bottom hole assemblys

7/22/2019 Bottom Hole Assemblys

1/18

Shallow Horizontal Wells In the Gulf of Mexico

Consolidated by Tony Pershall with Input from Scott Levad, Gary Wygul, James Tunnell,& Tim French.

Devons West Cameron 587 project we drilled seven wells, 1500 to 3000 feetTVD & as far out as 6000 feet in Section. The objective was to drill horizontally throughthese shallow thin gas bearing sands (8 to 20 feet thick) drilling 600 of pay. Utilizing theGST, and adapting our drilling practises we were able accomplish all objectives & did so30% under AFE. All seven wells are producing more that expected, averaging 12 MCFeach, 70% more than vertical wells drilled through these sands.

In this report I have included Lessons Learned & Best practices from the

Directional Drillers responsible for making what we wanted to do on paper work on therig. (Thanks guys)Ive also included PvS, BHAs, & Slide sheets from one well & some Bragging Graphsthat sums up what we were able to accomplish as a Team.

Drilling

Sidetracking is the most prevalent hazard while drilling. Always exercise extreme cautionregarding sidetrack during all drilling operations.

Intentional open hole sidetracks can be accomplished with one 20 stroke of the BHA at alow side orientation.

Never circulate off bottom unless back reaming or moving the pipe with a high sideorientation to avoid hole wash out and sidetrack.

Never short trip, the risk of sidetrack is too high.

Back-ream every connection to improve the condition of the hole and improve holecleaning. Back-ream connections instead of short tripping. Back ream up and orient tohigh side to run back to bottom. If you continually carry a high side-chalk mark on thedrill pipe, you will save time and avoid hole wash out by not having to wait for MWD T/Fsync.


2/18

y

Plan the drill string so that the HWDP never exceeds 60 degrees of inclination. Do notplan to trip out of the hole to move the HWDP. It may be necessary to pick up the HWDPbefore planned to get to bottom when tripping through the 9 5/8 casing to drill the 8 hole due to the higher coefficient of friction in new casing. In addition when drilling at1500 to 2000 TVD the HWDP should be run so that it is at the top when starting to drillthe horizontal section. And if necessary it should be stood back and used to drill whensliding becomes difficult due to lack of available string weight.

To achieve DLS, keep weight on the bit at all times by drilling up to 1000 feet per hour.Do not lower the pump rate below 250 gpm in any hole size. Do not stop drilling whenchanging from sliding to rotating. Spend as little time possible pumping and orienting the

BHA before sliding.

Record GST at bit inclination measurements every 10.

The DLS achieved on wells so far has been 3/100 to 15.5/100.

The 1.83-degree bend standard 6 motor generated 10/100 DLS in the 9 7/8pilot hole below the 20 drive pipe.

The 2.12-degree bend standard 6 motor generated 12/100 DLS in the 9 7/8pilot hole below the 20 drive pipe.

The 1.50-degree bend standard 6 motor generated 8/100 DLS in the 12 pilothole below the 20 drive pipe.

The 1.83-degree bend standard 6 motor generated 8+/100 DLS in the 12 pilot hole below the 20 drive pipe.

The 1.25-degree bend 6 GST motor generated 9+/100 DLS throughout the 97/8 pilot hole below the 13 3/8 casing.

The 1.50-degree bend 6 GST motor generated 12+/100 DLS throughout the 97/8 pilot hole below the 13 3/8 casing


3/18

Open the hole at a minimum of 300 feet per hour. Always try to keep a little weight onthe bit even if you must drill at 1000 feet per hour. Pump at least 650 gpm. Rotate at120 RPM.

Never rotate if sitting still.

Back ream the hole opener out of the hole.

Run a full gauge near bit stabilizer immediately behind all hole openers. The full gaugestabilizer will help prevent sidetrack. Also, a full gauge stabilizer will help to fully open thehole at the excessive rates of penetrations require for hole opening operations on these

type wells.

