Mahari - 1 Drilling Program

SSECTIONECTION 11

PPLANLAN SSUMMARYUMMARY

1

Maharvi – 1 Drilling ProgramMaharvi – 1 Drilling Program

1) Executive Summary1) Executive Summary

MAHARVI – 1 is an exploratory well in the Maharvi Concession. The objective of this well is to test the SaltRange Formation / Khewra Sandstone with the well to be drilled to a Target Depth of 7,300ft-RT or 200 ft inside “Basement” (whichever is shallower)

Spudded with the 12¼ bit, the well will be drilled to 1917ft-RT in the first hole section. This section will be cased with 9⅝ casing and cemented to the surface. After the casing/cementing job, 11 x 9⅝ 5K SOW wellhead will be installed.

The final phase will be drilled with 8½ hole to the T.D at 7,300ft-RT. This section will be drilled to test the potential of Salt Range Formation / Khewra Sandstone and will be logged as per the logging program. Decision to run 7 casing will be based on the E-log results, open hole testing and hydrocarbon shows. 8½ hole will be cased with 7 casing followed by cementation job to the surface. After cementing 7 casing hanger will be landed inside 9⅝ Casing Head Housing & 11 5K x 11 5K Tubing spool will be installed.

After running 7 casing, completion will be run, X-mass tree installed and pressure tested. The well will then be perforated and tested as per program.

In the event well has to be abandoned, appropriate abandonment procedure will be set in place as per the guidelines in the Plug and Abandonment section of this Program.

The well will be drilled and completed so that oil & gas production may commence as soon as possible.

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SSECTIONECTION 22WWELLELL SSYNOPSISYNOPSIS

3


WELL MAHARVI – 1

CLASSIFICATION Exploratory

LOCATION Line 2007 - MRV - 07, SP 1574

CO-ORDINATES Latitude 29° 51' 32.9817" N Longitude 72° 55' 55.7589" E

ELEVATION RT 506 ft. (AMSL)GL 476 ft. (AMSL)

EASTINGNORTHING

3219437.00 E 632898.90 N

CONCESSION AREA Maharvi E.L.

PROSPECT TYPE Tilted Fault block

REFERENCE SYSTEM Everest 1830 (Pakistan) Ellipsoid. Lambert Projection – India Zone I

PROGNOSED T.D 7300 ft RT (6794 ft SS) or 200 ft inside “Basement” (whichever is shallower)

OBJECTIVE SaltRange Formation / Khewra Sandstone.

AREAL CLOSURE 4895 Acres18317Acres

VERTICAL CLOSURE 100 ft

RIG OUTFIT TO BE DEPLOYED Global Drilling GD-1.

COMPLETION OF DRILLING ± 20 Days after spud in (excluding 7” Casing & Cmt)

RESPONSIBILITY OF EXECUTION OPII Drilling Department

2) WELL SYNOPSIS2) WELL SYNOPSIS

4


SSECTIONECTION 33GGEOLOGYEOLOGY

5


7 0 0 0

5 0 0 0

4 0 0 0

3 0 0 0

AG

E

FO

RM

AT

ION

DE

PT

H I

N

LIT

HO

LO

GY

CA

SIN

G

WIR

EL

INE

WE

IGH

T

FE

ET

(R

T)

R E M A R K S

B A S E M E N T

M A H A R V I - 1P R O G N O S E D S E C T I O N

M A H A R V I B L O C K

6 0 0 0

2 0 0 0

G L : 4 7 6 F T

1 0 0 0

T D . 7 , 3 0 0 F T R T ( 6 7 9 4 F T S S )

1 9 1 7 '

SA

LT

RA

NG

E (

21

65

')

( 2 9 8 ' + )P R E - C A M B R I A N

2 0 8 4 '

2 2 1 2 '

2 6 6 1 '

3 1 5 4 '

3 3 8 0 '3 4 2 6 '

3 6 8 8 '

4 8 3 7 '

SIW

AL

IKS

(+1

88

7')

NE

OG

EN

E

N A M M A L ( 1 6 7 ' )S A K E S A R +E O C E N E

D A T T A ( 1 2 8 ' )E - J U R A S S I C

S A R D H A I ( 4 4 9 ' )

W A R C H H A ( 4 9 3 ' )

D A N D O T ( 2 2 6 ' )

T O B R A ( 4 6 ' )

J U T A N A ( 2 6 2 ' )

K H E W R AK U S S A K +

( 1 1 4 9 ' )

PE

RM

IAN

CA

MB

RIA

NIN

FR

A C

AM

BR

IAN

7 0 0 2 '

X X X X X X X X X XX X X X X X X X X XX X X X X X X X X XX X X X X X X X X XX X X X X X X X X X

v v v v v v v v v

v v v v v v v v v

v v v v v v v v v

D O M I N A N T L Y S A N D S T O N E W I T H I N T E R C A L A T I O N O F C L A Y S T O N E .

D O M I N A N T L Y L I M E S T O N E W I T H T H I N B E D S

C L A Y S T O N E W I T H I N T E R C L A T I O N

D O M I N A N T L Y S A N D S T O N E W I T H

S A N D S T O N E W I T H T H I N B E D S O F C L A Y S T O N E .

D O M I N A N T L Y E V A P O R I T E S( D O L O M I T E , A N H Y D R I T E A N D S A L T ) W I T H T H I N B E D S O F C L A Y A N D S A N D S T O N E .

D O M I N A N T L Y S A N D S T O N E W I T H C L A Y S T O N E


P R E D O M I N A N T L Y D O L O M I T E

S A N D S T O N E W I T H I N T E R C A L A T I O N O F

I G N E O U S B A S E M E N T .

O F C L A Y S T O N E .

O F S A N D S T O N E

I N T E R C A L A T I O N O F C L A Y S T O N E .

L I M E S T O N E , T H I N B E D S O F S I L T S T O N E A N D D O L O M I T E .

R T : 5 0 6 F T

9-5

/8"

CA

SIN

G @

19

17

FT

RT

LO

GG

ING

BH

C-G

R

DL

L-M

SF

L-B

HC

-GR

-SP

LD

L-C

NL

-NG

S,

SH

DT

-GR

N O T E : T D W I L L B E 7 3 0 0 F T R T O R 2 0 0 F T I N S I D E B A S E M E N T ( W H I C H E V E R I S S H A L L O W E R )L E G E N D

V

A N H Y D R I T E

S H A L E

L I M E S T O N E

S I L T S T O N E

D O L O M I T E

S A N D S T O N E

S A L T

C L A Y S T O N E

V V V

V V V V

I G N E O U S

X X X XX X X XX X X X

MU

D

v v v v v v v v v

v v v v v v v v v

v v v v v v v v v

v v v v v v v v v

v v v v v v v v v

8-1

/2"

HO

LE

TO

BE

DR

ILL

ED

TO

TD

OP

TIO

NA

L 7

" C

AS

ING

TO

BE

RU

N I

F R

EQ

UIR

ED

9 - 1 0

9 - 1 0

SA

LT

SA

TU

RA

TE

D M

UD

TO

BE

US

ED

P

P

P

(PP

G)

P R I M A R Y O B J E C T I V EP

L A T : 2 9 ° 5 1 ' 3 2 . 9 8 1 7 " NL O N G : 7 2 ° 5 5 ' 5 5 . 7 5 8 9 " E

S

S

S E C O N D A R Y O B J E C T I V ES

3.1) PROGNOSED SECTION3.1) PROGNOSED SECTION

6


3.2) PROGNOSIS SUMMARY3.2) PROGNOSIS SUMMARY

RT: 506 ft (AMSL)GL: 476 ft (AMSL)

Age FormationTop - RT

(Ft)Top - SS

(Ft)Thickness

(Ft)

NEOGENE SIWALIKS Surface +476 +1887

EOCENESAKESAR + NAMMAL

1917 1411 167

E.JURASSIC DATTA 2084 1578 128

PERMIAN

SARDHAI 2212 1706 449

WARCHHA2661 2155 493

DANDOT3154 2648 226

TOBRA3380 2874 46

CAMBRIAN

JUTANA3426 2920 262

KUSSAK + KHEWRA 3688 3182 1149

INFRA -CAMBRIAN

SALT RANGE

4837 4331 2165

PRE -CAMBRIAN

BASEMENT7002 6496 298+

TD 7300 6794

NOTE:

T.D. will be 7300 ft RT or 200 ft inside “Basement” (whichever is shallower).

