spe 90376 presentation slides - turbine drilling with imgregnated diamond bits in hard abrasive...
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Breakthrough horizontal well drilling performance in hard abrasive sandstones by turbo-drilling in potassium formate brineTRANSCRIPT
Breakthrough Horizontal Drilling Performance in Pre-Khuff Strata with
Steerable Turbines
Mike Simpson, Shaohua Zhou, Dave Treece, Carlos Rondon, Tom Emmons, Saudi Aramco; Craig Martin Sii-Neyrfor and
Mohammad Tahir, Diamant Drilling Services
SPE 90376
Outline
Introduction
Economic Importance of Pre-Khuff Reservoirs
Pre-Khuff Geology
Turbo-drilling Experience in Saudi Arabia
Breakthrough Horizontal Drilling Performance
Turbo-drill Runs in Potassium Formate Brines
Conclusions
Introduction
Saudi Aramco Produces 8.1 mmbopd, 6.9 bscfd non-associated Gas &1 mmbpd NGL’s
Introduction
It operates 49 Land and Offshore Drilling & Workover Rigs consisting of:
25 Onshore Oil Rigs
3 Offshore Oil Rigs
21 Land Gas Rigs, 2000 hp or larger
Economic Importance of Pre-Khuff Reservoirs
25% Gas Prod. f/Pre-Khuff – Mostly UnzyUnzy’s Most Abrasive & Problematic to DrillGas Demand will inc. to 12 bscfd by 202550-55% of this must come from the Pre-Khuff Currently Drlg. 47 Gas Wells/year w/18 RigsUtilizes three Workover Rigs & one Snub. U.Unzy Well Design Changed to Horz. in 2003 to meet demand
Pre-Khuff Geology
Pre-Khuff – Formations of Lower Permian Age or older deposited before the Khuff
Include the Unayzah, Jauf, Tawil, Sharawra, Qusaiba, Sarah, Qasim and Saq
Mainly hard and ultra abrasive sandstones interbedded with siltstones and shales
Shales often unstable requiring 1500 psi overbalance to mitigate tight hole
Unayzah A, B & C
Unzy-A has 3000
to 9000 psi UCS (PDC Drillable)
Unzy-B (7000-27,000 on this RMA) Too hard & Abrasive for PDC’s – TCI’s & Impregs Only
Unzy-C 9000-22,000 UCS
Unayzah-A Core from Tinat-6
•Abrasive
• Not as Hard as UNZY-B
•Friable
Internal friction angle (phi): Unayzah reservoir core rock mechanics lab test result
40
45
50
55
60
65
0 2 4 6 8 10 12 14
porosity (%)
inte
rnal
fri
ctio
n a
ng
le (
deg
)
phi (WDYH-1)
phi (GHZL-2)
phi (GHZL-3)
Unayzah Porosity vs. Abrasivity from Offset Core
Unayzah Angle of Internal Friction typically ranges between 42 and 63° for the A, B and C.
BHA: 3 BHA TYPE : VerticalDATE: WELL : TINAT #3
JOB N° : RIG: SF 162 ARAMCOGRAPHIC DESCRIPTION OD (in)ID (in) LENGTH ( ft )SERIAL N°
8 3/8" Hughes Christensen S279G8-3/8" -- 1.17 1.17)
CUSTOMER :
15 x HWDP
2 x Drill Collars
5" 3" 452.41970.82ARAMCO
Jars
6-1/2" 59.45518.41 ARAMCO
Cross-Over 6-1/2” 1.49 458.96ARAMCO
Flex Joint 457.47ARAMCO
12 x Drill Collars
6-1/2” 1.50 426.81ARAMCO
6-1/2"
2-13/16"367.27425.31 ARAMCO
Roller Reamer 6-1/2" 2-7/8" 6.30 58.04 ARAMCO
8 3/8"
Circulating Sub 2 " 1.80 51.74 ARAMCO
Turbine Section 1 6-5/8" -- 17.61 49.94
Turbine Section 2 -- 16.96 32.33
8-516"
Turbine Bearing Section6-5/8" 12.40 15.37
Bit-Box-Stabilizer 3" 0.95 2.12 NEYRFOR
64010
6-5/8"
6-1/2"
Cross-Over 2-13/16"
66039
66042
2-13/16"15.33
8-516"
ARAMCO442.14
6-1/2"2-13/16"15.33
2-13/16"
2-13/16"
BIT-STUCK BHA: TINAT #3
8/30/97
--
Bearing Shaft(Box-End)
6-1/2"
6-5/8"
--
-- 0.85 2.97 NEYRFOR
The 1st Vertical Turbo-drill run was made with a Two Stage conventional turbine and Imprenated diamond Bit from 16,143 to 16,149’.
