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enne rapporttilhører
L 041U DOK. SEN RN �R.
KODE 131
Returneres etter bruk
RAPPORT
FRA
PRODUKSJONS,TEST NR 2
AV OLJE SONE
BRØNN: 31/2-2
RIG: WEST VENTURE
KARL GJERDE
MPPORT
FRA
PRODUKSJONS,TEST NR 2
AV OLJE SONE
BRØNN: 31/2-2
RIG: WEST VENTURE
KARL GJERDE
INNHOLD:
- Rekompleterings prograin for
"Oil-zone` og IIMJcaceous-zone" side
- tisub-surfacell kompletering
skjematisk side
- `Gas lift` generelt side
"Gas lift fldw-controler" and side
picket mandrel, skjematisk side 4
"Flow-controlerl' s-lde.
- "Flow-controler latch.assy." side
- USide - pocket - mandrel` side
- "Kick-over-tool" side/O
- `Sequence of events"-.
-cutting of CP-liner sidell
-preparing of well for prod.string sideJ�
-running of packer and prod.string sidei'�
-press. test of surface equipment side/9
-press. test of prod. string sidé/5
-press. test of equp. from x-mas
tree to burners sidet�
-third re-acidizing-job on the
oil zone si�det�
- Well fl owi,ng data from Otis side
- Otis well testing safety system. side. HT
- Problemer side H�
jr
N
Welt venture$h t�'t t �--'t ane
Om ngejr ep eppd eø-urgent -t o west �te n t u r e' ep d/2 'epptopy ta Stavanger.-attn. f. åa od I t
-ref tan140801 14.08.80.
t'eC�b Ptetion of 3112�2 ..I o r o�t o n.e a n d #D i c.a C e o us - 5 atts
f ol Cowl Ing 4istussions between no�ske s aspartiieri-�and npd, it �a's -heen agréed i_o pro.c e e d -a'
'r i'fi and openi x a-&r> d. � cl.rcutate-wett with brine..�' pick up 't opti t 1. sea[ tti Inger- out of pack�r then. tircutate �-we t t wikhbrine aga i n..
(2) poh vith 3-1121' tubing string.
(3) rig up schLuffiberger and run cctIgr f rom bottoffi inside gptiner to I 350 ip to ob* a in sch Lumberger, dtpths, 'f or the gptiner cottars. (n.b. througbout this., progra*me tetex, a t Ldepths witt be quoted with reference to isf/sonie run 3of 1114180, dritier's depths must be corrected- to makeatLowance for the 2 m d'e e p e r teadings obtai'n'eid by
(4) rih with cutting oh 511 dp and cut-5-1i21 Ibtank pipe at 1578 r. poh.
(5) r�trieve cut off btank pipe and sc-l 9 p� packer es perage 17, steps (5), (6) and (7)programme. p (in t h e. tthe safety joint s�ears- during-programme, page -.17 $tthe reinalning cut off portion'of btank pipe mus,t be r ove red
(6) rih with 30 m, 2-71811 tubing on 511 dp._st'ab intotiner and reverse hote cLean froin t ové any.,.,.and -f rotn inside the tiner reverse �ircu�,øgp 5 tetean littereo bririe-then poh:
(7) perforete. intervat,1570 1575 with 2-1 IV-1: hy.perdoi�éscattop guns 4 spf , 0 degree pha'sing vsin4`the Ø�- r forprocedure outtined in the programme, page. 2 8.p s t e p s... Cl
2 4) adjurt perforating depths -_and
8') -rih with 9-5181 tasing scraper with 2 5P,-.? '7tubing betow, using .59 '1 dp/6-1/41 t dtls ål.- 'ruii'nirig '£.triscråpe intervat 154 I 578 ffi (i 'to o ø. �,O�f 'cut 6 f,fgp tiner) then reverié cte when s,craper l s,_.& t 1578.i81. tubi 9-.tait'øi --at 1 5 9 0 .3_4",# 't �aboVe -A'i> V tIKn P e. shoetett
9 ,up s�htL un ..,gaugég. -ø t 1f, r: Oh
:'t' 16,6 �f i t db.¥a e t
w ch 1~ i�,
vNn 2�,' x 2
su v ̂ m 4.
u�i -2.53
53 3�C KA-SSD
t570.17 n1029
27/8di
5.21
2.� 3sc -i ?kcjccp.