Spiral-bladed near bit stabilizers will better support the hole opener, do less damage tothe well bore wall and have less ability to induce sidetrack in these soft formations thanwill straight-bladed stabilizers.

Casing

All casing strings should always be set on bottom prior to cementing. This is to avoid

hole troubles seen during well A-18 caused by sloughing and caving cement from the 59'of rat hole left below the 13 3/8" casing. The cement fell down hole and caused twoincidental sidetracks and a premature hole opener run.

Orienting the deviated drive pipe should only be done with a north-seeking electronicgyro. Conventional photomechanical gyro tools that are tied into north by eyeballmeasurements to a tugboat-compass rig-bow-heading are far too inaccurate.

The deviated drive pipe may walk right or left in azimuth by as much as 45 degrees whilebeing driven. The planned direction of the drive pipe should always take this intoconsideration for anti-collision. The pipe orientation can not be controlled while it is beingdriven, except while the pipe is still driving at less than 50 hit per foot, a pad eye can bewelded on and tension held with a air tugger which as the pipe is driven can turn the pipein the desired direction.


4/18

The 20" drive pipe had a deviated shoe with a 0.4-0.6 degree bend 8 feet behind theshoe. The deviated shoe on the 20 drive pipe could have a more aggressive bend, 0.8to 1.2 degrees to yield a greater DLS on future wells.

The maximum DLS that 13 3/8 casing can be run in without sidetrack is 10/100. The 133/8" casing should have a deviated shoe joint with a 1.0-1.5 degree bend 10 feet behindthe shoe to assist getting it bottom in the soft formations when the DLS is greater than10/100.

Displace the open 12 hole prior to running 9 5/8 casing with fresh mud (9% lowgravity solids), 2% lubricant and 6#/bbl polymer beads to reduce the coefficient of frictionsignificantly. Torque and drag calculations for 9 7/8 casing runs experienced on non-

lubricated wells yield a coefficient of friction 0.40. The A-17 well 12 open holedisplace yielded a coefficient of friction of 0.285. The lack of solids and the lubricationreduced the friction factor for A-17 by 29%. The cost of the new mud pill was $10,000.

Directional

Future well-bore planning should include a graduated build rate immediately beneath thedrive pipe. The formation at the drive pipe shoe is extremely soft and will not allow thehole-opener or 13-3/8 casing to follow an aggressive bend.

Always plan the wells with enough cushion to allow one incidental sidetrack. Everyincidental sidetrack will cause the loss of at least 3 degrees of inclination and or azimuthturn and the loss of at least 10 of TVD.

Survey intervals should be no more than 30 to insure TVD accuracy.

Once the well is horizontal in the target sand, angle can be maintained by weight on bit,flow or ROP. An ROP of 150ft/hr or less will cause a drop in angle, an ROP of 300ft/hr ormore will build angle. Except for azimuth or a change in geologic interpolation sliding canbe held to a minimum.

The drive pipe shoe will rarely end up being at the exact planned bottom hole location.Small inaccuracies in setting-depth, inclination and direction will dramatically effect the


5/18

Quality Control

Date Drawn:28-Sep-2000

Drawn by:Tony Pershall

Checked by: ______________

Client OK: ______________

Miscellaneous

Slot: P (A-17): A-17 Rev10 tp+jbj 4000' VS

Elev Ref: RKB(119.00ft above MSL)

Date Drawn: 11:47:45AM 28-Sep-2000

Surface Location

Lat: N28 9 40.028 Lon: W93 20 56.194

North: -178153.25 ftUS East: 1350253.06 ftUS

Grid Conv: -1.0078 Scale Fact:1.0004

Magnetic Parameters

Model: BGGM 1999

Dip: 58.259 Mag Dec: 3.386

Date: May 31, 2000 FS: 48107.6 nT

PennzEnergy A-Platform Rowan ParisSTRUCTURE

OG West Cameron Block 587FIELD

OCS-G-02021 Well A-17WELL

PennzEnergy Exploration & Production, L.L.C.