Attempted to pick up off bottom for connection, bit stuck on bottom on 8/30/97.
Back-reamed and jarred fish up to 16,144’.
Spotted Diesel, Pipe-Lax and 15% HCl, No Success.
Finally string-shot/backed off @ 14,674’ & again @ 15,736’ leaving 430’ of fish (Bit / turbine / CS / NBRR / 12 DC’s) in hole.
Lost time: 12 days
Stuck Pipe/Fishing Cost: $560,000
Turbo-drilling Experience in Saudi Arabia – 1st Run
Drilling Report
BHA: 2 BHA TYPE:VerticalDATE: WELL :
JOB N° : RIG:NAD-117 ARAMCOGRAPHICDESCRIPTIONOD (in)ID (in)LENGTH ( ft )SERIAL N°
CUSTOMER :9/21/97QTIF-150
BIT-STUCK BHA: QATIF #150
15 HWDP 3-1/2"2-1/16"458.84980.22ARAMCO
Jars
4-3/4"2-1/4"62.43521.388ARAMCO
2 x Drill Collars
12 x Drill Collars4-3/4"2-1/4"
28.36458.59ARAMCO
Roller Reamer4-3/4”2-1/4"5.2956.10ARAMCO
5-7/8"
Cross-Over 2 1/4"1.0750.81ARAMCO
5-13/16"Turbine Section 14-3/4"-- 18.2149.7446114
5-13/16"Turbine Section 24-3/4"-- 17.3231.5346115
5-13/16"Turbine Bearing Section4-3/4"-- 12.21514.212
(Box-End) Bearing Shaft
0.782.00
5 7/8"-- 1.221.225-7/8” Impreg Bit (Pin-Up
4-3/4"
4-3/4"
374.49 ARAMCO430.59
4-3/4"2-1/4"
--
Drilled 5-7/8” Hole with T-2 Turbine and 5-7/8” STC-K35TX Impreg Bit from 16,135 to 16,147’ (12’). Picked up to make connection and stuck pipe 7’ off bottom on 9/20/97.
Spotted 40 bbl Grease pill - jarred and worked on pipe, no success.
Spotted 1100 gal of HF acid & two 40 bbl EZ-Spot Pills & Worked pipe.
String Shot Backed off @ 15,866’ leaving 274’ of fish (7 DC, NBR, XO, Turbine & Bit) in hole.
Worked on fish a total of 11 days then decided to ST.
Spent another 13 days sidetracking back to 16,147’.
