1531 colibasi h th1 en rev 2
TRANSCRIPT
OMV PETROM
Well Name Numele Sondei 1531 Colibasi
Well Type Tipul Sondei Production
Asset Zona de Producţie Asset III ndash Muntenia Vest
Consulting Company Compania de Proiectare
Manager(only for the wells designed outside
Petrom)
Prepared by Proiectat de
Well Engineering Aurel ENACHE 05032012
GeologyGeologie Dorina LUCHIAN 05032012
Drilling FluidsFluide de Foraj Tudorel DIŢU 05032012
CementingCimentare Dumitru GEORGESCU 05032012
CostsCosturi Marinella-Daniella ALEXANDRESCU
05032012
Checked by Verificat de
Well Engineering Marian Dinu 05032012
Well Owner(Reservoir Exploration) Mihai Obreajan 05032012
Well Delivery Manager Marian DINU 05032012
Approval Aprobat
Head of Well Engineering Leo MAEKIAHO
Distribution Company Man (1)Field Cluster (1)Asset (1)Drilling Engineering amp Operations (1)Drilling Contractor (1)
TABLE OF CONTENTS
Pag 1
OMV PETROM
Chapter NAME Pag
GENERAL INFORMATIONS 3
DRILLING PROGRAM 4
1 DRILLING WELL DATA 4
2 EXECUTIVE SUMMARY 5
3 GEOLOGICAL CONDITIONS 7
4 CASING PROGRAM 10
5 DIRECTIONAL PROGRAM 12
6 DRILL STRING 16
7 MUD PROGRAM 18
8 BIT amp HIDRAULICS PROGRAM 19
9 LOGGING PROGRAM 20
10 CEMENTING PROGRAM 21
11 WELLHEAD AND BOP CONFIGURATION 24
12 RISK ASSESSMENT OFFSET WELLS REVIEW 25
13 SEQUENCE OF OPERATIONS 28
14 WELL MONTAGE 31
15 APPENDICES 32
Appendix 1 Drill Well On Paper
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional program
Appendix 4 BHArsquos and Hydraulics Summary
GENERAL INFORMATIONS
1 Well 1531 Colibasi
2 Structure Colibasi (Ag)
3 Type Gas Production
4 Depth 1594 m MD (1155 m TVD)Pag 2
OMV PETROM
5 Casing program (MD)
20 in x 2365 m RT hammered
958 in x 400 m MD TOC = 0 m
7 in x 1365 m MD TOC = 0 m
L 412 in x (1335-1599 m MD)
6
Drilling Rig
- maxim hook
- normal hook
MR 8000
200 t
113 t
7 Estimated drilling time 207 days
8 Owner OMV PETROM SA ndash ASSET III
9 Designer OMV PETROM SA ndash Well Engineering ndash Well Delivery Team 2
DRILLING PROGRAM
1 DRILLING WELL DATA
Well type Gas ProductionObjective Pontian 1Depth 1599m MD (1155m TVD) Drilling Rig MR 8000Surface coordinates N = 38472867 m
E = 48697239 m
Pag 3
OMV PETROM
Z (ground level)= 36483 m TVDRTZ (RT) = 37024 m TVDRT
Target coordinates- Top of target N = 38465001 m E = 4873089 m
Z = 114858 m TVD RT (77858 m TVDSS)
- End of target N = 38459677m E = 48753664 m
Z = 115527 m TVD RT (78527 TVDSS)
Horizontal displacement to top of target 34466 m10316ordm at 1365 m MD114858 m TVDRT
Horizontal displacement to TD 57793 m10316ordm at 1599 m MD115527m TVDRT
Geological limits - Dacian Pontian = 970 m TVD 974 m MD- Top Pontian 1 = 1145 m TVD 1313 m MD
Well construction ndash conductor 20 in x 2365 m RT hammered ndash surface casing 958 in x 400 m MD TOC = 0 m ndash production casing 7 in x 1365 m MD TOC = 0 m ndash production liner 412 in x (1599 ndash 1335 m) ndash sloted liner with 194 micron screen
NoteFor avoiding mud losses while drilling surface formations itrsquos recommended to
drill the first 60 m with reduced drilling parameters (low flowrate and ROP with big nozzles at bit) and using high viscosity mud (100-120 sec)
The 9-58 in surface casing shoe will be placed in a marly zone
2 EXECUTIVE SUMMARY
9 58rdquo Surface Casing Section
Section 0 ndash 400mFormations DacianMud Spud mud MW=1050-1150kgm3
For avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50-60 m with low flowrate and high viscosity mud (100-120 sec)
Traject Vertical Directional survey using TOTCOBHA Rigid BHA with 3 stabilizers
Pag 4
OMV PETROM
Bits amp hidraulics
12 frac14rdquo Roller bitWOB=8-14t RPM=110-120 Flow rate=40-45 lsFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50-60 m with reduced ROP and using bit with big nozzles
Logging GR in cased hole at total depthCasing 9 58rdquo 360 lbft (894 mm) J55 LC
TOC - surface
7rdquo Intermediate Production Casing Section
Section 400 ndash 1365 m MDFormations Dacian PontianMud NAF MW=1100-1150 (1200) kgm3
Mud weight will be increased only in case of hole instability or high gas influx
Traject Vertical using PDM to KOP-853 mBuild trajectory with about 6ordm30m to 85ordm inclination on 10316ordm azimuth till EOC- 1284 m MD ( 1143 m TVDRT) using PDM and LWDHold tangent at 85ordm inclination and 10316ordm azimuth to 1335 m MD (1147 m TVDRT) about 2 m bellow expected Top of P1 using PDM and LWDIncrease inclination angle till 89ordm on 10316ordm azimuth till 1365 m MD (11486 m TVDRT) ndash depth of 7rdquo casing shoe ndash about 35 m bellow Top of P1
BHA PDM + MWD+ LWD 8 frac34rdquo PDC bitBits amp hidraulics
8 34rdquo PDC bitWOB=4-10t RPM=40-60+PDM Flow rate=30-33lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res recorded with LWDCasing 7rdquo 260 lbft (919 mm) Extreme Line N80 J 55
TOC - surface
4 12rdquo Production Casing Section
Section 1365 ndash 1599 m MDFormations PontianMud NAF MW=1100-1150 (1200) kgm3
Mud weight will be increased only in case of hole instability or high gas influx
Traject Hold inclination angle at 89ordm on 10316ordm azimuth till 1499 m MD (115092 m TVDRT) using RSS and MWDLWDDecrease inclination angle till 87ordm at 1545 m MD (115245 m TVDRT) on 10316ordm azimuth due to dropping of P1 layerHold tangent at 87ordm inclination and 10316ordm azimuth to 1599 m MD (115527 m TVDRT) final TD using PDM and LWD
BHA PDM + MWD+ LWD 6 18rdquo roller bitBits amp 6 18rdquo roller bit
Pag 5
OMV PETROM
hidraulics WOB= 6-12t RPM=40-60+PDM Flow rate=15-17 lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res Sonic recorded with LWDCasing 4 12rdquo 135 lbft (737 mm) TSH Blue L 80 ndash slotted liner with premium
screen from HP with 194 micron screen and swell packers
3 GEOLOGICAL CONDITIONS
31 Offset wells
The Colibasi structure is located in Arges county at about 10 km North of the town of Pitesti From geological point of wiev it can be included in the Babeni-Sapunari-Merisani-Colibasi-Dobresti structure belongs to internal flank of Getic Depresion
The reservoirs in Colibasi field are Helvetian - Burdigalian (oil and free gas) Pontian and Oligocen (free gas)
From tectonical point of view the Colibasi field is an failed anticlineThe 1531 Colibasi well is a development well and is planned to be drilled horisontal to
develop hydrocarbons (free gas) from Pontian 1 and the projected final depth of the well will be 1155 m TVD (approximately 1599 m MD)
The well 1531 Colibasi has been proposed to be drilled in the ldquoReservoir Study for the commercial gas field Colibasi (Arges)rdquo issued in 2009 approved by OMV Petrom and confirmed by the National Agency for Mineral Resources
Pag 6
OMV PETROM
The geological condition it was determined used informations from following offset wells 1516 (drilled in 1997) 1590 (drilled in 1995) and 3019 (drilled in 1970)
-860
-785
-790
- 810
-795
-845
-850
-855
1501
1502
1514
1516
1530
1545
1546
1547
15481560
1580
1585
1590
1595
3000
3019
32
3225
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
-78377-77335
790800
810820
830840
850860
870
886
781SSTVD
1381
Co py o f 1 502 Co l iba s i - frag m en t CEjp gCo py o f 1 502 Co l iba s i - frag m en t CEjp g1502 [SSTVD]
485000 486000 487000 488000 489000 490000
485000 486000 487000 488000 489000 490000
383000384000
385000386000
3830
0038
4000
3850
0038
6000
0 100 200 300 400 500m
115000
-885-880-875-870-865-860-855-850-845-840-835-830-825-820-815-810-805-800-795-790-785-780-775
Depth
PETROM SA
COLIBASI - Ag
Top PONTIAN 1 STRUCTURAL MAP
Scale 115000 Designed by Iordache Claudiu
RM Asset III IVV IX
Pontian 1
Pontian 2
32 Lito-stratigraphic and structural conditions
Levantin and Dacian will be found between 0 and aprox 970 m TVD (973 m MD) It develops in predominantly sandy facies with intercalation of gravel sandstone marl sandy clay and thin beds of coal passing in the lower part in shally facies
Pontian is estimated between about 970ndash1155 m TVD (973ndash1599 m MD) Predominant facies is shally facies (made from marls and shales)
In base of Pontian (1145 m TVD 1313 m MD) there is a thin sandy layer named Pontian1 consisted of a 10 m poor consolidated sands
Pag 7
OMV PETROM
1531_3_5
-78911
-80600
-78377
-77335
-830
-845
-855
1516
1585
1590
3019
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
Top_P1
Base_best_zone
Top_P2
Base_P2Top_Helvet
Helvet_marker
790
800
810
820
830
840
850
860
870
880
890
900
912
776SSTVD
1492Copy of 1502 Colibasi - fragment CEjpgCopy of 1502 Colibasi - fragment CEjpg
