Tension Leg Platform - ALRDC - Home - Artificial Lift … · A" Annulus Packer Brine = 8.4 lb/gal...
Transcript of Tension Leg Platform - ALRDC - Home - Artificial Lift … · A" Annulus Packer Brine = 8.4 lb/gal...
1© 2004 Weatherford. All rights reserved.
Jerry W. RobinsonFebruary, 2006
Tension Leg PlatformGas Lift
2© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
• Deepwater TLP completions in the Gulf of Mexico present special challenges because of the water depths, pressures and environment.
• Because each of these completions are unique from one another, equipment is designed to meet specific parameters.
• There are many design variations for gas lift/chemical mandrels already available __ I’m sure there’s more to come.
• The gas lift design process and specific equipment used in several deepwater installations will be presented today.
3© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
• In some instances the riser sections of these completions must be unloaded. There are several methods used:1. Most TLP’s production casing runs through the riser
to the surface. Generally unloaded through gas lift mandrels placed in the production string.
2. Unload through a sliding sleeve placed in the gas lift injection line when production casing does not run to surface.
3. Unload through a control line installed in the riser section when production casing does not run to surface.
4© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
• The method used in the gas lift design of deepwater wells is essentially the same as in other gas lift installations witha few other considerations such as:
– water depths – production rates – tubing sizes – gas injection system pressures (KO & OP)– Temperature profiles– Special metallurgy
5© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
1. Water depths = 3,000’ to 6,000’2. 1500 to 10,000 BLPD3. 3.5”, 4.5” and 5.5” tubing4. 1400 psi to 3200 psi kickoff pressure5. 1400 psi to 3000 psi operating pressure6. Temperature profiles; Shelf Well vs. Deepwater Well. 7. Inconel, Super 13 Chrome-110 and 13 Chrome-85
material
6© 2004 Weatherford. All rights reserved.
TYPICAL TEMPERATURE PROFILE FOR ONSHORE OR SHELF (SHALLOW WATER) OFFSHORE WELL
7© 2004 Weatherford. All rights reserved.
EXAMPLE of FLOWING TEMPERATURE PROFILE for DEEPWATER OFFSHORE
8© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
• Reservoir information for initial and future production rates are evaluated with various nodal analysis programs (WellFlow, WEM, Prosper) for predicting:
– Optimum tubing size(s) for natural flow conditions
– Predicted reservoir pressure declines– Gas lift performance (injection depth,
injection pressure, injection rates, etc)– Production system upgrades
9© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
• Other parameters can effect the gas lift design and gas lift equipment in deepwater TLP well completions. For this presentation, there are three (3) examples:
– EXAMPLE (1) __ Casing restrictions & H2S Environment
– EXAMPLE (2) __ 2940 ft Water Depth, Casing & Liner restrictions, gas injection pressure upgrade from 1400 psig to 2950 psig
– EXAMPLE (3) __ 3400 ft Water Depth, Casing restrictions, gas lift design & mandrel spacing for unloading purpose
10© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
• EXAMPLE (1)– Six control lines are run in the well. 8-5/8” casing is
run to 9207’ MD, 7-5/8” to 9300’ and a 5.5” production liner run to depth.
– Production tubing is 4” 10.9# from 0 to 9000’ .– SBHP = 3000 psi.– Well is located in a water flood field and future H2s
production is a possibility. Metallurgy for tubing and accessories is 25 Chrome and Inconel.
11© 2004 Weatherford. All rights reserved.