Total Time lost: 23 days
Total Stuck Pipe/Fishing Cost: $690,000
Turbo-drilling Experience in Saudi Arabia - 2nd Run
Drilling Report
BHA:2 BHA TYPE:
VerticalDATE: WELL:
JOB N° : RIG:SF 174 ARAMCOGRAPHICDESCRIPTIONOD (in)ID (in)LENGTH ( ft )SERIAL N°
32 x 3-1/2" HWDP3-1/2"2-1/16"986.671549.9ARAMCO
3 x Spiral Drill Collars4-3/4"2-1/4"92.94563.22ARAMCO
Jars 4-3/4"2-1/4"31.35470.28ARAMCO
10 x Spiral Drill Collars4-3/4"2-1/4"310.73438.93ARAMCO
5-13/16"String Stabilizer-- 2-1/4"5.76128.20ARAMCO
2 x Spiral Drill Collars4-3/4"2-1/4"62.18122.44ARAMCO
Bit Sub w/ Float Valve4-3/4"2" 3.1560.26ARAMCO
Cross Over Double Pin.4-1/2"1-3/8"1.4457.11ARAMCO
5-13/16"String Stabilizer-- 2-1/4"5.7755.67ARAMCO
5-13/16"Turbine Section 14-3/4"-- 18.2049.9046143
5-13/16"Turbine Section 24-3/4"-- 17.3031.7046122
5-13/16"Turbine Bearing Section4-3/4"-- 12.1914.40Bearing Shaft (Pin-End) Safety Sub 5" 1-3/16"0.901.90 5-7/8"-- 1.001.005-7/8” Impreg bit (Box-Up / T.F.A: =1.00in²)
CUSTOMER:
BIT STUCK – HRDH-642
HRDH-642 12/28/99
4-3/4"-- 0.312.21
Drilled 5-7/8” Hole with T-2 Turbine and 5-7/8” STC-KGRCETPX Impreg Bit from 13,975 to 14,057’ in the Unayzah-B. Picked up to check 9’ Drilling Break f/5-25 fph – Pipe Stuck.
Spotted 50 bbl Hi-Vis and Grease pills & jarred with 25K, no success.
Jarred out of Neyrfor Bit Safety Sub with 60K. Left bottom half of Safety Sub and Impreg bit on bottom (1.57’).
Milled and worked on fish with 5-7/8” Burn shoes, Cobra Mills, Taper Taps and Jars for 21 days and finally broke through.
Total Time lost: 23 days
Total Stuck Pipe/Fishing Cost: $842,000
Turbo-drilling Experience in Saudi Arabia - 3rd RunDrilling Report
Primary Cause of Bit StickingRadial Hole Deformation
elastic hole deformation(E = 2.8 Mpsi, v = 0.3, Biot = 0.8, TVD = 14050 ft
Sv = 1.05 psi/ft, Shmax = 1.27 psi/ft, Shmin = 0.82 psi/ftPp = 90 pcf, MW = 100 pcf)
0.900
0.925
0.950
0.975
1.000
1.025
1.050
05 10 15 20 25
3035
4045
5055
606570
7580
85
90
95
100105
110115
120125
130135
140145
150155160165170175
180185190195200205
210215
220225
230235
240245
250
255260
265
270
275
280285
290295
300305
310315
320325
330335340345350355
For 8 3/8" bithole size reduction = 0.0684 (in)hole enlargement = 0.3936 (in)
For 5 7/8" bithole size reduction = 0.0476 (in)hole enlargement = 0.2761 (in)
roller cone bit drills hole usually1/16" (0.0625 in) larger than bit size
Shmax
Shmin
initial hole size
after elastic deformationdue to high in-situ stresses
initial breakout zone
Radial Hole Deformation and breakout in the near wellbore region due to High Insitu Stresses
Equivalent to 1/16” in 8-3/8” hole and 1/32” in 5-7/8” hole
Radial Hole Deformation
Excessive Breakouts normally occurred across Sandstones, as shown in this Image Log from HWYH-950
Secondary Cause of Bit Sticking – Unstabilized Rotating Length
Bit Box Stab
Pin Up Bit Box Down ShaftLower Brg Stab Turbine Body
2.97 ft
2.00 ft
Turbine BodyLower Brg StabBox Down ShaftPin Up Bit
2.21 ft
Turbine BodyLower Brg StabPin Down Shaft
Box Up Bit
TINAT-38 3/8”
Bit Sticking
QATIF 1505 7/8”
Bit Sticking
