill mud reaches the surface. Disadvantages of the method are the high annulus pressure / in case of gas kick / and the two circulations.
E9
The SCR being half or less of drilling pump rate. Establish it at the: -50% of drilling pump rate, -33% of drilling pump rate, -25% of drilling pump rate, For the following reasons: -Mud velocity in the annulus is reduced to the extent that cuttings are not transported to the surface anymore; this reduces the chance that the chokes get plugged while killing. Annular mud velocity must be less than 50 ft/min. -The chokes, wheter adjustable or manual, can operate in the proper orifice range. -It allows the operator more time to react when well killing or mechanical problems develop. -It allows the crew more time to mix the kill mud.
F9
Slow rate circula-tion pressure has to be established: -at the beginning of each shift, -after each BHA changing, -after each mud property changing, -after each mud pump repairing, -after each 328 ft drilling.
10. oldal
Total volumetotal volume in hole+active surface volume 1680.34 16490 str. 550 min.NOTE: basic data readable data calculated dataKick data
SIDPP-Shut in drill pipe pressure 508 psiSICP-Shut in casing pressure 725 psiGain-Pit gain 11.32 bbl
Open choke while bringing up pump speed to slow circulating rate. Increase pump rate slowly and hold Pcsg constant until the pump rate reaches the slow circulating rate and after hold Pdp on steady.
E103
Until this stroke, hold the Pdp on steady by adjustable choke. If kill mud is not ready, circulate with this Pdp and Pcsg until the kill mud gets ready to pump into the hole.
E104
Until this stroke hold the Pcsg on steady by adjustable choke and from now hold the Pdp again on steady till Pcsg becomes to ~zero
11. oldal
NOTE: basic data readable data calculated dataCalculations
P.omd-hidrostatic pressure of the original mudP.omd=OMD * TVD * 0,052 7637 psiP.form-formation pressure P.form=SIDPP+P.omd 8145 psiH.f-lenght of influx at bottom H.f=G/V.ab 389 ftr-ratio between bottom hole and surface volumes r=V.ab/V.as 0.61K-ratio between depth and specific gravity 0.72d1-original mud specific gravity 1.49 kg/lM.A.C.P.-max.annulus casing pressure M.A.C.P.=Yield pres.* 0,80 5488 psiP.Amax.-max. annulus pressure
1233 psiH.s-lenght of influx at surface H.s=P.form/P.Amax * (K * r * H.f) 1122 ftV.gas-volume of influx at surface V.gas=H.s * V.as 53.84 bblStrokes of V.gas Strokes of V.gas=V.gas/pump input 528 str'sD.influx-density of influx D.influx=OMD-(SICP-SIDPP)/(H.f * 0,052) 1.69 ppgPossible Kick Type Gas
268 psi796 psi
MAASP+=(OMD-D.influx) * H.s * 0,052 726 psiMAASPgs-if the gas reached the surface(MAASPmax.)
1790 psi218 psi
Rgm-gas migration 336 ft4973 psi
12 bblMax.pit gain-pit gain when influx reached the surfaceMax.pit gain=4 * root2((P.form * G * Vas)/OMW) 75 bbl
Fill in ONLY the blue & yellow cells with data and the program will calculate by itself !!!
Dp-pressure changing issued from mud density changingDp=(KMD-OMD) * 0,052 * csg.shoe depthMAASP KMD MAASP KMD=MAASP1-delta p.MAAS+-you can increase the MAASP if the gas reached the surface
MAASPgs=MAASPOMD+MAASP+= (MAASPmax.)DSICP- SICP changing based on a certain time.
