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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     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 post 2005 =             10,000

                                                                   35% of papers published categorised
                               Paper
Organisation             Source No.         Chapter         Section
Heriot Watt University    SPE   105189   Formation Damage   Scale Control
Heriot Watt University    SPE   115195   Formation Damage   Scale Control
SHELL                     SPE   107633   Formation Damage   Scale Control
Heriot Watt University    SPE   114058   Formation Damage   Scale Control
Heriot Watt University    SPE    98096   Formation Damage   Scale Control
Heriot Watt University    SPE   100480   Formation Damage   Scale Control
BP                        SPE   100356   Formation Damage   Scale Control

CHEVRON                   SPE   114042   Formation Damage   Scale Control
SCHLUMBERGER              SPE   114255   Formation Damage   Scale Control
BP                        SPE   100357   Formation Damage   Scale Control
Heriot Watt University    SPE    87445   Formation Damage   Scale Control
Heriot Watt University    SPE   112538   Formation Damage   Scale Control
Heriot Watt University    SPE   114082   Formation Damage   Scale Control

Imperial College          SPE   87445    Formation Damage   Scale Control
        Subject
       Chalk Reservoirs
             ESP's
Formation Damage Assessment
        Halite Inhibition
     Low Suphate Water
  Low Suphate Water Design
           Removal

         Steamflood
      Stimulated Wells
                                             Title
Scale Control in Chalk Reservoirs: The Challenge of Understanding the Impact of Reservoir Processes and Optimizing Scale M
Squeezing Scale Inhibitors to Protect Electric Submersible Pumps in Highly Fractured, Calcium Carbonate Scaling Reservoirs
Managing Formation-Damage Risk From Scale-Inhibitor Squeeze Treatments in Deepwater, Subsea Fields in the Campos Bas
Mechanistic Study of Chemicals Providing Improved Halite Inhibition
Low Sulfate Seawater Injection for Barium Sulfate Scale Control: A Life-of-Field Solution to a Complex Challenge
Design of Low-Sulfate Seawater Injection Based Upon Kinetic Limits
The Evaluation of Enhanced (Carbonate/Sulfate) Scale-Dissolver Treatments for Near-Wellbore Stimulation in Subsea Produc

Control of Silicate Scales in Steam Flood Operations
First Application of Scale Inhibitor During Hydraulic Fracturing Treatments in Western Siberia
The Development of a Revolutionary Scale-Control Product for the Control of Near-Well Bore Sulfate Scale Within Production
The Comparison of Nonaqueous and Aqueous Scale-Inhibitor Treatments: Experimental and Modeling Studies
Inhibition Mechanisms for Sulphide Scales
Using Nature to Provide Solutions to Calcareous Scale Deposition
The Comparison of Nonaqueous and Aqueous Scale-Inhibitor Treatments: Experimental and
Modeling Studies
                                Author                                       Abstract
M.M. Jordan, SPE, Nalco, and E.J. Mackay, SPE, Heriot-Watt U.               Abstract The scale control challenges for a large N
                                                                            Abstract Rosneft has oil fields in Western Volosh
Neil Poynton, SPE, Alan Miller, Dmitry Konyukhov, and Andre Leontieff, Baker Hughes, and Ilgiz Ganiev and AlexanderSiberia
                                                                            Summary This paper describes field M. Frigo, Sh
Philip Bogaert, Marcos C. Berredo, Celso Toschi, and Bill Bryson, Shell Brasil E&P; Myles M. Jordan, Nalco; Darioexperience a
                                                                            Abstract This paper investigates the application of
Hua Guan, SPE, M-I SWACO Production Technologies; Richard Keatch, OMS Limited; Charles Benson, SPE, and Neil Graing
                                                                            and Eric J. Mackay, Heriot-Watt University
Myles M. Jordan, Nalco, Ian R. Collins, BP Exploration Operating Company, Summary The injection of seawater into oil-bearin
                                                                            Abstract Reliance on Rice U.
J.E. McElhiney, SPE, Pratt Technology Management, and M.B. Tomson, SPE, and A.T. Kan, SPE,low sulphate seawater as so
                                                                            Abstract Dissolver technology has been develope
M.M. Jordan and D. Marlow, Nalco; T.L. Johnson, BP America; and C. Johnston, Nalco
Darrell L. Gallup, SPE, and Charles J. Hinrichsen, SPE, Chevron Energy
Technology Company                                                          Abstract Water circulating during steam flooding to
                                                                            Abstract Albert Gaifullin, SPE, Ildar Faizullin, SPE,
K. Cheremisov, SPE, D. Oussoltsev, SPE, and K.K. Butula, SPE, Schlumberger, and Problems related to inorganic scale precip
I.R. Collins and S.D. Duncum, BP, and M.M. Jordan and N.D Feasey, Nalco Abstract The formation of sulfate scales arising f
                                                                            Summary This paper U.
H. Guan, SPE, Champion Technologies, and K.S. Sorbie, SPE and E.J. Mackay, SPE, Heriot-Wattdescribes results from a ser
                                                                            Abstract: Sulphide scales have over
C. Okocha, K.S. Sorbie, and L.S. Boak, Institute of Petroleum Engineering, Heriot-Watt University, Edinburgh, UKrecent years
W.C. Cheong, A. Neville, P.H. Gaskell, and S. Abbott, University of Leeds Abstract The field of biomimetics is expanding in e