Haradh 6425 7/8”
Bit StickingBit Safety Sub
1.43
Box Up Bit
Pin Down Shaft
Lower Brg Stab
Turbine Body
HWYH 9618 3/8”
NO Bit Sticking
Turbo-drilling Experience in Saudi Arabia – 4th Run
4th Vertical Run on HWHY-961:
8-3/8” IADC M842 Impreg bit with Box-up Connection
Turbine Sleeve with Back-reaming Feature
Prismatic Link Release Mechanism (120,000 lbf)
Turbo-drilling Experience in Saudi Arabia – 4th Run
Run on HWYH-961
Made 242’ in 23.5 hrs @ 10.3 fph with cost of $443/ft
Figure 11: Caliper Log over Turbo-Drilled Interval (100 pcf MW) (No undergauge hole across Unayzah or Jauf)
7.250
7.625
8.000
8.375
8.750
9.125
9.500
9.875
10.250
10.625
11.000
11.375
11.750
12.125
12.500
13690
13700
13710
13720
13730
13740
13750
13760
13770
13780
13790
13800
13810
13820
13830
13840
13850
13860
13870
13880
13890
13900
13910
13920
13930
13940
Depth (feet)
Cal
iper
(in
ches
)
0
20
40
60
80
100
120
140
GR
(ap
i)
CALX (in)
CALY (in)
GR (api)
Khuff -D
Anhydr i teUnayzah Jauf
HWYH-961 – No Undergauge hole across Unayzah or Jauf
Fourth Turbodrill Run – No Undergauge hole
Horizontal Vs. Vertical Well Productivity
Horizontal Wells showed substantial increase in productivity over Vertical Wells without Fracking
GH
ZL-3
GH
ZL-8
GHZL-4
GHZL-11(H)GHZL-10 GHZL-5 GHZL-7(H)
GHZL-2
GHZL-9(DL)
GHZL-6(H)GHZL-1
Unayzah even tougher to drill horizontally
Diminished bit performance in 5-7/8” vs. 8-3/8” bits
Diminished bit performance in Horizontal vs. Vertical Hole
Requirement that all bit runs be made on PDM’s at much higher RPM’s than on rotary
Diminished bit performance in the target reservoir - the Unayzah-B
Abrasive Wear/Lost Cones – PDC/Impreg Wear Major Problems in Unayzah-B
Two 5-7/8” IADC 627Y TCI’s lost all three cones while drilling Unayzah-B on WDHY-1
HSE concern over tripping frequency with TCI’s (every 14 hrs) in desert climate with daytime temp ≥120°F
Lost Cones – PDC/Impreg Wear Major Problems in Unayzah-B
RR Impreg 100% Worn after drilling 22’ in 8.5 hours
Run on Low-Speed PDM
ROP: 2.6 fph
WOB: 13,000 lbf
RPM: 190Dull: 8-8-RO-G-X1/16
Lost Cones – PDC/Impreg Wear Major Problems in Unayzah Formation
PDC completely cored out after Drilling 219’ in 26.5 hours
Run on Low-Speed PDM
ROP: 8.2 fph
WOB: 18,000 lbf
RPM: 240Dull: 8-7-RO-M-X-IN-CR&BT-PR&DMF
Horizontal Solution to Radial Hole DeformationDrill Paralell to Maximum Horz. Stress Axis
Horizontal Wellbore Drilled Due East or West in Ghawar Area(Parallel to Shmax)
•Shmax
ShmaxShmax
Vertical WellHole diameter reduction causing ”bit sticking”
Slight Hole diameter enlargement providing stable hole & drilling
conditions “no sticking”
Shmax
Solution to hole spiraling – One Stage 4-3/4” Steerable Turbine & Box-Up bit (Min. Rot. Length)
One Power Section
99 Pressure Profile Turbine Blade Sections
Flexible Titanium Drive Shaft with1° integral bend
Use of Box-up bit with Turbine-Sleeve
Breakthrough Horizontal Drilling Performance on WDHY-1
1st Horizontal Run: 5-7/8” IADC M842 Box-up 12 blade Impregnated diamond bit run on advanced steerable turbodrillDrilled 737’ averaging 5.5 fph in 134 rotating hours with cost of $402/ft. Graded 3-3-WT-A-X-I