Top_P1
Top_P2
Top_Helvet Helvet_marker
Base_P2
Base_best_zone
1502 [SSTVD]
Top_P1
Base_best_zone
Top_P2
Base_P2Top_HelvetHelvet_marker
486000 487000
486000 487000
384000385000
3840
0038
5000
Actual GWC - 806m
33 Contaminants for drilling fluid
Lithological column analysis proposed to be traversed by the well 1531 Colibasi reveals the presence of thin layers of coals in Dacian like specific contaminants on drilling fluid However should that possibility predominantly clay-shale sequences (especially
Pag 8
OMV PETROM
those in Pontian and Meoţian) to disperse the drilling fluid with solid and uploading those negatively affecting rheological properties
Geological formation Pressure gradients ndash estimated (at10 m)
Fracture gradients ndash estimated (at10 m)
Levantin + Dacian 100 ndash 101 135 ndash 165Pontian 102 169 ndash 172Pontian 1 (reservoir) 08 ndash 09 165 ndash 167
As Geothermal gradient is around 35 ndash 360 C100 m (aprox 410 C on the final depth)
Pag 9
OMV PETROM
Pag 10
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Chapter NAME Pag
GENERAL INFORMATIONS 3
DRILLING PROGRAM 4
1 DRILLING WELL DATA 4
2 EXECUTIVE SUMMARY 5
3 GEOLOGICAL CONDITIONS 7
4 CASING PROGRAM 10
5 DIRECTIONAL PROGRAM 12
6 DRILL STRING 16
7 MUD PROGRAM 18
8 BIT amp HIDRAULICS PROGRAM 19
9 LOGGING PROGRAM 20
10 CEMENTING PROGRAM 21
11 WELLHEAD AND BOP CONFIGURATION 24
12 RISK ASSESSMENT OFFSET WELLS REVIEW 25
13 SEQUENCE OF OPERATIONS 28
14 WELL MONTAGE 31
15 APPENDICES 32
Appendix 1 Drill Well On Paper
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional program
Appendix 4 BHArsquos and Hydraulics Summary
GENERAL INFORMATIONS
1 Well 1531 Colibasi
2 Structure Colibasi (Ag)
3 Type Gas Production
4 Depth 1594 m MD (1155 m TVD)Pag 2
OMV PETROM
5 Casing program (MD)
20 in x 2365 m RT hammered
958 in x 400 m MD TOC = 0 m
7 in x 1365 m MD TOC = 0 m
L 412 in x (1335-1599 m MD)
6
Drilling Rig
- maxim hook
- normal hook
MR 8000
200 t
113 t
7 Estimated drilling time 207 days
8 Owner OMV PETROM SA ndash ASSET III
9 Designer OMV PETROM SA ndash Well Engineering ndash Well Delivery Team 2
DRILLING PROGRAM
1 DRILLING WELL DATA
Well type Gas ProductionObjective Pontian 1Depth 1599m MD (1155m TVD) Drilling Rig MR 8000Surface coordinates N = 38472867 m
E = 48697239 m
Pag 3
OMV PETROM
Z (ground level)= 36483 m TVDRTZ (RT) = 37024 m TVDRT
Target coordinates- Top of target N = 38465001 m E = 4873089 m
Z = 114858 m TVD RT (77858 m TVDSS)
- End of target N = 38459677m E = 48753664 m
Z = 115527 m TVD RT (78527 TVDSS)
Horizontal displacement to top of target 34466 m10316ordm at 1365 m MD114858 m TVDRT
Horizontal displacement to TD 57793 m10316ordm at 1599 m MD115527m TVDRT
Geological limits - Dacian Pontian = 970 m TVD 974 m MD- Top Pontian 1 = 1145 m TVD 1313 m MD
Well construction ndash conductor 20 in x 2365 m RT hammered ndash surface casing 958 in x 400 m MD TOC = 0 m ndash production casing 7 in x 1365 m MD TOC = 0 m ndash production liner 412 in x (1599 ndash 1335 m) ndash sloted liner with 194 micron screen
NoteFor avoiding mud losses while drilling surface formations itrsquos recommended to
drill the first 60 m with reduced drilling parameters (low flowrate and ROP with big nozzles at bit) and using high viscosity mud (100-120 sec)
The 9-58 in surface casing shoe will be placed in a marly zone
2 EXECUTIVE SUMMARY
9 58rdquo Surface Casing Section
Section 0 ndash 400mFormations DacianMud Spud mud MW=1050-1150kgm3
For avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50-60 m with low flowrate and high viscosity mud (100-120 sec)
Traject Vertical Directional survey using TOTCOBHA Rigid BHA with 3 stabilizers
Pag 4
OMV PETROM
Bits amp hidraulics
12 frac14rdquo Roller bitWOB=8-14t RPM=110-120 Flow rate=40-45 lsFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50-60 m with reduced ROP and using bit with big nozzles
Logging GR in cased hole at total depthCasing 9 58rdquo 360 lbft (894 mm) J55 LC
TOC - surface
7rdquo Intermediate Production Casing Section
Section 400 ndash 1365 m MDFormations Dacian PontianMud NAF MW=1100-1150 (1200) kgm3
Mud weight will be increased only in case of hole instability or high gas influx
Traject Vertical using PDM to KOP-853 mBuild trajectory with about 6ordm30m to 85ordm inclination on 10316ordm azimuth till EOC- 1284 m MD ( 1143 m TVDRT) using PDM and LWDHold tangent at 85ordm inclination and 10316ordm azimuth to 1335 m MD (1147 m TVDRT) about 2 m bellow expected Top of P1 using PDM and LWDIncrease inclination angle till 89ordm on 10316ordm azimuth till 1365 m MD (11486 m TVDRT) ndash depth of 7rdquo casing shoe ndash about 35 m bellow Top of P1
BHA PDM + MWD+ LWD 8 frac34rdquo PDC bitBits amp hidraulics
8 34rdquo PDC bitWOB=4-10t RPM=40-60+PDM Flow rate=30-33lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res recorded with LWDCasing 7rdquo 260 lbft (919 mm) Extreme Line N80 J 55
TOC - surface
4 12rdquo Production Casing Section
Section 1365 ndash 1599 m MDFormations PontianMud NAF MW=1100-1150 (1200) kgm3
Mud weight will be increased only in case of hole instability or high gas influx
Traject Hold inclination angle at 89ordm on 10316ordm azimuth till 1499 m MD (115092 m TVDRT) using RSS and MWDLWDDecrease inclination angle till 87ordm at 1545 m MD (115245 m TVDRT) on 10316ordm azimuth due to dropping of P1 layerHold tangent at 87ordm inclination and 10316ordm azimuth to 1599 m MD (115527 m TVDRT) final TD using PDM and LWD
BHA PDM + MWD+ LWD 6 18rdquo roller bitBits amp 6 18rdquo roller bit
Pag 5
OMV PETROM
hidraulics WOB= 6-12t RPM=40-60+PDM Flow rate=15-17 lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res Sonic recorded with LWDCasing 4 12rdquo 135 lbft (737 mm) TSH Blue L 80 ndash slotted liner with premium
screen from HP with 194 micron screen and swell packers
3 GEOLOGICAL CONDITIONS
31 Offset wells
The Colibasi structure is located in Arges county at about 10 km North of the town of Pitesti From geological point of wiev it can be included in the Babeni-Sapunari-Merisani-Colibasi-Dobresti structure belongs to internal flank of Getic Depresion
The reservoirs in Colibasi field are Helvetian - Burdigalian (oil and free gas) Pontian and Oligocen (free gas)
From tectonical point of view the Colibasi field is an failed anticlineThe 1531 Colibasi well is a development well and is planned to be drilled horisontal to
develop hydrocarbons (free gas) from Pontian 1 and the projected final depth of the well will be 1155 m TVD (approximately 1599 m MD)
The well 1531 Colibasi has been proposed to be drilled in the ldquoReservoir Study for the commercial gas field Colibasi (Arges)rdquo issued in 2009 approved by OMV Petrom and confirmed by the National Agency for Mineral Resources
Pag 6
OMV PETROM
The geological condition it was determined used informations from following offset wells 1516 (drilled in 1997) 1590 (drilled in 1995) and 3019 (drilled in 1970)
-860
-785
-790
- 810
-795
-845
-850
-855
1501
1502
1514
1516
1530
1545
1546
1547
15481560
1580
1585
1590
1595
3000
3019
32
3225
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
-78377-77335
790800
810820
830840
850860
870
886
781SSTVD
1381
Co py o f 1 502 Co l iba s i - frag m en t CEjp gCo py o f 1 502 Co l iba s i - frag m en t CEjp g1502 [SSTVD]
485000 486000 487000 488000 489000 490000
485000 486000 487000 488000 489000 490000
383000384000
385000386000
3830
0038
4000
3850
0038
6000
0 100 200 300 400 500m
115000
-885-880-875-870-865-860-855-850-845-840-835-830-825-820-815-810-805-800-795-790-785-780-775
Depth
PETROM SA
COLIBASI - Ag
Top PONTIAN 1 STRUCTURAL MAP
Scale 115000 Designed by Iordache Claudiu
RM Asset III IVV IX
Pontian 1
Pontian 2
32 Lito-stratigraphic and structural conditions
Levantin and Dacian will be found between 0 and aprox 970 m TVD (973 m MD) It develops in predominantly sandy facies with intercalation of gravel sandstone marl sandy clay and thin beds of coal passing in the lower part in shally facies
Pontian is estimated between about 970ndash1155 m TVD (973ndash1599 m MD) Predominant facies is shally facies (made from marls and shales)
In base of Pontian (1145 m TVD 1313 m MD) there is a thin sandy layer named Pontian1 consisted of a 10 m poor consolidated sands
Pag 7
OMV PETROM
1531_3_5
-78911
-80600
-78377
-77335
-830
-845
-855
1516
1585
1590
3019
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
Top_P1
Base_best_zone