0 500 1000 1500 2000 2500 3000 3500 4000 4500

1500

1000

500

AL Sand ToeAL Sand Heel

ProposalSurvey

PBHL/TD90.00 4902 MD

Begin 81.41 Lateral81.41 1382 MD

Begin 10.00/100' Build & Turn

KOP Begin 8.00/100' Build & T urn

Mud Line, Begin 3.00/100' Deviated Drive Pipe

9 5/8'' Casing Point89.78 4246 MD

Build and Turn 8.00/100 ft

13 3/8'' Casing Point29.02 855 MD

20'' Casing Point5.86 544 MD

Vertical Section View

Elev

Re

f:

RKB

(119.

00ft

above

MSL

)

Vertical Section Departure at 72.00 deg from (0.0, 0.0). (1 in = 500 feet)

0 800 1600 2400 3200 4000 4800

0

800

1600

AL Sand Toe

Surface Location: North:-178153.25 ftUS, East:1350253.06 ftUS NAD27 Louisiana State Planes, Southern Zone, US Feet

Grid Coord Local Cooord

Target Name N(+)/S(-) E(+)/W(-) TVD VSEC N(+)/S(-) E(+)/W(-) Shape Major Axis

ftUS ftUS ft ft ft ft

AL Sand Heel -177161.82 1353454.45 1542.00 3349.62 991.00 3200.00 Point

AL Sand Toe -176960.87 1354072.91 1574.00 3999.62 1191.86 3818.19 Point

Critical Points MD INCL AZIM TVD VSEC N(+)/S(-) E(+)/W(-) DLS

Mud Line, Begin 3 349.00 0.00 120.0 349.00 0.00 0.00 0.00 0.00

20" Casing Point 544.34 5.86 120.0 544.00 6.68 -4.99 8.64 3.00

KOP Begin 8.00/1 544.35 5.86 120.0 544.01 6.68 -4.99 8.64 3.00

13 3/8" Casing Po 855.01 29.02 79.2 839.00 93.41 1.28 97.80 8.00

Begin 10.00/100' 855.02 29.02 79.2 839.01 93.42 1.28 97.81 8.00

Begin 81.41 Late 1381.66 81.41 72.0 1129.33 510.28 113.67 499.60 10.00

Begin 4.00/100' 4036.83 81.41 72.0 1525.93 3135.66 924.89 2996.52 0.00

9 5/8" Casing Poi 4246.20 89.78 72.0 1541.99 3344.23 989.33 3194.87 4.00

AL Sand Heel 4251.59 90.00 72.0 1542.00 3349.62 991.00 3200.00 4.00

PBHL/TD 4901.59 90.00 72.0 1542.00 3999.62 1191.86 3818.19 0.00

PBHL/TD

HoldAz

imuth7

2.00

9 5/8'' Casing Point

13 3/8'' Casing Point

20'' Casing Point

PLAN VIEW Scale (1 in = 800 feet)