2 xUPPG;L
2.;.6152 �.7 6 m ISN. 5%2E
2.50
E p-6,4 b.16 is, 644 M
3y E u )L
-1531.20 M l�P-LINER6.6o > Yli'
4
1- 4 � �i - c
'3* ]B VAII
M Cn.3i
A'
-1 5 6, ri
15 13 �'3 -M
14 U Ti AT l s 8 a. 11
R -CCc�15 IhlQ VAM 13
C49
0
G A S L �r F T
GENERELT
utfØrt -Med enkel
kompletering andre produksjonstest ble utfØrt med dobbel
kompletering. Gas ble injisert fra overliggende gas sone.
Det ble brukt to "packers", og `side pocket mandrel` me(llom
disse. Som `flow controler` ble det brukt en `chemical
injection valve`. Den Øverste del-av denne ventilen er en
fj<�,rbelastet port som åpner for gas ved et bestemt minste-
trykk. Denne ble justert til et åpningstrykk på null for å
få minst mulig trykktap på gassen.
Ventilen består av to enheter:
- en choke-enhet for gass injeksjonen. Ventilen leveres
med `choke` stØrrelser på 3/16" og 5/16".
- en `check-valve` for å hindre retur av eventuell olje
med hØyt trykk gjennom "flow controler` og ut i
annulus.
Etter avsluttet produksjonstest av olje sone, setter en
plug i `S-1"-nipple, åpner 2 7/V XO SSD og 3�2` XA SSD for
produksjon kun fra `Micaceous sand zone`.
GAS-LIFT `FLOW-CONTROLER`
SIDE POCKET MANDREL no. 211-RW'30209-4
;1BK,11 LATCH no. 210-B0-5
CASING
VEE-PACKING
FLOW-CONTROLER no. 221-RCV-1000
WEL GAS
CHOKE:, 3/26 OR 5/16
VEE-PACKING411
CHECK VALVE
GAS
OIL
T.
Gas Lift Equipment and Systems
P~RTYPE RCV CHEMICAL INJECTION VALVES
ASSEMBLY NUMBER 221RCVlooo-l 22-1RCV`1001-*
Sizelinches
Port Sizellnches 0.187 (311&) 0.312515/Ii�.
DETAIL PART NAME Q`Ty PART NO. PART NO.
11 Upper Packing Sub i 221Sl300 221Sl3002 Sel Screw i 412SS555 412SS555
3 Female Adapter 2 21OF4 21OF44 Vec-Packing 16 9lV352 9lV352
5 0-Ring 2 9101210-H 910121 0-H
5 Lock Nut i 221Sl301 221Sl301
7 Nose i 22IS1208 221Sl2088 Retainer i 221Sl302 221Sl302
9 Spring, i Sce Table* See Table*10 Spring Body i 221Sl303 221Sl303
11 Stem i 221Sl304 221Sl30512 Spacer See Table None 221Sl307
13 Seat i 221Sl311 221Sl31214 0-Ring i 9101016-S 9101016-S
15 Back-Up Ring i glTll14 glTll1416 0-Ring i 9101114-S 9101114-S
17 Packing Mandrel i 221SI036 221Sl03618 0-Ring i 9101019-S 9101019-S19 Seat i 221Sl117 221 120 0-Ring i 9101018-S 9101018-S
21 i 221Sl213 221 1pin22 Pin i 22IS1187 221SI187
23 pring 1 1011216 N26624 Valve Housing i 221Sl091 S1091
25 0-Ring i 91OV1113-S glOV1113-s
lindicate spring setting when ordering by adding letters as shown in following tables.