Mudline at 3214+ below MSLA" Annulus Packer Brine = 8.4 lb/gal 2% KClB" Annulus Brine = 11.2 lb/gal CaCl2
PROPOSED MECHANICAL SKETCH*
Prod Csg Prod Tbg8 5/8" 44 lb/ft 4" 10.9 lb/ft - from 0' to 9,000' * Completion detail only; ML wellhead, outer casings, riser, tree omitted7.626" ID 25Cr-125M, VARST1
7.560" Spec. Drift 3.351" Drift Xmas Tree Wellbay Slot 143.476" ID Config. = B Water Depth 3214'
WP = 10 ksi RT Elevation 191' above MSLBore = 4 1/16" *All depths based on H&P 202 TLP rig
4 1/2" Baker Mudline Hanger @ 3639' except as noted(86'+ below DrillQuip 8 5/8" casing hanger) Production Riser
Nominal OD: 10 3/4"ID: 9.835" + 0.010"
Landing Nipples Control LinesType Size Bore No-Go Depth Type Size Wall Material DepthRPT 3 1/2" 2.750" ------ 5900' MLTH 1/2" .049" 316L 3639 XN 2 3/8" 1.875" 1.791" 15073' Chem Inject 3/8" .049" 825 5708'
Chem Inject 3/8" .049" 825 5858'SCSSV 1/4" .065" 825 5900Hydraulic GLM 1/4" .049" 825 9079'DHPG 1/4" .028" 825 14926'
3 1/2" & 2 3/8" Gas Lift Mandrels MD TVD Mandrel Valve TRO Choke / Port
9079' 8600' 3 1/2" Hydraulic 10024' 9200' 2 3/8" 1.0"10989' 9800' 2 3/8" 1.0"11925' 10400' 2 3/8" 1.0"12752' 11000' 2 3/8" 1.0"13512' 11600' 2 3/8" 1.0"14255' 12200' 2 3/8" 1.0"
3 1/2" RPT Profile (2.750" Seal Bore)3 1/2" HES SP 10K SCSSV, alloy 718@ 5900' (max allowable depth=6100')
8 5/8" X 7 5/8"
X-over @ 9207Prod casing
TOL 5 1/2" @ 9300' 7 5/8" 39.0 lb/ft6.625" ID
Prod Liner 6.500" Drift5 1/2" 20 lb/ft From 9207' to 9300'CYP-110 Hydril 5134.778" ID Prod Tubing 1st KOP: 4.653" Special Drift From 9000' to 15,046' will have SC-80 couplings 2nd KOP:
3 1/2" 10.2# 2.922" ID, 2.797" Drift Hole Angle through perforations = 36 deg22Cr-125, VARST1 SC-80
Prod Tubing2 JTS BELOW DHPG AT 14,926'3 1/2" 10.2# 2.922" ID, 2.797" Drift22Cr-125, VARST1
Production Packer Assembly
2 3/8" SCHL. DHPG Mandrel; Bore = 1.991" @ 14,926'HES "HVT" Production Packer alloy 718 ; Bore = 2.375" @ 15,046'3 1/2" "XN" Nipple (1.791" no-go) Set at < ?? Degrees @ 15,073'Ported sub @ 15,095'Production stinger Bore = 2.???" Push thru collect and indexing mule shoe
"N" SANDHES VTA Gravel Pack Packer @ 15,102'; Bore - 2.750"Ceramic Fluid Loss FlappersShear Sub (50,000# Shear Value)
20x40 US Mesh Perforations: 15330-430' (100')GP Sand 12 JSPF
Alloy 825 All Welded WWS (0.008" slot) on 2 3/8",4.7 lb/ft super 13CR95 Pipe, VARST1 Push Thru Collet, Seal Stinger with Mule Shoe
Sump Packer 15,440' (Min 10' below bottom perf)
PBTD = 15,550'TD 15,655' 5 1/2" ,20#, CYP-110, Hydril 513, casing Shoe @ 15,645'
Directional Detail
Completion Design SummaryOne perforated, gravel packed completion is installed in the N sand. High rate acid jobs and gravel packs were pumped to achieve low skin. 3 1/2" 22 chrome production tubulars are installed due to the H2S expected. A permanent downhole pressure gauge (i.e., PDG) will provide continuous reservoir pressure information. A 4-1/16" bore Xmas tree (10 ksi WP) utilizes a single wing and choke with a 6" Coflexip flow line leading to the TLP hard piped flow line. The production tubulars are installed through a large bore 10 3/4"x8 5/8" dual casing riser.
12© 2004 Weatherford. All rights reserved.
TLP – Gas LiftJerry W. Robinson
• The top gas lift mandrel (Hydraulic Valve) is located as deep as possible without going into the 5” liner.
