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Nov-09 NOTES: The papers listed here have been obtained by search SPE and IPTC papers post 2005 on the SPE's OnePetro The affiiations searched were; Total No Papers Reservoir Engineering Related BP 551 175 Shell 575 279 Chevron 482 238 ConocoPhillips 191 68 Marathon 55 37 Total 255 129 Schlumberger 1130 563 Imperial College, London 95 53 Heriot Watt University, Edinburgh 235 175 (Anywhere in Article) Total 3569 1717 Total number of papers published pos 10,000 35% of papers published categorised The papers relating to reservoir engineering have been catergorised for inclusion on the reservoirengin

Zonal Isolation

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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