SPRING SELECTION CHARTS
VALVE 22iRCV1000 VALVE 22iRCV1001
221ncvlooo- DIFFERENTIAL SPRING 221RCVlool- DIFFEREMIIALSPRING SPR�NG SPRING
SETTINGSI SM NGIINCHES INCHES
221RCV1000-A 500 90CN2035 221RCV1001-A 500 90CN2038 20221RCV1000-B 1000 90CN2035 221RCV1001-B 1000 90CN2038
221RCV1000-C 1500 90CN2035 2211`lcvlool-c' 1500 90CN2038221RCV1000-D 2000 90CN2036 221RCV1001-0 2000 90CN2035
221RCV1000-E 2000 90CN2036 221RCV1001-E 2500 -90CN203522IRCV1000-F 3000 90CN2036 221RCV1001-F 3000 90CN2035
221RCV1000-G 3500 90CN2036 221RCV1001-G 3500 90CN203522IRCV1000-H 4000 90CN2037 221RCV1001-H 4000 90CN2036
221RCV1000-J 4500 90CN2037 221RCV1001-J 4500 90CN2036221RCV1000-K 5000 90CN2037 22IRCV1001-K 5000 90CN2036
221RCV1000-1 5500 90CN2037 221 RCV1001-L 5500 90CN2036221RCV1000-M 6000 90CN2037 221RCV1001-M 6000 90CN2036
-Valve requires one spacer.
47
5-1z
Gas lift Equipment and Systems
GAS LIFT VALVE LATCHES AND DUMMIES
'ype M Latches - used in all '1�pe RW Mandreis. Type T2 well, expensive gas lift vaIves, installed above the fluid.atches - used in Type RL Mandrels. These are collet-type level, can be replaced with dummies, blc>ck-ing off injecdonatches desioned so that a niinimum force is required to pass gas. Dumn-lies are available in special materials, so indicatehe collet into the lock recess. This feature is very important service when specifying.vhere deviated wells prevent forceful downward jarring.)uring installation, the collet moves up and deflects as it OTIS LATCHES�asses the lock recess. Upward movement is designedhear the running tool, causing the collet to nlove into posion and be securely locked. When retrieving, a pin;heared, allowing the latch body to move upward and t e-ollet to defect. passing out of the lock recess.
rype BK Latch - used in aU 1-inch l�pe RW Side-Pocket�4andrels. This is a spring-loaded, ring-style latch. The lock-ng mechanism used is a spring-loaded ring that is designed to oock i pocket-locking recess of the mandrel. Latch can)e inst*d with a rninimum of force. When retrieving, a pins sheared, allowing the ring to move upward and perrfflttinghe valve to be pulled from the pocket.
rypes R and RA Latches-used in all sizes of RL mandrels,-xcept Type RLF that uses Type R Latches only. Tbe lockingmechaffism for these latches is a spring-loaded rotating cam�hat is desi£!rted to lock in die pocket-locking recess of themandrei. They may be installed with a "nimurn of force. 2:When retrieving, a pin is sheared, and the latch-release pinlifted to allow the latch cam to rotate frcely out of the way.Both latches are identical in fun'ction: Type RA contains two Type m o Type T2 Type R-xterior 0-rino seals and a shorter cam nose than the Type R.In the Type RLC, RLE and RLS Ported Mandrels, the Typen Latch is often used due to its inherently stronger 360' latchretention.
OTIS GAS LIFT VALVE DUMMIES
Dummy valves are installed in side-pocket, gas lift man-drel� ireline to block the mandrel's injection gas ports.Dumwcan be run prior to or after completion for testin9tubing, packers and other equipment. In new installations,
dumrnics can be retained in the niandrel until gas lift valves Type RA Type BKare required to maintain producfion. Dumrnies are pulled andgas lift valves installedby wireline. Also during the life of the
GUIDE TO TYPE M, BK, T2, RA and R OTIS LATCHES
Otis Pulling Neck Running Neck MaximumAssembly Type Material Diameter/ Diameter/ 0.0.1 Pulling HunningHumber lnches Inches lnches Tool Toci
96MO2 m Standard .875 .750 1.328 96MO38210BOS BK Standard .875 .750 1.358 40SM4 96MO38210803 BK Monel .875 .750 1.358 40SM4 96MO38
96CO5 BK Standard .875 .750 1.358 40SM4 96MO3896MOS T2 Standard 1.375 1.000 1.750 40SM1 96MO37
21OR03 RA Standard 1.375 1.359 1.750 40SM1 96MO20
21OR01 RA Monel 1.375 1.359 1.750 40SM1 96MO20210RO,1 R Standard 1.375 1.359 1.750 40SMI 96MO2021OR02 R Monel 1.375 1.359 1.750 l 40SM1 96MO20
NOTE: Caii OLs or s.z--s a�d types not kste or write Dallas direct.