Rgm=DSICP/W1New Pshoe New Pshoe=(OMW * TVDshoe * 0,052)+SICP+DSICPV1=Volume of mud to be bled off due to New PshoeV1=((Phidr+SIDPP) * Gain)/(Phidr+SIDPP-DSICP)
Start Infl.at shoe Infl.at surface Infl. in air KM at bit KM at shoe KM at surface0 2328.12931579195 4735.02667590036 5263.42506523258 7231.11531931305 9559.244635105 12494.5403845456
0
200
400
600
800
1000
1200
1400
1600
1800
2000
2200
914 914 914 914
433 433 433
725 725
1233
508 508
225
0
10
64
10
64
17
90
10
64
10
64
10
64
79
6
Analysis of driller's method /field unit/
Pdp
Pcsg
MAASP
strokes
Pre
ss
ure
s /
ps
i/
G118
There are five main possibilities to assamble the drillstring: - DC1-DC2-HWDP-DP1-DP2 - DC1-HWDP-DP1-DP2 - DC1-DC2-DP1-DP2 - DC1-DP1-DP2 - DP1-DP2 Since the DP2 never enters into the open hole, we can leave it out of consideration. The length of influx at bottom depends on the relation of drill-string and bottom hole. It means about thirty-two vari- ations to calculate the length of influx at bottom This program takes all of the main variations into conside-ration.
F120
See on "K" diagram
F128
If density of influx is: -1,5 - 3,0 ppg = gas -5,0 - 7,0 ppg = oil -8,6 - 12 ppg = saltwater
F137
If the procedure is paused for any time(before the influx is circulated above the shoe), the Pcsg will increase due to gas migration. In this case read and record the Pcsg increasing into the cell close by.
F139
IF New Pshoe>FBD, bleed of mud
I144
This diagram is based on the "Expected cir-culation status of driller's method" chart
12. oldal
NOTE: basic data readable data calculated data
Start Infl.at shoe Infl.at surface Infl. in air KM at bit KM at shoe KM at surface0 2328.12931579195 4735.02667590036 5263.42506523258 7231.11531931305 9559.244635105 12494.5403845456
0
200
400
600
800
1000
1200
1400
1600
1800
2000
2200
914 914 914 914
433 433 433
725 725
1233
508 508
225
0
10
64
10
64
17
90
10
64
10
64
10
64
79
6
Analysis of driller's method /field unit/
Pdp
Pcsg
MAASP
strokesP
res
su
res
/p
si/
13. oldal
Start Infl.at shoe Infl.at surface Infl. in air KM at bit KM at shoe KM at surface0 2328.12931579195 4735.02667590036 5263.42506523258 7231.11531931305 9559.244635105 12494.5403845456
0
200
400
600
800
1000
1200
1400
1600
1800
2000
2200
914 914 914 914
433 433 433
725 725
1233
508 508
225
0
10
64
10
64
17
90
10
64
10
64
10
64
79
6
Analysis of driller's method /field unit/
Pdp
Pcsg
MAASP
strokes
Pre
ss
ure
s /
ps
i/
14. oldal
Start Infl.at shoe Infl.at surface Infl. in air KM at bit KM at shoe KM at surface0 2328.12931579195 4735.02667590036 5263.42506523258 7231.11531931305 9559.244635105 12494.5403845456
0
200
400
600
800
1000
1200
1400
1600
1800
2000
2200
914 914 914 914
433 433 433
725 725
1233
508 508
225
0
10
64
10
64
17
90
10
64
10
64
10
64
79
6
Analysis of driller's method /field unit/
Pdp
Pcsg
MAASP
strokes
Pre
ss
ure
s /
ps
i/
Depth Balancing specific gravity Depth Balancing specific gravity
Effect of some different problem on pressures, string weight, pit level, pump rate
Problem Pit level Action to be taken
Choke wash out Decrease Decrease Same Increase Increase
Plugging choke Increase Increase Same Same Decrease
Moderate losses Decrease Decrease Same Decrease Increase
Total losses Decrease Decrease Increase
Drill string wash out Decrease Same Same Same Increase
Drill string twist off Decrease Same Decrease Same Increase
Plugging bit nozzle Increase Same Same Same Decrease
Bit nozzle wash out Decrease Same Same Same Increase
DP pressure
Ann. pressure
String weight
Pump rate /SPM/
Keep Pch cons- tant by pinching
choke. Close in and continue with other
choke
Keep Pch cons- tant by opening
choke. Close in and continue with other
choke
Mix some LCM and reduce circ. pres. with some psi, but
bottom- hole pres.should be
higher than form. pres.