Breakthrough Horizontal Drilling Performance on WDHY-1
2nd Horizontal Run: 5-7/8” IADC M842 Box-up 12 blade Impregnated diamond bit run on advanced steerable turbodrill, drilled 852’ averaging 7.0 fph in 122 rotating hours with cost of $330/ft. Graded 3-3-WT-A-X-I
Turbo-drill Operating Parameters
WDYH-1(re): turbine drilling parameters (SA5.4)
0
5
10
15
20
25
30
35
40
1585
0
1590
0
1595
0
1600
0
1605
0
1610
0
1615
0
1620
0
1625
0
1630
0
1635
0
1640
0
1645
0
1650
0
1655
0
1660
0
1665
0
1670
0
1675
0
measured depth, ft
RO
P /
WO
B /
Cir
c M
nt
0
500
1000
1500
2000
2500
3000
3500
4000
RP
M /
GP
M /
PS
I
Circ Mntaver WOBROP FT/HRturbine RPMPress PSIFlow GPM
WOB: 4,000 lbf
RPM: 1,400
ROP: 7.0 fph
P. Press: 2900 psi
Circ. Rate: 220 gpm
Breakthrough Horizontal Drilling Performance on WDHY-1
100 200 300 400 500 600 700 800 900
SA5.2 WDYH-4
XR40YODPDWDYH-4
KRG50CETPXXWDYH-1
SA5.4 WDYH-1
FOOTAGE DRILLED
TURBINE
TURBINE
PDM
PDM
FORMATION DRILLED
Unayzah –B –Siltstone/ Sandstone
100 200 300 400 500 600 700 800 900
SA5.2 WDYH-4
XR40YODPDWDYH-4
KRG50CETPXXWDYH-1
SA5.4 WDYH-1
FOOTAGE DRILLED
TURBINE
TURBINE
PDM
PDM
FORMATION DRILLED
Unayzah –B –Siltstone/ Sandstone
Breakthrough Horizontal Drilling Performance on WDHY-1
14000
14500
15000
15500
16000
16500
17000
17500
MD
(Fee
t)
8/3/2003 8/10/2003 8/17/2003 8/24/2003 8/31/2003 9/7/2003 9/14/2003
WDYH-1 first lateral, 5-7/8" bit record
SA5.4
KRG50OETPXX
MILL
XTG48PX
SL63DGKPR
XSD57D
DSX143D
XR40YOD
R4
Impreg/Turbine Runs
58% of Total Footage
TCI, PDC, IMPREG/PDM RUNS
TCI/PDM RUNS
AVERAGE 5-7/8" BIT PERFORMANCE IN UNAYZAH-B For WDHY-1 & 4
BIT TYPE # RUN
AverageFOOTAGE
AverageHOURS
Avg. ROP
Avg.$/FT
DULL GRADET- B
TSP/PDM 1 13 7 1.9 4608 3---3
IMPREG/PDM 7 82 23 3.6 2219 8---8
IMPREG/TURB 2 794 128 6.2 366 3---3
PDC/PDM 14 152 28 5.5 1233 6---5
TCI/PDM 49 124 12 10.6 545 5---8
TSP/PDMIMPREG/PDM
IMPREG/TURB.PDC/PDM
TCI/PDM
4608
13
2219
82
366
794
1233
152
545
1240
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
Fo
ota
ge
Co
st,
$/F
T
$/FT FOOTAGE
Turbo-drill Runs in Potassium Formate Brines
Clear “solids free” Liquid the can be used as drilling, spotting, workover or completion fluids
Sodium Formate – up to 85 pcf Potassium Formate up to 98 pcf Cesium Formate up to 144 pcf Used in over 400 wells since introduced by
Shell in 1993 Extends Temperature Range of Conventional
Viscosifiers and Fluid Loss Agents from 240-340º F. Cesium Formate successful up to 429°F
Turbo-drill Runs in Potassium Formate Brines
3rd Horizontal Run: 5-7/8” IADC M842 12 Blade Impreg run on 4-3/4” Turbine in Unzy-B on HRDH-658Suffered Total Failure of Impreg Segment Cutting Structure
Turbo-drill Runs in Potassium Formate Brines
4th Horizontal Run: 5-7/8” IADC M842 8 Blade Impreg run on 4-3/4” Turbine in Unzy-B on HRDH-658Drilled 81’ in 24.5 hrs at 3.31 fph in 93 pcf K-Formate Brine Drilling Fluid
Turbo-drill Runs in Potassium Formate Brines
5th Horizontal Run:
5-7/8” IADC M842 12 Blade Impreg run on 4-3/4” Turbine in Unzy-B on HRDH-658
