Nov-09 NOTES: The papers listed here have been obtained by
search SPE and IPTC papers post 2005 on the SPE's OnePetro The
papers relating to reservoir engineering have been catergorised for
inclusion on the reservoirengineering.org.uk website The
affiiations searched were; Total No Papers 551 575 482 191 55 255
1130 95 235 3569 Reservoir Engineering Related 175 279 238 68 37
129 563 53 175 1717
BP Shell Chevron ConocoPhillips Marathon Total Schlumberger
Imperial College, London Heriot Watt University, Edinburgh
(Anywhere in Article) Total
Total number of papers published post 2005 =
10,000
35% of papers published categorised
OrganisationSCHLUMBERGER SHELL SCHLUMBERGER BP BP CHEVRON
Paper Source No. ChapterSPE SPE SPE SPE SPE SPE 112021 102244
123773 100660 121761 102219 EOR/IOR EOR/IOR EOR/IOR EOR/IOR EOR/IOR
EOR/IOR
SectionWell Intervention Well Intervention Well Intervention
Well Intervention Well Intervention Well Intervention
CHEVRON
SPE
111512
EOR/IOR
Well Intervention
CHEVRON SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER
SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SHELL SHELL TOTAL TOTAL
SHELL
SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE IPTC SPE SPE
121761 103329 104755 107101 110968 111512 117066 126063 88765
107101 12131 121182 114886
EOR/IOR EOR/IOR EOR/IOR EOR/IOR EOR/IOR EOR/IOR EOR/IOR EOR/IOR
EOR/IOR EOR/IOR EOR/IOR EOR/IOR EOR/IOR
Well Intervention Well Intervention Well Intervention Well
Intervention Well Intervention Well Intervention Well Intervention
Well Intervention Well Intervention Well Intervention Well
Intervention Well Intervention Well Intervention
SubjectGas Shut-off Gas Shut-off Undeveloped Reservoirs Water
Shut-off Water Shut-off Water Shut-off
Water Shut-off
Water Shut-off Water Shut-off Water Shut-off Water Shut-off
Water Shut-off Water Shut-off Water Shut-off Water Shut-off Water
Shut-off Water Shut-off Water Shut-off Water Shut-off Water/Gas
Shut-off
TitleChallenging Chemical Gas Shut Off In a Fractured Carbonate
ReservoirCase Studies Effective Gas-Shutoff Treatments in a
Fractured Carbonate Field in Oman Recovery of Bypassed Reserves
Above Top Packer Using Innovative Cement Packer and Through Tubing
Add Perforation Late-Life Production Boost for BP Miller With
Combined Scale Squeeze and Chemical Water-Shutoff Treatments
Incremental Oil Success From Waterflood Sweep Improvement in Alaska
Water Shutoff Treatments Using an Internally Catalyzed System in
Boscan Field: Case Histories Innovative Water-Shutoff Solution
Enhances Oil Recovery From a West Venezuela Sandstone Reservoir
Incremental Oil Success From Waterflood Sweep Improvement in
Alaska Production Improvement Water Shut-Off for White Tiger Field
Case Study in Water Shutoff Fluid Placement Using Straddled
Through-Tubing Inflatable-Packers Technique Water-Shutoff Treatment
in Wells With Single-String Multizone Completion Intervals
(Brownfields) Successful Water Shut-off in Open Hole Horizontal
Well Using Inflatables Innovative Water-Shutoff Solution Enhances
Oil Recovery From a West Venezuela Sandstone Reservoir Horizontal
Water Shut-Off for Better Production Optimization and Reservoir
Sweep Efficiency (Case Study) Successful Utilization of Fiber Optic
Telemetry Enabled Coiled Tubing for Water Shut-off on a Horizontal
Oil Well in Ghawar Fi Development and First Field Application of a
Gel/Cement Water-Shutoff System Water-Shutoff Treatment in Wells
With Single-String Multizone Completion Intervals (Brownfields)
Tackling Gas Field Decline With Efficient Chemical Water Shut-off:
Successful Application on Peciko Field (East Kalimantan, I
Selective Water Shutoff in Gas Well Turns a Liability into an
Asset: A Successful Case History From East Kalimantan, Indones
Shallow Penetration Particle-Gel System for Water and Gas Shut-Off
Applications
Author
Abstract
Hamed Al-Sharji, Ali Ehtesham, Bela Kosztin, and Clement
Edwards, PDO; Abstract This paper discusses the gas shut-off trea
Fardin Ali Neyaei, and Tarek Shaheen, Schlumber E. Ali, F.E.
Bergren, and P. DeMestre, Petroleum Development Oman; E. Biezen and
J. van Eijden, Shell International Explora Summary A giant
fractured carbonate field in nort Wong Chun Seng and Suhaila Wahib,
Petronas Carigali; Choo Der Jiun andRonald Ramnarine, BJmature
field with 8 roun Abstract West Lutong is a Services Malaysia; and
G. Williams, SPE, A. MacDonald, SPE, J. Wylde, SPE, Clariant Oil
Services; C. Shields, C. Smitton, H.life production on BP E
Abstract The current late Frampton, SPE, the M Danielle Ohms, SPE,
Jennifer McLeod, SPE, and Craig J. Graff, SPE, BP Alaska; Harry
Frampton, SPE, BP in communication Abstract Waterflood thief zones
EPT; Jim C. Morg F. Mata, SPE, BJ Services de Venezuela CCPA, and
S. Ali, SPE, and Ernesto Cordova, Chevron Global Technology
Services Co. Abstract This paper describes the results obtained
Goran Andersson, SPE, PetroBoscan; Gregg Molesworth, SPE, Chevron
Technology Company; and Belkis Gonzlez, Salah Al-Harthy, and Eric
Lian, SPE, Schlumberger
Abstract With the discovery of new fields becomin
Danielle Ohms, SPE, Jennifer McLeod, SPE, and Craig J. Graff,
SPE, BP Alaska; Harry Frampton, SPE, BP EPT; Jim C. Morgan, SPE,
Jimtech; Stephen Cheung, SPE, Chevron; and Katrina Yancey, SPE, and
K.T. Chang, SPE, Nalco Abstract Waterflood thief zones in
communication Keng Seng Chan, Schlumberger Well Services; Duong
Danh Lam and Aleksey Ivanov, VietSovPetrol; Kiam P. of wells in the
W Abstract Oil production from some Apisitsareekul, Redha Kelkouli,
SPE, and Maen Razouqi, SPE, Schlumberger, and Saeed Al-Shaheen,
Abdul Rasool Al-Khamees, and Abdu Abstract Most of the wells in
Sabriya Field (Northe Victor E. Uadiale, Schlumberger; Otaru
G.Oghie, Shell E&P, U.K.; and Vincent O. Nwabueze, Shell
E&P, Nigeria reservoirs in Abstract Due to the stacked nature
of Faisal F. Al-Shahrani, Zulfiqar A. Baluch, Nashi M. Al-Otaibi,
Saudi Aramco,Abstract WaterSarfraz, Schlumberger and Tashfeen
shut-off treatment (WSOT) using t Goran Andersson, SPE,
PetroBoscan; Gregg Molesworth, SPE, Chevron TechnologyWith the
discovery of new fields becomin Abstract Company; and Belkis
Gonzlez, Sala Alaa A. Dashash, Ibrahim Al-Arnaout, Saad M.