6/18

OCS-G-02021 Well A-17 OH

West Cameron Block 587

Bit

Cross Over Sub

A675M Power Pak w/ 1.83Bend

Float Sub

Non-Mag Pony Collar

Cross Over Sub

MWD Tool

Filter Sub

UBHO Sub

NM Flex Collar

NM Flex Collar

9 Jnts HWDP (5)

G DP 5 to Surface

BitGT-1; TFA= .79

349Depth

Date

Rig

40004739Job Number

ROWAN Paris

Client

Well lease

Location

853

5/13/005/13/00

DescriptionHTC

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

ROWAN

ROWAN

P05YC

MBS-80295

675-01152

XOS-60115

672-MC

XOS-70199

MDC-925

DY-243

MSS-60003

NMF-60054

NMF-60058

9HWDP

DP

.30

14.84

3.30

3.30

12 1/8

1.00

1.05

19.99

1.68

9.38

2.69

27.31

3.12

2.62

30.97

30.91

271.01

Vendor Serial # Connections F.N. LengthOD/ID Blade Cumulated1.00

2.05

22.04

23.72

33.10

35.79

63.10

66.22

68.84

99.81

130.72

401.73

401.73

1Bit #

12 1/44 x 16 6 5/8 REG PIN6 3/4x7

2 1/4

6 5/8 REG BOX

4 1/2 REG PIN

4 1/2 IF

4 1/2 IF

4 1/2 IF

5 1/2 FH

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 REG

4 1/2 IF

4 1/2 IF

4 1/2 IF

5 1/2 FH

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

6 3/4

6 1/2

6 3/4

6 3/4

6 3/4

7

6 1/2

6 3/4x5

6 3/4x5

5

5

Tool

3 1/2

2 7/8

2 3/4

Tool

3 1/4

3

2 7/8

2 7/8

3

4.276

DEVON Energy

Bottom Hole Assembly

# 1 IN OUT


7/18

40004739Job Number

Client

Well lease

DEVON Energy

OCS-G-02021 Well A-17

West Cameron #587Location

Scott Levad

Mike Felder

Directional

Drillers

ROWAN ParisRig

Bit

Steerable

675-01152

Bit Description

BHA Type

PDM Description

Slide Sheetfor

BHA #1

Date S/R From ToToolFace Slide Rotate

SurveyWOB RPM GPM Torque PSI Off PSI On

Footage

Inc Azi DLSMDComments

5/13/2000 415.0 2.50 117.00 3.80 2 25 20300 500 500 Clean 20 DP

R 520 530 10 5 25 20300 500 550

S 530 570 30L 40 5 300 500 550

R 570 591 21 510.0 6.50 107.00 4.30 5 25 20300 500 550

S 591 629 30L 38 5 300 500 550

R 629 638 9 5 60 50300 500 550

S 638 660 35L 22 5 300 500 650

R 660 686 26 605.0 11.75 101.00 5.60 5 60 50300 500 550

S 686 724 20L 38 5 300 500 600

R 724 734 10 3 60 50300 500 550S 734 772 5L 38 5 300 500 600

R 772 774 2 723.0 16.47 110.23 4.40 3 60 50300 500 550

S 774 824 30L 50 753.2 18.58 109.17 7.10 10 300 500 650

R 824 834 10 3 60 50300 500 550

S 834 853 30L 19 801.0 22.03 107.10 7.40 15 300 500 700

Drill the 12 1/4 pilot hole to 13 3/8 csg pnt.

Comments

Page 1

245Total 8835.00Avg. Slide

Avg. Rotate 12.57 73.6% 26.4%%

2MIN

15MAX

25

60

300

300

20

50

Version 4.1


8/18



17 1/2 Hole Opener

16 1/2 Stabilizer

NM Flex Collar

NM Flex Collar

9 Jnts HWDP (5)

Bull Nose

349Depth

Date

Rig

40004739Job Number

ROWAN Paris

Client

Well lease

Location

853

5/13/005/13/00

DescriptionSmith

Smith

Smith

Anadrill

Anadrill

ROWAN

N/A

46078

C 28059

NMF-60054

NMF-60058

9HWDP

2.006 5/8

3.30

3.30

Jet=3x20

16 1/2

3.45

4.32

18.62

30.97

30.91

271.01


7.77

26.39

57.36

88.27

359.28

Bit #7 11/16

2 7/8 6 5/8 REG PIN8

2 7/8

6 5/8 REG BOX

6 5/8 REG PIN

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

6 5/8 REG

4 1/2 IF

4 1/2 IF

4 1/2 IF

BOX

BOX

BOX

BOX

BOX

PIN

PIN

PIN

8 1/2

6 3/4x5

6 3/4x5

5

2 7/8

2 7/8

2 7/8

3

DEVON Energy


# 2 IN OUT


9/18



9-7/8 Bit

Bit Cross Over Sub

A675M - GST w/ 1.5 Bend7/8 R/S; Nozzle= None

Float Sub

Cross Over Sub

Receiver Sub

CDR Tool

MWD Tool

Filter Sub

NM Flex Collar

NM Flex Collar

90 Jnts. G DP 5

9 Jnts HWDP (5)

Jars (Hyd/Mech)