Top_P2
Base_P2Top_Helvet
Helvet_marker
790
800
810
820
830
840
850
860
870
880
890
900
912
776SSTVD
1492Copy of 1502 Colibasi - fragment CEjpgCopy of 1502 Colibasi - fragment CEjpg
Top_P1
Top_P2
Top_Helvet Helvet_marker
Base_P2
Base_best_zone
1502 [SSTVD]
Top_P1
Base_best_zone
Top_P2
Base_P2Top_HelvetHelvet_marker
486000 487000
486000 487000
384000385000
3840
0038
5000
Actual GWC - 806m
33 Contaminants for drilling fluid
Lithological column analysis proposed to be traversed by the well 1531 Colibasi reveals the presence of thin layers of coals in Dacian like specific contaminants on drilling fluid However should that possibility predominantly clay-shale sequences (especially
Pag 8
OMV PETROM
those in Pontian and Meoţian) to disperse the drilling fluid with solid and uploading those negatively affecting rheological properties
Geological formation Pressure gradients ndash estimated (at10 m)
Fracture gradients ndash estimated (at10 m)
Levantin + Dacian 100 ndash 101 135 ndash 165Pontian 102 169 ndash 172Pontian 1 (reservoir) 08 ndash 09 165 ndash 167
As Geothermal gradient is around 35 ndash 360 C100 m (aprox 410 C on the final depth)
Pag 9
OMV PETROM
Pag 10
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
5 Casing program (MD)
20 in x 2365 m RT hammered
958 in x 400 m MD TOC = 0 m
7 in x 1365 m MD TOC = 0 m
L 412 in x (1335-1599 m MD)
6
Drilling Rig
- maxim hook
- normal hook
MR 8000
200 t
113 t
7 Estimated drilling time 207 days
8 Owner OMV PETROM SA ndash ASSET III
9 Designer OMV PETROM SA ndash Well Engineering ndash Well Delivery Team 2
DRILLING PROGRAM
1 DRILLING WELL DATA
Well type Gas ProductionObjective Pontian 1Depth 1599m MD (1155m TVD) Drilling Rig MR 8000Surface coordinates N = 38472867 m
E = 48697239 m
Pag 3
OMV PETROM
Z (ground level)= 36483 m TVDRTZ (RT) = 37024 m TVDRT
Target coordinates- Top of target N = 38465001 m E = 4873089 m
Z = 114858 m TVD RT (77858 m TVDSS)
- End of target N = 38459677m E = 48753664 m
Z = 115527 m TVD RT (78527 TVDSS)
Horizontal displacement to top of target 34466 m10316ordm at 1365 m MD114858 m TVDRT
Horizontal displacement to TD 57793 m10316ordm at 1599 m MD115527m TVDRT
Geological limits - Dacian Pontian = 970 m TVD 974 m MD- Top Pontian 1 = 1145 m TVD 1313 m MD
Well construction ndash conductor 20 in x 2365 m RT hammered ndash surface casing 958 in x 400 m MD TOC = 0 m ndash production casing 7 in x 1365 m MD TOC = 0 m ndash production liner 412 in x (1599 ndash 1335 m) ndash sloted liner with 194 micron screen
NoteFor avoiding mud losses while drilling surface formations itrsquos recommended to
drill the first 60 m with reduced drilling parameters (low flowrate and ROP with big nozzles at bit) and using high viscosity mud (100-120 sec)
The 9-58 in surface casing shoe will be placed in a marly zone
2 EXECUTIVE SUMMARY
9 58rdquo Surface Casing Section
Section 0 ndash 400mFormations DacianMud Spud mud MW=1050-1150kgm3
For avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50-60 m with low flowrate and high viscosity mud (100-120 sec)
Traject Vertical Directional survey using TOTCOBHA Rigid BHA with 3 stabilizers
Pag 4
OMV PETROM
Bits amp hidraulics
12 frac14rdquo Roller bitWOB=8-14t RPM=110-120 Flow rate=40-45 lsFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50-60 m with reduced ROP and using bit with big nozzles
Logging GR in cased hole at total depthCasing 9 58rdquo 360 lbft (894 mm) J55 LC
TOC - surface
7rdquo Intermediate Production Casing Section
Section 400 ndash 1365 m MDFormations Dacian PontianMud NAF MW=1100-1150 (1200) kgm3
Mud weight will be increased only in case of hole instability or high gas influx
Traject Vertical using PDM to KOP-853 mBuild trajectory with about 6ordm30m to 85ordm inclination on 10316ordm azimuth till EOC- 1284 m MD ( 1143 m TVDRT) using PDM and LWDHold tangent at 85ordm inclination and 10316ordm azimuth to 1335 m MD (1147 m TVDRT) about 2 m bellow expected Top of P1 using PDM and LWDIncrease inclination angle till 89ordm on 10316ordm azimuth till 1365 m MD (11486 m TVDRT) ndash depth of 7rdquo casing shoe ndash about 35 m bellow Top of P1
BHA PDM + MWD+ LWD 8 frac34rdquo PDC bitBits amp hidraulics
8 34rdquo PDC bitWOB=4-10t RPM=40-60+PDM Flow rate=30-33lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res recorded with LWDCasing 7rdquo 260 lbft (919 mm) Extreme Line N80 J 55
TOC - surface
4 12rdquo Production Casing Section
Section 1365 ndash 1599 m MDFormations PontianMud NAF MW=1100-1150 (1200) kgm3
Mud weight will be increased only in case of hole instability or high gas influx
Traject Hold inclination angle at 89ordm on 10316ordm azimuth till 1499 m MD (115092 m TVDRT) using RSS and MWDLWDDecrease inclination angle till 87ordm at 1545 m MD (115245 m TVDRT) on 10316ordm azimuth due to dropping of P1 layerHold tangent at 87ordm inclination and 10316ordm azimuth to 1599 m MD (115527 m TVDRT) final TD using PDM and LWD
BHA PDM + MWD+ LWD 6 18rdquo roller bitBits amp 6 18rdquo roller bit
Pag 5
OMV PETROM
hidraulics WOB= 6-12t RPM=40-60+PDM Flow rate=15-17 lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res Sonic recorded with LWDCasing 4 12rdquo 135 lbft (737 mm) TSH Blue L 80 ndash slotted liner with premium
screen from HP with 194 micron screen and swell packers
3 GEOLOGICAL CONDITIONS
31 Offset wells
The Colibasi structure is located in Arges county at about 10 km North of the town of Pitesti From geological point of wiev it can be included in the Babeni-Sapunari-Merisani-Colibasi-Dobresti structure belongs to internal flank of Getic Depresion
The reservoirs in Colibasi field are Helvetian - Burdigalian (oil and free gas) Pontian and Oligocen (free gas)
From tectonical point of view the Colibasi field is an failed anticlineThe 1531 Colibasi well is a development well and is planned to be drilled horisontal to
develop hydrocarbons (free gas) from Pontian 1 and the projected final depth of the well will be 1155 m TVD (approximately 1599 m MD)
The well 1531 Colibasi has been proposed to be drilled in the ldquoReservoir Study for the commercial gas field Colibasi (Arges)rdquo issued in 2009 approved by OMV Petrom and confirmed by the National Agency for Mineral Resources
Pag 6
OMV PETROM
The geological condition it was determined used informations from following offset wells 1516 (drilled in 1997) 1590 (drilled in 1995) and 3019 (drilled in 1970)
-860
-785
-790
- 810
-795
-845
-850
-855
1501
1502
1514
1516
1530
1545
1546
1547
15481560
1580
1585
1590
1595
3000
3019
32
3225
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
-78377-77335
790800
810820
830840
850860
870
886
781SSTVD
1381
Co py o f 1 502 Co l iba s i - frag m en t CEjp gCo py o f 1 502 Co l iba s i - frag m en t CEjp g1502 [SSTVD]
485000 486000 487000 488000 489000 490000
485000 486000 487000 488000 489000 490000
383000384000
385000386000
3830
0038
4000
3850
0038
6000
0 100 200 300 400 500m
115000
-885-880-875-870-865-860-855-850-845-840-835-830-825-820-815-810-805-800-795-790-785-780-775
Depth
PETROM SA
COLIBASI - Ag
Top PONTIAN 1 STRUCTURAL MAP
Scale 115000 Designed by Iordache Claudiu
RM Asset III IVV IX
Pontian 1
Pontian 2
32 Lito-stratigraphic and structural conditions
Levantin and Dacian will be found between 0 and aprox 970 m TVD (973 m MD) It develops in predominantly sandy facies with intercalation of gravel sandstone marl sandy clay and thin beds of coal passing in the lower part in shally facies
Pontian is estimated between about 970ndash1155 m TVD (973ndash1599 m MD) Predominant facies is shally facies (made from marls and shales)
In base of Pontian (1145 m TVD 1313 m MD) there is a thin sandy layer named Pontian1 consisted of a 10 m poor consolidated sands
Pag 7
OMV PETROM
1531_3_5
-78911
-80600
-78377
-77335
-830
-845
-855
1516
1585
1590
3019
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
Top_P1
Base_best_zone
Top_P2
Base_P2Top_Helvet
Helvet_marker
790
800
810
820
830
840
850
860
870
880
890
900
912
776SSTVD
1492Copy of 1502 Colibasi - fragment CEjpgCopy of 1502 Colibasi - fragment CEjpg
Top_P1
Top_P2
Top_Helvet Helvet_marker
Base_P2
Base_best_zone
1502 [SSTVD]
Top_P1
Base_best_zone
Top_P2
Base_P2Top_HelvetHelvet_marker
486000 487000
486000 487000
384000385000
3840
0038
5000
Actual GWC - 806m
33 Contaminants for drilling fluid