Al-Driweesh, Saudi Aramco; Abstract Water production is a major
problem for a Samer A. Al-Sarakbi and Khzam Al Shaharani, Sc Ahmed
Al-Zain, Jorge Duarte, Surajit Haldar, Saad Driweesh, Ahmed
Al-Jandal and Faleh Shammeri,the keyAramco; Vsevolo Abstract Water
control is Saudi to prolong well li Jip van Eijden and Fred
Arkesteijn, Shell Intl. E&P, B.V.; Ihab Akil and Jacques van
Vliet, Al Furat Petroleum Co.; and Diederik Summary Water
production in northeast Syria has Victor E. Uadiale, Schlumberger;
Otaru G.Oghie, Shell E&P, U.K.; and Vincent O. Nwabueze, Shell
E&P, Nigeria reservoirs in Abstract Due to the stacked nature
of Armon Armon and Latief Riyanto, SPE, Total E&P Indonesie
Abstract High water production in a gas well could Chat
Junesompitsiri, Antoine Berel, and Richard Curtice, Halliburton,
and Latief Riyanto, Etienne Thouvenin, and a procedure Abstract
This case history describes Pascal Chen Dwyann Dalrymple, Larry
Eoff, and Julio Vasquez, Halliburton, andJip van Eijden,This paper
presentsE&P development of Abstract Shell International the
iscusses the gas shut-off treatments carried out in a fractured
carbonate field in north Oman and also describes the good practices
and les actured carbonate field in north Oman has both complex
geology and complex reservoir-drive mechanisms. The upper densely
fractured la g is a mature field with 8 rounds of field development
campaigns and close to 40 years of production. Currently only 50%
of total strings ar t late life production on the Miller field is
characterised by high water cut wells that need frequent scale
inhibitor squeezes to manage the thief zones in communication with
the rest of the reservoir are a severe and previously challenging
problem. This paper gives an introductio
describes the results obtained using an Internally-Catalyzed
System1 (ICS) to reduce water production in the Boscan oil field
near Maracai
covery of new fields becoming less common and the continued
development of brownfields water control is becoming increasingly
essenti
thief zones in communication with the rest of the reservoir are
a severe and previously challenging problem. This paper gives an
introductio on from some of wells in the White Tiger field
producing from a fissured Basement reservoir; have been impaired by
excessive water produc wells in Sabriya Field (Northern Kuwait)
produce from reservoirs where multiple layers are opened to
production. Problems related to nontacked nature of reservoirs in
the Niger Delta the predominant completion types are dual-string
multizone and single-string multi-zone com off treatment (WSOT)
using through tubing bridge plug (TTBP) in open hole completion has
been employed for the first time in a dead horiz covery of new
fields becoming less common and the continued development of
brownfields water control is becoming increasingly essenti uction
is a major problem for any oil and gas field. If not properly
managed unwanted water production will seriously impact the
economics ol is the key to prolong well life for economical and
efficient oil recovery. When water reaches certain levels oil
production profitability decre duction in northeast Syria has
increased significantly in recent years.As a result costs per
barrel of oil have increased and the field tacked nature of
reservoirs in the Niger Delta the predominant completion types are
dual-string multizone and single-string multi-zone com production
in a gas well could significantly reduce gas production due to high
friction losses in the tubing the effect of water blocking in fron
istory describes a procedure in which a polymer sealant and a
bridge plug were used to shut off water production from upper zones
to enab presents the development of a particle-gel (PG) system for
water shutoff operations. This system combines an organically
crosslinked polym
he good practices and lessons learnt from a number of jobs. In
addition to the technical analysis the paper also addresses the
economic v pper densely fractured layers are produced using the
gas/oil gravity-drainage (GOGD) process while the less-fractured
lower set of layers nly 50% of total strings are flowing. OnePetro
the idle wells could possibly access undeveloped marginal reserves
in shallow reservoirs. Th However squeezes to manage the production
of scale. In addition the wells are often choked back due to plant
water constraints.The key to ma paper gives an introduction to the
nature of a novel heat-activated polymer particulate. Details of a
trial of this indepth diversion system
can oil field near Maracaibo West Venezuela. This field is
divided in two blocks: north and south. In the south block wells
can eventually
ming increasingly essential to enhancing oil recovery. Water
control operations are especially challenging in under-pressured
reservoirs wi
paper gives an introduction to the nature of a novel
heat-activated polymer particulate. Details of a trial of this
indepth diversion system by excessive water production. Excess
water not only reduced the artificial lift efficiency but also
imposed various damages to the oil zones Problems related to
non-desired water production are drastically affecting the oil
production and have been an ongoing concern. The excl ngle-string
multi-zone completions. These designs have been adopted to reduce
the number of infill wells required for field development. Ho e
first time in a dead horizontal well in one of the onshore fields
in Saudi Arabia. It was successfully applied by setting an
inflatable bridge p ming increasingly essential to enhancing oil
recovery. Water control operations are especially challenging in
under-pressured reservoirs wi sly impact the economics of a project
through lost hydrocarbon production reserves recovery and ever
increasing treatment costs. It may c oduction profitability
decreases dramatically and even goes to negative. One feasible
option in this case is a rigless water shut-off treatmen creased
and the fields production is currently constrained by the
facilities capacity. Production logging tool (PLT) surveys combined
w ngle-string multi-zone completions. These designs have been
adopted to reduce the number of infill wells required for field
development. Ho ct of water blocking in front of perforations and
formation damage due to water which eventually could lead to a
significant loss of recover from upper zones to enable gas
production from productive lower zones. Offshore gas fields
operated in East Kalimantan were producing OnePetro ganically
crosslinked polymer (OCP) system with non-cement particulates to
provide shallow matrix shutoff in openhole or perforated compl
addresses the economic value of the campaign. Oil production
from this field with complex geology and reservoir mechanism was
negative actured lower set of layers is subjected to waterflooding.
The production from the GOGD layers is through vertical and
horizontal wells comp
straints.The key to managing the decline in oil production is
therefore to reduce water production. This allows the wells to flow
un-chok depth diversion system resulting in commercially
significant incremental oil from a BP Alaskan field are presented.
The system of one in
ock wells can eventually produce oil with 90% water cut due to
the influence of an aquifer. The accumulated production per well
can be a
er-pressured reservoirs with openhole completions such as in the
Boscan field in West Venezuela. Gravel-packed slotted liners and
standa
depth diversion system resulting in commercially significant
incremental oil from a BP Alaskan field are presented. The system
of one in damages to the oil zones. Since 2002 a joint industrial
project was set up to study the feasibility of performing water
shutoff treatments in ongoing concern. The exclusion of this water
represents a challenging task by itself especially in case of
multiple zones interval simultaneou d for field development.
However they come with a disadvantage in regard to carrying out a
successful intervention when water break throu etting an inflatable
bridge plug (TTBP) in the 6 1/8 open hole at 10 600 ft at 88 and
capping it with cement and gel using coiled tubing (C er-pressured
reservoirs with openhole completions such as in the Boscan field in
West Venezuela. Gravel-packed slotted liners and standa g treatment
costs. It may cause major economic and operational problems for
several reasons. It requires increased capacity of water separ ss
water shut-off treatment which involves an intensive process
starting from candidate selection and finishing with post-treatment
well pe PLT) surveys combined with a reservoir study showed that
good-quality sands were not properly swept by the water probably
because of d for field development. However they come with a
disadvantage in regard to carrying out a successful intervention
when water break throu significant loss of recoverable reserves.
Selective mechanical water shut-off (i.e. casing patch) the main
technique used to solve this pro
nhole or perforated completions. The PG system can be considered
as an alternative to standard cement squeeze operations repairing
ca
mechanism was negatively affected by gas breakthroughs in
several wells. The constraints on gas handling capacity resulted in
shutting-in and horizontal wells completed in a thin fracture oil
rim. Gas conformance control is a challenge in many of these wells
because the gas br
s the wells to flow un-choked and also lightens the fluid column
increasing drawdown and oil rate in the well. Other advantages
include inc ted. The system of one injector and two producers was
selected because of a high water oil ratio and low recovery factor
which was recog
oduction per well can be as high as 6 (six) million barrels and
typical rates range from 600 to 2 400 BFPD (barrels of fluid per
day). In orde
d slotted liners and standalone premium screens are common
completion methods in this field. Dual injection combined with
permanent w
ted. The system of one injector and two producers was selected
because of a high water oil ratio and low recovery factor which was
recog water shutoff treatments in the open-hole completion oil
wells. The study involved evaluation of a high temperature polymer
base water shut zones interval simultaneously producing and where
completion of the wells restricts considerably the convoyed
down-hole tools configuratio n when water break through occurs.