20Jnts HWDP (5)

G DP 5 to Surface

9-7/8 BitMX-C1; TFA= .79

853Depth

Date

Rig

40004739Job Number

ROWAN Paris

Client

Well lease

Location

4368

5/17/005/15/00

DescriptionHTC

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

ROWAN

ROWAN

Griffith

ROWAN

ROWAN

B20ZA

MBS-80328

675-01441

XOS-60115

XOS-70199

006

7139

MDC-925

DY-243

NMF-60054

NMF-60058

90DP

9HWDP

4746758900

20HWDP

DP

3.30

3.30

1.81

jets =4 x 16

9 3/4

1.00

1.08

28.95

1.68

2.69

5.52

22.42

27.31

3.12

30.97

30.91

2824.47

271.01

32.30

602.98


2.08

31.03

32.71

35.40

40.92

63.34

90.65

93.77

124.74

155.65

2980.12

3251.13

3283.43

3886.41

3886.41

2Bit #

9 7/86 5/8 REG PIN

7 3/4

2 1/4

6 5/8 REG BOX

4 1/2 REG PIN

4 1/2 IF

4 1/2 IF

5 1/2 FH

5 1/2 FH

5 1/2 FH

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 REG

4 1/2 IF

4 1/2 IF

5 1/2 FH

5 1/2 FH

5 1/2 FH

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

6 3/4

6 1/2

6 3/4

6 7/8

6 7/8

6 3/4

7

6 3/4x5

6 3/4x5

5

5

6 1/2

5

5

Tool

3 1/2

2 3/4

Tool

Tool

Tool

3 1/4

2 7/8

2 7/8

4.276

3

2 3/4

3

4.276

DEVON Energy


# 3 IN OUT


10/18

40004739Job Number

Client

Well lease

DEVON Energy



Scott Levad

Mike Felder

Directional

Drillers

ROWAN ParisRig

9-7/8 Bit

Steerable

675-01441

Bit Description

BHA Type

PDM Description

Slide Sheetfor

BHA #3



Footage


5/15/2000 S 853 863 20L 10 10 300 600 700

S 863 905 20L 42 10 300 600 700

S 905 943 20L 38 919.9 31.38 105.95 10.45 10 300 600 700

S 943 975 15L 32 15 300 600 700

S 975 1000 15L 25 15 300 600 700

R 1000 1005 5 8 60 80300 550 700

S 1005 1035 20L 30 1014.8 41.95 102.58 11.34 20 300 600 750

R 1035 1038 3 8 60 80300 550 700

S 1038 1064 20L 26 20 300 600 750

R 1064 1069 5 8 60 80300 600 750S 1069 1094 25L 25 20 300 600 750

R 1094 1101 7 8 60 80300 600 750

S 1101 1131 15L 30 1109.2 51.56 99.54 10.44 20 350 800 900

S 1131 1160 25L 29 20 350 800 900

R 1160 1163 3 8 60 80350 800 900

S 1163 1227 25L 64 1201.4 61.73 96.30 11.42 20 350 800 900

R 1227 1230 3 8 60 80350 800 900

S 1230 1280 28L 50 12 350 800 900

R 1280 1286 6 8 60 80350 800 900

S 1286 1312 25L 26 1292.2 71.00 94.12 10.44 12 350 800 900R 1312 1317 5 8 60 80350 800 900

S 1317 1440 30L 123 1387.2 78.54 91.91 8.25 20 350 800 900

S 1440 1495 90L 55 1481.5 83.58 88.33 6.52 20 350 800 900

S 1495 1561 100L 66 20 350 800 900

R 1561 1568 7 8 60 80350 800 900

9 7/8 pilot hole.