Strong decrease no
returns
Increase, due to less
bouyancy
Try to spot heavy mud of sufficient
weight through the drill string to kill the well from the btm. to the loss
zone. Consi- deration must be given to spotting
Barite or Gunk plugs through the drill string to seal off influx from the
hole
Keep Pch cons- tant and conti- nue
at lower circ. pressure. If not
possible use Volumetric Met-
hod
Keep Pch cons- tant and conti- nue
at higher circ. pressure. If
completely plug- ged, use Volu- metric Method
Keep Pch cons- tant and conti- nue
at lower circ. pressure. If not
possible use Volumetric Method
Pump failure Decrease Decrease Same Same Increase
Keep Pch cons- tant, observe circ. Pressure. Close in
and start other pump
21. oldal
LEAK OFF TESTWritten by Gabor Nemeth
Preparations
1. Drill out the casing shoe. / be sure, there is no flapper valve in the string !/2. Drill ahead 5-50 ft; (1.5-15 m.) / it depends on company regulation /.3. Circulate for conditioning mud in the hole. /no cuttings in the mud !/4. Get ready a cementing pump with a sensitive pressure gauge.5. Calculate the pressure loss due to gel strength of mud.6. Pull the string above the casing shoe.Data Metric unit Field unitL = length of string 3054.6 m 9000 ft
10 10d = DP ID 3 3/16 in 3 3/16 in
0 in 8 1/2 in0 in 5 in
2480 m 9000 ftTMW = mud weight during LOT 1280 10.35 ppg
Calculations of pressure losses
Formula to be used, when LOT is performed through DP
94 psi723 kPa
Formola to be used, when LOT is performed on annulus
86 psi0 kPa
Procedure
1. Fill up cementing line & bell nipple with mud by cementing pump and stop pump.2. Close BOP / bag type or pipe rams /3. Start cementing pump slowly and as soon as pressure starts to show on the gauge,
4. Wait some 3 minutes and plot pressure versus volume.
the graph.6. Continue this way until the pressure increase becomes less than the previous increase i.e. the line on the graph starts bending to the right. This point is the leak off point and gives the value for the MAASP.
off has now started and the pressure reached is the formation break down pressure.8. Bleed-off pressure, check returns and very carefully repeat pressure building up to get a check on the result.
Leak off point pressure (read on graph and write here) 18800 kPa
18077 kPa
PLOT=MAASP. MAASP has to be recalculated for the appropriate mud weight.
MAASPnew mud=MAASP-((NewMW-TMW) x 0,052 x TVDcsg.shoe)
Vol. m3
Calculation of real Leak Off Pressure /PLOT/
PLOT= Leak off point pressure (read on graph) - pressure loss due to gel strenght
PLOT when LOT is performed through DP
0 1 2 3 4 5 6 7 8 9
10
11
12
13
14
15
16
17
18
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
11000
12000
13000
14000
15000
16000
17000
18000
19000
20000
21000
22000
23000
24000
351
6
703
2
105
48
140
64
177
88
181
33
179
26
165
47
159
96
157
20
155
82
155
13
154
78
154
44
154
44
154
44
154
44
154
44
Leak Off Test
Time /min/
Pre
ssu
re /
kPa/
24. oldal
0 kPa
Real leak off pressure determines the Maximum Allowable Annulus Surface Pressure.