Water breakthrough and high basic sediments and water (BS&W)
are problems associated with fields d gel using coiled tubing (CT).
Historically it has been difficult if not possible to perform
mechanical water shut-off in open horizontal well d slotted liners
and standalone premium screens are common completion methods in
this field. Dual injection combined with permanent w ed capacity of
water separation and handling facilities decreases hydrocarbon
production and results in large amounts of produced water ith
post-treatment well performance analysis. This kind of operation
becomes more challenging for horizontal wells with open hole
completi ater probably because of poor connectivity in the
reservoir.It was anticipated that these unswept sands could
contribute to production i n when water break through occurs. Water
breakthrough and high basic sediments and water (BS&W) are
problems associated with fields que used to solve this problem so
far has some disadvantages mainly reducing the inside diameter of
the production tubing which makes
e operations repairing casing leaks sealing off thief zones and
addressing lost-circulation zones. The OCP system which comprises
the
city resulted in shutting-in a number of high GOR wells. These
wells were required to be treated to shut-off source of the gas
breakthrough e wells because the gas breakthrough occurs for a
variety of reasons: downward movement of fracture gas/oil contact
(fracture-oil-rim thinni
her advantages include increased scale inhibitor squeeze (SISQ)
life reduced OPEX costs and reduced environmental impact of
overboar ry factor which was recognized as an indicator of the
presence of an injection water thief zone and confirmed by study of
a previous injectio
of fluid per day). In order to mitigate the high water cut and
water production the operator implemented in 1998 a water shut-off
(WSO) p
mbined with permanent water shutoff (WSO) gels or relative
permeability modifiers to control water production in these
completions has tra
ry factor which was recognized as an indicator of the presence
of an injection water thief zone and confirmed by study of a
previous injectio e polymer base water shut-off fluid for deep
penetration of the fissure formation and a micro-fine cement system
for sealing off the water en own-hole tools configuration This
paper covers water shut off case history of an oil producer that
has shown according to the productio ems associated with fields
having strong aquifer drive mechanisms. As a result most
exploration and production companies have learned t off in open
horizontal well as inflatables are quite sensitive to be set in
open hole. This paper shows that this type of water shut-off in
open mbined with permanent water shutoff (WSO) gels or relative
permeability modifiers to control water production in these
completions has tra mounts of produced water that need to be
disposed in an environmentally friendly manner. Some fields in
Saudi Arabia use water injection fo ls with open hole completion.
Well A a horizontal open hole producer with 2 440 ft of reservoir
contact was drilled and completed in Novem d contribute to
production if the watered-out sands were shut off. A newly
developed gel/cement has been used to shut off the watered-out ems
associated with fields having strong aquifer drive mechanisms. As a
result most exploration and production companies have learned t
ction tubing which makes future mechanical water shut-off of the
deeper reservoirs more difficult. Chemical water shut-off is the
preferred s
em which comprises the fluid portion of the PG system easily
penetrates into the formation matrix. It has proven successful in
the oil indus
e of the gas breakthrough in order to restore oil production.
Challenges faced in shutting off these gas zones included: 1) Poor
cement bon tact (fracture-oil-rim thinning) gas breakthrough via
high-conductivity fractures (fracture gas breakthrough)
zonal-isolation failure at the we
mental impact of overboard discharge of produced water and
production chemicals.However the presence of scale in the wells
means study of a previous injection survey. The area around the
wells is bounded by faults so the system can be considered to be
isolated from su
a water shut-off (WSO) program. In 2003 the ICS was introduced
as part of this program. The ICS is solids-free and internally
activated. It
these completions has traditionally produced inconsistent
results. This method can fail to change the well production profile
and possibly da
study of a previous injection survey. The area around the wells
is bounded by faults so the system can be considered to be isolated
from su or sealing off the water entries. Based on this study a
cost-effective chemical treatment method was progressively
developed. In 2005 the according to the production data an
increasing water production figures. The nature of water problem
and the fact that the targeted section companies have learned to
manage water production up to a tolerable limit which is dependent
on the water handling capacity of the instal of water shut-off in
open hole is feasilble and very effective. This will open the doors
to apply similar techniques to liven dead horizontal we these
completions has traditionally produced inconsistent results. This
method can fail to change the well production profile and possibly
da rabia use water injection for reservoir pressure maintenance
which makes water production and handling a necessity even at a
relatively e d and completed in November 2000. The last well
production profile was determined by a Flow Scan Image (FSI) log
which showed 51% o o shut off the watered-out sands in a
cost-effective manner.The gel/cement system combines the properties
of two shutoff techniques: companies have learned to manage water
production up to a tolerable limit which is dependent on the water
handling capacity of the instal shut-off is the preferred solution
to this problem. Peciko is a giant multilayer gas field located in
the Mahakam delta of East Kalimantan wi
successful in the oil industry with more than 350 jobs performed
around the world. The addition of particulates to the OCP system
resulted
uded: 1) Poor cement bond behind the liner shoe. 2) Massive
fractures resulting in loss circulation. 3) Uncertainty with
fractures volume esti -isolation failure at the wellbore
(mechanical gas breakthrough) and increasing gas saturation in the
matrix (matrix gas breakthrough). An i
scale in the wells means that intrusive surveillance and
mechanical water shut off would require costly milling to gain
access. The field is ered to be isolated from surrounding wells and
operations. The position of the thermal front in the reservoir
tracer transit times injection rat
and internally activated. It is used for permanent zone plugging
and lost circulation control delivered into the matrix of the
targeted zone. L
ion profile and possibly damage oil-producing layers. This paper
will discuss the development implementation and results of an
innovative
ered to be isolated from surrounding wells and operations. The
position of the thermal front in the reservoir tracer transit times
injection rat y developed. In 2005 the treatments were performed
through-tubing with and without isolation packers. Two Candidate
wells were having t that the targeted section is located in-between
multiple oil producer zones revealed the necessity of a complex
thru tubing zonal isolation dling capacity of the installed
facilities and also the economic cutoff limits for the wells in
question. The reason for this type of water manag o liven dead
horizontal wells in other fields. Introduction Excess water
production in oil well is always a cause of concern. There are many
ion profile and possibly damage oil-producing layers. This paper
will discuss the development implementation and results of an
innovative ssity even at a relatively early stage of some of these
fields life cycle. As drilling technology advanced in the past
years horizontal wells bec log which showed 51% of water cut and
the entry of most of the water was from the toe of the horizontal
section. Based on economical an f two shutoff techniques: Cement
for mechanically strong perforation shutoff. Gel for excellent
matrix shutoff. The gel used as dling capacity of the installed
facilities and also the economic cutoff limits for the wells in
question. The reason for this type of water manag lta of East
Kalimantan with water depths of around 30 40 meters. There are more
than 100 reservoirs per well with average thickness
the OCP system resulted in synergistic results. The PG system
provides (1) leakoff control for shallow penetration into the rock
matrix and
with fractures volume estimation. 4) Fracture shut-off in
open-hole sections. 5) Treatment execution under sub-hydrostatic
conditions. To o ix gas breakthrough). An integrated
multidisciplinary team studied well and reservoir performance and
openhole (OH) and cased-hole logs
o gain access. The field is therefore ideal for the use of
chemical selective water shut off (SWSO) treatments which can be
deployed witho transit times injection rates and inter-well
separations indicated that the slowest reacting of the three
commercial grades available was mo
rix of the targeted zone. Laboratory evaluations were conducted
to determine effects on the hard setting of ICS resulting from the
contact
nd results of an innovative solution for water shutoff that was
engineered for the complex completion methods mentioned. The
solution invo
transit times injection rates and inter-well separations
indicated that the slowest reacting of the three commercial grades
available was mo ndidate wells were having 6.5 open-hole size at
approximately 4 200 meter TD and 150 deg C reservoir temperature.
The water cut were 9 hru tubing zonal isolation solution before
performing the water shut-off treatment. Temporary coiled tubing
conveyed straddle system was c r this type of water management is
the lack of confidence in the water shutoff remedial operations.