Comments

Page 1


Avg. Rotate 50.37 29.8% 70.2%%

5MIN

25MAX

50

100

300

450

80

150

Version 4.1


11/18

40004739Job Number

Client

Well lease

DEVON Energy



Scott Levad

Mike Felder

Directional

Drillers

ROWAN ParisRig

9-7/8 Bit

Steerable

675-01441

Bit Description

BHA Type

PDM Description

Slide Sheetfor

BHA #3



Footage


S 1568 1600 120L 32 1576.0 84.61 81.18 7.61 12 350 800 900

R 1600 1610 10 8 60 80350 800 900

S 1610 1631 120L 21 12 350 800 900

R 1631 1641 10 8 60 80350 800 900

S 1641 1663 120L 22 12 350 800 900

R 1663 1673 10 1672.2 82.60 75.69 6.04 8 60 80350 800 900

5-15-2000 S 1673 1694 90L 21 10 350 800 900 1694 @ MN

5-16-2000 R 1694 1705 11 8 60 80350 800 900

S 1705 1725 90L 20 10 350 800 900

R 1725 1736 11 6 60 80350 800 900

S 1736 1757 85L 21 12 350 800 900

R 1757 1767 10 1765.1 82.30 70.32 5.74 6 60 80350 800 900

S 1767 1782 88L 15 12 350 800 900

R 1782 1851 69 6 60 80350 800 900

R 1851 1881 30 1856.9 81.11 69.66 1.48 10 60 80350 900 1000

S 1881 1891 60L 10 10 350 900 1000

S 1891 1906 90L 15 12 350 900 1000

R 1906 1943 37 8 60 90300 700 800

R 1943 2030 87 1951.4 81.63 66.52 3.33 12 60 90300 700 800

S 2030 2038 5R 8 10 300 700 800

R 2038 2125 87 2046.5 82.27 66.58 0.68 12 50 100300 700 800

R 2125 2195 70 2143.0 81.37 66.38 0.95 12 50 100300 700 800

S 2195 2210 10R 15 12 300 700 800

R 2210 2221 11 12 50 100300 700 800

S 2221 2228 20R 7 12 300 700 800

9 7/8 pilot hole.

Comments

Page


Avg. Rotate 50.37 29.8% 70.2%%

5MIN

25MAX

50

100

300

450

80

150

Version 4.1


12/18

40004739Job Number

Client

Well lease

DEVON Energy



Scott Levad

Mike Felder

Directional

Drillers

ROWAN ParisRig

9-7/8 Bit

Steerable

675-01441

Bit Description

BHA Type

PDM Description

Slide Sheetfor

BHA #3



Footage


. . . .