New Mud Weight /NewMW/ ( write here ) 1170
20754 kPa
PLOT when LOT is performed on annulus
PLOT=MAASP. MAASP has to be recalculated for the appropriate mud weight.
kg/m3
MAASPnew mud- MAASP with new mud weightMAASPnew mud=MAASP-(((NewMW-TMW) x 9,81 x TVDcsg.shoe)/1000)
Volumetric StrippingWritten by Vilmos Barka
Procedure: 1. Closing in the well. Determine the influx volume.Record pressure at two minute intervals. After closed-in pressures have stabilized complete strip sheet. Further record pressures at five minute intervals or after running in each stand. 2. Determine the volume of mud in the OH/DC annulus equivalent to one psi of hydrostatic head. Equivalent volume per psi = Ann. Volume per ft / Mud gradient ( bbl/psi ) 3. Determine a convenient working pressure increment PW. 4. Convert a selected working pressure PW /psi/ into an equivalent working
5. Determine the extra back pressure. 6. Adjust the closing pressure on the annular preventer to a minimum, avoid leakage. 7. Allow annulus pressure to build up to Pchoke whilst stripping the first stand. Pchoke = P an. + PS +PW P an > initial closed-in annulus pressure before second built up PS > allowance for the loss of hydrostatic head as DC enter the influx PW > working pressure increment 8. Maintain Pchoke constant whilst stripping pipe. Closed-end displacement of drillpipe is purged into the trip and stripping tank. 9. Avoid excessive surge pressure.
has accumulated into the trip tank.
tank at constant choke pressure, Pchoke is allowed increase again by the value PW now becomes Pchoke (where Pchoke 1 = Pchoke + PW )12.Fill each stand and remove any sharp edges or tong marks from the pipe body.13.By repeating this cycle is maintained nearly constant BHP14. Any data should be record 15.On bottom the well can be kill using the " driller's method ". Be sure the string is full of mud. Pump slow rate from the bit to the Gray-valve. Stop pump, check trapped pressure and then continue circulation.16.To avoid differential sticking consider moving the string trough the preventer.
Closed-end Displacement of DP Stand:Average stand length 94 ft
DP C/E displacement 2.38 bbl/stand
F factor calculation:F = F= ( 1 / OH cap.) X ( p1 - pi ) X ((Ohcap / [OH/DC ann.cap] ) - 1 ) 12.5 psi/bbl
mud gradient (p1): 0.78 psi/ft
Calculation of the volume in the OH/DC ann. equivalent to the selected loss of hydrostatic pressure. For one psi loss of hydrostatic pressure we calculate the volume.
OH/DC ann.vol. per ft. / mud gradient 0.04 bbl/psi
Equivalent volume of the selected Pw increment 1.55 bbl
The volume per inch in the trip tank 0.12 bbl/inch 0.24 bbl/in
The selected Pw /psi/ increment is equivalent 13 inch 6 1/2 in
Calculations for Pchoke :
Pchoke = Pchoke = Pan + Ps + Pw 339 psi
Ps = Ps = Inf.vol. / OH cap. X (p1-pi) X (( OH cap /[OH/ DCann. Cap]) - 119 psi
Ps = Ps = F x influx volume ( bbls ) 119 psi
Pan > initial close-in pressure before 2nd build-up. Reading from Ann. press. gauge.
Ps > allowance for the loss of hydrostatic head as DC enter the influx.
Pw > selected, set for yourself. ( recommended 40-50 psi )
F > derived factor
Procedure:1, Allow Pan to become Pchoke Pchoke= Pann + Ps + Pw 339 psi
2, After running each stand bleed-off into the stripping tank 2.38 bbl
19 8/9 in 10 in3, When the level in the trip tank increases 6 1/2 in, increase Pchoke 40 psi
13 in, increase Pchoke 40 psi
4, Repeat this cycle until bit is on bottom.