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3.3) FORMATION CHARACTERISTICS 3.3) FORMATION CHARACTERISTICS

3.3.1) RECENT – SIWALIKS : ( Surface – 1917 ft RT )

Recent: ( Surface – 830 ft )The Lithology consists dominantly of loose Sand with Clay.

Rawalpindi Group: ( 830 – 1917 ft RT )

Lithology

The Lithology typically consists of red Claystone with Sandstone. At the base which is overlain by thick Sandstone and Claystone with minor Limestone. Rawalpindi group is anticipated at 830 ft. The thickness of the Limestone encountered at the Top of this group is 50 m at Marot # 1 and 20 m at Bahawalpur East # 1.

Sandstone:

Light brown, clear, white, pale yellow, fine to medium grained, i/p coarse grained, angular to subangular, unconsolidated to consolidated, i/p sorted, calcareous cement, micaceous.

Claystone:

Medium to light brown, grey, soft, swell, calcareous..

Siltstone:

Reddish brown, buff, greenish grey, calcareous cement.

Limestone:

Off white, light grey, moderately hard, microcrystalline.

SAKESAR AND NAMMAL FORMATION : ( 1917 – 2084 ft RT ) 3.3.2) SAKESAR FORMATION:

Lithology

8


At type locality the formation consists dominantly of Limestone with subordinate Marl. The Limestone is cream coloured to light grey, nodular, usually massive with considerable development of Chert in the upper part. The Marl is cream coloured to light grey.

At Bahawalpur East #1 and Marot #1 the lithology encountered is as follows:

Limestone:

White, off white, yellowish brown, occasionally brown, microcrystalline, chalky, argillaceous, moderately hard to hard, traces fossils, Packstone.

Clay stone:

Light brown, green, buff, bluish grey, i/p grey, sticky, firm, amorphous, blocky, silty, calcareous..

Marl:

Light grey, moderately hard..

3.3.3) NAMMAL FORMATION:

LithologyAt type locality the formation consists alternation of Shale, Marl and Limestone. The Shale is grey to olive green, while the Limestone and Marl are light grey to bluish grey. The Limestone is argillaceous in places.

The Lower part of the formation is composed of bluish grey Marl with subordinate interbedded calcareous Shale and minor Limestone. The upper part consists of bluish grey to dark grey Limestone with intercalation of Marl and Shale.

At Bahawalpur East # 1 and Marot #1 the lithology encountered is as follows :

Claystone:

Dark grey, green, light grey, olive green, soft, traces pyrite, calcareous, non swell..

Marl:

Off white, brown, soft, sticky.

Siltstone:

Grey, off white, moderately hard, calcareous, argillaceous, mic..

ContactThe Upper contact with Sakessar Limestone is transitional..

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EARLY JURASSIC

3.3.4) DATTA FORMATION: (2084 – 2212 ft RT )

Lithology

At type locality the formation is mainly of continental origin and consist of varigated (red, maroon, grey, green and white) Sandstone, Shale, Siltstone and Mudstone with irregularly distributed calcareous, dolomitic, carbonaceous, ferruginous glass Sand and fireclay horizons. Fireclay is normally present in the Lower part while the upper part includes a thick bed of maroon Shale.

At Bahawalpur East # 1 and Marot #1 the lithology encountered is as follows :

Limestone: Grey, off white, clear, fine to medium grained, angular to subangular, i/p subrounded, sorted, lig streaks, calcareous cement.

Claystone / Shale: Reddish brown, dark grey, chocolate brown, soft to hard, calcareous, silty, sticky, i/p amorphous, (org).

Siltstone:

Grey, moderately hard, calcareous, micaceous..

PERMIAN3.3.5) SARDHAI FORMATION: (2212 – 2661 ft RT )

LithologyAt type locality the formation is composed of bluish and greenish grey Clay, with some minor Sand and Siltstone beds. It also contains some carbonaceous Shale. The Clay

10


predominantly displays Lavender colour. Minor chert and gypsum are found dissiminated in the formation with occasional calcareous beds in the upper part of it.

At Bahawalpur East #1 Sardhai Formation predominantly composed of Sandstone..

Sandstone:

Grey, dark grey, green, occasionally yellow, clear, fine to medium grained, i/p coarse grained, angular to subangular, quartz, calcareous cement, glauconitic, sorted.

Claystone:

Olive green, grey, firm, calcareous, non swell..

3.3.6) WARCHHA SANDSTONE: (2661 – 3154 ft RT )

LithologyThe formation consists of medium grained Sandstone, conglomeratic in places and has interbeds of Shale / Claystone.

Sandstone:

Clear, translucent, light brown, fine to medium grained, angular to sub rounded, moderately sorted, calcareous cement. At type locality it is red, purple or shows lighter shades of pink, arkosic, the pebble of the unit are mostly of pink colour and of quartzite..

Claystone:

Dark brown, dark grey, green, reddish brown, moderately hard to firm, calcareous, non-swell, (pyr), silty..

ContactThe Warchha Sandstone conformably overlies the Dandot Formation.

3.3.7) DANDOT FORMATION: (3154 – 3380 ft RT )

Lithology

The formation consists of light to dark grey, olive green, yellowish Sandstone with occasional thin pebbly beds and subordinate dark grey and greenish splintery Shales.

11


Sandstone:

Dark grey, fine grained, angular to subangular, sorted, argillaceous.Boulder Bed: dark grey, Clayey matrix, firm, non calcareous, Sandy..

Claystone / Shale:

Dark grey, green, i/p brown, i/p silty, i/p calcareous.The formation has a gradational contact with the underlying Tobra Formation and is terminated in sharp but conformable contact with the overlying Warchha Sandstone.

3.3.8) TOBRA FORMATION: (3380 – 3426 ft RT )

Lithology

The formation consists of marine Sandstone, alternating facies of Siltstone and Shale.At

Bahawalpur East # 1 and Marot #1 the formation dominantly consists of Sandstone.

Sandstone:

Dark grey, fine grained, angular to subangular, sorted, argillaceous.Boulder Bed: dark grey, Clayey matrix, firm, non calcareous, Sandy.

CAMBRIAN

3.3.9) JUTANA FORMATION: (3426 – 3688 ft RT )

Lithology

The Lower part of the formation consists of light green, hard, massive, partly Sandy Dolomite and the upper part is composed of light green to dirty white massive Dolomite.

Dolomite:

Light brown, grey, hard, cryptocrystalline, Sandy.The formation is conformably underlain by the Kussak Formation.

KUSSAK AND KHEWRA FORMATION: (3688 – 4837 ft RT )

3.3.10) KUSSAK FORMATION:Lithology

12


The formation is composed of Sandstone and Siltstone, with minor light grey Dolomite, pink Gypsum lenses may be present near the Top.

Sandstone:

Brown, greenish grey, yellow, clear, i/p light brown, i/p translucent, fine grained, angular to subangular, i/p dol, moderately sorted to sorted, i/p glauconitic, i/p micaceous, i/p argillaceous.

Siltstone: Brown, greenish grey, dolomitic, pyrite.parts, slightly to non calcareous, silty in parts, occasionally grades to siltstone, traces of pyrite.

3.3.11) KHEWRA SANDSTONE:Lithology

The formation consists predominantly of purple to brown, yellowish brown, fine grained Sandstone and Siltstone. The Lower most part of the formation is red, flaggy shale with minor Siltstone.

Sandstone:

Purple to brown, yellowish brown, fine grained.

Shale / Claystone:

Reddish brown, non calcareous, non-swell, silty..

Siltstone:

Reddish brown, off white, firm to hard, i/p dolomitic.