Lithological column analysis proposed to be traversed by the well 1531 Colibasi reveals the presence of thin layers of coals in Dacian like specific contaminants on drilling fluid However should that possibility predominantly clay-shale sequences (especially
Pag 8
OMV PETROM
those in Pontian and Meoţian) to disperse the drilling fluid with solid and uploading those negatively affecting rheological properties
Geological formation Pressure gradients ndash estimated (at10 m)
Fracture gradients ndash estimated (at10 m)
Levantin + Dacian 100 ndash 101 135 ndash 165Pontian 102 169 ndash 172Pontian 1 (reservoir) 08 ndash 09 165 ndash 167
As Geothermal gradient is around 35 ndash 360 C100 m (aprox 410 C on the final depth)
Pag 9
OMV PETROM
Pag 10
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Z (ground level)= 36483 m TVDRTZ (RT) = 37024 m TVDRT
Target coordinates- Top of target N = 38465001 m E = 4873089 m
Z = 114858 m TVD RT (77858 m TVDSS)
- End of target N = 38459677m E = 48753664 m
Z = 115527 m TVD RT (78527 TVDSS)
Horizontal displacement to top of target 34466 m10316ordm at 1365 m MD114858 m TVDRT
Horizontal displacement to TD 57793 m10316ordm at 1599 m MD115527m TVDRT
Geological limits - Dacian Pontian = 970 m TVD 974 m MD- Top Pontian 1 = 1145 m TVD 1313 m MD
Well construction ndash conductor 20 in x 2365 m RT hammered ndash surface casing 958 in x 400 m MD TOC = 0 m ndash production casing 7 in x 1365 m MD TOC = 0 m ndash production liner 412 in x (1599 ndash 1335 m) ndash sloted liner with 194 micron screen
NoteFor avoiding mud losses while drilling surface formations itrsquos recommended to
drill the first 60 m with reduced drilling parameters (low flowrate and ROP with big nozzles at bit) and using high viscosity mud (100-120 sec)
The 9-58 in surface casing shoe will be placed in a marly zone
2 EXECUTIVE SUMMARY
9 58rdquo Surface Casing Section
Section 0 ndash 400mFormations DacianMud Spud mud MW=1050-1150kgm3
For avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50-60 m with low flowrate and high viscosity mud (100-120 sec)
Traject Vertical Directional survey using TOTCOBHA Rigid BHA with 3 stabilizers
Pag 4
OMV PETROM
Bits amp hidraulics
12 frac14rdquo Roller bitWOB=8-14t RPM=110-120 Flow rate=40-45 lsFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50-60 m with reduced ROP and using bit with big nozzles
Logging GR in cased hole at total depthCasing 9 58rdquo 360 lbft (894 mm) J55 LC
TOC - surface
7rdquo Intermediate Production Casing Section
Section 400 ndash 1365 m MDFormations Dacian PontianMud NAF MW=1100-1150 (1200) kgm3
Mud weight will be increased only in case of hole instability or high gas influx
Traject Vertical using PDM to KOP-853 mBuild trajectory with about 6ordm30m to 85ordm inclination on 10316ordm azimuth till EOC- 1284 m MD ( 1143 m TVDRT) using PDM and LWDHold tangent at 85ordm inclination and 10316ordm azimuth to 1335 m MD (1147 m TVDRT) about 2 m bellow expected Top of P1 using PDM and LWDIncrease inclination angle till 89ordm on 10316ordm azimuth till 1365 m MD (11486 m TVDRT) ndash depth of 7rdquo casing shoe ndash about 35 m bellow Top of P1
BHA PDM + MWD+ LWD 8 frac34rdquo PDC bitBits amp hidraulics
8 34rdquo PDC bitWOB=4-10t RPM=40-60+PDM Flow rate=30-33lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res recorded with LWDCasing 7rdquo 260 lbft (919 mm) Extreme Line N80 J 55
TOC - surface
4 12rdquo Production Casing Section
Section 1365 ndash 1599 m MDFormations PontianMud NAF MW=1100-1150 (1200) kgm3
Mud weight will be increased only in case of hole instability or high gas influx
Traject Hold inclination angle at 89ordm on 10316ordm azimuth till 1499 m MD (115092 m TVDRT) using RSS and MWDLWDDecrease inclination angle till 87ordm at 1545 m MD (115245 m TVDRT) on 10316ordm azimuth due to dropping of P1 layerHold tangent at 87ordm inclination and 10316ordm azimuth to 1599 m MD (115527 m TVDRT) final TD using PDM and LWD
BHA PDM + MWD+ LWD 6 18rdquo roller bitBits amp 6 18rdquo roller bit
Pag 5
OMV PETROM
hidraulics WOB= 6-12t RPM=40-60+PDM Flow rate=15-17 lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res Sonic recorded with LWDCasing 4 12rdquo 135 lbft (737 mm) TSH Blue L 80 ndash slotted liner with premium
screen from HP with 194 micron screen and swell packers
3 GEOLOGICAL CONDITIONS
31 Offset wells
The Colibasi structure is located in Arges county at about 10 km North of the town of Pitesti From geological point of wiev it can be included in the Babeni-Sapunari-Merisani-Colibasi-Dobresti structure belongs to internal flank of Getic Depresion
The reservoirs in Colibasi field are Helvetian - Burdigalian (oil and free gas) Pontian and Oligocen (free gas)
From tectonical point of view the Colibasi field is an failed anticlineThe 1531 Colibasi well is a development well and is planned to be drilled horisontal to
develop hydrocarbons (free gas) from Pontian 1 and the projected final depth of the well will be 1155 m TVD (approximately 1599 m MD)
The well 1531 Colibasi has been proposed to be drilled in the ldquoReservoir Study for the commercial gas field Colibasi (Arges)rdquo issued in 2009 approved by OMV Petrom and confirmed by the National Agency for Mineral Resources
Pag 6
OMV PETROM
The geological condition it was determined used informations from following offset wells 1516 (drilled in 1997) 1590 (drilled in 1995) and 3019 (drilled in 1970)
-860
-785
-790
- 810
-795
-845
-850
-855
1501
1502
1514
1516
1530
1545
1546
1547
15481560
1580
1585
1590
1595
3000
3019
32
3225
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
-78377-77335
790800
810820
830840
850860
870
886
781SSTVD
1381
Co py o f 1 502 Co l iba s i - frag m en t CEjp gCo py o f 1 502 Co l iba s i - frag m en t CEjp g1502 [SSTVD]
485000 486000 487000 488000 489000 490000
485000 486000 487000 488000 489000 490000
383000384000
385000386000
3830
0038
4000
3850
0038
6000
0 100 200 300 400 500m
115000
-885-880-875-870-865-860-855-850-845-840-835-830-825-820-815-810-805-800-795-790-785-780-775
Depth
PETROM SA
COLIBASI - Ag
Top PONTIAN 1 STRUCTURAL MAP
Scale 115000 Designed by Iordache Claudiu
RM Asset III IVV IX
Pontian 1
Pontian 2
32 Lito-stratigraphic and structural conditions
Levantin and Dacian will be found between 0 and aprox 970 m TVD (973 m MD) It develops in predominantly sandy facies with intercalation of gravel sandstone marl sandy clay and thin beds of coal passing in the lower part in shally facies
Pontian is estimated between about 970ndash1155 m TVD (973ndash1599 m MD) Predominant facies is shally facies (made from marls and shales)
In base of Pontian (1145 m TVD 1313 m MD) there is a thin sandy layer named Pontian1 consisted of a 10 m poor consolidated sands
Pag 7
OMV PETROM
1531_3_5
-78911
-80600
-78377
-77335
-830
-845
-855
1516
1585
1590
3019
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
Top_P1
Base_best_zone
Top_P2
Base_P2Top_Helvet
Helvet_marker
790
800
810
820
830
840
850
860
870
880
890
900
912
776SSTVD
1492Copy of 1502 Colibasi - fragment CEjpgCopy of 1502 Colibasi - fragment CEjpg
Top_P1
Top_P2
Top_Helvet Helvet_marker
Base_P2
Base_best_zone
1502 [SSTVD]
Top_P1
Base_best_zone
Top_P2
Base_P2Top_HelvetHelvet_marker
486000 487000
486000 487000
384000385000
3840
0038
5000
Actual GWC - 806m
33 Contaminants for drilling fluid
Lithological column analysis proposed to be traversed by the well 1531 Colibasi reveals the presence of thin layers of coals in Dacian like specific contaminants on drilling fluid However should that possibility predominantly clay-shale sequences (especially
Pag 8
OMV PETROM
those in Pontian and Meoţian) to disperse the drilling fluid with solid and uploading those negatively affecting rheological properties
Geological formation Pressure gradients ndash estimated (at10 m)
Fracture gradients ndash estimated (at10 m)
Levantin + Dacian 100 ndash 101 135 ndash 165Pontian 102 169 ndash 172Pontian 1 (reservoir) 08 ndash 09 165 ndash 167
As Geothermal gradient is around 35 ndash 360 C100 m (aprox 410 C on the final depth)
Pag 9
OMV PETROM
Pag 10
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Bits amp hidraulics
12 frac14rdquo Roller bitWOB=8-14t RPM=110-120 Flow rate=40-45 lsFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50-60 m with reduced ROP and using bit with big nozzles
Logging GR in cased hole at total depthCasing 9 58rdquo 360 lbft (894 mm) J55 LC
TOC - surface
7rdquo Intermediate Production Casing Section
Section 400 ndash 1365 m MDFormations Dacian PontianMud NAF MW=1100-1150 (1200) kgm3