• The depth of the hydraulic gas lift valve is not effective as the SBHP declines to 3000 psi or less.
• For deeper injection depths, retrievable, slimhole gas lift mandrels are positioned in the liner section every 600’to the top of the packer. This 600’ spacing was selected because it would provide for optimum gas lift operations over a broad range of rates and pressures.
13© 2004 Weatherford. All rights reserved.
Liquid Rate Gas Inj Depth
Qg inj (Mscfd)50004000300020001000
LIQ
UID
RA
TE
(b
bl/d
)
2600
2400
2200
2000
1800
1600
1400
GA
S IN
J D
EP
TH
(f
t)
10050
10000
9950
9900
9850
9800
9750
9700
9650
System Deliverability Plot
Fluid Properties : Oil Gr = 34.0 API Gas Gr = 0.66 Water Gr = 1.06 WLR = 50.0 % GOR = 500.0 scf/bbl
Wellbore Data : WHP = 250.0 psig TVD = 13029. ft Corr =Hage/Brown Tbg/4.000/15150 Csg/0.00/15151
Reservoir Data : Pr = 3000.0 psig BHT = 220.0 deg F
PI = 8.0 b/d/psi
LIQ
UID
RA
TE
(b
bl/d
)
2600
2400
2200
2000
1800
1600
1400
GA
S IN
J D
EP
TH
(f
t)
10050
10000
9950
9900
9850
9800
9750
9700
9650
14© 2004 Weatherford. All rights reserved.
Liquid Rate�OPER P DIF = 150.0 Liquid Rate�OPER P DIF = 200.0Liquid Rate�OPER P DIF = 268.0 Liquid Rate�OPER P DIF = 400.0Liquid Rate�OPER P DIF = 500.0 Gas Inj Depth�OPER P DIF = 150.0Gas Inj Depth�OPER P DIF = 200.0 Gas Inj Depth�OPER P DIF = 268.0Gas Inj Depth�OPER P DIF = 400.0 Gas Inj Depth�OPER P DIF = 500.0
Qg inj (Mscfd)50004000300020001000
LIQ
UID
RA
TE
(b
bl/d
)
3000
2500
2000
1500
1000
GA
S IN
J D
EP
TH
(f
t)
10500
10000
9500
9000
8500
8000
System Deliverability Plot
Fluid Properties : Oil Gr = 34.0 API Gas Gr = 0.66 Water Gr = 1.06 WLR = 50.0 % GOR = 500.0 scf/bbl
Wellbore Data : WHP = 250.0 psig TVD = 13029. ft Corr =Hage/Brown Tbg/4.000/15150 Csg/0.00/15151
Reservoir Data : Pr = 3000.0 psig BHT = 220.0 deg F
PI = 8.0 b/d/psi
LIQ
UID
RA
TE
(b
bl/d
)
3000
2500
2000
1500
1000
GA
S IN
J D
EP
TH
(f
t)
10500
10000
9500
9000
8500
8000
15© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
• Because H2s production is possible, it was necessary to use a gas lift mandrel that would not allow any produced fluids to enter into the casing annulus in any circumstance, even if the pocket was empty.
• The DVX mandrel was developed to meet this criteria.• External check valves are installed on the gas lift mandrel
and injection gas passes through them into the valve pocket area and out into the tubing string.
• The external checks prevent any flow from the tubing back into the casing regardless of what type of valve or check mechanism if any, is loaded into the pocket. Valve changes can be done without any worry of tubing-to-casing communication path.
• Status: installation of equipment pending.
16© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
DVX mandrel features true secondary pressure barrier from tubing to casing provided by external check valves
17© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
• EXAMPLE (2)– Water Depth: 2940’– Production Casing: 7-58” 33.7# , 7-5/8” 39# and 5.5”
20#– Production Tubing: 4.5” 15.10# to SSCSV and 3.5”
10.2# to depth, 13 chrome 110 ksi– Gas lift operating pressures of 1400 psi and 2400 psi
are evaluated
18© 2004 Weatherford. All rights reserved.