Equivalent Working Volume for Volumetric Steps D V:
DV =
D V > triptank level increase per Pw step
Strip Sheet
Pchoke= Pchoke = Pann +Ps +Pw 339 psi
P annulus 180 psi
F-factor 12.5 psi/bbl
Volume Influx 9.5 bbls
Ps = Ps = F x Vi 119 psi
Pw selected 40 psi
in (cm)
Time Stand no. Pchoke T.T.level Remarks Triptank level with req. Pchoke
T.T. -level Pch
DV= division in triptank
Written by Vilmos Barka
Measured depth 0 m DC C/E cap.:
Csg. Measured depth 0 m Open hole capacity: 0.03552
Total length of DP 2875.2 m OH/DC ann volume: 0.01575
Number of DP stand 100 mud weight: 1797
DP closed-end cap.: 0.01314 Influx volume: 1.51
DP capacity: 0 Pressure annulus: 1241 Kpa
DP metal cap.: 0 Pressure drillpipe: 0 Kpa
29.02 kg/m 276 Kpa
158.75 mm influx gradient (pi) : 2.26 Kpa/m
Cylindrical Tank Rectangle Tank
Dia (m ) H ( m ) W (m) L ( m ) H ( m )
Dimensions of trip tank: 0.975 2.44 1.22 1.22 2.44
Dimensions of strip tank: 0.975 2.44 1.22 1.22 1.22
Pre Kick Information (to be record on standard kill sheet ) !
Calculation of Wellbore force ( WBF )
WBF= WBF = ((ODtj)^2 x p/4 x Pann x 1,02)+ Ffr 2959 kg
454 kg
Hence: Minimum necessery weight of string to perform the procedure 2959 kg
Closed-end Displacement of DP Stand:Average stand length 28.75 m
DP C/E displacement 0.378
F factor calculation:F = F= ( 1 / OH cap.) X ( p1 - pi ) X ((Ohcap / [OH/DC ann.cap] ) - 1 ) 543
mud gradient (p1): 17.63 Kpa/m
Calculation of the volume in the OH/DC ann. equivalent to the selected loss of hydrostatic pressure. For one psi loss of hydrostatic pressure we calculate the volume.
OH/DC ann.vol. per m / mud gradient 0.00089
Equivalent volume of the selected Pw increment 0.246
The volume per cm in the trip tank 7.46 l/cm 14.86 l/cm
The selected Pw /Kpa/ increment is equivalent 33 cm 16.6 cm
Calculations for Pchoke :
Pchoke = Pchoke = Pan + Ps + Pw 2337 Kpa
Ps = Ps = Inf.vol. / OH cap. X (p1-pi) X (( OH cap /[OH/ DCann. Cap]) - 820 Kpa
Ps = Ps = F x influx volume ( m3 ) 820 Kpa
Pan > initial close-in pressure before 2nd build-up. Reading from Ann. press. gauge.
Ps > allowance for the loss of hydrostatic head as DC enter the influx.
Pw > selected, set for yourself. ( recommended 300 Kpa )
F > derived factor
Procedure:1, Allow Pan to become Pchoke Pchoke= Pann + Ps + Pw 2337 Kpa
2, After running each stand bleed-off into the stripping tank 0.38
50.6 cm 25.4 cm3, When the level in the trip tank increases 16.6 cm, increase Pchoke 276 Kpa
33 cm, increase Pchoke 276 Kpa
4, Repeat this cycle until bit is on bottom.