Mud weight will be increased only in case of hole instability or high gas influx
Traject Vertical using PDM to KOP-853 mBuild trajectory with about 6ordm30m to 85ordm inclination on 10316ordm azimuth till EOC- 1284 m MD ( 1143 m TVDRT) using PDM and LWDHold tangent at 85ordm inclination and 10316ordm azimuth to 1335 m MD (1147 m TVDRT) about 2 m bellow expected Top of P1 using PDM and LWDIncrease inclination angle till 89ordm on 10316ordm azimuth till 1365 m MD (11486 m TVDRT) ndash depth of 7rdquo casing shoe ndash about 35 m bellow Top of P1
BHA PDM + MWD+ LWD 8 frac34rdquo PDC bitBits amp hidraulics
8 34rdquo PDC bitWOB=4-10t RPM=40-60+PDM Flow rate=30-33lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res recorded with LWDCasing 7rdquo 260 lbft (919 mm) Extreme Line N80 J 55
TOC - surface
4 12rdquo Production Casing Section
Section 1365 ndash 1599 m MDFormations PontianMud NAF MW=1100-1150 (1200) kgm3
Mud weight will be increased only in case of hole instability or high gas influx
Traject Hold inclination angle at 89ordm on 10316ordm azimuth till 1499 m MD (115092 m TVDRT) using RSS and MWDLWDDecrease inclination angle till 87ordm at 1545 m MD (115245 m TVDRT) on 10316ordm azimuth due to dropping of P1 layerHold tangent at 87ordm inclination and 10316ordm azimuth to 1599 m MD (115527 m TVDRT) final TD using PDM and LWD
BHA PDM + MWD+ LWD 6 18rdquo roller bitBits amp 6 18rdquo roller bit
Pag 5
OMV PETROM
hidraulics WOB= 6-12t RPM=40-60+PDM Flow rate=15-17 lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res Sonic recorded with LWDCasing 4 12rdquo 135 lbft (737 mm) TSH Blue L 80 ndash slotted liner with premium
screen from HP with 194 micron screen and swell packers
3 GEOLOGICAL CONDITIONS
31 Offset wells
The Colibasi structure is located in Arges county at about 10 km North of the town of Pitesti From geological point of wiev it can be included in the Babeni-Sapunari-Merisani-Colibasi-Dobresti structure belongs to internal flank of Getic Depresion
The reservoirs in Colibasi field are Helvetian - Burdigalian (oil and free gas) Pontian and Oligocen (free gas)
From tectonical point of view the Colibasi field is an failed anticlineThe 1531 Colibasi well is a development well and is planned to be drilled horisontal to
develop hydrocarbons (free gas) from Pontian 1 and the projected final depth of the well will be 1155 m TVD (approximately 1599 m MD)
The well 1531 Colibasi has been proposed to be drilled in the ldquoReservoir Study for the commercial gas field Colibasi (Arges)rdquo issued in 2009 approved by OMV Petrom and confirmed by the National Agency for Mineral Resources
Pag 6
OMV PETROM
The geological condition it was determined used informations from following offset wells 1516 (drilled in 1997) 1590 (drilled in 1995) and 3019 (drilled in 1970)
-860
-785
-790
- 810
-795
-845
-850
-855
1501
1502
1514
1516
1530
1545
1546
1547
15481560
1580
1585
1590
1595
3000
3019
32
3225
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
-78377-77335
790800
810820
830840
850860
870
886
781SSTVD
1381
Co py o f 1 502 Co l iba s i - frag m en t CEjp gCo py o f 1 502 Co l iba s i - frag m en t CEjp g1502 [SSTVD]
485000 486000 487000 488000 489000 490000
485000 486000 487000 488000 489000 490000
383000384000
385000386000
3830
0038
4000
3850
0038
6000
0 100 200 300 400 500m
115000
-885-880-875-870-865-860-855-850-845-840-835-830-825-820-815-810-805-800-795-790-785-780-775
Depth
PETROM SA
COLIBASI - Ag
Top PONTIAN 1 STRUCTURAL MAP
Scale 115000 Designed by Iordache Claudiu
RM Asset III IVV IX
Pontian 1
Pontian 2
32 Lito-stratigraphic and structural conditions
Levantin and Dacian will be found between 0 and aprox 970 m TVD (973 m MD) It develops in predominantly sandy facies with intercalation of gravel sandstone marl sandy clay and thin beds of coal passing in the lower part in shally facies
Pontian is estimated between about 970ndash1155 m TVD (973ndash1599 m MD) Predominant facies is shally facies (made from marls and shales)
In base of Pontian (1145 m TVD 1313 m MD) there is a thin sandy layer named Pontian1 consisted of a 10 m poor consolidated sands
Pag 7
OMV PETROM
1531_3_5
-78911
-80600
-78377
-77335
-830
-845
-855
1516
1585
1590
3019
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
Top_P1
Base_best_zone
Top_P2
Base_P2Top_Helvet
Helvet_marker
790
800
810
820
830
840
850
860
870
880
890
900
912
776SSTVD
1492Copy of 1502 Colibasi - fragment CEjpgCopy of 1502 Colibasi - fragment CEjpg
Top_P1
Top_P2
Top_Helvet Helvet_marker
Base_P2
Base_best_zone
1502 [SSTVD]
Top_P1
Base_best_zone
Top_P2
Base_P2Top_HelvetHelvet_marker
486000 487000
486000 487000
384000385000
3840
0038
5000
Actual GWC - 806m
33 Contaminants for drilling fluid
Lithological column analysis proposed to be traversed by the well 1531 Colibasi reveals the presence of thin layers of coals in Dacian like specific contaminants on drilling fluid However should that possibility predominantly clay-shale sequences (especially
Pag 8
OMV PETROM
those in Pontian and Meoţian) to disperse the drilling fluid with solid and uploading those negatively affecting rheological properties
Geological formation Pressure gradients ndash estimated (at10 m)
Fracture gradients ndash estimated (at10 m)
Levantin + Dacian 100 ndash 101 135 ndash 165Pontian 102 169 ndash 172Pontian 1 (reservoir) 08 ndash 09 165 ndash 167
As Geothermal gradient is around 35 ndash 360 C100 m (aprox 410 C on the final depth)
Pag 9
OMV PETROM
Pag 10
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
hidraulics WOB= 6-12t RPM=40-60+PDM Flow rate=15-17 lsThe flow rate has to be decrease on possible mud losses intervals or increase gas influx
Logging GR Res Sonic recorded with LWDCasing 4 12rdquo 135 lbft (737 mm) TSH Blue L 80 ndash slotted liner with premium
screen from HP with 194 micron screen and swell packers
3 GEOLOGICAL CONDITIONS
31 Offset wells
The Colibasi structure is located in Arges county at about 10 km North of the town of Pitesti From geological point of wiev it can be included in the Babeni-Sapunari-Merisani-Colibasi-Dobresti structure belongs to internal flank of Getic Depresion
The reservoirs in Colibasi field are Helvetian - Burdigalian (oil and free gas) Pontian and Oligocen (free gas)
From tectonical point of view the Colibasi field is an failed anticlineThe 1531 Colibasi well is a development well and is planned to be drilled horisontal to
develop hydrocarbons (free gas) from Pontian 1 and the projected final depth of the well will be 1155 m TVD (approximately 1599 m MD)
The well 1531 Colibasi has been proposed to be drilled in the ldquoReservoir Study for the commercial gas field Colibasi (Arges)rdquo issued in 2009 approved by OMV Petrom and confirmed by the National Agency for Mineral Resources
Pag 6
OMV PETROM
The geological condition it was determined used informations from following offset wells 1516 (drilled in 1997) 1590 (drilled in 1995) and 3019 (drilled in 1970)
-860
-785
-790
- 810
-795
-845
-850
-855
1501
1502
1514
1516
1530
1545
1546
1547
15481560
1580
1585
1590
1595
3000
3019
32
3225
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
-78377-77335
790800
810820
830840
850860
870
886
781SSTVD
1381
Co py o f 1 502 Co l iba s i - frag m en t CEjp gCo py o f 1 502 Co l iba s i - frag m en t CEjp g1502 [SSTVD]
485000 486000 487000 488000 489000 490000
485000 486000 487000 488000 489000 490000
383000384000
385000386000
3830
0038
4000
3850
0038
6000
0 100 200 300 400 500m
115000
-885-880-875-870-865-860-855-850-845-840-835-830-825-820-815-810-805-800-795-790-785-780-775
Depth
PETROM SA
COLIBASI - Ag
Top PONTIAN 1 STRUCTURAL MAP
Scale 115000 Designed by Iordache Claudiu
RM Asset III IVV IX
Pontian 1
Pontian 2
32 Lito-stratigraphic and structural conditions
Levantin and Dacian will be found between 0 and aprox 970 m TVD (973 m MD) It develops in predominantly sandy facies with intercalation of gravel sandstone marl sandy clay and thin beds of coal passing in the lower part in shally facies
Pontian is estimated between about 970ndash1155 m TVD (973ndash1599 m MD) Predominant facies is shally facies (made from marls and shales)
In base of Pontian (1145 m TVD 1313 m MD) there is a thin sandy layer named Pontian1 consisted of a 10 m poor consolidated sands
Pag 7
OMV PETROM
1531_3_5
-78911
-80600
-78377
-77335
-830
-845
-855
1516
1585
1590
3019