Tubing4 1/2", 13.5#, SM25CR125, VARST-1ID 3.920", Drift 3.795"Coupling OD 5.030"(Max) Beveled
3 1/2", 10 ksi Schumberger HPCI-DC-II CIN w/ sliding sleeve VARST-1-SB5.50"±OD x 2.902" Min ID, 2.797" Drift, w/Pup Joints T&B **
3 1/2", 10 ksi SCSSV HES SP VARST-1-SB5.40" OD x 2.750" ID, w/Pup Joints T&B **2.750" Bore "RPT" LN Profile in Top Sub
6007' MD
Hanger Setting / Annulus Displacing Tube
Production Casing
Cameron Back Pressure Valve Prep
Chemical Injection 3/8" OD x .065" Wall,
x 7", 38#, P-110, 10,650'-TDID 6.625" Drift 6.50" x ID 6.094", Drift 5.969"
3 1/2", 10 ksi, Schlumberger PDPG Mandrel
PDPG TEC 1/4" OD x .028" wall, I825 (Encapsulated 9MM round)
H:/c
once
pt/m
ars/
mar
-a15
-a.d
wg
04/1
2/04
SCSSV 1/4" OD x .065" Wall, 2205 Duplex
2.656" Drift. Production Pkr, Baker HP/HT Edge7", 38#, VARST-1 T&B, 5.70" Max OD, 2.70" Min ID
2.562" Bore OTIS "RN" LN, 2.329" Min ID,VARST-1, w/Pup Joint ** @ 17,398'
3 1/2" Straight Slot LocatorGP Packer @17,293' MD WL
2 7/8", 26' Lead-in w/ Indexing Mule Shoe
Port Closing SleeveFluid Loss Control Device
w/ 25CR, 85 ksi mandrel
6136' MD
5.33"OD, 5.55" OD drift, 2.902" ID, 2.867" ID drift w/ Pup Joint T&B **
(1) Joint, Tubing **
(1) Joint, Tubing **
6' Pup Joint **
Pup Joint,4 1/2", 13.5#, SM25CR125, VARST1
** 3 1/2", 10.2#, SM25CRW125, VARST-1 Beveled
6' Pup Joint **
3/8" OD x .049 Wall 316L SS
Baker Mudline Tubing Hanger, VARST-12.912"ID, 2.867" Drift, 6068' MD, w/Pup Joints T&B **
3 1/2" Blank, 232', 13CR
302', 316 SS Wire Wrap Screen
7" Casing Shoe @ 19,400' MD WL
Inconel 825
@ 17,333' MD Tubing Tally
on 13CR Base, 4.12 OD x 2.992" Drift
Packer Releases w/ Retrieving Tool.
17,253' MD
protector and centralizer placement.NOTE: See tubing detail for control line
Annular Fluid: 2% KCl water plus O and
Sump Packer @ 17,889' MD WL
Cement Retainer @ 19,324' MD WLwith 100' of Cement on top.
5.695" OD
7 5/8", 39#, P-110, 0'-2940' x 7", 32#, P-110, 2940'-10,650'
x ID 5.920", Drift 5.795"
(1) Joint, Tubing **
17,418' MD Tubing Tally
(16' is 8 ga non-perf, 32' is 6 ga, 254' is 8 ga)
fish at 18,162 MD DP. (18,052' MD WL)Pushed 2 Sump Packers downhole. top of
No Shear Joint run below GP Packer
WATER DEPTH 2940'
I625 on 4130 75ksi material with 718 internals.NOTE: Tree is FMC 4 1/16", 10k, BMV is full clad
Remainder of tree is 410 SS body and trim.
Schlumberger WRFC-H GLM control line1/4" OD x .049" wall, 2205 Duplex filled w/ Diala-ax
(1) Joint, Tubing **
(1) Joint, Tubing **
2.867" Drift, 24CR, 85 ksi mandrel. Anchor has 100,000 lb
Baker SRA, sz 80-40, made up to top of packer5.558" Max OD, 2.972" Min ID
shear ring release or right hand rotation.
Hole angle through
is 68 @ 17,888'.Max hole angle
Note:
perfs is 65 - 68 .Perforate 17,610'-880'UPPER GREEN (M ) SANDwith 12 spf.