m3/stand
Kpa/m3
Equivalent Working Volume for Volumetric Steps D V:
DV = m3/Kpa
m3
D V > triptank level increase per Pw step
m3
Strip Sheet
Pchoke= Pchoke = Pann +Ps +Pw 2337 Kpa
P annulus 1241 Kpa
F-factor 543
Volume Influx 1.51
Ps = Ps = F x Vi 820 Kpa
Pw selected 276 Kpa
cm
Time Stand no. Pchoke T.T.level Remarks Triptank level with req. Pchoke
T.T. -level Pch
Kpa/m3
m3
DV= division in triptank
35. oldal
General data
Open hole capacitysize in " cap.in l/m cap.in bbl/m cap.in bbl/ft
26 342.5 2.1543 0.65716 129.72 0.816 0.249
12 1/4 76.04 0.4783 0.1468 1/2 36.61 0.2303 0.07
6 18.24 0.1147 0.035
Capacity of csg.size in " weight in lb/ft cap.in l/m cap.in bbl/m cap.in bbl/ft
L1=the deepest depth of the operation in meter 3600 mL2=the beginning of the operation in meter 3580 ml =length of a stand in meter 28.6 m
260 m100 m
0 mReal weight of bit, stabilizer, drilling jar, pony DC, etc. in kg 1300 kgDC 1 real weight in kg/m 242 kg/mDC 2 real weight in kg/m 214.8 kg/mHWDP real weight in kg/m 73.4 kg/mDP 1 real weight (or tbg., or csg.) in kg/m 29.02 kg/m
1900 mDP 2 real weight (or tbg., or csg.) in kg/m 23.1 kg/m
1320 mMud density in kg/l 1.49 kg/lP=total weight of travelling block-elevator assembly in kg 8000 kgp=weight of DP with tool joints(accounting for buoyancy) in kg/m 21.53 kg/md=additional weight due to BHA(DC,HWDP,bit etc.)(accounting for buoyancy) kg 69433 kgBUOYANCY FACTOR k=1-(Mud density/Steel density) 0.810
DC 1 apparent weight = DC 1 real weight-Buoyancy DC 1 196.07 kg/mDC 2 apparent weight = DC 2 real weight-Buoyancy DC 2 174.03 kg/mHWDP apparent weight = HWDP real weight-Buoyancy HWDP 59.47 kg/mDP 1 apparent weight = DP 1 real weight-Buoyancy DP 1 23.51 kg/mDP 2 apparent weight = DP 2 real weight-Buoyancy DP 2 18.69 kg/mBit, stabilizer, drilling jar, pony DC, etc. apparent weight 1053.25 kgBuoyancy DC 1 = (DC 1 real weight*Mud density)/Steel density 45.93 kg/mBuoyancy DC 2 = (DC 2 real weight*Mud density)/Steel density 40.77 kg/mBuoyancy HWDP= HWDP real weight*Mud density/Steel density 13.93 kg/mBuoyancy DP 1 = (DP 1 real weight*Mud density)/Steel density 5.51 kg/mBuoyancy DP 2 = (DP 2 real weight*Mud density)/Steel density 4.38 kg/m
H E N C E :Apparent weight = Real weight x ((Steel density - Mud density) / Steel density)
Type of operation: pooh Tm=(0,981*(p*L*(L+l)+4*L897 890
Write the type of operation into this cell, from the follows: -Round trip -POOH -RIH -Short trip -Drilling 1 /to depth L1 / -Drilling 2 /from depth L2 to depth L1/ -Reaming -Coring -Running casing /take the note into consideration/; and the program will caculate by itself
B55
In this case: l = average length of csg /m/ p = average weight of csg /kg/m/(accounting for buoyance) d ="0"
Fill
in O
NL
Y t
his
se
cti
on
wit
h d
ata
11811 ft11745 ft
L =length of a stand in feet 93.83 ft853 ft328 ft
0 ftReal weight of bit, stabilizer, drilling jar, pony DC, etc. in lbs 2866 lbsLength of bit, stabilizer, drilling jar, pony DC, etc. in feet 10 ftDC 1 real weight in lb/ft 162.89 lb/ftDC 2 real weight in lb/ft 144.34 lb/ftHWDP real weight in lb/ft 49.32 lb/ftDP 1 real weight (or tbg., or csg.) in lb/ft 19.5 lb/ft