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
Top_P1
Base_best_zone
Top_P2
Base_P2Top_Helvet
Helvet_marker
790
800
810
820
830
840
850
860
870
880
890
900
912
776SSTVD
1492Copy of 1502 Colibasi - fragment CEjpgCopy of 1502 Colibasi - fragment CEjpg
Top_P1
Top_P2
Top_Helvet Helvet_marker
Base_P2
Base_best_zone
1502 [SSTVD]
Top_P1
Base_best_zone
Top_P2
Base_P2Top_HelvetHelvet_marker
486000 487000
486000 487000
384000385000
3840
0038
5000
Actual GWC - 806m
33 Contaminants for drilling fluid
Lithological column analysis proposed to be traversed by the well 1531 Colibasi reveals the presence of thin layers of coals in Dacian like specific contaminants on drilling fluid However should that possibility predominantly clay-shale sequences (especially
Pag 8
OMV PETROM
those in Pontian and Meoţian) to disperse the drilling fluid with solid and uploading those negatively affecting rheological properties
Geological formation Pressure gradients ndash estimated (at10 m)
Fracture gradients ndash estimated (at10 m)
Levantin + Dacian 100 ndash 101 135 ndash 165Pontian 102 169 ndash 172Pontian 1 (reservoir) 08 ndash 09 165 ndash 167
As Geothermal gradient is around 35 ndash 360 C100 m (aprox 410 C on the final depth)
Pag 9
OMV PETROM
Pag 10
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
The geological condition it was determined used informations from following offset wells 1516 (drilled in 1997) 1590 (drilled in 1995) and 3019 (drilled in 1970)
-860
-785
-790
- 810
-795
-845
-850
-855
1501
1502
1514
1516
1530
1545
1546
1547
15481560
1580
1585
1590
1595
3000
3019
32
3225
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
-78377-77335
790800
810820
830840
850860
870
886
781SSTVD
1381
Co py o f 1 502 Co l iba s i - frag m en t CEjp gCo py o f 1 502 Co l iba s i - frag m en t CEjp g1502 [SSTVD]
485000 486000 487000 488000 489000 490000
485000 486000 487000 488000 489000 490000
383000384000
385000386000
3830
0038
4000
3850
0038
6000
0 100 200 300 400 500m
115000
-885-880-875-870-865-860-855-850-845-840-835-830-825-820-815-810-805-800-795-790-785-780-775
Depth
PETROM SA
COLIBASI - Ag
Top PONTIAN 1 STRUCTURAL MAP
Scale 115000 Designed by Iordache Claudiu
RM Asset III IVV IX
Pontian 1
Pontian 2
32 Lito-stratigraphic and structural conditions
Levantin and Dacian will be found between 0 and aprox 970 m TVD (973 m MD) It develops in predominantly sandy facies with intercalation of gravel sandstone marl sandy clay and thin beds of coal passing in the lower part in shally facies
Pontian is estimated between about 970ndash1155 m TVD (973ndash1599 m MD) Predominant facies is shally facies (made from marls and shales)
In base of Pontian (1145 m TVD 1313 m MD) there is a thin sandy layer named Pontian1 consisted of a 10 m poor consolidated sands
Pag 7
OMV PETROM
1531_3_5
-78911
-80600
-78377
-77335
-830
-845
-855
1516
1585
1590
3019
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
Top_P1
Base_best_zone
Top_P2
Base_P2Top_Helvet
Helvet_marker
790
800
810
820
830
840
850
860
870
880
890
900
912
776SSTVD
1492Copy of 1502 Colibasi - fragment CEjpgCopy of 1502 Colibasi - fragment CEjpg
Top_P1
Top_P2
Top_Helvet Helvet_marker
Base_P2
Base_best_zone
1502 [SSTVD]
Top_P1
Base_best_zone
Top_P2
Base_P2Top_HelvetHelvet_marker
486000 487000
486000 487000
384000385000
3840
0038
5000
Actual GWC - 806m
33 Contaminants for drilling fluid
Lithological column analysis proposed to be traversed by the well 1531 Colibasi reveals the presence of thin layers of coals in Dacian like specific contaminants on drilling fluid However should that possibility predominantly clay-shale sequences (especially
Pag 8
OMV PETROM
those in Pontian and Meoţian) to disperse the drilling fluid with solid and uploading those negatively affecting rheological properties
Geological formation Pressure gradients ndash estimated (at10 m)
Fracture gradients ndash estimated (at10 m)
Levantin + Dacian 100 ndash 101 135 ndash 165Pontian 102 169 ndash 172Pontian 1 (reservoir) 08 ndash 09 165 ndash 167
As Geothermal gradient is around 35 ndash 360 C100 m (aprox 410 C on the final depth)
Pag 9
OMV PETROM
Pag 10
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
1531_3_5
-78911
-80600
-78377
-77335
-830
-845
-855
1516
1585
1590
3019
1531_3_5
-79900
-80950
-81100
-78911
-80200
-81100
-80600
-80600
-83200
-79870
-85374
-79200
-80500
-87800
-80200
-78300
-80600
-78230
Top_P1
Base_best_zone
Top_P2
Base_P2Top_Helvet
Helvet_marker
790
800
810
820
830
840
850
860
870
880
890
900
912
776SSTVD
1492Copy of 1502 Colibasi - fragment CEjpgCopy of 1502 Colibasi - fragment CEjpg
Top_P1
Top_P2
Top_Helvet Helvet_marker
Base_P2
Base_best_zone
1502 [SSTVD]
Top_P1
Base_best_zone
Top_P2
Base_P2Top_HelvetHelvet_marker
486000 487000
486000 487000
384000385000
3840
0038
5000
Actual GWC - 806m
33 Contaminants for drilling fluid
Lithological column analysis proposed to be traversed by the well 1531 Colibasi reveals the presence of thin layers of coals in Dacian like specific contaminants on drilling fluid However should that possibility predominantly clay-shale sequences (especially
Pag 8
OMV PETROM
those in Pontian and Meoţian) to disperse the drilling fluid with solid and uploading those negatively affecting rheological properties
Geological formation Pressure gradients ndash estimated (at10 m)
Fracture gradients ndash estimated (at10 m)
Levantin + Dacian 100 ndash 101 135 ndash 165Pontian 102 169 ndash 172Pontian 1 (reservoir) 08 ndash 09 165 ndash 167
As Geothermal gradient is around 35 ndash 360 C100 m (aprox 410 C on the final depth)
Pag 9
OMV PETROM
Pag 10
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
those in Pontian and Meoţian) to disperse the drilling fluid with solid and uploading those negatively affecting rheological properties
Geological formation Pressure gradients ndash estimated (at10 m)
Fracture gradients ndash estimated (at10 m)
Levantin + Dacian 100 ndash 101 135 ndash 165Pontian 102 169 ndash 172Pontian 1 (reservoir) 08 ndash 09 165 ndash 167
As Geothermal gradient is around 35 ndash 360 C100 m (aprox 410 C on the final depth)
Pag 9
OMV PETROM
Pag 10
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Pag 10
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
4 CASING PROGRAM
Pag 11
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
41 Casing necessaryCasing Interval Length Size Grade-
connectionWall
thicknessNomina
lweight
Totalweight
- m -m m in - mm kgm kg
Surface 0 - 400 400 9-58 J55 LC 894 5426 21704
Production 0 - 1100 11007
N80 XC 919 3840 42240
1100 - 1365 265 J55 XC 919 3840 9984
Liner 1335 - 1599 264 4-12 L80 TSH Blue 737 2009 5304
42 TECHNICAL CONDITIONS FOR CASING CALCULATIONNo Specifications UM Casing
Surface Product Liner1 Outside diameter in 958 7 4122 Casing depth m 400 1365 15993 Casing length m 400 1365 2644 Bottom formation pressure bar 40 124 1245 Calculation surface Ps bar 56) 111 111
pressure bottom Pb bar 61) 124 1246 Max internal pressure Pmax bar 210 210 2107 Mud weight kgm3 1100-1150 1150-1200 1150-12008 Cementing interval m - m 400 - 0 1365 - 0 -
9 Empty casing depth m Total Total Total10 Casing Type - LC XC TSH Blue
coupling Outside diameter mm 2699 1877 127011 Bit diameter in 1214 834 618
mm 3112 2223 155612 Casing factor - 00663 00778 00919 13 Minimum inside casing diameter mm 2266 1594 995714 Drift diameter mm 22263 15624 963915 Collapse resistance bar 139 373 298 58916 Burst resistance bar 242 499 343 62217 Tensile strength to 205 274 188 13818 Supplementary conditions - - - -19 Safety Burst - 110 110 110
factor forhellip Collapse - 100 100 100(min values) Tensile - 150 150 150
20 Make-up torque
min daNm 470 960800 725opt daNm 625 - 805max daNm 780 12001000 885
Notes- Ps Pb maximum pressure to surfacebottom gas inside
) means that the pressure is limited by fracture gradient)- Pmax maximum internal pressure admited for whole casing water inside- Casing characteristics have to be communicated by the casing supplier
Pag 12
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
43 Casing accesories
431 Casing 958 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Float shoe single
valve894mm J55 958 LC 1 -
2 Float collar single valve
894mm J55 958 LC 1 20
3 Centralizers ST A2 958 - 16 int 400-3001c1jint 250- 501c5j
4 Stop collars - 958 - 32 2scNote Float shoe float collar and the nonrotated plugs must be PDC drillable
432 Casing 7 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve919mm J55 7 XC 1 -