From a survey carried out in the early 90 concern. There are many
side effects of this bad water production: It adds to oil
production cost by way of increased lifting separation and nd
results of an innovative solution for water shutoff that was
engineered for the complex completion methods mentioned. The
solution invo years horizontal wells became the norm in many fields
managed by Saudi Aramco especially in the giant Ghawar filed the
largest oil filed Based on economical and technical feasibility
fiber optic telemetry enabled coiled tubing (CT) was selected for
an accurate and effective w hutoff. The gel used as mix water of
the cement will be squeezed into the matrix creating a shallow
matrix shutoff. The cement will re r this type of water management
is the lack of confidence in the water shutoff remedial operations.
From a survey carried out in the early 90 ell with average
thicknesses of less than 1 m. Most of these reservoirs were
perforated and produced commingled throughout the lifetime o
n into the rock matrix and (2) squeeze-pressure properties. The
slurry filtrate (OCP) is thermally activated. After exposure to the
targeted b
drostatic conditions. To overcome these challenges a robust
chemical shut off methodology had to be innovated. This methodology
consis OH) and cased-hole logs to diagnose the source of
higher-than-expected gas/oil ratio (GOR) in several GOGD wells. The
most important lo
ch can be deployed without access to production logging data. BP
Miller and Clariant have progressively applied SWSO treatments on a
r l grades available was most appropriate for the trial. The
treatment was designed using laboratory tests and numerical
simulation informed
esulting from the contact between ICS and other fluids deployed
on well construction and well production enhancement as well as
reservo
entioned. The solution involves three key stages; the temporary
isolation of the producing layers the permanent shutoff of the
water zones
l grades available was most appropriate for the trial. The
treatment was designed using laboratory tests and numerical
simulation informed ture. The water cut were 95% in one well and
30% in the other well. It was found that these two wells certainly
had big difference in fluid inj yed straddle system was created
using two thru tubing inflatable packers isolating the top and
bottom perforated zones in order to provide carried out in the
early 90s it was estimated that only 35% success was achieved
worldwide in water shutoff remediation. This low succes ased
lifting separation and disposal cost. It leads to scaling in
wellbore tubing flow lines and processing facilities. It also leads
to corrosio entioned. The solution involves three key stages; the
temporary isolation of the producing layers the permanent shutoff
of the water zones ar filed the largest oil filed in the world.
Some of these wells started cutting water and as the water cut
increased the need to perform rigles an accurate and effective way
to isolate the water producing interval reduce water cut and
enhance oil production. The advanced and intel shutoff. The cement
will remain in the perforation tunnel as a rigid seal. This system
showed superior shutoff performance in the laboratory carried out
in the early 90s it was estimated that only 35% success was
achieved worldwide in water shutoff remediation. This low succes d
throughout the lifetime of a well. Efficient water shut-off is very
critical when water breakthrough occurs at some of these reservoirs
in ord
xposure to the targeted bottomhole temperature of the well it
forms a three-dimensional gel structure. The transition time from
slurry to gel
. This methodology consisted of the following main pillars: a)
Utilize various reservoir diagnostics tools to identify fractures
and sources of h ells. The most important logs in this work were
memory-production-logging-tool (MPLT) surveys used to identify the
sources of gas product
d SWSO treatments on a range of wells.A dilute solution of
cross-linkable polymer is bullheaded down the wells and reacts with
added merical simulation informed by pressure and chemical tracer
tests. Long sandpack tests indicated permeability reduction factors
of 11 to 350
cement as well as reservoir fluids acids cement filtrate brines
formation water and crude oil. This paper summarizes the results of
19 WS
hutoff of the water zones and the effective cleanup of the
isolated producing layers. The results of ten water control
treatments are presen
merical simulation informed by pressure and chemical tracer
tests. Long sandpack tests indicated permeability reduction factors
of 11 to 350 d big difference in fluid injectivity and original
designed treatment was modified on site. This paper summarizes key
lessons learnt includin zones in order to provide both proper zonal
isolation and accurate treatment placement. The post water shut off
treatment showed up to 70 mediation. This low success rate is due
to poor diagnosis wrong selection of water shutoff solutions and
how complicated the well completi s. It also leads to corrosion and
degradation of completion and flow lines. It imparts higher
hydrostatic pressure on the formation as water hutoff of the water
zones and the effective cleanup of the isolated producing layers.
The results of ten water control treatments are presen the need to
perform rigless water shutoff was needed due to the high demand and
high cost of workover rigs. This paper will highlight the m . The
advanced and intelligent CT enables real time downhole measurements
via fiber optic telemetry system. The system consists of surf
ormance in the laboratory compared to normal cement squeeze
techniques. Selective perforation of the hydrocarbon zones will
re-establish mediation. This low success rate is due to poor
diagnosis wrong selection of water shutoff solutions and how
complicated the well completi of these reservoirs in order to
optimize gas production from the other reservoirs. Production
logging measurements are used to identify the
ion time from slurry to gel is controlled by the crosslinker
concentration of the OCP system and is not altered by the addition
of the particles
fractures and sources of high GOR. b) Use of flowing
cross-linked polymer gel combined with a ringing type of
cross-linked polymer gel as he sources of gas production and
formation-microimager (FMI) logs used for fracture identification
and characterization. This paper illustrat
ells and reacts with added cross-linker in situ. After
cross-linking the web of polymer is inflated in the presence of
water effectively blockin uction factors of 11 to 350 for
concentrations of 1500 to 3500 ppm active particles in sand of 560
to 670 mD permeability at149F. 1
arizes the results of 19 WSO jobs performed.. In some specific
wells water cut decreased by 20%; on others by 70% with consequent
oil
trol treatments are presented here. The average water cut was
reduced to 30% from 88% and oil production was increased by an
average
uction factors of 11 to 350 for concentrations of 1500 to 3500
ppm active particles in sand of 560 to 670 mD permeability at149F.
1 key lessons learnt including tool and packer conveyance mixing
and pumping of water shut-off fluids under offshore rig and
wellsite conditio reatment showed up to 70% water flow reduction
from the targeted layer has been achieved. Introduction Fulfilling
requirement such as lim plicated the well completion is with
respect to the zone of interest to be treated. Field X 1 2 which
consists of a large gas cap and a 100on the formation as water is
heavier than oil thus reducing the pressure available for carrying
oil to the surface. In many cases high water p trol treatments are
presented here. The average water cut was reduced to 30% from 88%
and oil production was increased by an average is paper will
highlight the methodology equipment and procedure used in the first
rigless horizontal WSO in South Ghawar area by Coiled he system
consists of surface readouts including dynamic interpretation
software fiber optic cable and bottom-hole sensors which provide
bon zones will re-establish the oil production. The shutoff zones
can be reopened later in the wells life when artificial lift has
been instal plicated the well completion is with respect to the
zone of interest to be treated. Field X 1 2 which consists of a
large gas cap and a 100nts are used to identify the water producing
reservoir to be isolated. This paper presents a successful field
application of chemical water sh
he addition of the particles wellbore fluids or variations in
lithology (sandstone dolomite limestone shale etc). Bullheading the
PG syste
oss-linked polymer gel as a capping fluid. c) Utilize an on-fly
mixing system that enables volume and concentration adjustment as
plugging zation. This paper illustrates the work carried out in
horizontal openhole and vertical cased-hole completions to shut off
the undesirable gas
f water effectively blocking the flow path whilst deflating in
the presence of oil.Since the whole producing zone is treated water
will b meability at149F. 15 587 gallons of particulate product was
dispersed using 8 060 gallons of dispersing surfactant into 38 000
barre
70% with consequent oil production increase in some cases of
more than 400 BOPD per well. The WSO treatments have been designed
f
increased by an average of 300 BOPD per well through the
application of this water shut-off solution. In one particular well
two previous w
meability at149F. 15 587 gallons of particulate product was
dispersed using 8 060 gallons of dispersing surfactant into 38 000
barre re rig and wellsite conditions. It also shares a method of
post treatment production evaluation and suggests operational
change to improve ng requirement such as limited outside diameter
(OD) due to the production tubing restrictions or high expansion
ratio conformance due to large gas cap and a 100-ft total vertical
depth (TVD) oil column was developed with the single-string
multizone completion design. Due to n many cases high water
production from the formation results in dead wells. All these
concerns make the water shut-off a matter of high i increased by an
average of 300 BOPD per well through the application of this water
shut-off solution. In one particular well two previous w h Ghawar
area by Coiled Tubing (CT) intervention to isolate the water
producing zone at the toe of the well with a through tubing
inflatable ole sensors which provides Casing Collar Locator (CCL)
readings Distributed Temperature Survey (DTS) temperature internal
and extern artificial lift has been installed. The system was
tested in the field in two wells. In the first field trial 84 m of
perforations (gross) was squeez large gas cap and a 100-ft total
vertical depth (TVD) oil column was developed with the
single-string multizone completion design. Due to ation of chemical
water shut-off at Peciko field. In this application the chemical
water shut-off is the unique solution due to the thickness of
Bullheading the PG system into the well allows easy placement
and calculation of treatment volume. The limited and controlled
leakoff into
n adjustment as plugging progression dictates. d) Utilize matrix
diagnostics plot along with modified hall plot in real-time to
continually estim hut off the undesirable gas flow successfully.