Drilled 60’ in 16 hrs at 3.75 fph in 102 pcf K-Formate Brine Drilling Fluid
Effect of Overbalance of Rock Confined Compressive Strength
Increased overbalance between formation and Drilling fluid increase confined compressive strength and impede drilling rates
18000
20000
22000
24000
26000
28000
30000
32000
34000
36000
0 100 200 300 400 500 600 700 800 900 1000 1100 1200
confined pressure (overbalance) in psi
rock
co
mp
ress
ive
stre
ng
th (
psi
)
f = 40o
f = 45o
f = 50o
f = 55o
f = 60o
Potassium Formate Brine Performance HRDH-658
Use of a 102 pcf potassium Formate Brine with excess CaCO3 on HRDH-658:
Lowered Pump Pressures
Decreased Rotating Torque and Drag
Allowed a 11,649’ horizontal section to be drilled with 1500 psi overbalance without differentially sticking the drillstring
Turbo-drill Run in 90 pcf K-Formate Brine on Tinat-3
4-3/4” Steerable Turbo-drill prior to being RIH on Tinat-3
Setting Turbo-drill bearing section in Mouse-hole
Stabbing Power Section onto BearingSection & Making up same
Making up Turbine Sleeve Impreg Bit and checking bearing gap on Turbo-drill
RIH with Turbo-drill Assembly
Record Breaking ROP run in Tinat-3 Unayzah-A
6th Horizontal Run:
5-7/8” M834 Impreg drilled 360’ in 50 hrs @ 7.2 fph with avg cost of $402/ft.
Graded 3-4-WT-A-X-I
Run in 90 pcf Sodium/Potassium Formate drilling fluid
Average 5-7/8" Bit Performance on Tinat-3 in the Unayzah-A
BIT TYPE # RUN
AverageFOOTAGE
AverageHOURS
Avg. ROP
Avg.$/FT
DULL GRADET- B
IMPREG/TURB 1 360 50 7.2 410 1---0
PDC/PDM 3 320 35 9.3 320 5---5
TCI/PDM 2 118 13 8.9 472 2---1
IMPREG/TURB.PDC/PDM
TCI/PDM
410
360320320
472
118
0
100
200
300
400
500
Average Drilling Cost,
$/FT $/FT
FOOTAGE
Potassium Formate Brine Performance in Tinat-3
Lowered Pump Pressures from 4200 to 3400 psi at 220 gpmDecreased Rotating Torque from 9400 to 7600 ft-lbReduced hole drag from 25,000 to 10,000 lbf at the end of the horizontal section
Composition of formate-based drilling fluidComponent Function Concentration
Formate brine Density control
Lubricity
Polymer protection
Biocide
1 bbl
Xanthan Rheology control
Drag reducer
1 ppb
Modified starch and/or ULV PAC
Fluid loss control 4 –8 ppb
Sized calcium carbonate
Bridging agent 20 ppb
Potassium carbonate
pH and corrosion control
2 ppb
Typical properties of formate-based drilling fluid
Property Initial Hot rolling @285oF
Mud density (pcf) 90 90
PV (cp) 24 30
YP (lb/100 ft2) 22 29
Gel (lb/100 ft2) 4/5 7/9
API Filtrate (cc/30 min)
2.4 1.8
HTHP fluid loss (cc/30 min) @ 285oF
13.6 12
ph 10.5 11
Solids Control System for K-Formate Brine
Two Decanting Centrifuges
Two Linear Motion Shale Shakers w/180 & 200 Mesh Screens
Total Solids Content ~ 5%
Drill Solids ~ 0.45%
Potassium Formate Brine Liquor in Individual Bulk Containers (IBC’s)
Potassium Formate Powder in 25 kg sacks
Poor-Boy Brine Recovery System
Drain Lines from Rig Floor
Brine collected in IBC’s for Reuse
Expandable Sand Screen Completion
Well Completed with 1410’ of 4”/230 micron expandable Sand Screens
Run and expanded without major problems.