2 Float collar single valve
919mm J55 7 XC 1 10
3 Centralizers - Centek
7 x 812 7 - 45 int1365 -12001c1jint1200 - 8501c2jint 850 - 501c5j
4 Stop collars - 7 - 90 2scNote Float equipment and cementing plugs must be Weatherford
The position of the centralizers will be establish before set casing
433 Casing 412 in
No Accessories Characteristics Size Conn Pieces Position (distance above shoe)
- - - in - no m1 Reamer shoe
single valve737mm L80 412 TSH
Blue1 -
2 Centralizers (Spirolizer)
4 frac12rdquo x 5 78rdquo 4 12 - 26 int1599-13351c1j
3 Swell packers (oil sweling isolation seal)
149 mm
10 Will be decide
5 DIRECTIONAL PROGRAM
Pag 13
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Wall Plot
Pag 14
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Pag 15
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
6 DRILL STRING
String components MU Interval m - m
0 - 400Bit Diameter in 12-14
Downholemotor (PDM)
Outside diameter in
Length m
Type -
Stabiliser
Outside diameter in 12-14 + 12-316
Body diameter in 8
Bow type - Spiral
Position m bit 918
Max admis wear in 116
Nonmagneticdrill collars
Outside diameter in
Length m
Connection in
Drill collars (Spiral)
Outside diameter in mm 82032 + 6-12 1651
Inside diameter in mm 2 1316 7144
Connection - NC 56 + NC 50
Wear - Premium
Make-up torque daNm 6534 + 4022
Weight kgm 22311 + 13659
Length m 36 + 72
Weight in air incl NMDCrsquos kg 17866
JarOutside diameter in 612
Connection in NC 50
Position m 145
Heavy WeightDrill pipe
Outside diameter in mm 4 1016
Inside diameter in mm 2 916 651
Connection - XTF 39
Make-up torque daNm 1993-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 427
Length m 110
Weight in air kg 4697
Drill pipe
Outside diameter in 4
Wall Thickness mm 838
Steel - S 135
Wear - Premium
Connection - XTF 39
Make-up torque daNm 1990-3321
Box OD mm 127
Pin ID mm 651
Weight kgm 2083
Length m 182
Weight in air kg 3791
KellyTop drive Dimension in Top drive
Profile -
Weight of string in air kg 26354
Over pull reserve kg 60000
Note Drill string components for the 8-34rdquo and 6-18rdquo sections can be found in appendix 4The position of stabilizators will be in conforming to the well behavior while drillingCan use more HWDP instead of DC in case of stuck dangerThe jar position will be established in according to speciality provider One or two stands above jar have to set an acceleratorDrill string components can be changed according to the well condition while drilling
Pag 16
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
7 MUD PROGRAM
Mud program and Waste management process was recommanded by the speciality OMV PETROM
Pag 17
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
While drilling the mud contractor and the owner with one accord can change the mud program depending on new drilling information
71 Mud parameters
No
Drilling fluid characteristics
UM
Phase Interval (m - m)
Phase I Phase I Phase I
0 - 400 400 - 1365 1365 - 15990 Bit Diameter in 12 14 8 34 6 181 Drilling fluid type - Spud Mud NAF NAF2 Density kgm3 1050-1100-1150 1100-1150(1200) 1100-1150(1200)3 Marsh Viscosity secl 50-120 55-70 55-704 Plastic viscosity cP 14-30 22-35 22-355 Yield point lb100ft2 16-35 16-25 16-256 Reading at 6 rpm - - 8-9 6-77 Gel-10 sec lb100ft2 5-10 6-12 8-128 Gel-10 min lb100ft2 15-40 12-20 14-209 API Filtrate cm3 8-12 - -
10 Filtrate at HPHT cm3 - lt5 lt5
11Filter cake(API HPHT)
mm 15-20 05-10 05-10
12 pH - 8-9 - -
13Concentration of Ca2+
and Mg2+ mgl lt250 - -
14Concentration of chloride ions
mgl lt5000 - -
15 LGS vol lt8 lt6 lt516 Sand Content vol lt1 lt05 lt05
17Active Shale Content (MBT)
kgm3 lt77 - -
18Water phase salinity(WPS)
mgl - 110000-125000 110000-125000
19 Activity of water - - 088-090 088-09020 OW ratio - - 7525 752521 Electrical stability V - gt800 gt80022 SCE Efficiency 75 85 85
NOTEThe mud density will be maintain as low as possible (between 11-115 sg) Only in case of bore hole stability issue the mud density will be increased to 12 sg It is mandatory for the drilling fluids contractor to have sufficient chemicals at the rig site to prepare one release pill and keep LCM in stock to fight unexpected losses
8 BIT amp HIDRAULICS PROGRAM
Phase Interval (MD)
FormDrilling system
Bits Mechanicals amp hydraulics parameters
Type (IADC)
Nozzles WOB RPM Flow rate
Jet speed
Specific hydr power
Press Drop at bit
Pump press
Pag 18
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
- (m-m) - - - nrxin32 to 1min ls ms HPin2 bar bar
I 0 - 400 Dacian RotaryR 12-14
(117)
3 x 1632
1 x 1432
8-14110-120
40-45 84-94 21-29 45-57105-130
II400 ndash 1365
Dacian Pontian
Rotary + PDM
PDC8-34
(M223)
5 x 1332
4-640-60
+ PDM
30-33 67-75182-251
29-36206-246
II1365 ndash 1599
PontianRotary (RSS)
R6-18 (117)
3 x 1332
3-5160-180
15-17 65 197 27 162
Back-up bits = int 400-1365m R 834 (137) ndash 1 pieceint 1365-1599m R 618 (117) ndash 1 piece
Note The flow rate has to be decrease on possible mud losses intervals or increase gas contentFor avoiding mud losses while drilling surface formations itrsquos recommended to drill the first 50- 60m with reduced drilling parameters (low flowrate and ROP with big nozzles) and using high viscosity mud (100-120 sec) Drilling parameters can be modified according to the well condition while drilling
Pag 19
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
9 LOGGING PROGRAM
91 Geophysical logging
Section Hole sizeinch
Wireline log Type
I 12-14 GR in cased hole during POOH BHA from drilling interval 400-1365 mMD
II 8-34 GR + Res while drilling recorded with LWD
III 6-18 GR azimuthal+ Res + Sonic while drilling recorded with LWD
Mud logging unit will record parameters on interval 400 ndash 1599 m
92 Directional survey
Section Interval (MD) Distance between points
Tool Method
- m - m m - -I 0 - 400 200 TOTCO -Before POOH BHA from 400
mII 400 - 850 2 joints LWD -while drilling at every 2 joints
+ checking survey during adding new double
850 ndash 1365 1 joint LWD -while drilling at every joint+ checking survey during adding new double
III 1365 - 1599 1 joint LWD -while drilling at every joint+ checking survey during adding new double
On interval 400-1599 m wersquoll have in BHA a tool which will measure annular pressure (APWD)
10 CEMENTING PROGRAM
Pag 20
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Before beginning preparations for the casing operation it is necessary to analyze the compatibility between the drilling fluid and the cement slurry to establish whether spacer fluids are necessary
101 Properties of cement stones and cement slurries
No Properties MU Values
Casing diameter in 9 58 71 Liquids solids ratio - 054 110 0452 Density kgm3 1800 1500 19003 Free water(Separation) 0 0 04 Fluid loss(API filtration) cm330 235 290 485 Plastic viscosity (PV) cP(m Pa s) 58 25 706 Yield Point (YP) lb100 ft2(Pa) 25(12) 20(96) 25(12)7 Thickening time min 180 240 180
8 Compressive strength
after 8 hours after 12 hours after 24 hours
daNcm2-
4080
-7
25
-45
110
102 Cementing program
DATA UM VALUESCasing size in 9 58 7
Pag 21
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
The casing depth on trajectory (vertical) m 400 1365(1148)Hole diameter Nominal mm 3112 2223
Estimated mm 345 235Mud
drillingDensity kgm3 1150 1200Plastic viscosity (PV) cP (mPas) 24 25Yield Point (YP) lbf100ft2 (Pa) 20(96) 20(96)
Max admissible casing running speed ms 10 06Circulation
withthe casing at bottom
hole
Maximum flow rate dm3s 30 20Pump pressure bar 135 34Max ECD() at the shoe kgm3 1216 1385Complete circuit time minutes 19 42
Preflushes Spacers
Density kgm3 1000 1400Plastic viscosity (PV) cP (mPas) Cem solution 18Yield Point (YP) lbf100ft2 (Pa) 0 17(81)Total volume pumped m3 4- 5 5
Cementslurry
Cemented interval m - m 400-0 900-0 1365-900Type of cement - G GCement slurry density kgm3 1800 1500 1900Volume of cement slurry m3 19 155 9Cementmixture quantity t 225 11 12Volume of solution() m3 125 125 55Pumping flow rate dm3s 16 13 10Time of preparation and pumping slurry on string
minutes 20 20 15
Thickening time minutes 180 240 180The
displacementfluid
of cementon string
Total volume pumped m3 155 26Maximum rate of pumping dm3s 30 20Density kgm3 1150 1200Maximum pressure at the aggregatespumps
bar 33 70
Maximum ECD() at shoe kgm3 1874 1754Loss of maximum pressure in the annular
bar 36 23