INFRA CAMBRIAN

3.3.11) SALT RANGE FORMATION: (4837 – 7002 ft RT )

Lithology

The Lower part of SaltRange Formation is mainly composed of Marl with Salt, Sandstone and Claystone while the beds of Dolomite, Anhydrite, Limestone, Siltstone and Shale are the constituents of the Upper part.

Dolomite:

13


White, creamy, grey, off white, i/p green, i/p light grey, i/p light brown, massive, hard, i/p moderately hard to hard, blocky, microcrystalline, argillaceous, chalky, dense, i/p suc,i/p calc cmt, loc vuggy.

Limestone:

Light brown to brown, off white, grey, i/p light grey, firm to moderately hard, argillaceous, microcrystalline, stromatolitic filaments, dolomitic, Mudstone.

Claystone:

Off white, grey, reddish brown, bluish grey, i/p light grey, i/p green, i/p dark brown, mic, soft to moderately hard, i/p sticky, non-swell, silty, calcareous.

Sandstone:

Brown, green, reddish brown, dark brown, i/p white to off white, fine to coarse grained, angular to subrounded, micaceous, sorted, calcareous to non calcareous cement, silty, brecciated, with dolomitic streaks, ferru, lam.

Siltstone:

White, off white, dark brown to red, dark grey, friable to moderately hard, ferru, crm, i/p oolitic, moderately calcareous to calcareous cement.

Marl:

Grey, green, i/p red, dolomitic

Anhydrite :

White, off white, green, soft to firm, i/p moderately hard, i/p amorphous, chalky, occasionally Siltstone with few Anhydrite, Dolomite beds (Breccia ), i/p lam.

Salt:

Clear, occasionally translucent, i/p pink, hard to moderately hard.

Shale:

Dark grey, black, firm, crm, non calcareous, lam, (org).

PRE CAMBRIAN

3.3.12) BASEMENT: (7002 – 7300+ ft RT )

Lithology

14


These oldest rocks are composed of sedimentary, metasedimentary, metamorphic and igneous complexes. The lithology is composed of dark coloured and hard but more importantly fractured rock.

At Bahawalpur East #1 and Marot # 1 the characteristics of the formation are as follows:

Basement:

Black, dark green, hard, fractured, calc veins, chlorite, pyrite, metamorphosed basic Igneous rock, Dolerite.

15


SSECTIONECTION 44DDRILLINGRILLING & & CCASINGASING

16


Top of 7 Liner @ ± 7,300 ft , ± 300 ft Liner Lap

7 29 ppf TPCQ pin X Box casing Shoe @ ± 7,300 ft ,

17


4.1) Planned Well Schematic4.1) Planned Well Schematic

8½ Hole ± 9,709 ft

9⅝ Top of cement

16 Line Pipe Conductor @ 60 - 80 ft

12¼ Hole ± 1,917 ft

8½ Hole ± 7,300 ft

9⅝ Casing 47 PPF, L-80, BTC, Shoe @ ± 1,917 ft

Maharvi – 1 DrillingMaharvi – 1 Drilling

ProgramProgram

4.2) Drilling Montage4.2) Drilling Montage

18

Maharvi – 1 DrillingMaharvi – 1 Drilling

ProgramProgram

vv

v vv v

v vv v

v v

7 0 0 0

6 0 0 0

5 0 0 0

4 0 0 0

3 0 0 0

2 0 0 0

1 0 0 0

D E P T H

( F T - R T )

L I T H O L O G Y

P R O G .

C A S I N G / L I N E RS H O E D E P T H

D R I L L I N G T I M E D E P T H C U R V E

0 1 0 2 0 3 0 4 0 5 0N U M B E R O F D A Y S

G L : 4 7 6 ' ( A M S L )

F O R M A T I O NA G EA C T U A L

M A H A R V I X - 1

P R O G N O S E D

T O P

( F T - R T )

R T : 5 0 6 ' ( A M S L )D R I L L I N G M O N T A G E

A C T U A L

T O P S

S P U D D A T E :

0 1 0 2 0 3 0 4 0 5 0

( F T - R T )

L O G G I N G

P R O G N O S E D A C T U A LS A M P L E

( F T - R T )

S C A L E : 1 : 6 0 0 0M A H A R V I X - 1

A C T U A L

L I T H .

C O L U M N

F O R M A T I O N

K A R A M P U R - 1 ( W E L L S U M M A R Y )

B I TD A T A

( F T - K B )

LIN

ER

SH

OE

DE

PT

H

CA

SIN

G

( P P G )W E I G H T

M U D

A G E F M - 12 6 ' 'O S Q - 2 ( 1 B I T U S E D )

2 . 7 5 H R7 7 . 1 F T /H R

T D . 9 , 9 6 1 ' K B

+ C O M P L E T I O N & T E S T I N G

DL

L-M

SF

L-B

HC

-GR

-SP

L

DL

-CN

L-N

GS

, SH

DT

-GR

W I R E L I N E L O G G I N G + 9 - 5 / 8 " C A S I N G J O B + W O R K O N W E L L H E A D .

T D W I L L B E 7 3 0 0 F T R T O R 2 0 0 F T I N S I D E B A S E M E N T ( W H I C H E V E R I S S H A L L O W E R )

NE

OG

EN

E

SIW

AL

IKS

(+1

887'

)

N A M M A L ( 1 6 7 ' )S A K E S A R +E O C E N E

D A T T A ( 1 2 8 ' )E - J U R A S S I C

PE

RM

IAN

S A R D H A I ( 4 4 9 ' )

W A R C H H A ( 4 9 3 ' )

D A N D O T ( 2 2 6 ' )

T O B R A ( 4 6 ' )

CA

MB

RIA

N

J U T A N A ( 2 6 2 ' )

K H E W R AK U S S A K +

( 1 1 4 9 ' )

SA

LT

RA

NG

E (

2165

')

INF

RA

CA

MB

RIA

N

B A S E M E N T ( 2 9 8 '+ )

P R E - C A M B R I A N

9-5/

8" C

AS

ING

@ 1

917

FT

RT

1 9 1 7 '

2 0 8 4 '

2 2 1 2 '

2 6 6 1 '

3 1 5 4 '

3 3 8 0 '3 4 2 6 '

3 6 8 8 '

4 8 3 7 '

7 0 0 2 '

v vv v

v vv v

v vv v v

v v v

X X X X XX X X X XX X X X XX X X X XX X X X X

v v v v

T D . 7 , 3 0 0 F T R T ( 6 7 9 4 F T S S )

BH

C-G

R

P

P

P

N E

O G

E N

E -

Q U

A T

E R

N A

R Y

S I

W A

L I

K S

(+

1481

')

E O C E N E

M E S . J U R ?

P E

R M

I A

N

P R

E -

C A

M B

R I

A N

PU

NJA

B S

AL

INE

SE

RIE

S (

2900

')

C A

M B

R I

A N

PU

RP

LE

S.S

TS

.ST

MA

GN

AS

IAN

PS

EU

DO

-M

OR

PH

S (

?)

SA

LT

MID

DL

E P

RO

DU

CT

BE

DS

(48

2')

(34

8')

1 4 9 9 '

2 7 6 9 '

3 2 5 1 '

3 5 9 9 '

5 1 7 0 '

5 6 4 3 '

6 9 0 0 '

9 8 0 0 '

13-3

/8"

CA

SIN

G @

198

3.1

FT

7" C

AS

ING

@ 7

205.