                                                                      Summary This paper U.
H. Guan, SPE, Champion Technologies, and K.S. Sorbie, SPE and E.J. Mackay, SPE, Heriot-Wattdescribes results from a ser
 ontrol challenges for a large North Sea carbonate reservoir are reviewed in this paper.� Field data from a reservoir where the process of s
s oil fields in Western Siberia producing fluids from a number of wells via Electric Submersible Pumps (ESP’s). While production rates ar
r describes field experience and lessons learned from bullhead-deployed scale-control operations in a deepwater subsea development in the
nvestigates the application of halite inhibitors and the mechanisms associated with salt formation and inhibition. Several new chemistries (two
 on of seawater into oil-bearing reservoirs to maintain reservoir pressure and improve secondary recovery is a well-established mature opera
n low sulphate seawater as sole protection against sulphate scale may be discomforting to some operators when such expensive subsea we
 echnology has been developed and applied with varying degrees of success over the past few years to clean carbonate and the more challe

ating during steam flooding to recover additional oil from reservoirs often becomes enriched in dissolved silica. As the silica concentration inc
lated to inorganic scale precipitation are common in oil fields across Russia. The predominantly calcium carbonate scale rapidly precipitates
tion of sulfate scales arising from the injection of seawater into hydrocarbon-bearing formations for pressure maintenance and secondary oi
r describes results from a series of comparative corefloods and static compatibility tests examining the differences in laboratory-test procedu
cales have over recent years become increasingly common in many oil and gas producing regions. The main sulphide scales are iron zinc a
biomimetics is expanding in engineering and refers to the mimicking of natural system functionality in technological systems. The most well k

r describes results from a series of comparative corefloods and static compatibility tests examining the differences in laboratory-test procedu
 m a reservoir where the process of scale ion stripping between the seawater injection well and production wells is known to occur is studied
ESP’s). While production rates are increased using ESP’s run time can be compromised by the formation of scale within the inner w
                                                                                   is about deploying such treatments from the floating produ
 eepwater subsea development in the Campos basin Brazil; specifically this paper OnePetro
hibition. Several new chemistries (two inorganic compounds and one organic nitrogen-based product) have been identified which provide imp
  y is a well-established mature operation. Moreover the degree of risk posed by deposition of mineral scales to the injection and production
 ors when such expensive subsea wells are at stake. Normal methods such as bullheading squeeze chemicals are nearly impossible to imp
  clean carbonate and the more challenging sulphate/sulphide scales from production tubing and process equipment.� The intention of th

d silica. As the silica concentration increases in the water silicate minerals become supersaturated. At supersaturation conditions amorphou
  carbonate scale rapidly precipitates from the produced water and causes reduction in reservoir permeability restricts fluid flow in tubing and
ssure maintenance and secondary oil recovery has been a significant problem in many onshore/offshore operations.� To address this ba
differences in laboratory-test procedure scale-inhibitor (SI) returns and modeling approaches for nonaqueous and aqueous SI treatments.ï¿
 main sulphide scales are iron zinc and lead with the latter two often occurring together. This paper presents experimental results from a ser
                                                                                     OnePetro OnePetro
chnological systems. The most well known example of biomimetics is the development of Velcro which resulted from the inability of burrs from

differences in laboratory-test procedure scale-inhibitor (SI) returns and modeling approaches for nonaqueous and aqueous SI treatments.ï¿
on wells is known to occur is studied in detail to identify if it is possible to predict the impact it has on scale management.� Injection water
 formation of scale within the inner workings of the pump. The deposition of scale can be detected by the pumps requiring increasing amoun

ave been identified which provide improved halite inhibition. Their inhibition performance was studied and compared with commercially availa
cales to the injection and production wells during such operations has been much studied. The current deep water subsea developments off
emicals are nearly impossible to implement due to the long and sometimes multiple flow lines connecting injection wells. Subsea interventio
 s equipment.� The intention of this proposed application was to select a chemical that could be applied into the near wellbore region of t