The horizontal wells identified with poor zonal isolation behind
the liner were treated with an in
ne is treated water will be retarded without the need to know
where it is coming from. Providing due precautions are taken this
can be hig urfactant into 38 000 barrels of injected water and
pumped over 3 weeks at a concentration of 3300 ppm active
particles. Placement deep
nts have been designed for deeper formation penetration and
long-lasting water blockage. Applied WSO treatments with ICS have
been fo
ticular well two previous water control treatments using a
conventional water shutoff technique including a relative
permeability modifier (R
urfactant into 38 000 barrels of injected water and pumped over
3 weeks at a concentration of 3300 ppm active particles. Placement
deep ational change to improve the production. Introduction White
Tiger Field in offshore Vietnam is producing from a highly fissured
granite Bas ratio conformance due to the large inside diameter (ID)
of the producing casing through tubing inflatable packers (TTIP)
technology conve ompletion design. Due to the presence of a strong
aquifer in this field water production started early and some of
the wells were shut-in du shut-off a matter of high importance and
concern. There are several techniques being used to reduce or
eliminate water production: 1. Ch ticular well two previous water
control treatments using a conventional water shutoff technique
including a relative permeability modifier (R through tubing
inflatable packer and a cement cap topped with mud push and high
viscosity gel to reduce the cement slumping effect. Intr rature
internal and external CT pressure measurements. Permanent zonal
isolation utilizing an inflatable packer with a cement plug above
ations (gross) was squeezed off with the gel/cement in a single
attempt. After reperforation of the top and the middle zone the
well produce ompletion design. Due to the presence of a strong
aquifer in this field water production started early and some of
the wells were shut-in du on due to the thickness of the reservoir
to be isolated (>8 m) not feasible using current mechanical
techniques and the interest of keeping
and controlled leakoff into the matrix during the PG system
squeeze results in a controlled depth of invasion. Selective
perforation of the oil
al-time to continually estimate flowing gel volume. e) Deploy a
fit-for-purpose gel placement assembly for treatment under
Sub-hydrostatic c er were treated with an innovative gel
gas-shutoff procedure. The merits of this procedure outweighed
those of other proposed solutions: ta
s are taken this can be highly successful. For example in May
2005 on Slot 32 oil production increased from 800 bopd to 2 800
bopd wh articles. Placement deep in the reservoir between injector
and producer was confirmed by pressure fall off analysis and
injectivity tests. Th
ents with ICS have been found to effectively block water
production over a long period. Cost of treatments has been paid out
within approxi
ve permeability modifier (RPM) had left the well producing 100%
water. The new solution reduced the water cut to 25% resulting in a
gain
articles. Placement deep in the reservoir between injector and
producer was confirmed by pressure fall off analysis and
injectivity tests. Th highly fissured granite Basement formation.
Basement consists of igneous crystalline rocks characterized by
petrography heterogeneity bec s (TTIP) technology conveyed with
Coiled Tubing has evolved to the point to become an established
alternative for the oilfield operators pro f the wells were shut-in
due to lift problems associated with the water production. A
sidetrack option was considered as a means of bringing e water
production: 1. Chemical techniques like resins epoxies polymer gels
etc. to plug the water producing features. 2. Using bridge p ve
permeability modifier (RPM) had left the well producing 100% water.
The new solution reduced the water cut to 25% resulting in a gain
ment slumping effect. Introduction Some horizontal wells started to
produce less oil rate due to increasing water production. Basic
horizon with a cement plug above the packer was successfully
performed using CT conveyed fiber optic system. The availability of
CCL temperat dle zone the well produced at a strongly reduced water
cut (i.e. 25 to 33% compared with 60 to 62% before the treatment)
and an increas f the wells were shut-in due to lift problems
associated with the water production. A sidetrack option was
considered as a means of bringing nd the interest of keeping a full
bore access to allow future mechanical water shut-off for the other
deeper reservoirs while isolating the wat
ctive perforation of the oil zones re-establishes the desired
hydrocarbon production from the targeted interval. The PG system
can be easil
nt under Sub-hydrostatic conditions. Introduction The giant
fractured carbonate field was discovered in 1964 and came on stream
three yea ther proposed solutions: targeted placement a strong
full-blocking gel to fill up channels behind the liner inert
particles to control fluid loss
0 bopd to 2 800 bopd whilst water cut reduced from 92% to 77%.
The most likely explanation for this is a combined effect of the
treatmen sis and injectivity tests. The incremental oil predicted
from the simulation was 50 000 to 250 000 bbl over 10 years. In
fact over 60 000 barre
en paid out within approximately 45 days. This paper includes
laboratory tests operational procedures and results for each
treatment done
o 25% resulting in a gain in oil production of 300 BOPD. This
innovative solution was established as a standard practice for
water shutoff in
sis and injectivity tests. The incremental oil predicted from
the simulation was 50 000 to 250 000 bbl over 10 years. In fact
over 60 000 barre ography heterogeneity because they were formed in
different tectonic activities in their geological evolution. Since
being formed to recent th r the oilfield operators proving to be
capable of effective zonal isolation on a broad range of
applications (multiple zones stimulation water ed as a means of
bringing these wells back on production but was not used because of
the absence of a gas gathering facility for the field. eatures. 2.
Using bridge plugs cement plugs and other mechanical devices to
stop water production. Definition of problem The well w o 25%
resulting in a gain in oil production of 300 BOPD. This innovative
solution was established as a standard practice for water shutoff
in production. Basic horizontal well completion in South Ghawar was
4 - 3 tubing of an existing vertical wellbore and 6 1/8 inches op
ailability of CCL temperature and differential pressure readings
enabled precise depth control proper packer inflation and
optimization of th reatment) and an increased oil production (i.e.