6234 ftDP 2 real weight (or tbg., or csg.) in lb/ft 15.5 lb/ft
4320 ftMud density in ppg 12.43 ppgM=total weight of travelling block-elevator assembly in lbs 17637 lbsW = Bouyed weight of drill pipe in lb/ft 14.47 lb/ft
DC 1 apparent weight = DC 1 real weight-Buoyancy DC 1 131.98 lb/ftDC 2 apparent weight = DC 2 real weight-Buoyancy DC 2 116.95 lb/ftHWDP apparent weight = HWDP real weight-Buoyancy HWDP 39.96 lb/ftDP 1 apparent weight = DP 1 real weight-Buoyancy DP 1 15.80 lb/ftDP 2 apparent weight = DP 2 real weight-Buoyancy DP 2 12.56 lb/ftBit, stabilizer, drilling jar, pony DC, etc. apparent weight 2322.20 lbsBuoyancy DC 1 = (DC 1 real weight*Mud density)/Steel density 30.91 lb/ftBuoyancy DC 2 = (DC 2 real weight*Mud density)/Steel density 27.39 lb/ftBuoyancy HWDP= HWDP real weight*Mud density/Steel density 9.36 lb/ftBuoyancy DP 1 = (DP 1 real weight*Mud density)/Steel density 3.70 lb/ftBuoyancy DP 2 = (DP 2 real weight*Mud density)/Steel density 2.94 lb/ft
H E N C E :Apparent weight = Real weight x ((Steel density - Mud density) / Steel density)
Type of operation: pooh TM=((D*(L+D)*W/1056000623 618
1. Round trip tonmiles
2. POOH 311 tonmiles
3. RIH tonmiles
4. Short trip tonmiles
5. Drilling 1 tonmiles
6. Drilling 2 tonmiles
7. Reaming tonmiles
8. Coring tonmiles
9. Running casing tonmiles
N O T E :
S t e e l d e n s i t y : 65.51 ppg
WORK DONE BY A DRILLING LINE /field units/D1=the deepest depth of the operation in feetD2=the beginning of the operation in feet
LDC 1=length of DC in feetLDC 2=length of DC in feetLHWDP=length of HWDP in feet
LDP 1=length of DP 1 in feet
LDP 2=length of DP 2 in feet
C = Bouyed weight of BHA minus bouyed weight of equal length DP in lbs
Tm1 Tm2
D94
Write the type of operation into this cell, from the follows: -Round trip -POOH -RIH -Short trip -Drilling 1 /to depth L1 / -Drilling 2 /from depth L2 to depth L1/ -Reaming -Coring -Running casing /take the note into consideration/; and the program will caculate by itself
B113
In this case: L = average length of csg /ft/ W = average weight of csg /lb/ft/(accounting for buoyance) C ="0"
PROCEDURE FOR SLIP & CUT DRILLING LINE PROGRAMME
INTRODUCTION
This procedure has issued as a guidline for slip and cut drilling line programme
RIG BASIC DATA
Mast Drilling Line Drawworks Drum
Capacity Height tons Type Breaking load Type Cap. Type OD "
14 mlbs 142 ft 500
in tons14 Plain Grooved 30
75.7
1.09 3.34173CUT OFF LENGTH IN NUMBER OF DRUM LAPS FOR DRILLING LINE ( as per API RP 9B )
X laps + 1/2 lap for counterbalanced grooved drum = 11 1/2 laps
Conversion of laps to length is
90.32 ft 27.53 m
Fast line tension = Hook load/(Number of line x Reeving efficiency) 64.22 tons
Safety factor ( S.F. ) is equal S.F. = Breaking load / Fast line tension 1.18
Ton- Miles per foot cut when operating at safety factor 5 is 20, for full cut - off length
20 * 90,32' = 1806 ton-miles
This is a good drilling practice to slip three times between cut - off.