upersaturation conditions amorphous silica and metal silicates may deposit in heat exchangers. Scale deposits not only reduce heat exchan
bility restricts fluid flow in tubing and perforation fails electric submersible and rod pumps and plugs surface equipment. Local industry offe
e operations.� To address this batch scale inhibitor squeeze treatments scale removal and modification of the injection brine (sulfate re
ueous and aqueous SI treatments.� Two types of nonaqueous systems one ethylene glycol (EG) -based and two oil-soluble products eac
sents experimental results from a series of static iron sulphide (FeS) inhibition efficiency tests using 2 scale inhibitors (SI) a phosphonate an


ueous and aqueous SI treatments.� Two types of nonaqueous systems one ethylene glycol (EG) -based and two oil-soluble products eac
le management.� Injection water sulphate ions are shown to break through eventually but the seawater fraction at which this occurs varie
e pumps requiring increasing amounts of current to maintain the flow rates. Eventually the pumps fail (either mechanically or electrically) and

 d compared with commercially available inhibitors. Salt deposition in high salinity brines can cause blockages to production and process sys
deep water subsea developments offshore West Africa and Brazil have brought into focus the need to manage scale in an effective way. To t
 ng injection wells. Subsea intervention to place squeeze inhibitors is prohibitively expensive due to the requirement of utilizing a service boa
 ied into the near wellbore region of the reservoir to recover scale induced damage while not creating any secondary precipitation or�nega

deposits not only reduce heat exchange efficiency due to fouling but they may plug tubes resulting in tube failure. Control of these deposits in
urface equipment. Local industry offers a number of inhibitors to prevent scale deposition. Although regular and planned injection of inhibitors
ation of the injection brine (sulfate removal produced water injection aquifer water injection) have been applied with varying degrees of suc
 sed and two oil-soluble products each containing penta-phosphonate SIs were investigated. Detailed compatibility and injectivity tests were
 ale inhibitors (SI) a phosphonate and a polymer. The paper also highlights the methodology which has been developed for assessing iron s


sed and two oil-soluble products each containing penta-phosphonate SIs were investigated. Detailed compatibility and injectivity tests were
ter fraction at which this occurs varies between different wells.� The impact of the various possible driving mechanisms and the extent to
ther mechanically or electrically) and have to be replaced. Typically examination of these pumps indicated the main failure mechanism to be

kages to production and process systems requiring remedial action often on short notice. Current commercial halite inhibitors are only effec
anage scale in an effective way. To this end the challenge of scale control during the lifecycle of water injection production and onto produc
 equirement of utilizing a service boat over the well for many days.[1] Calculations of scaling index from formation and injected seawater mix
ny secondary precipitation or�negative wettability effects. The impact of dissolver chemical formulation on the reservoir�formation’

e failure. Control of these deposits in boilers and co-generation equipment is necessary to reduce down-time for mechanical cleanout. In the
lar and planned injection of inhibitors into producing and injector wells is the most common method of scale precipitation prevention no succ
 applied with varying degrees of success.�The development of deepwater projects where conventional scale control technology may be
ompatibility and injectivity tests were carried out before coreflooding and a carefully designed application/treatment process was required as
been developed for assessing iron sulphide scale inhibition. The objective of this preliminary iron sulphide inhibition efficiency study was (a) t


ompatibility and injectivity tests were carried out before coreflooding and a carefully designed application/treatment process was required as
riving mechanisms and the extent to which matrix and fracture flow contribute to the process are described.� The discussion is generalis
ed the main failure mechanism to be the deposition of Calcium Carbonate scale within the pump. The actual run times achieved tend to be d

mercial halite inhibitors are only effective at high concentrations (250 – 5 000 ppm). Therefore a more efficient salt inhibitor would need to
njection production and onto produced water reinjection has been reviewed for a number of fields by the authors. This outlines the risk ass
 formation and injected seawater mixtures are routinely based upon the thermodynamics of the mixed brines. Although some mixing does o
 on on the reservoir�formation’s wettability and the potential for mobilization of fines (both reservoir silicate and scale) has not been o