6 F

T9-

5/8"

CA

SIN

G @

600

0.7

FT

S I

W A

L I

K S

R

A W

A L

P I

N D

I Z

AL

UC

H /

NIL

AW

AH

AN

(1

571)

BA

GH

AN

-W

AL

A (

473

)K

US

SA

KK

HE

WR

AJ H

E L

U M

(12

57)

JUT

AN

A

SA

LT

RA

NG

E

BA

SE

ME

NT

(161

' +)

BA

SE

ME

NT

V V VV

V V VVV V VV

VV VV

VV VVVV V VVV VV

V V V VV V V VV V V V

F M - 2

M U

R R

E E

(12

70')

T D . 7 , 3 0 0 F T R T ( 6 7 9 4 F T S S )

1 2 - 1 / 4 " H O L E

F T - D R I L L E D ( 2 1 2 ' )

1 7 - 1 / 2 ' 'O S C - 3 ( 1 B I T U S E D )

3 7 . 7 5 H R4 7 F T /H R

F T - D R I L L E D ( 1 7 7 4 ' )

1 2 - 1 / 2 ' 'O S C - 3 J ( 4 B IT S U S E D )

8 2 . 2 5 H R3 8 . 2 F T /H R

F T - D R I L L E D ( 3 1 4 3 ' )

1 2 - 1 / 2 ' 'O S C - J ( 2 B I T S U S E D )

3 2 . 5 0 H R1 5 . 9 F T /H R

F T - D R I L L E D ( 5 1 8 ' )

1 2 - 1 / 2 ' 'O S Q - 2 J ( 1 B I T U S E D )

1 5 . 5 0 H R1 9 . 6 F T /H R

F T - D R I L L E D ( 3 0 4 ' )

8 - 1 /2 "O S C - 3 J ( 2 B IT S U S E D )

1 8 . 7 5 H R2 9 . 8 F T /H R

F T - D R I L L E D ( 5 5 8 ' )

8 - 1 /2 "O S C - J ( 3 B I T S U S E D )

4 0 H R1 3 . 6 F T /H R

F T - D R I L L E D ( 5 4 4 ' )

8 - 1 /2 "O S Q - 2 J ( 1 B I T U S E D )

8 . 2 5 H R5 . 1 F T / H R

F T - D R I L L E D ( 4 2 ' )

8 - 1 /2 "O W S - J ( 7 B I T S U S E D )

6 9 . 2 5 H R3 . 9 F T / H R

F T - D R I L L E D ( 2 7 2 ' )

8 - 1 /2 "O W V - J ( 6 B I T S U S E D )

7 1 H R5 . 7 F T / H R

F T - D R I L L E D ( 4 0 2 ' )

8 - 1 /2 "O W C - J ( 8 B I T S U S E D )

9 8 . 2 5 H R8 . 6 F T / H R

F T - D R I L L E D ( 8 6 0 ' )

8 - 1 /2 "W 7 R ( 2 8 B IT S U S E D )

2 8 8 .7 5 H R4 . 2 F T / H R

F T - D R I L L E D ( 1 1 9 0 ' )

8 - 1 /2 "R 1 ( 1 B IT U S E D )

4 . 5 H R1 . 6 F T / H R

F T - D R I L L E D ( 7 ' )

1 09 . 4 3

1 0 . 8

9 . 4

8 0 0 0

L E G E N D

V

A N H Y D R I T E

S H A L E

L I M E S T O N E

S I L T S T O N E

D O L O M I T E

S A N D S T O N E

S A L T

C L A Y S T O N E

V V V

V V V V

I G N E O U S

X X X XX X X XX X X X

P R I M A R Y O B J E C T I V EP

P R O G N O S E D

P R O G N O S E D

F M - 1 ( F R O M C O M P O S I T E L O G )F M - 2 ( F R O M S U M M A R Y C H A R T )

8 - 1 / 2 " H O L E

W I R E L I N E L O G G I N G + 7 " L I N E R / C A S I N G ( O P T I O N A L )

S

S


CENTRAL INDUS BASINMAHARVI BLOCK

MAHARVI - 1DRILLING MONTAGE

RT = 506’ (AMSL)GL = 476’ (AMSL)

19

4.3) GENERAL DRILLING INSTRUCTIONS4.3) GENERAL DRILLING INSTRUCTIONS

Hold pre-spud meeting

Prior to spud in, ensure that the conductor is correctly aligned & centered below the rig rotary table to prevent offset casing wear.

Maintain at least 500 bbls of 12 ppg (appropriate kill mud) in reserve at all times commencing from spud. Maintain hole verticality as straight as possible. If necessary ream hole section repeatedly to reduce angle. Survey frequency should be increased if hole deviation becomes a problem. Time spent on drilling with low weights and reaming to reduce angle would prevent problems with casing wear in later stages.

All casing strings must be hung in tension to reduce the effect of helical buckling on the casing. The slips should be set with ± 70% of casing hanging weight in mud.

Maximum internal test pressure to be applied to any casing string must not exceed 65% of the casing burst rating taking into consideration the fluids inside and outside the casing string.

Maximum external test pressure to be applied to any casing string must not exceed 75% of the rated collapse pressure. These ratings can only be increased after specific instructions received from head office.

Drill pipe-casing protector must be used during drilling 8½ hole section. At no time should drill pipe fitted with protector be allowed to enter into open hole.

Extreme care should be taken at all times while tripping. Swab/surge pressures can cause serious problems, especially when a delicate balance between losses and inflows exist. Consequently during critical conditions, swab/surge pressure, pulling/running speeds must be determined and used as a guide in these situations.

Regular well control drills should be carried out from below the 9⅝ casing shoe. These drills should be noted in the IADC drilling reports & proper record maintained at the rigsite.

During all long string cement jobs, every precaution must be taken to prevent cement from hardening in the wellhead sections. Immediately after displacing cement, the wellhead sections must be thoroughly flushed out to remove any excess cement displaced or channeled to the surface.

SCR should be recorded as per directions in section 7.1.

Work instructions should be issued in written form to drilling contractor and other service personnel. A proper record to be maintained at the rig site of such documents.

It would be appreciated if good drilling practices are followed with special emphasis on safety measures.


20

4.4) 12 ¼4.4) 12 ¼ HOLE (SURFACE TO ± 1,917 ft) HOLE (SURFACE TO ± 1,917 ft)

4.4.1) SECTION OBJECTIVE

The main objective of the 12 ¼ section is to set a competent casing string to provide well control for the continuation of the drilling to the next casing seat. The other objective is to isolate surface aquifers and seal off the loose / top sediments of Siwaliks.

4.4.2) DRILLING 12 ¼ HOLE Carry out full inspection of rig in accordance with the checklist available with the

Company Man and rectify all shortfalls.

Check that the conductor pipe is centralized.

Prepare spud mud. Install cellar-jetting system. Before spud in of the well check entire mud hook up.

Nipple up the bell nipple and flow line.

Function test rig components & pressure test H.P lines at 3500 psi.

M/u and rack back stands of DC’s & 5” HWDP’s required for the BHA, & around 75 stands of 5” DP’s in derrick.

Arrange pre-spud meeting to be chaired by Senior OPII representative. All the aspects of the well operations and materials to be thoroughly discussed and recorded.

Spud in well, drill initial 100 ft with low rpm and flow rate.

Drill 12 ¼ hole down to ± 1,917 (9⅝ casing shoe depth).

Drill hole with lightweight on bit to ensure vertical hole.

Circulate out Hi-Vis pills to ensure hole cleaning as required.

Take deviation survey after every 250 interval and on bit change depending upon hole condition.

At the Section T.D. sweep hole with Hi-Vis pill and spot 20 bbls Hi-Vis pill at bottom.

POOH for casing.

Rig up and run 9⅝ casing. Carry out cement job as per program. Complete work on wellhead and pressure test all pressure control equipment.


21

4.4.3) INSTRUCTIONS WHILE DRILLING 12¼ HOLE

Keep the mud rheology and pumping rate to effectively lift the cuttings to surface.

Continuously run solids removal equipment in order to effectively control mud rheology including mud weight in order to minimize loading of mud with solids and to minimize possibilities of losses, cavings & washouts.

4.4.4) RUNNING 9⅝ CASING

R/UP to run casing and hold pre job safety meeting.

Run 9⅝ casing.

Carry out cement job as per program.

Cut conductor casing.

If needed, carry out top cement job so that the wellhead area is properly anchored and sealed.

Wait on cement 06 Hrs.

If the cement does not appear on surface, conduct Top Cement Job.

Cut 9⅝ casing. Install & weld wellhead and pressure test weldment at ±1000 psi.

N/UP, function and pressure test 13⅝ BOP stack.

Install wear bushing.

4.4.5) INSTRUCTIONS FOR 9⅝ CASING JOB

Prior running in casing, condition mud and circulate till shale shakers are free from cuttings.