35
Gas Lift Equipment and Systems
CODE DESCRIPTION FOR OTIS WIRELINE SIDE-POCKET MANDRELS
Example: 211R 20401-1
Class number for mandrels LJ L J L i. - withmi poitioning sleeve and deflectorWireline mandrel 2. - With positioning sleeve onlySize valve to be set in pocket: 3. - With deflector only
W - 1-in. 0.D. gas lift valve 4. -With both positioning sleeve and defledorL - 11/2-in. 0.D. gas lift valve 5. -Two-pock-et mandrel with both positioning
This space used to designate following: sleeve and deflectorC - Ported mandrel 6. - Side-strin.- mandrel with both positioningF - Waierfi ood mandrel sleeve and deflectorS - Special external port outlet Type threads (SeeThread Code)X - Special clearance Material and coating (See Material Code)
NOTE: When mandrels cannot fit this code due to variations Norninal size 20 - 2 inchor features requested, a partially coded number will be as- 25 - 2112 i nchsigned Aith a complete description of side-pocket mandrel 30 - 3 inchappearing on drawing or speeification shett. And other sizes sce Drift Code.
c TYPE RW OTIS OVAL-0-D MA NDRELS - Dimensions and Code Drawings
A
D _�RTL_B_fDrift E
SIZE: 2-318-in.. CODE 1-,*ithout deflector or posnioninv -,Qeeve.2-71"n. 3-112-in.
CODE�and2A
Defiéctor
CODE4-witIldeljectorandpositioningsieeve.
112,1 NPT 11/2- NPT
PORTING CODE F-waterflood mandrel. no pores. CODE C-ported ffiandrel.
VARIATIONS11/2- NP-I
C00ES-ehamberliftniandrel.s~I~Iports.
DIMENSIONS Type RWDimensions-inches
Tubing Weight/0.D.Anches Mandreil Å (EU) D E F Pounds
2-318 NU- 64 3.875 2.90 1.901 1.027 1.027 602-318 63 4.25 2.90 1.901 1.027 1.027 642-318 (With Posifioning Sieeve) 73 4.25 2.90 1.901 1.027 1.027 74
2-718 63 4.75 3.56 2.375 1.027 1.027 902-718 (With Posifionina Steeve) 73 4.75 3.56 2.375 1.027 1.027 106
3-112 64 5.62 4.37 2. 1.027 1.027 1173-112 (Wiih Positioning Sieeve) 73 5.62 4.37 2.875 1.027 1.027 142
4 75 5.85 5.00 3. 1.027 1.027 185
4-112 75 6.05 5.00 3.375 1.027 1.027 1854-112 77 6.62 5.35 3.833 1.027 I 1.027 185
'When specifying, ineludeport data. driftl.D.. material,thread typeandaccessoryitems. -Positioning sieevenotavailable. NOTE- Theaddition ofdefleclordoes nolaiter �;mensions.For availability of additional sizes no'. isted, contact your local Ns Specialist or write Dallas direct.