 -time for mechanical cleanout. In the present study at a steam flooded field steam boiler and co-generation tube deposits consisted of opal
cale precipitation prevention no successful attempt to enhance scale prevention in conjunction with a stimulation treatment has been docum
 nal scale control technology may be uneconomic for the control of mineral scale has required a re-evaluation of the methods of scale inhib
 n/treatment process was required as a result of the hydrophobic nature of these products. To understand the SI-transport and -retention mec
de inhibition efficiency study was (a) to establish which of the conventional SI tested inhibit FeS and under which test conditions; (b) to determ


n/treatment process was required as a result of the hydrophobic nature of these products. To understand the SI-transport and -retention mec
 bed.� The discussion is generalised to findings applicable to other carbonate systems. The mechanisms of scale inhibitor retention when
ctual run times achieved tend to be dependant on the severity of the scaling produced water but were typically in the order of weeks. Howev

 efficient salt inhibitor would need to reduce both treatment level and production downtime. The inhibition performance of three new chemica
 e authors. This outlines the risk assessment process that should be undertaken to select the most economical and effective scale control m
brines. Although some mixing does occur in the interwell distance the most vigorous mixing occurs in the vicinity of the production wellbore
oir silicate and scale) has not been outlined before.�In this paper reservoir condition coreflood studies are outlined where scale is formed

ation tube deposits consisted of opal-A pectolite aegerine clinamphibole serpentine-like minerals iron oxide corrosion products and apatit
 mulation treatment has been documented. This paper describes the first application of a combined scale inhibitor and hydraulic fracturing tr
aluation of the methods of scale inhibitor deployment. For the past five years BP Exploration has been developing a novel approach to the
 d the SI-transport and -retention mechanisms for these nonaqueous systems comparisons were made with the corresponding aqueous app
er which test conditions; (b) to determine the mechanisms through which SIs inhibit FeS; and (c) to determine if it is possible to determine a â


 d the SI-transport and -retention mechanisms for these nonaqueous systems comparisons were made with the corresponding aqueous app
sms of scale inhibitor retention when phosphonate polymer and vinyl sulphonate co-polymer inhibitor squeeze treatments are applied in this
pically in the order of weeks. However in some extreme cases pump failures had occurred in a matter of days from replacement and start u

 n performance of three new chemicals and two commercial products were evaluated under static conditions along with performance assess
nomical and effective scale control methodology (which for sulfate-based scale could be seawater injection with scale inhibitor squeeze treat
he vicinity of the production wellbore where water from multiple layers and streamlines impinge. These near wellbore mixtures have short re
es are outlined where scale is formed within the cores to allow assessment of sulphate dissolver performance. This will form a critical part o

 oxide corrosion products and apatite. Iron in the silicate minerals appears to derive from transporting incompletely oxygen scavenged circu
le inhibitor and hydraulic fracturing treatment in Western Siberia. It allowed the operator to place significant amount of scale inhibitor within t
developing a novel approach to the application of scale inhibitors with the objective of eliminating the requirement for both active scale inhib
 with the corresponding aqueous applications. These comparisions were made in terms of SI-return performance flowback permeability pos
rmine if it is possible to determine a “minimum inhibitor concentration (MIC) with this methodology. This preliminary study shows that: (i)


with the corresponding aqueous applications. These comparisions were made in terms of SI-return performance flowback permeability pos
queeze treatments are applied in this carbonate reservoir are outlined.� Chemical placement represents the most significant technical cha
of days from replacement and start up. It was proposed that one treatment strategy to increase the pump run time by inhibiting scale formati

 ions along with performance assessment after aging. Both sea salt and pharmaceutical-grade sodium chloride were used in the tests. All thr
ion with scale inhibitor squeeze treatments to maintain production or sulfate reduction of the injection water with or without the need to scale
near wellbore mixtures have short residence times before being produced therefore reaction kinetics must be considered and it is not clear
mance. This will form a critical part of the technical evaluation of the dissolver formulation suitability for field application.�Results from the

ncompletely oxygen scavenged circulating water to the boilers and co-generation unit in carbon steel pipe. Increasing the concentration of ox
 ant amount of scale inhibitor within the propped fracture and into the adjacent formation. The case history delineates the detailed sampling a
equirement for both active scale inhibitor squeezing and scale removal operations.�This has been achieved by the development of nano-
 ormance flowback permeability possible formation damage and changes in the wettability conditions that might account for any post-treatm
This preliminary study shows that: (i) The conventional SIs tested in this study do inhibit FeS scale formation; (ii) A clarification phenomenon


 ormance flowback permeability possible formation damage and changes in the wettability conditions that might account for any post-treatm
ents the most significant technical challenge when performing scale
 p run time by inhibiting scale formation was via a Scale Inhibitor Squeeze applicat

hloride were used in the tests. All three new chemicals showed improved inh
ater with or without the need to scale inhibitor squeeze). In the case
ust be considered and it is not clear how low the sulphate concentration
field application.�Results from these coreflood studie

e. Increasing the concentration of oxygen scavenger and EDT
ry delineates the detailed sampling and pretreatment analys
hieved by the development of nano-sized controlled release solid
hat might account for any post-treatment differences. In addition approaches to mathema
tion; (ii) A clarification phenomenon was observed after sul


hat might account for any post-treatment differences. In addition approaches to mathema

				
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