3 000 BOPD compared with 1 000 BOPD before the treatment). The oil
production declined ed as a means of bringing these wells back on
production but was not used because of the absence of a gas
gathering facility for the field. irs while isolating the water
source located above. Sealing quality at the isolated water zone
was confirmed by a production logging job pe
e PG system can be easily washed out of the wellbore as compared
to cement which must be drilled out. The temperature range of the
PG
came on stream three years later. The field has 7 reservoir
layers (A to G) and multiple subunits within each layer. The upper
layers A B C rticles to control fluid loss of the full-blocking gel
to small fractures and the formation matrix and displacement with
an already-cured gel tha
ned effect of the treatment stimulating production from the
J-sand region while limiting water flow potential from wetter
areas. Introductio s. In fact over 60 000 barrels of oil was
recovered in the first 4 years at a cost comparable with
traditional well work and less than sidetrackin
s for each treatment done with ICS technology demonstrating to
be an excellent option to enhance oil recovery on mature fields
with wate
ractice for water shutoff in the Boscan field. Introduction The
Boscan field lies 40-km southwest of Maracaibo Venezuela and covers
an a
s. In fact over 60 000 barrels of oil was recovered in the first
4 years at a cost comparable with traditional well work and less
than sidetrackin being formed to recent the basement rocks of the
Cuulong basin have been strongly affected by different alteration
processes. These pro e zones stimulation water/gas shut off zonal
production evaluationetc) where accurate selective fluid placement
is essential for the succ hering facility for the field. As a
result of production decline and lack of infill opportunities
cement-water shutoff and re-perforation intervent on of problem The
well was completed as an S shape open hole producer with
approximately 2675 ft of reservoir contact. Out of this 1 ractice
for water shutoff in the Boscan field. Introduction The Boscan
field lies 40-km southwest of Maracaibo Venezuela and covers an a
lbore and 6 1/8 inches open hole completions. Production flow
profile is needed to determine the water producing intervals and
come up w ation and optimization of the cement design. This paper
highlights the application of a CT equipped with fiber optic
advanced technology on The oil production declined to 2 000 BOPD
over a year; the water cut gradually increased over that period to
56%. In the second well full sh hering facility for the field. As a
result of production decline and lack of infill opportunities
cement-water shutoff and re-perforation intervent production
logging job performed after the chemical water shut-off operation.
This successful chemical water shut-off reduced the water pr
mperature range of the PG system is 80 to 350F. To date more
than 54 jobs have been performed with this system. This paper
presen
r. The upper layers A B C D and E1/E2 are more intensely
fractured than lower layers E3/E4 F and G reservoirs. Initial
production from the h an already-cured gel that could be washed out
of the wellbore. Significant drops in the GORs of these wells
resulted in sustained oil-prod
wetter areas. Introduction to Water Shut Off Techniques Water
production is a world wide challenge with an average of three
barrels of k and less than sidetracking. Introduction In a 2004 SPE
Distinguished Lecture it was stated that the world wide recovery
factor for oil will
on mature fields with water high water production. Introduction
Boscn field is located near to Maracaibo Zulia State at west of
Maraca
enezuela and covers an area of approximately 660 km2 produces a
10.5API gravity asphaltic oil from the upper Eocene Boscan
(Miso
k and less than sidetracking. Introduction In a 2004 SPE
Distinguished Lecture it was stated that the world wide recovery
factor for oil will ion processes. These processes changed not only
the composition petrophysical characteristics but also were
principal causes creating g nt is essential for the success of the
job. However the biggest challenge remains the nonproductive time
due to the tools reliability esp nd re-perforation intervention in
the wells was adopted. The objective of the cement-water shutoff
was to ensure that the perforations whic ervoir contact. Out of
this 1600 ft was placed horizontally at the top 50 ft reservoir
while the remaining footage was drilled slanted across the enezuela
and covers an area of approximately 660 km2 produces a 10.5API
gravity asphaltic oil from the upper Eocene Boscan (Miso g
intervals and come up with the best method to isolate that section.
The production profile indicated that water production is from the
toe o c advanced technology on a rigless water shut-off job. The
paper also discusses the water shut-off (WSO) job design and
execution challen In the second well full shutoff was achieved but
oil production could not be resumed for reasons that are not fully
understood. Introductio nd re-perforation intervention in the wells
was adopted. The objective of the cement-water shutoff was to
ensure that the perforations whic t-off reduced the water
production rate from 4 000 bwpd to less than 100 bwpd and allowed
an instantaneous gas production gain of 10 M
system. This paper presents case histories methodology of job
designs and results obtained from laboratory evaluations.
Introduction Wa
Initial production from the reservoirs (1967 to 1970) was by
natural depletion supported by gas injection in the A reservoir
unit starting 196 sulted in sustained oil-production increases.
This is a step change in the ability to manage detrimental gas
production in this field and is exp
verage of three barrels of water being produced for every barrel
of oil [1]. Economic and environmental issues are created due to
lifting se recovery factor for oil will be less than 33 percent1.
Even achieving 40 percent would abandon significant residual oil
unless innovative
a State at west of Maracaibo Lake with a total area of 627 Km2
(Figure 1). This field have being producing since 1940 actually is
operated
per Eocene Boscan (Misoa) Formation with a live oil viscosity
ranging from 200-400 cp at reservoir conditions. The reservoir dips
to the so
recovery factor for oil will be less than 33 percent1. Even
achieving 40 percent would abandon significant residual oil unless
innovative principal causes creating good reservoir properties of
some granitoid basement bodies. Some main alteration processes are
volume shrinka to the tools reliability especially in harsh HPHT
(high-pressure high temperature) environment and challenging
well-bores configuration (Hi that the perforations which were
flushed were completely sealed off and isolated and subsequently
re-perforated shallower. After slurry p s drilled slanted across
the same reservoir for evaluation purposes (Fig. 1). per Eocene
Boscan (Misoa) Formation with a live oil viscosity ranging from
200-400 cp at reservoir conditions. The reservoir dips to the so
oduction is from the toe of the horizontal open hole section. Job
Objective and Design The objective of the operation is to shut off
the wat sign and execution challenges. Introduction Drilling
horizontal wells become the norm in many Saudi Aramco fields. As
horizontal wells ma y understood. Introduction Waterdrive either
natural or through water injection is probably the most important
recovery mechanism for oil that the perforations which were flushed
were completely sealed off and isolated and subsequently
re-perforated shallower. After slurry p s production gain of 10
MMscfd with an estimated cumulative gain of 10 Bscf in 3 years.
Introduction Peciko is a giant offshore gas field in
luations. Introduction Water drive either natural or through
water injection is probably the most important recovery mechanism
for oil prod
reservoir unit starting 1968. After this initial period of gas
injection water injection was implemented in the A C D and E
reservoirs (1970 t tion in this field and is expected to lead to
further opportunities for improved gas management and well
performance in this field and other f
e created due to lifting separation and disposal of unwanted
water. Water production can also lead directly to loss of
hydrocarbon produc sidual oil unless innovative steps are taken to
recover it. Recovery factor can be increased by improved access
displacement or sweep.
1940 actually is operated by the Joint Venture Petroboscan
(PDVSA and Chevron). More than 1.2 billion barrrels of 10.5 API oil
have b
he reservoir dips to the southwest and ranges from 5000 to 9000
ft in depth. Boscan Field is a combination structural/stratigraphic
trap. The
sidual oil unless innovative steps are taken to recover it.
Recovery factor can be increased by improved access displacement or
sweep. cesses are volume shrinkage due to the crystallization of
magma lavas alteration due to the tectonic activities alteration
due to the hydroth ell-bores configuration (High inflation
ratioetc). The recently developed TTIP systems are specifically
designed to perform reliable zonal d shallower. After slurry
placement and squeezing it is important to ensure that a good
cement job has been performed. Operationally the
he reservoir dips to the southwest and ranges from 5000 to 9000
ft in depth. Boscan Field is a combination structural/stratigraphic
trap. The ation is to shut off the water production zone by
plugging back the lower zone. Production engineering evaluated all
the available technique lds. As horizontal wells mature oil rate is
reduced due to increasing water production which dictates the need
to perform water shut-off job ecovery mechanism for oil production
from oil-bearing rocks.In a layered reservoir this will cause water
breakthrough in the high-perme d shallower. After slurry placement
and squeezing it is important to ensure that a good cement job has
been performed. Operationally the a giant offshore gas field in the
Mahakam delta at East Kalimantan - Indonesia which covers an area
of of 350 km2 with water depths of 30
ery mechanism for oil production from oil-bearing rocks.
