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