1
Successful Installation of 1410 ft of Expandable Sand Screens in TINT-3
7" Liner, 32 ppf@ 15191 ft MD
9-5/8" Casing, 58.4 ppf
7" Liner
Reservoir top
Running
4" ETC, 230 micron, 5-½" 15.5#Vam FJL Box x 4" ESS Pin
4" ESS 230 micron, 38ft, 4"ESS Box x Pin
Sand ControlCirculating Valve,4-½" Stub AcmeBox Up
4" EBC, 230 micron, 4" ESSBox x 4-½" Stub Acme Pin
6' EXY Tieback PBR, 5.625" OD 8TPI S.AcmeThreaded Down
7" x 5-½" EXP Deployment Hanger/Packer5.625" OD 8TPI S.Acme Thread Up x 5-½" 15.5 lb/ft Vam FJL Pin Down
M. Depth of 7" Liner Shoe : 15191 ftM.Depth/Length of 5-7/8" O.H. : 16747 ftTotal Length of O.H. : 1556 ft5-7/8" O.H. Max Inclination : 84.5 degMud : 90 pcf (Na/K/Formate)Total ESS Run Length : 1410 ft (37Jnts)
Top EXP @14482 ft
5-7/8" hole, TD@ 16747 ft
ESS Screenbottom at 1606 ft(131 ft from TD)
7" LinerHanger top @ 14181 ft
@ 14711 ft
Hanger top @ 13465 ft
Bridge Plug top @ 14014 ft
Whipstock top @ 13990 ft
7" Liner Shoe@ 15698 ft
Conclusions
Steerable turbo-drill/Impreg bit drilling has emerged as the most cost effective and HSE friendly manner to drill the Unayzah-B formation if the well can be drilled parallel to the maximum horizontal stress axis.
Trajectory control was improved with consistent reactive torque of 30-35° and a build rate of 0.3°/100’ in the rotating mode.
Conclusions, cont.
IADC 627-737 TCI bits are also cost effective when total revolutions are maintained in the 150,000 to 175,000 total revolutions range.
PDM/PDC drilling appears to be the cheapest way to drill the lower compressive strength Unayzah-A horizontally in the Tinat Area.
Conclusions, cont.
The 90 & 102 pcf potassium formate brines used in Tinat-3 & HRDH-658 provided lower pump pressures, torque and drag values and better bit performance than previously observed with conventional water base drilling fluids.
In HRDH-658 the 102 pcf K-Formate Brine allowed a 1649’ quasi-horizontal section to be drilled with 1500 psi overbalance without differential sticking.
Conclusions, cont.
Plans are to use Impreg/Turbo-drill assemblies over the entire Unayzah build and horizontal sections in conjunction with K-formate brines to further access their applicability and cost savings potential.
Breakthrough Horizontal Drilling Performance in Pre-Khuff Strata with
Steerable Turbines
Thank You! Questions?
SPE 90376