R 2317 2412 95 2331.3 82.56 67.98 2.54 8 60 100300 800 900

R 2412 2507 95 2424.5 81.69 68.46 1.06 10 60 120300 800 900

R 2507 2598 91 2517.3 81.31 68.70 0.48 10 100 120450 1350 1450

S 2598 2618 35L 20 2611.0 82.27 68.14 1.18 15 300 700 800

R 2618 2693 75 10 100 120450 1400 1500

R 2693 2787 94 2707.1 81.86 66.79 1.46 10 100 150450 1400 1500

S 2787 2802 HS 15 2800.9 83.13 67.87 1.77 15 300 800 900

R 2802 2882 80 8 100 150450 1400 1500

R 2882 2975 93 2893.5 83.28 68.35 0.54 8 100 150450 1400 1500

R 2975 3065 90 2984.2 82.91 68.62 0.50 8 100 150450 1400 1500

R 3065 3156 91 3071.5 82.76 68.95 0.41 8 100 150450 1400 1500

S 3156 3171 95L 15 20 300 800 950

R 3171 3242 71 3162.0 83.05 67.84 1.26 5 100 150450 1500 1600

R 3242 3338 96 3258.5 82.93 67.60 0.72 8 100 150450 1500 1600

R 3338 3428 90 3350.0 81.77 67.90 1.31 10 100 150450 1600 1700

R 3428 3519 91 3441.3 81.18 67.96 0.65 10 100 150450 1600 1700

S 3519 3539 65L 20 3529.9 82.07 66.68 1.75 25 300 850 1000

R 3539 3609 70 10 100 150450 1600 1700

R 3609 3699 90 3621.2 82.51 66.47 0.53 5 100 150450 1600 1700

S 3699 3716 17 3711.4 81.26 65.62 1.67 20 300 850 1000

R 3716 3790 74 5 100 150450 1600 1700

R 3790 3880 90 3803.0 80.47 65.42 0.89 10 100 150450 1600 1700

S 3880 3900 HS 20 3897.3 81.46 65.74 1.10 20 300 850 950

R 3900 3975 75 12 100 150450 1600 1700

9 7/8 pilot hole.

Comments

Page


Avg. Rotate 50.37 29.8% 70.2%%

5MIN

25MAX

50

100

300

450

80

150

Version 4.1


13/18

40004739Job Number

Client

Well lease

DEVON Energy



Scott Levad

Mike Felder

Directional

Drillers

ROWAN ParisRig

9-7/8 Bit

Steerable

675-01441

Bit Description

BHA Type

PDM Description

Slide Sheetfor

BHA #3



Footage


. . . .R 3990 4068 78 12 100 150450 1600 1700

R 4068 4161 93 4083.3 82.58 65.86 0.27 12 100 150450 1600 1700

R 4161 4230 69 4177.4 82.41 66.23 0.43 12 100 150320 950 1050

S 4230 4240 HS 10 20 320 950 1050

R 4240 4262 22 12 100 150320 950 1050

S 4262 4274 HS 12 4270.5 84.08 67.08 2.01 20 320 950 1050

R 4274 4294 20 4291.7 85.07 67.22 4.72 12 100 150320 950 1050

S 4294 4307 HS 13 20 320 950 1050

R 4307 4324 17 12 100 150320 950 1050

S 4324 4336 HS 12 20 320 950 1050R 4336 4348 12 12 100 150320 950 1050

R 4348 4368 20 12 100 150320 950 1050 TD f/ 9 5/8 csg.

9 7/8 pilot hole.

Comments

Page


Avg. Rotate 50.37 29.8% 70.2%%

5MIN

25MAX

50

100

300

450

80

150

Version 4.1


14/18



12 1/4 Hole Opener

12 1/4 Near Bit Stabilizer

Cross Over Sub

NM Flex Collar

NM Flex Collar

90 Jnts. G DP 5

9 Jnts HWDP (5)

Jars (Hyd/Mech)

20Jnts HWDP (5)