32
� �-11
Gas lift Equipment and Systems �i�l 21ul l
OTIS TRU-GUiDE SIDE-POCKET TUBING MANDREL AND KICKOVER TOOL
The Otis Tru-Guide Side-Pocket Tubin- Nlandrel is de- 0 Transfer guide rails are designed to prevent other servicesigned for installing gas lift valves in tubin.- and still permits tools from lodging on top of pocket.a relative full opening through the mandrel. The Otis Tru- 0 Patented muleshoe alignment assembly is designed forGuide Kickover Tool bas many exclusive features for ii3stal-]ing gas lift valves and other subsurface controls iii deviated cngagement and orientation of kiekover tool.wells by pumpdown as well as wireline techniques. Quite 0 Continuous stop shoulder is designed to prevent accidentaloften, several trips can be eliminated by running kickover travel past mandrel.tools in tandem to pull and install gas lift valves. 0 Gas lift valves can be run in tandem with Tru-Guide kick-
over tools.BENEFITS OF DESIGN PRINCIPLE
APPLICATION* Full-opening, side-pocket tubing mandrel.
Side-pocket mandrels (with lensile strength greater than0 Unique, flexible kickover tool for going around five-foot the tubing) can be run in the initial tubing string of a flowing
radius loops in pumpdown instafiations. well completion, so well can be converted to gas lift at a
0 Gas lift valves may be serviced by either pumpdown or future date without a major workover. Using pumpdown orwireline methods. -% siandard wirelinemethods, kickovertoolscanberuntoinsert
0 Exclusive full-length transfer guide rails in mandrel allow or pull gas lift valves. Unique transfer guide rails in mandrelgas lift valves to be installed and removed, utilizing and the pivot arm of the kickover tool are designed to insert orstraight forces to help keep the kickover tool from bending pull gas lift valves straight in or out of the pocket to proteet
the valve. valves from bending.
ACTIVATORSHOUIDER
Step 1 Step 2 Step 3 Step 4 OPERATING DESIGN PRINCIPLE
These drawings illustrate how simple it is to installa gas lift valve with Otis Tru-Guide equipment. Simi-lar steps are used to retrieve the valve from theside-pocket landing nipple.
Step 1 -After the kickover tool has moved throughthe Tru-Guide Mandrei, it is reversed and movedback up through the mandret. The spring-loaded
B" alignment key on the kickover tool orientation as-IRANSFER
sembly (A) is designed to align the kickover tool and -GUIDE RAIL
hold it in the proper position to be activated.
C. Step 2 - Upward movement shears the first shearfing on the actuator assembly (13), permitting the
D� pivot arm (C) to move out and lock at right angles tothe carrier tray assembly (IJI) for positioning on thecenter line of the side-pocket landing nipple for set-ting or pulling the gas lift valve.
Step 3-Downward movement of the gas lift valve iscontrolled by the transfer guide rails for a straight lineinto or out of the landing nipple. A no-go on -thelocking mandrel locates the gas lift valve in the nip-ple. Continual downward movement releases lthelocking keys, locking the valve in the nipple. When SIDE-POCKET
LANDINGpulling a gas lift valve, this downward action en- NIPPLE
gages the pulling tool on the fishing neck of thevalve.
Step4-Aftersettingthe gas liftvalve (installing)orZ; engaging the valve with a pulling tool (ret�eving),
upward movement shears a second shear ring in the -MULESHOE
actuator assembly (121), unlatching the pivot arm andallowing the kickover tool to move up and out of themandrei.
A. Kickover Tool Odentation AssemblyB. Aduator AssemblyC. Pivot ArmD. Carrier Tray Assembly otis
Tru-GuideSide-Pocket mandret
34
SEQUENCE OF EVENTS
WELL 31/2-2.-KEST VENTURE
P.T. no. 2
DATE T:1ME OPERATI:0N
CUTTING OF 5k" GP-LINER AND RETR=ING OF SC-1 GP PACKER
15/8 00:00 POOH 3k` tubing and prod-. assy.
05:30 Rig up Schlumberger
06:00 Run Schlumberger CCL/GR-loggers, T.D.1588.8 m.
Located top of Production packer at 1550 m
at 30 cm low tide
08:30 Rig down Schlumberger
09:00 Make up servco cutter and assy. RIB-
12:3k Cut 5�" liner at 1578.5 m
13:30 POOR cutter assy. - same hung up at 1564 m.