Prior running in casing drift and visually inspect each joint on rack for any damaged threads. Measure casing on rack, make up float shoe and install stop collars on the rack.

Thread-lock shoe with first casing joint.

Fill up casing string with mud after every 2 to 3 joints. Monitor and record hook load before and after filling casing with mud.

While running in casing avoid shock load to casing string and cautiously land the string in slips.


22

Adjust casing tally prior to running in hole to avoid coupling at casing cutting point.

Slack 2 – 5T weight on sting in adapter.

Circulate through stinger to check any leakage from 9⅝ x 5 annulus prior to start pumping cement slurry.

Chain down casing and drill pipes to avoid floating action.

Install centralizers as per casing program.

Check wellhead and 7 casing hanger profile for any damage etc. prior to installation.

After WOC cut and dress 9⅝ casing joint. Weld and pressure test weldment of 9⅝ x 5K casing head housing at 1000 psi.

Complete work on wellhead, N/UP BOP and all pressure control equipment. Pressure test as per details mentioned in Section 8.

Time spent on wellhead should be reduced by efficient planning and preparation.

Install wear bushing prior to RIH with 8½ bit.


23

4.4.6) WH & BOP STACK– AFTER PHASE – 1


Casing Head Assembly11 5K Top x 9⅝ SOW Btm

Cross over Spool13⅝ 10K Top x 11 5K Btm

Mud Cross13⅝ 10K Top x 13⅝ 10K Btm

Lower Pipe Ram 10K

Blind Ram 10K

Upper Pipe Ram 10K

Annular BOP 5K

Flow Riser

24

4.5) 8½4.5) 8½ HOLE (± 1,976 ft TO ± 7,300 ft) HOLE (± 1,976 ft TO ± 7,300 ft)

4.5.1) SECTION OBJECTIVE

The objective of this section is to case off the SaltRange Formation / Khewra Sandstone, which will enable to control the properties of mud system in the reservoir section. Well directionality is critical in this section and all surveys will be plotted and verified to ensure the well bore positional uncertainty places it in the target area.

4.5.2) DRILLING 8½ HOLE

RIH with 8½ PDC bit with stabilized BHA to top of 9⅝ casing shoe and test casing at 1500 Psi (SAP).

Drill out cement/shoe and cement in rat hole.

Pump 20 bbls of water ahead and displace spud mud with KCl PHPA polymer mud.

Drill out new formation to 1,986 ft. Pull back to shoe, rig up cementing unit for formation integrity test (FIT). Make sure that mud is properly homogenized before conducting FIT.

Conduct FIT at 12ppg EMW.

Apply lower drilling parameters while stabilizers are inside the casing.

Pump Hi-Vis pills to ensure hole cleaning after drilling every 2-3 stands or as required.

Conduct deviation survey after every 250 / 500 ft and on bit change depending upon hole condition.

At section T.D. ± 7,300 ft sweep hole with a Hi-Vis pill.

Conditioning trip to be done with same BHA used in drilling.

Spot 30 bbls Hi-Vis pill at bottom prior to POOH for logging.

POOH.

Conduct logs as per program.

Retrieve wear bushing & change one set of D.P. ram with 7 casing ram.

R / u to run 7 casing.


25

4.5.3) INSTRUCTIONS FOR DRILLING 8½ HOLE

Keep the mud rheology and pumping rate to effectively lift the cuttings to surface.

Prior using PDC Bit ensure the hole is clean from any steel junk/debris etc.

Due to high rate of penetration while drilling with PDC Bit, hole cleaning is of prime importance. Therefore, observe and ream hole on connections and sweep hole with Hi-Vis after drilling every 2 to 3 stands.

Continuously run solids control equipment in order to effectively control mud rheology.

Monitor and record upward and downward over pull / drags while drilling this hole section.

4.5.4) RUNNING 7 CASING

Retrieve wear bushing from 9⅝ casing head housing.

Run casing to section T.D. and circulate. Casing not to be rotated.

Perform cement job as per cementing program.

Flush BOP’s, wellhead with water by opening side outlet valve on CHH.

N / d bell nipple and lift BOP stack.

Set slip and seal assembly as per instructions of wellhead engineer.

Cut and dress 7 casing. Use cold cutter if available.

Install and test tubing spool as per wellhead manufacturer’s specifications.

N / u BOP stack, change casing rams to DP rams and test. (Test pressure rating attached)

N / u bell nipple and the flow line.

Install wear bushing in 11 tubing spool bowl.

.


26

4.5.5) INSTRUCTIONS FOR 7 CASING JOB

Prior to running in, drift casing and visually inspect each joint on rack for any damaged threads. Measure casing on rack, make up Float Shoe, Float collar and stop collars on the rack.

Thread lock shoe, float collar and bottom three joints. Fill up the casing with mud after every 4 to 5 joints. Monitor and record hook load before and after filling casing with mud.

Calculate volumetric efficiency of mud pumps to be used for displacement.

While running in casing avoid shock load to casing string and cautiously land the string in slips.

Minimize rat hole to avoid down hole problems. For this adjust casing tally prior to running in hole.

Install centralizers as per casing program.


27

4.5.6) WH & BOP STACK – UP AFTER PHASE – 2


28


Casing Head Assembly11 5K Top x 9⅝ SOW Btm

9⅝Casing

Tubing Spool11” 5K Top x 11 5K BtmW/- NX Btm. Prep for 7 csg.

Mud Cross13⅝ 10K Top x 13⅝ 10K Btm

Lower Pipe Ram 10K

Blind Ram 10K

Upper Pipe Ram 10K

Annular BOP 5K

Flow Riser

7Casing

DSA11” 5K x 13⅝ 10K

29

4.7) BIT PROGRAMME4.7) BIT PROGRAMME

BIT SIZE DEPTH INTERVALDESCRIPTION OF

BITSQTY. NOZZLE

12¼Surf. to 1,917 ft

Mill toothIADC 117 & 217

21 x 14/32

+3 x 18/32

8½ 1,917 ft to 7,300 ft

PDC: 7 Bladed

PDC: 6 Bladed2

6 x 12/32

5 x 12/32

TCI: IADC: 517

2 3 x 14/32

6 For clean out & Drilling Optional.

Milled ToothIADC: 517/537 IADC: 117/127

23 x 14/32 &

Open


30

4.8) DRILLING PARAMETERS4.8) DRILLING PARAMETERS

Hole size WOB RPMFlow rate

(GPM)SPP (PSI)

12 ¼ (TCI) 1 – 5 60-90 200-400 100 – 1400

8 ½ (PDC) 5 – 10 70-100 400 – 500 1500 – 2500

8 ½ (TCI) 5 – 10 70-100 450 – 550 1500 – 2500


31


4.9) DRILL PIPES

OD IDGRAD

E

Wt./ft. (lbs./f

t.)

Capacity

(bbl/ft.)

Metallic Displacem

ent (bbl/ft.)

Torsional

Yield Strength (ft. lbs)

Tensile Yield Streng

th (lbs)

Torsional

Collapse

Pressure

(Psi.)

Tensile

Burst Pressure

(Psi.)