2
GP Packer are tied to WL depths.strap. Measurements below theGP Packer are from the tubing tallyMeasurements above the
w/ PQG gauge VARST-1-SB, 25Cr, 80 ksi
Pup Joint T&B **5.672" OD, 2.716" ID, 2.637" drift. Mandrels have dummies installedWeatherford 3 1/2" SBRO-2 GLM @ 7586', 10,411', 15,808',
Casing patch across EBO @ 7900'Weatherford-HOMCO .089" wall, 20' long, 5.894" ID
Casing patch across MLCH @ 3260'Weatherford-HOMCO .089" wall, 20' long, 5.894" ID
Weatherford-HOMCO .089" wall, 20' long, 5.894" IDCasing patch across FMC Casing hanger
I718 FMC Tubing Hanger
Tension rating of mandrel is 315,000 lbs. @ 6208'. Mandrel has turned down SM25CRW125 coupling. Schlumberger WRFC-H GLM, 5.70" OD, 2.724" ID, 2.681" drift
Choke in FCV has two 1/16"
(1) Joint, Tubing **
slots, Pup joint T&B **
H S scavengers2
2
19© 2004 Weatherford. All rights reserved.
Liquid Rate Gas Inj Depth
Qg inj (Mscfd)4000350030002500200015001000
LIQ
UID
RA
TE
(b
bl/d
)
4500
4000
3500
3000
2500
GA
S IN
J D
EP
TH
(f
t)
7200
7000
6800
6600
6400
6200
System Deliverability Plot
Fluid Properties : Oil Gr = 24.4 API Gas Gr = 0.7 Water Gr = 1.06 WLR = 80.0 % GOR = 925.0 scf/bbl
Wellbore Data : WHP = 300.0 psig TVD = 16537. ft Corr =Hage/Brown Tbg/4.500/17745 Csg/7.63/17888
Reservoir Data : Pr = 6000.0 psig BHT = 181.0 deg F
PI = 5.0 b/d/psi
LIQ
UID
RA
TE
(b
bl/d
)
4500
4000
3500
3000
2500
GA
S IN
J D
EP
TH
(f
t)
7200
7000
6800
6600
6400
6200
20© 2004 Weatherford. All rights reserved.
Liquid Rate Gas Inj Depth
Qg inj (Mscfd)4000350030002500200015001000
LIQ
UID
RA
TE
(b
bl/d
)
5600
5200
4800
4400
4000
3600
3200
2800
GA
S IN
J D
EP
TH
(f
t)
16500
16000
15500
15000
14500
14000
System Deliverability Plot
Fluid Properties : Oil Gr = 24.4 API Gas Gr = 0.7 Water Gr = 1.06 WLR = 80.0 % GOR = 925.0 scf/bbl
Wellbore Data : WHP = 300.0 psig TVD = 16537. ft Corr =Hage/Brown Tbg/4.500/17745 Csg/7.63/17888
Reservoir Data : Pr = 5500.0 psig BHT = 181.0 deg F
PI = 5.0 b/d/psi
LIQ
UID
RA
TE
(b
bl/d
)
5600
5200
4800
4400
4000
3600
3200
2800
GA
S IN
J D
EP
TH
(f
t)
16500
16000
15500
15000
14500
14000
21© 2004 Weatherford. All rights reserved.
• The hydraulic valve at 6208’ is used with the operating pressure of 1400 psi.
• Future platform plans call for upgrading gas injection system to a 2950 psioperating pressure.
TLP – Gas LiftJerry W. Robinson
22© 2004 Weatherford. All rights reserved.
• The gas lift mandrels at 7586’, 10409’ and 15433’will be utilized if the operating casing pressure is increased to 2950 psi; under the assumed production rates of 6500 to 8000 blpd.
• Status: Shut in due to storm damage.
TLP – Gas LiftJerry W. Robinson
23© 2004 Weatherford. All rights reserved.
24© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
• EXAMPLE (3)– Water Depth: 3400’– Production Casing: 8-5/8”– Production Tubing: 4.5”– Gas lift operating pressure 1800 psi– Based on information supplied by operator for current
and future reservoir parameters, an unloading gas lift mandrel spacing was installed
– STATUS – currently flowing on its own, waiting on rig move so wireline operations be done
25© 2004 Weatherford. All rights reserved.
Liquid Rate Gas Inj Depth
Qg inj (Mscfd)40003000200010000
LIQ
UID
RA
TE
(b
bl/d
)
12570
12560
12550
12540
12530
12520
12510
12500
GA
S IN
J D
EP
TH
(f
t)
5950
5945
5940
5935
5930
5925
5920
5915
System Deliverability Plot
Fluid Properties : Oil Gr = 27.0 API Gas Gr = 0.765 Water Gr = 1.06 WLR = 0.0 % GOR = 950.0 scf/bbl
Wellbore Data : WHP = 392.0 psig TVD = 19142. ft Corr =Hage/Brown Tbg/4.500/20259 Tbg/2.875/20506 Csg/8.63/20526 Csg/8.63/20850
Reservoir Data : Pr = 7342.0 psig BHT = 182.0 deg F
PI = 16.64 b/d/psi
LIQ
UID
RA
TE
(b
bl/d
)
12570
12560
12550
12540
12530
12520
12510
12500
GA
S IN
J D
EP
TH
(f
t)
5950
5945
5940
5935
5930
5925
5920
5915
26© 2004 Weatherford. All rights reserved.
27© 2004 Weatherford. All rights reserved.
Liquid Rate
Qg inj (Mscfd)40003000200010000
LIQ
UID
RA
TE
(b
bl/d
)
8000
7800
7600
7400
7200
7000
6800
6600
System Deliverability Plot
Fluid Properties : Oil Gr = 27.0 API Gas Gr = 0.765 Water Gr = 1.06 WLR = 5.0 % GOR = 891.0 scf/bbl
Wellbore Data : WHP = 392.0 psig TVD = 19142. ft Corr =Hage/Brown Tbg/4.500/20259 Tbg/2.875/20506 Csg/8.63/20526 Csg/8.63/20850
Reservoir Data : Pr = 6020.0 psig BHT = 182.0 deg F
PI = 16.64 b/d/psi
28© 2004 Weatherford. All rights reserved.
TVD vs Pres�Rate = 7800 TVD vs Inj Gas Pres�Rate = 7800Mandrel Depth�Mandrel = Mandrel 1 Mandrel Depth�Mandrel = Mandrel 2Mandrel Depth�Mandrel = Mandrel 3 Mandrel Depth�Mandrel = Mandrel 4Mandrel Depth�Mandrel = Mandrel 5 Mandrel Depth�Mandrel = Mandrel 6Mandrel Depth�Mandrel = Mandrel 7 Mandrel Depth�Mandrel = Mandrel 8Mandrel Depth�Mandrel = Mandrel 9 Mandrel Depth�Mandrel = Mandrel 10
PRESSURE (psig)6000500040003000200010000
TRU
E V
ER
TIC
AL
DE
PTH
(ft)
20000
15000
10000
5000
0NEW SPACING�
Pressure Profile
Rate = 7800.0 bbl/d Fluid Properties : Oil Gr = 27.0 API Gas Gr = 0.765 Water Gr = 1.06 WLR = 5.0 % GOR = 891.0 scf/bbl
Wellbore Data : WHP = 392.0 psig TVD = 19142. ft Corr =Hage/Brown Tbg/4.500/20259 Tbg/2.875/20506 Csg/8.63/20526 Csg/8.63/20850
29© 2004 Weatherford. All rights reserved.
Tension Leg Platform – Gas LiftJerry W. Robinson
• Summary– As can be seen in the gas lift deliverability plots, gas lift
had little impact based on original reservoir data. An unloading design was therefore chosen in the event the well loaded up. An unloading rate of 2000 BFPD was used to space out the unloading mandrels. Had the current reservoir data been used to design the gas lift spacing, a closer mandrel spacing would have been used in order to optimize production with gas lift. The new deliverability plot indicates an increase of 500 BFPD with 4 MMSCF of input gas at a depth of 6,600'.