Took 70 000 lbs. Overpull to work free.
14:30 Continue POOH - låy down cutting tool
all 3 knives broken
17:30 Maké up packer retrieving tool,
A set of jars, 3 stands 6k`
Drill collars, 5 STD HW and
5` drill pipes. RIH-
20:30 Engage tool into packer.
Took 80 000 LBS. overpull to
pick up cut-off section.
21; 30 POOH.
SEQUENCE OF EVENTS
WELL 31/2-2r WEST VENTURE
P.T. no. 2
DATE TIME OPERATION
16/8 01:00 Got all cut-offs - a total of 27.3 m
including packer length.
01:00 Lay down jars. packer and cut-off liner section.
PREPARING OF WELL BEFORE RUNNING GAS LIFT PROD. STRING:
03:00 Service of production equipment:
Replace swivel on Otis surface X-mas
tree and replace connections on lubricator valve.
05:00 RIH with 2 7/8, 30 m stinger,
HW drill pipe and 5` drill pipe t6 clean out
hole from sand.
07:30 Rig up Dowell and filtercleaners
08:00 Tag sand at 1583 m - shut hydril and reserve
circulate and wash down to 1589 m with
Hydril closed.
3 - 4 bbl/min and 400 - 480 pump press.
and cleaning brine 25 - 5 - 2 microns approx.
50 litre sand retn.
17:00 Rig down Dowell, POOH and lay down 2 7/V stringer.
19:00 Rig up Schlumberger
19:30 Load perfo. guns.
20:30 Perforated interval 1570.- 1575 m with
2 118` hyperdome scallop guns, 4 SPF.
22:30 Rig down Sdhlumberger
23:00 Make up 9 5/V casing scrapper
13
SEQUENCE OF EVENTS
WELL 31/2-2, WEST VENTURE
P.T. n6. 2
DATE TIME OPERATION
17/8 00:00 RIH with scrape and 2 7/8` tail pipe below
02:00 Scrape interval 1540 - 1576 m
02:30 Rig Up chicksand and circ. head
03:00 Lower string with tail pipe to 1589 m.
Reverse out with 400 psi pump pressure.
No more sand returns
04:00 POOH
06:00 Rig up Schlumberger
06:30 Schlumberger run gauge ring and junk basket
to 1579 m. Than pull out same
RUNNING OF PACKERS AND PRODUCTION STRING:
07:30 Pick up model "DB` packer and run it with
Schlumberger.
Set it at 1576 m
09:30 Rig down Schlumberger
10:00 Make up tail pupe for SC-1 packer. Pressure
te'st to 3000 p!si for 15 min. Rig up Otis
wire-line and retrieve S-1 plug
14:00 Rig down Otis wire-line
15:30 RIH with SC-1 padker and tail pipe assy.
17:00 Make up circ. head and chicksand. Circulate
slowly with 50 psi. Obsurve entry of seal
assy. into "DB` packer. Pressure increase to
200 psi upon entering. Bled off same. Space
out tUbing to get tubing in the right position
in BOP-stack drop ball. Pressure test in
stages: 800 psi, 1000 psi, 1300 psi, 1500 psi,
1800 psi.,
SEQUENCE OF EVENTS
WELL 31/2-2, WEST VENTURE
P.T. no. 2
DATE T= OPERATION .....
17/8 17:00 Shear tool. Packer is set at 1520.5 m.
loggers and 1518.5 m Drl. depth
Pressure test annulus to 500 psi for 15 min.
release setting tool 14 x ri.ght for retracting
- of setting tool
19:00 POOH and lay down setting tool
20:30 Mak,e up 201, G22 locator seal assy. with mule
shoe, 3�2" tubi,ng,, 3�" "XA-SSD` and 5" VAM
tubing.
18/8 00:00 Continue RIRwith 5` VAM tubing on 5` drill
pipe to SC-1 packer to space out same.
05:00 Pressure test annulus too 500 psi.
05:30 POOH with 5` drill pipe
06:00 Space out 5" VAM tubing.