THE GOOD PROCEDURE IS
Hook load No. of
line
Type of
bear- rings
1 3/8 6 x 19 IPS, IWRC
Midco U914
1400 HP
p * OD/12 * No.of drum laps
ta= F/(N x hm)
Reeving efficiency (hm)=(Friction factor/depending on type of bearrings/ to the number of line th power) - 1
Number of line x (Friction factor -1) x (Friction factor to the number of line th power)
Slip drilling line 9 m after every 602 ton - miles / 862 Tkm /
Cut - off drilling line 27 m after every 1806 ton - miles / 2586 Tkm /
K15
Write here: either -Plain or -Roller depending on the type of bearrings
I21
Read the data from the Drilling Data Handbook page 271 chart
Rig No. Drilling line work report Units : Tons, meters, Tkm
Determination of the length of free pipe in a stuck stringWritten by Gabor Nemeth
Data Metric Unit Field Unit25.05 kg/m 16.83 lb/ft31.83 kg/m 21.39 lb/ft
HWDP real weight 73.4 kg/m 49.32 lb/ft149.8 kg/m 100.66 lb/ft123.9 kg/m 83.26 lb/ft1000 m 3281 ft1500 m 4921 ft
HWDP length 300 m 984 ft150 m 492 ft100 m 328 ft
Mud density 1.4 kg/l 11.68 ppg141.2 317430 lbs
Distance between the two datum lines / l / 300 mm 11 4/5 inches
Procedures
1. Calculate the maximum pull on drill pipe.2. Calculate the weight of the drill string in mud.3. Calculate the allowable pull margin.
should be approximately the weight of drill string in mud + 30 % of the pull margin. Draw a mark at the kelly-bushing level. Pull on approximately 2-6 tons / 4400-13200 lbs/ more than before and return to the previous weight. Draw a second mark at the kelly- bushing level. This second mark should be distinct from the first caused by friction of drill pipe in the hole. Draw a datum line midway between these two marks.
drill string in mud + 65 % of the pull margin. Draw a mark at the kelly-bushing level.
the previous weight. Draw a second mark as before and draw a datum line midway between these two marks.6. Measure the distance / l / in mm or inches between the two datum lines.7. Calculate the length of free pipe.
Calculation of max. pull on drill pipe 130 tons 285687 lbs
Calculation of weight of drill string in mud 107 tons 234880 lbs
Calculation of the allowable pull margin 23 tons 50807 lbs
113 tons 250122 lbs
122 tons 267905 lbs
Calculation of the length of free pipe 2538 m 8337 ft
Weight of travelling block, hook etc. 8 tons 17637 lbs1000 m 3281 ft1500 m 4921 ft
HWDP length 300 m 984 ft150 m 492 ft100 m 328 ft
Mud density 1.4 kg/l 11.68 ppgDepth of stuck point 3384 m 11117 ftDepth of back-off 2500 m 8202 ftTool joint matting surface area 21.93 3.4
141.2 317430 lbsMax torsional limit for 1000 m DP 12 1/2 turns/1000 m 12 1/2 turns/3281 ft
Procedures
1. Before any back-off, determine the depth of stuck point. Decide the depth of back-off.2. Make up the drill string to 80% of the torsional limit of the drill pipe in tension ( weight of drill string in mud ). Read the torsional limit in the "Drilling Data Handbook" K21-K24 chart, and multiply by the back-off depth/1000 m ( back-off depth/3280,84 ft ). Make-up the drill string to the right.3. Set the neutral point at the depth of back-off. The weight indicator should show the cal- culated tension.4. Apply leftward twist amounting to 80% of the rightward twist used to make-up the string.
Calculation of weight of drill string in mud 107 tons 234880 lbs
80% of max. torsional limit at back-off depth in tension 25 right turns 25 right turns
Hydrostatic pressure at the depth of back-off 34335 kPa 4982 psi
Weight in mud of free length of drill pipe + block 68 tons 149504 lbs
Weight indicator tension at neutral point 75 tons 166446 lbs
80% of rightward turns for applying leftward twist 20 left turns 20 left turns