5 4.276

E-75X-95

G-105S-135

19.5 0.01776 0.0071

41, 16752, 14457, 63374, 100

395, 595501, 087553, 833712, 070

9, 96212, 02612, 99915, 672

9, 50312, 03713, 30417, 105

3 ½ 2.764

E- 75X- 95

G- 105S- 135

13.30 0.0074 0.0048

18, 55123, 49825, 97233, 392

271, 569343, 988380, 197488, 825

14, 11317, 87719, 75825, 404

13, 80017, 48019, 32024, 840

32


33


4.10) BOTTOM HOLE ASSEMBLY

Bit Size

Bit sub (with

recess)/ NB stab

DrillCollar

String Stab

Drill collar

String Stab

Drill Collar

Cross

over

Drill Collar

JarDrill Colla

r

Cross

over

HWDP

12¼ 1/1 8 x 2 1 8 x 5 - - - - 8 8 x 2 1 5 x 12

8½ 8 x 16½

NMDC x 1

8 x 16½ DC

x 28 x 1 6½ x 10 - - 6½ 6½ x 3 1 5 x 12

34


4.11) MUD PARAMETERS

Hole

size

Mud Type

Density

(ppg.)VIS

Gel10

sec/10min

Cake W/L PV YP PH % S

% Oil

12¼

Bentonite

Spud mud

8.6 - 9.2 60-70 - - - - - 8.5+ - -

8½

5% KCL –

Polymer Non

damaging

9.0 – 10.0 50-55 4-5/12-

151

Less than 5cc

18 - 2020 – 25

8.5-9.5 Min 0

Note: KCL –Polymer PHPA will be used to drill shale section upto +/- 4500 ft

Mud system will be replaced with salt saturated mud while drilling in the salt range. while drilling in the salt range

35


4.12) HAZARDS SUMMARY4.12) HAZARDS SUMMARY

Hole Size Interval Hazards Mitigation

12¼ Surface - 1,976 Loss circulation High ROP – hole pack off

LCM material Mud rheology – control

ROP high pump rates

8½ 1,976 - 7,300

Reactive shales Well Bore Stability – Stuck Drill

Pipe High ROP – hole pack off Missing geological target Hydrocarbon kick/swab kick

Inhibitive mud system (PHPA) polymer

Salt range will be drilled with slat saturated mud

Mud Type, Weight, Selection and Maintenance

Mud rheology, flow rates and controlled ROP

Surveying/ correction run

36


4.13) CASING PROGRAMME4.13) CASING PROGRAMME

Hole size

Casing OD

Specification

Cased Interval

Pressure

Test

ShoeTrack

CentralizersFloat

Equipment

12¼ 9⅝ 47 PPF, L-80, BTC

1,976 to surface 1500 Psi 2 jts 1 SB in 16 cond. 1 SB x 5 jts 1 SB on shoe jt

Float shoe –1 conventional

Float collar- 1 conventional

Plugs Top and Bottom 1 each

8½ 7 29 PPF, L-80 TPCQ

7,300 to surface 3000 Psi 2 jts

3 Rigid inside 9⅝ csg.

1 SB x 5 jts over coupling

1 SB x coupling in shoe track

1 SB on shoe jt

Float shoe –1 conventional

Float collar- 1 conventional

Plugs Top and Bottom 1 each

Note: Final Centralization program will be conveyed by the Head Office at the time of casing

37


CASING OD

SPECIFICATION

BODY YIELD

STRENGTH

(1000lbs)

INTERNAL YIELD

PRESSURE

Psi.

COLLAPSE RESISTANC

E

Psi.

9⅝47 lbs/ft

L-80BTC

1086 6870 4760

729 lbs/ft

L-80TPCQ

676 8160 7020

4.14) CASING SPECIFICATIONS4.14) CASING SPECIFICATIONS

38


SSECTIONECTION 55GDOGDO

39


40


C O N C E S S I O N A R E A :

T Y P E O F W E L L :

C O - O R D I N A T E S : D R I L L I N G R I G : G L O B A L D R I L L I N G7 2 ° 5 5 ' 5 5 . 7 5 8 9 " E

E X P L O R A T O R Y

M A H A R V I E . L .

2 9 ° 5 1 ' 3 2 . 9 8 1 7 " N

M A H A R V I B L O C K ( L O C A T I O N M A P )

S P U D E D O N :

E L E V A T I O N :

P R O G N O S E D T D .

L O C A T I O N :

R T : 5 0 6 F T ( A M S L )

L I N E 2 0 0 7 - M R V - 7 , S P 1 5 7 4

G L : 4 7 6 F T ( A M S L )

7 3 0 0 ' R T ( 6 7 9 4 ' S S )

D I S T R I C T :

P R O V I N C E :

( S C A L E : = 1 : 6 , 0 0 0 )

M A H A R V I - 1G E O L O G I C A L D R I L L I N G O R D E R

DE

PT

H I

N F

EE

T

HO

LE S

IZE

& V

OLU

ME

CA

SIN

G S

ET

TIN

G D

EP

TH

SA

ND

CE

ME

NT

PO

SIT

ION

FO

RM

AT

ION

LIT

HO

LOG

Y

CO

RE

S

W E L LC O N S T R U C -

T I O NG E O L O G I C A L D A T A

L I T H O L O G Y( D E S C R I P T I O N )

OB

JEC

TIV

ES

+ E

XP

EC

TE

D

ST

RU

CT

UR

AL

CO

ND

ITIO

NS

EX

PE

CT

ED

FO

RM

AT

ION

FO

RM

AT

ION

PR

ES

SU

RE

IN

PR

OB

AB

LE /

PO

SS

IBLE

OIL

& G

AS

SH

OW

S

PR

ES

SU

RE

S

TE

RM

S O

F M

UD

WE

IGH

T

PV

/ Y

P (

CP

S /

LB

S /

100

FT

)

PH

OIL

(%

)S

OLI

DS

(

%)

CA

KE

(M

. M)

WA

TE

R L

OS

S (

C.C

. / 3

0 M

INS

)

GE

L, 1

0 S

EC

. 10

MIN

. (LB

S/1

00F

T.)

F.

VIS

CO

SIT

Y (

SE

CO

ND

/ Q

RT

.)W

EIG

HT

(P

PG

)

TY

PE

OF

MU

D

FO

R D

RIL

LIN

G

2

FO

R O

PE

NIN

G H

OLE

B I TS I Z E

&T Y P E

WE

IGH

T O

N B

IT(K

lbs)

RO

TA

RY

(R

PM

)D

RIL

LIN

G P

IPE

S

DR

ILLI

NG

CO

LLA

RS

BO

TT

OM

HO

LE A

SS

EM

BLY

DR

ILL

ST

RIN

GC

OM

PO

SIT

ION

NO

. O

F L

INE

S

M U D P A R A M E T E R S D R I L L I N G P A R A M E T E R S

M U D H Y D R A U L I C S

NO

& T

YP

E O

F P

UM

PS

LIN

ER

SIZ

ES

(IN

CH

ES

)

ST

RO

KE

S /

MIN

UT

E

JET

SIZ

E (

INC

HE

S)

JET

NO

ZZ

LE V

EL

(FT

/SE

C.)

AN

NU

LAR

VE

LOC

ITY

AR

OU

ND

D/ P

IPE

S (

FT

/ M

IN.)

ST

AN

D P

IPE

PR

ES

SU

RE

(P

SI)

PU

MP

OU

T (

GP

M)

R E M A R K S /

P R O D U C T I O N T E S T I N G / W R I T E U P

1 2 3 4 5 8 9 1 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 0 2 1 2 2 2 3 2 4 2 5 2 6 2 7 2 8 2 9 3 0 3 1 3 2 3 3 3 4 3 5 3 6 3 7 3 8

LOG

GIN

G P

RO

GR

AM

ME

CO

MP

LIC

AT

ION

DU

RIN

G

DR

ILLI

NG

39 4 0

1 0 0 0

2 0 0 0

7 , 0 0 0

6 , 0 0 0

3 0 0 0

4 0 0 0

N O

R M

A L

H Y

D

R O

S

T A

T I

C

P

R E

S S

U R

E

BH

C -

GR

DLL

- M

SF

L -

BH

C -

GR

- S

P

8.5

+

60

- 70

8.6

- 9

.2

BE

NT

ON

ITE

SP

UD

MU

D

12-

1/4

"

(10

Klb

s)

60

- 90

5"

8"

x 9

256

60

- 80

100

- 1

40

0 P

SI

200

- 4

00

20

- 25

8.5

- 9

.5

-

MIN

IMU

M

1

L E

S S

T

H A

N

5

C .

C .