Adding 1 PUP-joint. Pressure up EZ tree for
release test and pressure test lines to
3000 psi, .
RIH with 4k" rise-r with control lines.
Testing every tubi.ng conn.
Kooke up X-mas tree and surface lines.
15:00 Stabe into SC-1 pc-�cker.
Landed EZ-tree in well head and pressure test
casing to 500 psi.
PRESSURE TESTING OF SURFACE. EQUIPMENT ON RIG FLOOR.
18:00 Pressure test wire-line lubricator and wire-
line BOP. Difficulties due to leaks.
SEQUENCE OF EVENTS
WELL 31/2-2r WEST VENTURE
P.T. no. 2
DATE TIME OPERATION
PRESSURE TESTING OF PRODUCTION STRrNG
19/8 00:30 Rig up Otis wire-line with 2.2` drift.
00:45 RIH with 2` drift to 1590 m
01:30 Rig up N-type test tool
01:45 Pressure test wire-line lubricator to 3000 psi
02:00 RIH with N-type test tool stuch in EX-tree valve
POOH. Hang up in lubricator valve
03:00 Recovere tools
Covere in pipe dope
03:30 RIH with lib. diam. 2.78".
Hang up in lubricator valve.
Diam. of impression: rD obstruction = 2.74".
04:00 Rig up S-1 plug
04:30 RrH with S-1 plug
Loadcell stucy when pull over 250 LBS.
Set at 1580 m in S-1 nipple
05:30 Ri.g up pulling tool for S-1 plug
05:45 Pressu-re test tubing
S-1 plug leakihg at 1500 psi
06:00 RIH with 2` `RS` to retrieve
S-1 plug stuch at 1580 m
Jaring with 750 LBS and shear off `RS` tool
11:00 POOH with `RS` tool
11:30 Make up 2.313` "B" shifting tool. RI�R.
To close "XO SSD"
14
SEQUENCE OF EVENTS
WELL 31/2-2, WEST VENTURE
P.T. no. 2.
DATE TIME O.PERATrON
19/8 13:30 Pressure test production string
against S-1 plug to 3000 psi
14:00 RIH with 2` `RS', prong, 101 x stem and
hyd.jars. latch on S-1 plug. POOH
PRESSURE TESTING OF EQUIP. FROM X-MAS TREE TO BURNERS:-
17:10 Pressure test against choke manifold, sandtraplinlet and b' ves: 5000 psi.
.ypass val
17:17 Pressure test against sandtrap outlet and
bypass valves: 5000 psi
17:30 Pressure test against Thornton manifold inlet
and by-pass valves: 5000 psi
17:40 Pressure test against Thornton manifold inlet
and outlet valves: 5000 psi
17:50 Pressure test against Thornton manifold
body complete: 5000 psi
18:00 bypass sand trap. Pressure test back to
choke manifold valves: 5000 psi
18:08 Pressure test heater inlet and by-pass
valve: 3000 psi
18:17 Pressure test heater coils against outlet
valve: 1400 psi
18:30 Pressure test separator inlet, oil by-pass
and gas bypass valve: 2000 psi
18:40 Pressure test automatic high pressure pilot
in automatic shut down system.
19:05 Pressure test separator vessel against oil
and gas outlet valves: 1300 psi
SEQUENCE OF EVENTS
WELL 31/r2-2, WEST VENTURE
P.T. 2
DATE TIME OPERATION
19/8 19:11 Pressure test separator safety valves
Lift at 1500 psi
19:12 Retest separator vessel to check valve
seating: 1300.psi
19:28 Pressure test oil-lines against burner head
valves. Leak at.Weco-union
19:38 Retest oil lines: 1500 psi
Waiting to start acidizing.
Will start t6 f low well in day-light and
do azidizing just before.
THIRD RE-ACIDIZATION JOB ON THE OIL ZONE:
20/8 00:45 Rig up wireline and RIH with `B` shifting
tool. Open W' XA-SSD at 1553.46 m.
POOH
Wireline operator open up SSD at 1553.46 m
instead of SSD at 1506.93 m. after order from
Shell services supervisor
02:00 Change `B` shifting tool.