Consequently water is produced together with the oil. Generally oil
production dec
D and E reservoirs (1970 to 1984). Previously unknown fracture
networks in these layers resulted in rapid water breakthrough. This
was follo ce in this field and other fields where the GOGD recovery
mechanism is used. Introduction The giant fractured carbonate field
was discov
ss of hydrocarbon production due to gross fluid processing
constraints or simply the inability to lift a well back to
production due to very hig splacement or sweep. Access is typically
the domain of sidetrack and infill drilling. Improved displacement
is addressed by Enhanc of 10.5 API oil have been produced through
artificial lift. The estimated original oil in place (OOIP) is
36.84 billion barrelsl
and recove
ural/stratigraphic trap. The reservoir sands were deposited in a
tidal-dominated depositional setting. Boscan Field has a complex
stratigraph
splacement or sweep. Access is typically the domain of sidetrack
and infill drilling. Improved displacement is addressed by Enhanc
eration due to the hydrothermal activities alteration due to the
weathering activities. The inside volume of magma bodies is often
shrank wh to perform reliable zonal isolation in HPHT environment
high inflation ratio applications with enhanced differential
pressure capabilities th ormed. Operationally the top of cement
(TOC) is tagged using slick-line in a vertical or deviated well. If
the TOC is not at the theoretical de
ural/stratigraphic trap. The reservoir sands were deposited in a
tidal-dominated depositional setting. Boscan Field has a complex
stratigraph all the available techniques to conduct this job with
out utilizing a workover rig and was able to do so as this paper
will show. The best avai perform water shut-off jobs to sustain oil
production. through in the high-permeability layers leaving oil
behind in the unswept layers. Generally oil production decreases
with the maturity of an ormed. Operationally the top of cement
(TOC) is tagged using slick-line in a vertical or deviated well. If
the TOC is not at the theoretical de m2 with water depths of 30-40
meters. The field has multilayer pay zones at around 2 000 4 000
meters subsea with an unfaulted str
enerally oil production decreases with the maturity of an asset
while water production increases. For 1999 the worldwide daily
water produ
eakthrough. This was followed by GOGD (Gas-Oil-Gravity-Drainage)
development (1984 to 1998) which was successful in arresting the de
carbonate field was discovered in 1964 and came on stream 3 years
later. The field has seven reservoir layersA through Gand
multip
production due to very high water cut. The major environmental
impacts of high water production are discharge of oil and entrained
produ t is addressed by Enhanced Oil Recovery methods. There has
been a shortage of tools for improving sweep particularly when
thief zon
llion barrelsl
and recoverable reserves of 2.47 billion Barrels. Primary
production began in 1947 with an initial reservoir pressure of 3
450
has a complex stratigraphic framework the interpretation of
which is made particularly difficult by the 1 to 0.6 kilometer well
spacing. The fi
t is addressed by Enhanced Oil Recovery methods. There has been
a shortage of tools for improving sweep particularly when thief zon
bodies is often shrank when the magma lavas crystallized and
solidified. This volume shrinkage caused by sudden change of
temperature al pressure capabilities through technological advanced
component design. The complicated nature of the water problem in
northern Kuwa s not at the theoretical depth then a top-up job is
carried out with additional slurry. On the other hand if the TOC is
at the theoretical depth
has a complex stratigraphic framework the interpretation of
which is made particularly difficult by the 1 to 0.6 kilometer well
spacing. The fi er will show. The best available option was found
to be setting an inflatable packer at the top of water zone in the
open hole and cap it with
es with the maturity of an asset while the water production
increases. For 1999 the worldwide daily water production associated
with o s not at the theoretical depth then a top-up job is carried
out with additional slurry. On the other hand if the TOC is at the
theoretical depth bsea with an unfaulted structure. The producing
layers are in Upper Miocene formations with a mud dominated delta
environment and thin
orldwide daily water production associated with oil production
has been reported as 33 million m or roughly three barrels of water
for ev
ccessful in arresting the decline in the oil production.
Following a simulation study in 1996 it was decided to implement a
line-drive waterflo A through Gand multiple subunits within each
layer. The upper layers A C D and E1/E2 are more intensely
fractured than lower layers
of oil and entrained production chemicals in overboard water.
Reducing the volume of disposed water is clearly the best way to
reduce the particularly when thief zones or channels are in contact
with lower permeability less efficiently swept zones and an in
depth block is ne
eservoir pressure of 3 450 psi and it has declined to a current
average reservoir pressure of 1 500 psi. The production goal in
this field is 1
meter well spacing. The field currently produces ~ 115 000 BOPD.
Figure 1 shows the geographic location of the Boscan field. Since
its di
particularly when thief zones or channels are in contact with
lower permeability less efficiently swept zones and an in depth
block is ne en change of temperature as well as by viscosity
increase during the times that these magma lavas crystallized and
resulting in the formatio problem in northern Kuwait because of the
fact that the targeted sections are usually located in-between
multiple oil producer zones revea is at the theoretical depth then
a pressure test is performed to confirm that the perforations are
squeezed off. For intervals behind the sle
meter well spacing. The field currently produces ~ 115 000 BOPD.
Figure 1 shows the geographic location of the Boscan field. Since
its di open hole and cap it with 200 ft of cement and 300 ft of gel
plug. The cement in conjunction with gel plug must be carefully
designed to red
duction associated with oil production has been reported as 33
million m3 or roughly 3 bbl of water for every barrel of oil
(Bailey et al. 200 is at the theoretical depth then a pressure test
is performed to confirm that the perforations are squeezed off. For
intervals behind the sle elta environment and thin sand stone
reservoirs generally less than 1 meter in thickness. Due to the
complexity of the field a phased devel
ree barrels of water for every barrel of oil (Bailey et al.
2000). The United States petroleum industry generates 2.4 billion m
of water ann
ment a line-drive waterflood with horizontal wells in those
layers considered to be sparsely fractured. Because GOGD is not
effective in spa ractured than lower layers the E3/E4 F and G
reservoirs. Initial production from the reservoirs (1967 to 1970)
was by natural depletion su
he best way to reduce these types of discharge. Reducing water
production also has the potential to reduce the requirement for
some typ an in depth block is needed to achieve commercial oil
recovery2. A range of thermally sensitive particulate products have
been develop
uction goal in this field is 115 000 BOPD. This can be reached
by the data gathering and implementations of processes to optimize
and man
Boscan field. Since its discovery by the Richmond Exploration
Company in 1947 the Boscan field has had over 800 wells drilled
with 525
an in depth block is needed to achieve commercial oil recovery2.
A range of thermally sensitive particulate products have been
develop nd resulting in the formation of individual micro fractures
and misco-vugs in granitoid rocks. These micro-pore types can be
only beneficial oil producer zones revealed the necessity of a
complex zonal isolation solution before performing the water
shut-off treatment. An oil produ or intervals behind the sleeve as
in the case of Field X ascertaining the TOC is technically
impossible because the perforations are behind Boscan field. Since
its discovery by the Richmond Exploration Company in 1947 the
Boscan field has had over 800 wells drilled with 525 carefully
designed to reduce the chance of cement slumping. Coiled Tubing
Forces were simulated in order to determine if CT can get to
rrel of oil (Bailey et al. 2000). The U.S. petroleum industry
generates 2.4 billion m3 of water annually (Sustainable Development
2004).T or intervals behind the sleeve as in the case of Field X
ascertaining the TOC is technically impossible because the
perforations are behind the field a phased development was applied
in order to minimize the risk and to optimize the field production.