The differential pressure bar 25 44Final pressure before bump plug bar 33 70The string reciprocation - Yes YesEstimated time of the whole job minutes 55 60
() The equivalent density of fluids in the annular space during circulation() The preparation solution volume of the cement slurry is calculated without reserve
103 Materials for cement slurries
No DESIGNATION OF THE ELEMENTS
MU CASING (STAGE ) TOTAL
Pag 22
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
1 Casing diameter in 9 58 7 - 2 Casing length m 400 1365 - 3 Cement G Type API t 225 11 12 455 4 Bentonite) (D020) kg - 220 - 220 5 CaCl2 (S001) - accelerator kg 790 220 - 1010 6 BDC 031 - fluid loss kg 45 - - 45 7 NF 6 (DF-740) - antifoam l 23 - - 23 8 D167 - fluid-loss kg - 55 48 103 9 D206 - antifoam l - 11 12 2310 D080 - dispersant l - - 24 24 ) Bentonite yield gt 12 m3t
For cementing operations 2 cementing pump units for the 9-58rdquo surface casing and 1 for the 7rdquo production casing are recommended
Spacer for 7 in casing (5 m3 density 1400 kgm3)- D031 (barite) = 2750 kg- D182 (spacer) = 60 kg- D206 (antifoam) = 2 l- U066 (solvent) = 125 l- F110 (surfactant) = 250 l
11 WELLHEAD amp BOP CONFIGURATION
111 Wellhead
No Casing head components
SizePressure
Casing
Primary Hanger Secondary
Pag 23
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
seal seal
- - in bar in in In
1 Casing head flange 11 x 9-58 x 210 7 7 -
2 Tubinghead 11 x 7-116 x 210 2-78 2-78 7
Wellhead 11 x 958 x 7 x 278 x 210 bar
112 BOP
BOP Rams
No Casing size
Insidediameter
Type Pressure (diameter)
Drilling RunCasing
- in in - bar in In
1 9-58 11 DF 210 0 4 0 7
11 VH 210 annular Annular
2 7 7116 DF 210 0 4 0 4
7116 VH 210 annular Annular
12 RISK ASSESSMENT
While drilling there is the possibility to appear the next difficulties (possible not necessary expected)
Partial mud losses in surface formations and Pontian Hole instability in Dacian Overpull in Pontian Increase gas content in Pontian
Pag 24
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Drilling on Colibasi (Ag) field was generally done without major difficulties The appearance of mud losses can be avoided or attenuated using recommended mud parameters
If these mud losses still appear it will be necessary to treat mud with LCM (calcium carbonate)
Drilling in gas zone involve intermediary circulations to eliminate gas from mud using low flow rate and ROP It will be avoided as much as possible the breaks of circulation
It is recommended to permanently use the mud cleaning system to maintain mud parameters
Risk assessments ndash 12 14 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Mud losses in surface formations
NPT due to low ROP and mud treatment or even cement plug
M L M
Use low MW and high vascosity mud (low ROP and flow rate if is necessary) Best practices for solving loss circulation Use LCM
L
Risk assessments ndash 8 34 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L M
Use proper mud parameters Use flow rate as per project Circulate at every 5 doubles (10 minutes) during POOH BHA
L
Unable to achieved planned DLS (630 m)
NPT due to cement plug and side track to achieve target
H M HTake survey at every joint during building trajectory and check survey after drilling every double
M
Risk assessments ndash 6 18 in Section
Potential RiskHazard
Consequence
Imp
ac
t
Pro
ba
bil
ity
Ris
k
Mitigation and Control
Re
mn
an
t R
isk
Hole CleaningNPT due to reaming overpull cavings Stuck pipe Fishing operations
M L MUse proper mud parameters Use best practices for hole cleaning Best practices for reaming and tripping
L
Pag 25
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Gas influx during drilling in P1 reservoir
NPT due to more circulation M L M
Use proper mud parameters Reduce drilling parameters if gas influx rate is high Increase mud density if gas influx is too high Perform technological brake with bit in previous casing depth to check if well is stable Reduce number of trips for avoiding suplimentary circulations Use mud logging unit for faster detection
L
Unable to maintain trajectory in P1 layer due to small thickness of layer (6-7 m)
NPT due to side track operations
H M H
Wersquoll use near bit inclination and GR azimuthal to keep trajectoty in P1 layer During drilling 6 18rdquo section wersquoll have a geologist with high experience about Colibasi Structure
M
Offset wells
Pag 26
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Pag 27
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Pag 28
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
13 SEQUENCE OF OPERATIONS
1531 Colibasi DWOPNo
Phase Operation Steps
Depth Plan
[m] [hrs] cum [d]
1
12-1
4rdquo
sect
ion
Prepare to start drilling 0 40 02
2 Drill with 12-14 bit adding 8rdquo+612 DCrsquos circulate mud to clean hole
50 80 05
3 POOH to surface 50 10 05
4 RIH BHA with 3 stabilizers to 100m possible reaming circulate 50 20 06
5 Drill with 12-14 bit adding 6-12rdquo DCrsquos circulate mud to clean hole 400 440 25
6 IF IS NECESSARY -Wiper trip for gauging hole circulate 400 40 26
7 POOH to surface LD 8 DCs 400 60 29
8 Run 9-58rdquo casing to 400m 400 80 32
9 Cementing job 400 30 33
10 WOC 400 80 37
11 NU BOPrsquos 400 160 43
12 Test (pressure amp function) BOP 400 40 45
13
8-3
4rdquo
sec
tio
n
Spud works for resume drilling make up 8-34 PDC bit amp PDM + MWD+LWD RIH mill float collar plugs float valve cement and float shoe mud treatment
400 130 50
14
Drill vertical with 8 34 bit and PDM + MWD to 450 m circulate mud POOH 450 50 53
15 MU BHA with PDM (15 bent sub) + MWD + LWD RIH to 450 m circulate drill to 850 m (KOP) circulate mud to clean hole
850 460 72
16 Wiper trip to 400 m for gauging bore hole 850 60 74
17 RIH BHA to 850 m circulate mud drill with directional BHA to 1150 m
1150 280 86
18 Wiper trip to 800m for gauging bore hole 1150 50 88
19 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1285 180 95
20 Drill directional with 8-34 PDC bit amp PDM + MWD + LWD till 1285 m circulate mud to clean hole
1365 200 104
21 POOH to surface with circulating at every 5 doubles LD PDM 1365 80 107
22MU BHA with 2 stabilizers at bit and 10 m and MWD and RIH Circulate mud at 400 m 1000 m RIH with circulation and rotation till 1365 m POOH to surface with circulating at every 5 doubles
1365 200 115
23 Run 7rdquo casing to section TD circulate 1365 160 122
24 Cementing job 1365 60 125
25 WOC 1365 120 130
26 NU BOPrsquos 1365 160 136
27 Test (pressure amp function) BOP 1365 20 137
28
6-1
8rdquo
se
ctio
n
Spud works for resume drilling make up 6-18 RB amp PDM + MWD + LWD 4-34 DCs 4 HWDP and DP RIH mill float collar plugs float valve cement and float shoe mud treatment
1365 180 145
29 Drill directional with 6-18 RB amp PDM circulate mud to clean hole 1500 320 158
Pag 29
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
30 Wiper trip to 1300 m for gauging hole circulate possible overpull amp reaming
1500 60 160
31 Test (pressure amp function) BOP 1500 20 161
32 Drill directional with 6-18 RB amp PDM to final TD circulate mud to clean hole
1599 200 170
33
POOH BHA to 7 casing shoe POOH to 1000 m with circulating at every 5 doubles on interval 1365 m - 1000 m RIH with circulation and rotation to 1599 m POOH with circulation at every 5 double on interval 1360 m - 1000 m POOH to surface with LD directional BHA
1599 200 178
34 Run 4-12rdquo liner to TD 1599 180 185
35 Circulate mud set liner hanger and packer at TOL POOH and LD liner running tool
1599 120 190
36 ND BOP MU tubinghead NU rams preventer 1599 80 194
37 Test (pressure amp function) BOP 1599 20 195
38 Pick up amp RIH 3 12 tubing with 7 inflatable packer to 1250 m displaced NAF with brine set packer
1599 160 201
39 Set tubing in tubing head ND rams preventer NU X-tree pressure test
1599 60 204
40 Ending works 1594 80 207
12-14rdquo section 1080 45
8-34rdquo section 2210 92
6-18rdquo section 1680 70
TOTAL WELL 4970 207
Pag 30
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
14 WELL MONTAGE
Pag 31
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Pag 32
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
Pag 33
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-
OMV PETROM
15 APPENDICES
Appendix 1 DWOP
Appendix 2 Drilling fluid technical offer
Appendix 3 Directional Program
Appendix 4 ndash BHArsquos and Hydraulics Summary
Pag 34
- 5 DIRECTIONAL PROGRAM
- 6 DRILL STRING
- 7 MUD PROGRAM
- 71 Mud parameters
- G
- G
-
- 111 Wellhead
-
- 14 WELL MONTAGE
- 15 APPENDICES
-