G DP 5 to Surface

12 1/4 Hole Opener3-cutter; TFA= 1.33

800Depth

Date

Rig

40004739Job Number

ROWAN Paris

Client

Well lease

Location

4368

5/18/005/17/00

DescriptionJets =

3x16 & 3x18

Anadrill

Anadrill

Anadrill

Anadrill

ROWAN

ROWAN

Griffith

ROWAN

ROWAN

HOC-333

775369

XOS-80129

NMF-60054

NMF-60058

90DP

9HWDP

4746758900

20HWDP

DP

0.78

2.07

1.51

3.30

3.30

1.81

12 1/4

6.27

4.70

3.00

30.97

30.91

2824.47

271.01

32.30

602.98


10.97

13.97

44.94

75.85

2900.32

3171.33

3203.63

3806.61

3806.61

Bit #8

2 7/8 6 5/8 REG PIN7 7/8

2 7/8

6 5/8 REG BOX

6 5/8 REG PIN

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

6 5/8 REG

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

PIN

PIN

PIN

PIN

PIN

PIN

PIN

8

6 3/4x5

6 3/4x5

5

5

6 1/2

5

5

2 7/8

2 7/8

2 7/8

4.276

3

2 3/4

3

4.276

DEVON Energy


# 4 IN OUT


15/18



Milled Tooth Bit

A675M - GST w/ 1.25 Bend7/8 R/S; Nozzle= None

Float Sub

Cross Over Sub

Receiver Sub

CDR Tool

MWD Tool

Filter Sub

NM Flex Collar

NM Flex Collar

126 Jnts. G DP 5

30 Jnts HWDP (5)

G DP 5 to Surface

Milled Tooth BitGT-MG1; TFA= .52

4368Depth

Date

Rig

40004739Job Number

ROWAN Paris

Client

Well lease

Location

5450

6/4/006/3/00

DescriptionHTC

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

Anadrill

ROWAN

ROWAN

ROWAN

Y23XL

675-1135

XOS-60115

XOS-70199

006

7139

MDC-925

DY-243

NMF-60054

NMF-60058

126DP

30HWDP

DP

3.30

3.30

Jets=3x15

8 3/8

0.80

29.15

1.68

2.69

5.52

22.42

27.31

3.12

30.97

30.91

3955.24

904.24


29.95

31.63

34.32

39.84

62.26

89.57

92.69

123.66

154.57

4109.81

5014.05

5014.05

3Bit #

8 1/24 1/2 REG PIN

6 3/4

Tool

4 1/2 REG BOX

4 1/2 IF BOX

4 1/2 IF

5 1/2 FH

5 1/2 FH

5 1/2 FH

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

5 1/2 FH

5 1/2 FH

5 1/2 FH

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

4 1/2 IF

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

BOX

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

PIN

6 1/2

6 3/4

6 7/8

6 3/4

6 3/4

7

6 3/4x5

6 3/4x5

5

5

5

3 1/2

2 3/4

Tool

Tool

Tool

3 1/4

2 7/8

2 7/8

4.276

3

4.276

DEVON Energy


# 5 IN OUT


16/18

40004739Job Number

Client

Well lease

DEVON Energy



G. Wiygul

Mike Felder

Directional

Drillers

ROWAN ParisRig

Milled Tooth Bit

Steerable

675-1135

Bit Description

BHA Type

PDM Description

Slide Sheetfor

BHA #5



Footage


6-4-2000 R 4368 4373 5 20 50 400369 1250 1300

S 4373 4383 O HS 10 30 364 1200 1250

R 4383 4413 30 16 50 300344 1150 1250

R 4413 4424 11 4424.7 89.51 67.63 3.35 10 50 300369 1300 1350

R 4424 4445 21 10 50 300393 1300 1350

R 4445 4465 20 8 50 300442 1650 1725

S 4465 4472 180 7 35 393 1400 1450

R 4472 4609 137 4485.2 89.51 67.36 0.45 6 50 300393 1400 1450

R 4609 4619 10 4576.5 89.31 67.72 0.45 8 50 280418 1550 1600

R 4619 4688 69 4666.9 89.05 67.95 0.38 8 50 280442 1675 1725R 4688 4735 47 8 50 280393 1475 1525

R 4735 4807 72 4757.4 88.94 68.20 0.30 18 50 330369 1300 1400

R 4807 4826 19 12 50 300442 1800 1850

R 4826 4838 12 10 50 320442 1800 1850

R 4838 4917 79 4847.6 89.63 69.06 1.22 18 50 360369 1375 1500

R 4917 4984 67 4938.5 90.11 69.23 0.56 10 50 340432 1750 1800

R 4984 5007 23 14 50 340432 1750 1850

R 5007 5020 13 18 50 320369 1350 1500

R 5020 5068 48 5032.6 90.03 69.45 0.25 18 50 360418 1700 1800

R 5068 5101 33 10 50 360418 1700 1750R 5101 5150 49 5127.4 90.29 69.47 0.28 16 50 380393 1500 1650

R 5150 5166 16 10 50 300423 1750 1800

R 5166 5225 59 5221.2 90.89 69.83 0.75 18 50 360393 1550 1650

R 5225 5291 66 12 50 340418 1750 1800

R 5291 5302 11 5317.0 90.86 69.96 0.14 12 50 340403 1650 1700

Comments

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