5 phases of development ha
4 billion m of water annually (DOE 2004). This amounts to an
average of 78 barrels water per barrel of oil. Khatib et al.
reported in SP
OGD is not effective in sparsely fractured reservoir water
flooding those layers was expected to substantially increase
recovery in those lay as by natural depletion supported by gas
injection in the A reservoir unit from 1968 onward. After this
initial period of gas injection water in
requirement for some types of production chemicals associated
with water production e.g. scale inhibitors. Frequent scale
squeezes also oducts have been developed for in-depth waterflood
sweep control. They are sub-micron sized particulate systems
supplied as 30 perc
esses to optimize and mantain the levels of production over the
life of the field. Boscn is characterized by low pore pressure
reservoirs
800 wells drilled with 525 of them currently active. Most of the
shut-in wells in the field are located in the south end of the
field that in recen
oducts have been developed for in-depth waterflood sweep
control. They are sub-micron sized particulate systems supplied as
30 perc pes can be only beneficial for reservoir if they had linked
together by fractures and microfractures which were formed due to
tectonic activiti -off treatment. An oil producer that has shown
-according to the recent production data - an increasing water
production figures was identifie e perforations are behind the
production tubing. For such single-string selective completions
only a pressure test can be performed to conf
800 wells drilled with 525 of them currently active. Most of the
shut-in wells in the field are located in the south end of the
field that in recen etermine if CT can get to the target depth
without locking-up and that the maximum tensile and compressive
loads required at the packer d
Development 2004).This amounts to an average 7 to 8 bbl of water
per 1 bbl of oil.Water production within the one group has roug e
perforations are behind the production tubing. For such
single-string selective completions only a pressure test can be
performed to conf phases of development have already been performed
to develop the field. There are around 100 development wells
already drilled in Pecik
Khatib et al. reported in SPE 73853 that water production within
the Shell Group increased from 350 000 m/D in 1990 to more than 1
00
ease recovery in those layers. Since 1997 field development and
operation has utilized this combination of GOGD and localized
waterflood d of gas injection water injection was implemented in
the A C D and E reservoirs (1970 through 984). Previously unknown
fracture netwo
uent scale squeezes also involve excessive down-time leading to
significant production loss. stems supplied as 30 percent active
emulsions in light mineral oil. The technology recently proved
successful in a technical field trial3 4
pore pressure reservoirs high pressure and large underlaying
active aquifer in the south block (Figure 2) high accumulated
production an
d of the field that in recent years has experienced a surge in
water production. Most of the wells in this particular area are
experiencing wat
stems supplied as 30 percent active emulsions in light mineral
oil. The technology recently proved successful in a technical field
trial3 4 med due to tectonic activities at later times. The
tectonic activities are principally factors making strong and
widespread alteration of baseme uction figures was identified as a
good candidate for such approach. A temporary straddle system was
created using two through tubing inf can be performed to confirm
that the perforations are squeezed off. This paper addresses the
planning operational and the learning from
d of the field that in recent years has experienced a surge in
water production. Most of the wells in this particular area are
experiencing wat ds required at the packer during the operation are
within the string capabilities and limitations. The friction
coefficients were estimated based
n the one group has roughly increased from 350 000 m3/d in 1990
to more than 1 000 000 m3/d today (Khatib and Verbeek 2002). The co
can be performed to confirm that the perforations are squeezed off.
This paper addresses the planning operational and the learning from
ells already drilled in Peciko located on 6 production platforms.
The production was started at the end of 1999 with a peak
production of a
in 1990 to more than 1 000 000 m/D in 2002 (Khatib and Verbeek
2002). The costs associated with handling produced water are
typic
D and localized waterflood1. y unknown fracture networks in
these layers resulted in rapid water breakthrough. This was
followed by GOGD development (1983 through
in a technical field trial3 4. Evidence of the commerciality of
the technology was required. The purpose of the trial discussed
here w
ccumulated production and high production rates. Due to a rising
Water Oil Contact (WOC) high water cut levels have been observed on
d
area are experiencing water cut of 90% or higher. Problem Scope
The main production challenges in south Boscan wells are; 1)
Surface f
in a technical field trial3 4. Evidence of the commerciality of
the technology was required. The purpose of the trial discussed
here w pread alteration of basement rocks. The basement rocks have
been fractured broken and catalazited at various degrees developing
differe sing two through tubing inflatable packers therefore
isolating the top and bottom perforated zones in order to provide
both proper zonal isol nal and the learning from the through-tubing
water shutoff campaign successfully carried out on wells with
single-string multizone completio
area are experiencing water cut of 90% or higher. Problem Scope
The main production challenges in south Boscan wells are; 1)
Surface f ents were estimated based on the available friction data
in offset wells.
nd Verbeek 2002). The costs associated with handling produced
water are typically proportional to the amount of water
produced.Cons nal and the learning from the through-tubing water
shutoff campaign successfully carried out on wells with
single-string multizone completio ith a peak production of around 1
400 MMscfd in 2005. The current gas production of the field is
close to 1 000 MMscfd and the condensat
g produced water are typically proportional to the amount of
water produced. Consequently costs per barrel of oil produced
continue to incr
evelopment (1983 through 1998) which was successful in arresting
the decline in the oil production. Following a simulation study in
1996 it
the trial discussed here was to measure the commercial effect on
a small number of isolated wells. The BP Milne Point field is on
the Nort
have been observed on deeper production zones. Wells located in
the south block of the field have most of the water production this
zon
can wells are; 1) Surface facility limitations in handling
produced water; therefore the volume of fluid produced is limited.
In addition produc
the trial discussed here was to measure the commercial effect on
a small number of isolated wells. The BP Milne Point field is on
the Nort egrees developing different fracturing systems with
different directions. The fracturing and breaking did not change
the rock composition b vide both proper zonal isolation and
accurate treatment placement. TTIP Technology Overview The TTIP is
run in the well on the end of co string multizone completions.
Introduction Cement-water shutoff intervention behind the sleeve in
multizone completions is a solution that i
can wells are; 1) Surface facility limitations in handling
produced water; therefore the volume of fluid produced is limited.
In addition produc
water produced.Consequently costs per barrel of oil produced
continue to increase with increasing water production.Ultimately
ind string multizone completions. Introduction Cement-water shutoff
intervention behind the sleeve in multizone completions is a
solution that i Mscfd and the condensate to gas ratio is around 15
bbl condensate / MMscf gas. The well potentials currently range
from 1 to 30 MMscfd o
produced continue to increase with increasing water production.
Ultimately individual wells or complete fields are abandoned when
cash fl
imulation study in 1996 it was decided to implement a line-drive
waterflood with horizontal wells in layers that were considered
sparsely-fra
e Point field is on the North Slope of Alaska. The reservoir
shows structural compartmentalisation into separate fault blocks
called Hydr
water production this zone has been producing for more than 50
years is partially depleted and wet sands are part of the
production i
mited. In addition production enhancement is restricted.
e Point field is on the North Slope of Alaska. The reservoir
shows structural compartmentalisation into separate fault blocks
called Hydr ge the rock composition but they strongly altered the
structure texture and particularly the petrophysical
characteristics of the basement ro n the well on the end of coiled
tubing to the required depth and then inflated depending on the
type of the application being performed and pletions is a solution
that is not common due to its low probability of success. Shell
Petroleum Development Company Nigeria and Schlumb
mited. In addition production enhancement is restricted.
duction.Ultimately individual wells or complete fields are
abandoned when cash flows turn negative because of excessive water
produ pletions is a solution that is not common due to its low
probability of success. Shell Petroleum Development Company Nigeria
and Schlumb nge from 1 to 30 MMscfd of gas. A typical Peciko well
is a deviated well of 20-60 degree deviation with 3 500 4 000
meters subsea tota
abandoned when cash flows turn negative because of excessive
water production. The heterogeneous geologic nature of most oil
reserv
re considered sparsely-fractured. Because GOGD is not effective
in sparsely fractured reservoirs waterflooding these layers was
expected
te fault blocks called Hydraulic Units or HUs. The fault density
is moderate with two dominant orientations few open fractures
and
are part of the production intervals (Upper Boscn) with water
cut ranging from 60 to 90% in this area.
te fault blocks called Hydraulic Units or HUs. The fault density
is moderate with two dominant orientations few open fractures and
eristics of the basement rocks. The petrophysics characteristics of
altered basement rocks in the White Tiger (Bach Ho) field change
very s ation being performed and once the desired treatment is
pumped the packer is either deflated and retrieved or the running
tools are discon pany Nigeria and Schlumberger successfully carried
out this operation in four wells drilled and completed in Field X.
The biggest issue ass
of excessive water production. The heterogeneous geologic nature
of most oil reservoirs however provides opportunities to prevent or
re pany Nigeria and Schlumberger successfully carried out this
operation in four wells drilled and completed in Field X. The
biggest issue ass 4 000 meters subsea total depth. Most of of the
wells have a monobore completion with a production tubing size of
4.5 or 5.5(Figure-1). Th
c nature of most oil reservoirs however provides opportunities
to prevent or reduce excessive water production. In layered
reservoirs water