4 -

5

/

1 2

-

1 5

50

- 55

9.0

- 1

0.0

PP

G

5"

6 -

1/2

" x

15

T D . 7 3 0 0 ' R T ( 6 7 9 4 ' S S )

B A H A W A L N A G A R

P U N J A B

10

180

mm

80

- 12

0

10

NO

RM

AL

HY

DR

OS

TA

TIC

PR

ES

SU

RE

9-5/

8'' C

AS

ING

@ 1

917'

RT

12-

1/4

" B

IT +

NB

ST

AB

+ 2

x 8

" D

C +

S.S

TA

B +

5 x

8"

DC

8"

JAR

+ 2

x 8

" D

C +

XO

+ 1

2 x

5" H

WD

P

2 x

Tri

ple

x H

HF

- 1

600

HP

18/

32, 1

8/3

2,1

8/32

, 14/

32

NO

ST

RU

CT

UR

E C

OM

PL

ICA

TIO

NS

AR

E E

XP

EC

TE

D

5%

KC

L P

OLY

ME

R

8-1

/2"

TC

I: (

10

- 25

Klb

s) /

PD

C: (

10 -

25

Klb

s)

TC

I: (

70

- 10

0)

/ P

DC

: (8

0 -

120)

8-1

/2"

BIT

+ N

. B. S

TA

B +

1 x

6-1

/2"

NM

DC

+ S

. ST

AB

+ 2

x 6

-1/2

" D

C +

(400

- 5

00

TC

I)

(4

50

- 55

0 P

DC

)

150

0 -

25

00

200

- 2

50

250

- 3

00

PD

C (

6 x

12

/ 3

2",

5 x

12

/ 3

2")

( 3

x 14

/32"

) T

CI

120

S.S

TA

B +

10

x 6

-1/2

" D

C +

6-1

/2"

JAR

+ 2

x 6

-1/2

" D

C +

XO

+ 1

2 x

5" H

WD

P

160

- 1

80

mm

X X XX X XX X XX X XX X X

v v v

v v v

v v v

v v v

v v v

v v v

v v v

v v v

1 9 1 7 '

2 0 8 4 '

2 2 1 2 '

2 6 6 1 '

3 6 8 8 '

4 8 3 7 '

3 1 5 4 '

3 3 8 0 '3 4 2 6 '

7 0 0 2 '

D O M I N A N T L Y S A N D S T O N E W I T H I N T E R C A L A T I O N O F C L A Y S T O N E .

D O M I N A N T L Y L I M E S T O N E W I T H T H I N B E D S

C L A Y S T O N E W I T H I N T E R C A L A T I O N O F

D O M I N A N T L Y S A N D S T O N E W I T H

S A N D S T O N E W I T H T H I N B E D S O F C L A Y S T O N E .



P R E D O M I N A N T L Y D O L O M I T E

O F C L A Y S T O N E .

S A N D S T O N E

I N T E R C A L A T I O N O F C L A Y S T O N E

D O M I N A N T L Y E V A P O R I T E S( D O L O M I T E , A N H Y D R I T E A N D S A L T ) W I T H T H I N B E D S O F C L A Y A N D S A N D S T O N E

S A N D S T O N E W I T H I N T E R C A L A T I O N O F

I G N E O U S B A S E M E N T .

L I M E S T O N E , T H I N B E D S O F S I L T S T O N E A N D D O L O M I T E .

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ALI

KS

(+1

887

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AS

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EN

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29

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)

N A M M A L ( 1 6 7 ' )

S A K E S A R +

D A T T A ( 1 2 8 ' )

SA

RD

HA

I (

449'

)W

AR

CH

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(49

3')

D A N D O T ( 2 2 6 ' )

T O B R A ( 4 6 ' )

J U T A N A ( 2 6 2 ' )

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RA

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AK

+

(1

149'

)

SA

LT R

AN

GE

(21

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N O T E : T D W I L L B E 7 3 0 0 F T R T O R 2 0 0 F T I N S I D E B A S E M E N T ( W H I C H E V E R I S S H A L L O W E R )L E G E N D

V A N H Y D R I T ES H A L E L I M E S T O N ES I L T S T O N E D O L O M I T ES A N D S T O N E S A L TC L A Y S T O N EV V V

V V V V I G N E O U S

X X X XX X X XX X X X P R I M A R Y O B J E C T I V EP

Z O N E - I I

Z O N E - I I

P A I G E

2 9 7 2 - 4

M A R O T - 0 1

B A H A W A L P U R E A S T( 2 9 7 1 - 5 )

Z O N E = I I2 4 9 5 S q . K m s

P P L

B A H A W A L P U R E A S T - 0 1

S E E P A G EJ U G U W A L A O I L

S U T L E J

1 9 2 7 . 9 4 S Q . K M S

C H O L I S T A N

N A T I V SN A T I V S

1 8 3 8 . 6 0 S Q . K M S

M A H A R V IO P I I

2 9 7 2 - 3

P U N J A BP U N J A B

Z O N E - I I

3 0 7 2 - 4N A T I V S

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Z O N E - I I2 5 0 5 . 1 8

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M U L T A N

M U L T A N S O U T HO G D C L

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K A R A M P U R - 0 1

Z O N E - I I

K A R A M P U R - 0 1

T O L A - 0 1T O L A - 0 1

A L I S H A I B - 1A L I S H A I B - 1N A N D P U RO G D C L

S A R A I S I D H U - 0 1S A R A I S I D H U - 0 1N A N D P U R - 0 1N A N D P U R - 0 1

2 5 3 5 . 4 1 S Q . K M S

S H A K A R G A N J W E S TN A T I V U S

C H I S H T I A N M A N D I

- - - - - -

2 x

Tri

ple

x H

HF

- 1

600

HP

5 0 0 0

X X XX X XX X XX X XX X XX X X

P

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P

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L -

CN

L -

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S, S

HD

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GR

12-

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M A H A R V I - 1

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S


41


SSECTIONECTION 66CCEMENTINGEMENTING

42


6.1) Specifications6.1) Specifications

Note: Exact volume of cement slurry (tail and lead) and cement recipe will be advised by the Head Office at the time of job.

9⅝ Casing – 1,976 ft 7 Casing – 7,300 ft

Interval: Surf. – 1,976 ft

Open Hole Excess – 150 %

Cementing Method: Conventional

Density – 15.0 ppg

Lead Cmt: Surface – 6,400 ft

Tail Cmt: 6,400 ft – 7,300 ft

Open Hole Excess: 20%

Cementing Method: Conventional

Lead Slurry: 13.2 ppg.

Tail Slurry: 15.8 ppg.

43


6.2) ANNULAR VOLUME (bbls / ft)6.2) ANNULAR VOLUME (bbls / ft)

Size Capacity

I n n e r T u b i n gI n n e r T u b i n g

3½ 4¾ 5 6 ½ 7 8 9 ⅝ -

A n n u l u s C a p a c i t y

OH 12¼ 0.1458 - - 0.1215 - - 0.0836 0.0558 -

CSG 9⅝ 0.0732 - - 0.0489 0.0322 0.0256 - - -

OH 8½ 0.0702 - - 0.0459 0.0291 0.0226 - - -

CSG 7 0.0371 0.0252 0.0152 - - - - - -

44


SSECTIONECTION 77WWELLELL CCONTROLONTROL

45


7.1) GENERAL INSTRUCTIONS7.1) GENERAL INSTRUCTIONS

General Instructions to avoid / combat well control situations:

Record mud weights every 15 / 30 mins as directed.

Monitor well for signs of changing pressures

Record SCR regularly in every shift and specially in the following situations:

1. Significant change of mud properties

2. Change of BHA

3. Change of bit / bit nozzle configuration

4. After changing mud pump liner – piston sizes

5. Before entering into a potential pay zone and after entering into new formations

Before entering a potential high-pressure zone, ensure that the MW is appropriate enough.

Minimize contamination of mud with foreign elements like drill solids / cement / hydrocarbons.

Ensure proper hole fill up during tripping through a properly calibrated trip tank.

Ensure integrity of low-pressure mud system to avoid intercommunication / intermittent dilution.

Maintain reasonable stock of weighting agent (Barite / CaCO3) on location as advised by the Company Man.