RIffand close bottom 3k` XA SSD
POOH
03:45 Rig up 'W' shifting tool
RIH and open top 3�," XA SSD.
POOH
05:05 Pump 10 BBLS diesel, 21 galls tretolite and
42 galls UGG initial/final pump pressure = 500 psi
Fluid rate = 1.5 BBLS/min.
05:12 Pumpe 20 BBLS 15% HCL
84 galls UGG and 9 galls A-200 initial/final
pump pressure = 20,0 psi
Fluid rate 0.8 BBLS/min
SEQUENCE OF EVENTS
WELL 31/2-2, WEST VENTURE
P.T. no. 2
DATE TIME OPERATION
20/8 05:30 Pumpe 10 bbls diesel and 42 galls UGG.
initial/final pump pressure = 400 psi
Fluid rate = 1.2 BBLS/min.
05:38 Pump 37 BBLS diesel
initial/final pump pressure = 650 psi
Fluid rate = 4.5 BBLS/min
Static THP = 550 psi
close upper 3k` XA-SSD
Pressure test annulus to 500 psi for 15 min.
06:35 Dicplåce and bullhead fluid with 62 BBLS diesel
After 17 BBLS of diesel, the pressure drop
from a steady rate of 1625 psi and 0.5 BBLS/min.
to 800 psi over 45 seconds.
It came back to 1624 psi with same rate
0.5 BBLS/mi.n.
Pumpe a total of 40 BBLS with 0.5 BBLS/min and
pump pressure = 1625 psi.
The excess of 22 BBLS with 1 BBLS/min and
final pump pressure = 1700 ps,i
FIRST FLOW PERIOD:
09:35 Start to flow (See "Otis field readings` on
next pagel
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OTIS `SAFETY SHUT DOWN" SYSTEM PÅ WEST VENTURE
4
V�5b SEM 12A-r0 ?C
7=7) SF-fAJM-TOk ~TAK
WPICAU-115 k�ir- Do
k) 4 VF7'-
p P, -4 U L- i 5 k-,
Vrs
Stiger trykket ved inntaket til Otis test separator,
åpner high-pressure-pilot automatisk til atmoferisk
trykk det fØrer til at kontroll ventilen åpner til
reservoaret fra flow head `flow-valve` og `master valve
vil da st-enge. (Di.sse ventilene må ha trykk for å
åpnes).
På `rig-floor" og ved separator kan en stenge manuelt.
SIKKERHETSYSTEM PÅ OTIS'SEPARATOR:
Det er etter Ønske'fra Shell instalert to sikkerhets-
ventiler av typen "Farris` på separatoren. Begge
ventilene skal åpne på 1460 psi. Det er incjen
"Rupture-disc` på separator fra sikkerhetsventilene
er det montert en 3" linje med uttak under platformen.
PROBLEMER MED OTIS S-1 PLUG
Ved nedkjØring av S-1 plug, for test av prod. string, ble
det påvist feil ved dybde-indikatoren i 110tis W/L winch".
Pluggen ble så satt i S-1 nippelen. Strengen skulle trykk--
testes til 3000 psi. En oppn4dde kun et trykk på 1500 psi.
Ved trekking av pluggen måtte en bruke en jar-kraft på 750 LBS.
Satte deretter S-1 plugen igjen. Uten å oppnå den forventede
trykk Økningen. Etter en tid steg trykket og en oppnådde
3000 psi. FØr denne trykktesten ble det kjØrt "Drift-run
En påviste da en del forurensing. Blant annet en del DOP.
Dette kan muligens være årsaken til problemene'med S-1
pluggen.
PROBLEMER MED FLOPETROLS SSTT
SSTT fra Flopetrol er utstyrt med injiserings-system for
Glykol.
Etter oppstart fikk en problemer med pumping av Glykol.
En antar at grunnen kan være forurensningi`linjen plugget
utaksventilen i SSTTr
e,tter at Glykol linjen har fått skade ved ned-kjØring.