Conduct flow-check at following situations:

1. During tripping

2. When at bottom after running in

3. After entering in cased hole from OH while tripping out.

4. Before pulling out BHA.

5. When at surface after pulling out

6. Observing kick warning signs as mentioned above.

46


7.2) WARNING SIGNS OF A KICK7.2) WARNING SIGNS OF A KICKObserve for following changes in well behavior so that a potential kick can be handled promptly and safely:

Increase in Flow rate

Increase in Pit Volume

Well not static on flow check

Reduced hole fill up volume during tripping out.

Gas cuts

Drilling break

Erratic torque

7.3) SHUT IN PROCEDURES7.3) SHUT IN PROCEDURES

7.3.1) WHILE DRILLING

If a kick is encountered while drilling, follow the procedure outlined below:

1. Stop drilling.

2. Stop rotation.

3. Raise the string so as to bring tool joint above the rotary table.

4. Stop the pump(s). Observe well & conduct flow check.

5. Close the annular preventer and open HCR valve to the hydraulic choke. Keep the choke lined up for hard shut-in (i-e closed position during normal drilling operations)

6. Inform Company Man, Tool pusher and other crew members.

7. Record the following:

i. Shut-in casing pressure at the choke manifold (SICP)

ii. Shut-in Drill pipe pressure at the standpipe manifold (SIDPP)

iii. The pit gain

Note: Sufficient time must be allowed for the readings to be stabilized before recording. (±30 mins)

47


7.3.2) WHILE TRIPPING

If a kick is encountered while tripping, following procedure must be followed:

1. Run down stand to bring tool joint at the rotary table and set slips under it.

2. Install a Fully Opened Safety Valve and close it. Ensure at hand availability of a fully opened safety valve on the rig floor during the entire time of tripping.

3. Close the annular preventer and open HCR to the hydraulic choke.

4. Inform Company Man, Tool pusher and other crew members.

5. Record the following:

i. Shut-in casing pressure at the choke manifold (SICP)

ii. Shut-in Drill pipe pressure at the standpipe manifold (SIDPP)

iii. The pit gain

Note: Sufficient time must be allowed for the readings to be stabilized before recording. (±30mins)

7.4) KILLING METHOD7.4) KILLING METHOD

The underlying principle is to:

Keep the bottom hole pressure constant and just above formation pressure at all times.

Minimize the pressure exerted on the open formations (1st priority), the casing shoe and the BOP

The DRILLER’S METHOD will be employed to combat any kick situation. Following outline procedure shall be adopted:

1. Shut in the well

2. Read & record SIDPP, SICP and pit gain.

3. Brief the crew about the procedure

4. Open the choke and simultaneously start pumping mud (of current weight) at the SCR.

5. Whilst reaching and maintaining the SCR adjust the choke opening until the choke pressure equals the closed-in annulus pressure. Record and keep the choke pressure constant throughout the first circulation.

48


6. Read standpipe pressure. It should equal the normal pre-kick pump test circulation pressure at the selected pump speed plus the closed-in drill pipe pressure. If the observed standpipe pressure does not agree with the calculated value, consider the observed pressure to be correct.

7. Maintain constant standpipe pressure and pump rate (SCR) whilst the influx is circulated out.

8. When all influx has been circulated out, stop the pump and close in the well to check the closed-in drill pipe and annulus pressures. At the end of the first circulation the closed-in pressures of the annulus and drill pipe should be the same and equal to the initial closed-in drill pipe pressure. The well is controlled but not killed.

9. Once the drilling fluid has been weighed up to the correct density the second circulation can begin. Prepare kill sheet & pumping schedule (Kill sheet format attached in Section 7.5) format and follow through out the second circulation.

10. Start the pump and circulate kill mud at the SCR. Hold casing pressure constant until the kill mud reaches the bit. At the same time monitor DP pressure against the pump schedule.

11. When the kill mud reaches the bit, hold drill pipe pressure constant at Final Circulating Pressure (FCP) until the weighted mud is surfaced.

12. When the kill mud is surfaced shut off the pump, close the well and check pressures. Both pressures should record “zero”. If so open the well and conduct a flow check. If it is not flowing, the well has been killed successfully. If it flows, follow the killing procedure again.

49


7.5) KILL WORK SHEET7.5) KILL WORK SHEET

Date: __________________

Well NameFIT EMW (A) ppg

Initial MAASP Current Drilling Mud((A) - Current MW) x Shoe TVD x 0.052 Weight ppg

= psi

Casing Shoe DataSize "MD ft

bbls / stk bbls / stk TVD ft

OH DataSCR 45 SPM Size "

MD ftTVD ft

LENGTH CAPft bbls / ft

x

x

Drill Collars x

Drill String Volume (D) bbls (E) Strokes Mins

x

x

OH Volume (F) bbls Strokes Mins

DP x CSG. x (G) bbls Strokes

TOTAL ANNULUS VOL. bbls Strokes Mins

TOT WELL SYS VOL. bbls Strokes Mins

TOT ACTIVE SUR. VOL. bbls Strokes

TOT ACT. FLUID SYS bbls Strokes

psi psi bbls

………… + (………… / ……………. x 0.052) = _________

………… + ………… = _________ psi

………… x ………… / ………… = _________ psi

……… - ……… = ________ …… x 100 / …...…… = _________

(D)+(H) = (I)

CURRENT WELL DATA

MUD PUMP DATA

FORMATION STRENGTH DATA

VOLUMEbbls

(PL) Dynamic Pressure Losses

Drill Pipe

PUMP STROKES

PRE-RECORDED VOL DATA

60 SPM30 SPM

TIME

PUMP STROKES SCR

MinsStrokes

V O L U M EPUMP OUT PUT

(F)+(G) = (H)

KMW x Dynamic Losses / Current MW

PRESSURE DROP / 100 STKS (PSI PER 100 STKS)

(J)

(I)+(J)

Dynamic Pressure Losses + SIDPP

FINAL CIRCULATING PRESSURE (FCP)

KICK DATA

SIDPP PIT GAINSICP

KILL MUD WEIGHT (KMW)

(K) = ICP - FCP (K) x 100 / (E)

WELL CONTROL WORK SHEET

Pump OutoutPump 1 Pump 2

Current MW + (SIDPP / TVD x 0.052 )

INITIAL CIRCULATING PRESSURE (ICP)

DC x OH

DP x OH

Pump No. 1Pump No. 2

HWDP

DC

DP

50


Pressure(psi)Strokes

PUMP SCHEDULE

DP

Pre

ss

ure

(p

si)

Strokes

51


52


SSECTIONECTION 88PPRESSURERESSURE TTESTEST

53


8.1) PRESSURE TEST WELL CONTROL EQUIPMENTS8.1) PRESSURE TEST WELL CONTROL EQUIPMENTS

BOP SIZE

ANNULAR TYPE RATING

RAM TYPE

RATING

PRESSURE TEST

ANNULAR RAM BLINDCHK /

KILL LINE M / F

13⅝ 5 M 10 MLow : 300 psi

High : 2500 psiLow : 300 psi



High : 4500 psi

Low-pressure test for 10 min.

High-pressure test for 15 min.

Use test plug to test BOP stack and cup tester for newly installed casing spool, flanges & valves.

Press test casing head housing (through weld test port. 75% of the casing collapse pressure or Well Head Housing rated press which ever is Lower).

54


SSECTIONECTION 99PPLUGLUG & &

AABANDONMENTBANDONMENT

55


9.1) OBJECTIVES9.1) OBJECTIVES

To place impermeable tested barriers between deep reservoirs and shallow aquifers / surface. Final P & A will be sent to the well site based on results, testing well bore conditions and formations.

9.2) SEQUENCE OF EVENTS9.2) SEQUENCE OF EVENTS

500' cement plug inside open / cased hole at the top of the sands.

500' plug around 9⅝ (cement as per 9⅝ tail slurry).

300' plug inside 9⅝ casing from 100' to 400'

Test (mechanically & hydraulically) all the cement plugs.

N / d BOP stack and cut off wellhead.

Surface dry cement plug after having removed the wellhead (accelerated setting recipe).

56

Mahari - 1 Drilling Program

Documents

record hook

inform company

install wear

blind ram

lithologythe

vv vv vv

kill mud reaches

lithologyat