Sand Control - Reservoir Engineering - Reservoir Engineering Community

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Sand Control - Reservoir Engineering - Reservoir Engineering Community Powered By Docstoc
					  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
SCHLUMBERGER              SPE    112491   Well Deliverability   Sand Control
SHELL                     SPE    101187   Well Deliverability   Sand Control
SHELL                     SPE    101181   Well Deliverability   Sand Control
CONOCO                    SPE    105541   Well Deliverability   Sand Control
SCHLUMBERGER              SPE    105541   Well Deliverability   Sand Control
SCHLUMBERGER              SPE    117518   Well Deliverability   Sand Control
CHEVRON                   SPE     98563   Well Deliverability   Sand Control

CHEVRON                   SPE    112394   Well Deliverability   Sand Control
SHELL                     SPE    116091   Well Deliverability   Sand Control
SHELL                     SPE    111635   Well Deliverability   Sand Control
CONOCO                    SPE    105542   Well Deliverability   Sand Control
SCHLUMBERGER              SPE    105542   Well Deliverability   Sand Control
SCHLUMBERGER              SPE    128606   Well Deliverability   Sand Control
SCHLUMBERGER              SPE    112456   Well Deliverability   Sand Control
BP                        SPE    104532   Well Deliverability   Sand control
BP                        SPE    107297   Well Deliverability   Sand Control

CHEVRON                    SPE   110395   Well deliverability   Sand Control
Heriot Watt University     SPE   122054   Well Deliverability   Sand Control
Heriot Watt University     SPE   122064   Well Deliverability   Sand Control
SCHLUMBERGER               SPE   105758   Well Deliverability   Sand Control
SCHLUMBERGER               SPE   107297   Well Deliverability   Sand Control
SCHLUMBERGER               SPE   121093   Well Deliverability   Sand Control
SCHLUMBERGER               SPE   121834   Well Deliverability   Sand Control
SCHLUMBERGER               SPE   121912   Well Deliverability   Sand Control
TOTAL                     IPTC    12388   Well Deliverability   Sand Control
TOTAL                      SPE    98562   Well Deliverability   Sand Control
SCHLUMBERGER              IPTC    12448   Well Deliverability   Sand Control
SCHLUMBERGER               SPE    98151   Well Deliverability   Sand Control


CHEVRON                    SPE   106707   Well Deliverability   Sand Control
TOTAL                      SPE   107341   Well Deliverability   Sand Control
SCHLUMBERGER              IPTC    12581   Well Deliverability   Sand Control
SCHLUMBERGER               SPE   123495   Well Deliverability   Sand Control
BP                         SPE    98252   Well Deliverability   Sand control
SCHLUMBERGER               SPE   112050   Well Deliverability   Sand Control

CHEVRON                    SPE   112084   Well Deliverability   Sand Control
SCHLUMBERGER              IPTC    12385   Well Deliverability   Sand Control

CHEVRON                   SPE    107440   Well Deliverability   Sand Control
SCHLUMBERGER              SPE    107440   Well Deliverability   Sand Control
SCHLUMBERGER              SPE    102185   Well Deliverability   Sand Control

CHEVRON                   SPE    103821   Well Deliverability   Sand Control
Heriot Watt University    SPE    101994   Well Deliverability   Sand Control
SHELL                     SPE    116713   Well Deliverability   Sand Control
TOTAL   SPE   107767   Well Deliverability   Sand Control
            Subject
          Albacora Field
Associated with Hydraulic fracturing
     Challenging Conditions
    Completion Optimisation
    Completion Optimisation
         Complex Wells
           Deepwater

            Deepwater
            Deepwater
        Expandable Screen
              Failure
              Failure
         Failure Mitigation
              Failures
           Gravel Pack
           Gravel Pack

          Gravel Pack
          Gravel Pack
          Gravel Pack
          Gravel Pack
          Gravel Pack
          Gravel Pack
          Gravel Pack
          Gravel Pack
          Gravel Pack
          Gravel Pack
      Gravel Pack Modelling
         Gravel Packing


         Horizontal Wells
    Microemulsion Technology
           Optimisation
      Perforate/Gravel Pack
        Perforating Policy
       Perforation Method

          Screen Failure
        Screen Technology

     Screenless Completions
     Screenless Completions
            Screens

            Steamflood
            Tapti Field
                                             Title
Sand Control Completions for the Development of Albacora Leste Field
Innovative Use of Expandable Sand Screens Combined With Propped Hydraulic Fracturing Technology in Two Wells With Inte
Design and Implementation of a Sand-Control Completion for a Troublesome Shallow Laminated Gas Pay—A Case Study
Magnolia Deepwater Experience—Frac-Packing Long Perforated Intervals in Unconsolidated Silt Reservoirs
Magnolia Deepwater Experience--Frac Packing Long, Perforated Intervals in Unconsolidated Silt Reservoirs
TAML Level 3 tri-lateral with Sand Control application for Saudi Aramco
Deepwater Extended-Reach Sand-Control Completions and Interventions
Sanding Study for Deepwater Indonesia Development Wells: A Case History of Prediction and
Production
Screen Development to Withstand 4,000-psi Overbalance, Subhydrostatic Completion in Deepwater GOM Subsea Waterflood
Sandface Completion for a Shallow Laminated Gas Pay With High Fines Content
Lessons Learned on Sand-Control Failure and Subsequent Workover at Magnolia Deepwater Development
Lessons Learned on Sand-Control Failure and Subsequent Workover at Magnolia Deepwater Development
Novel Through Tubing Sand Control Solution for Failed Gravel Pack - Alpha Well - 4L Case Study
Sand Control Completion Failures: Can We Talk the Same Language?
Development Strategies of Soft-Friable Carbonate Gas Reservoirs Through Horizontal Open Hole Gravel Packed Completions
Greater Plutonio Openhole Gravel-Pack Completions: Fluid Design and Field Applications
High-Angle Well Deliverability Modeling for Openhole Gravel-Pack Completion Under Ultrahigh Gas
Rate
Horizontal Open Hole Gravel Pack Placement Requirements in Selective Completion Projects
A Comparison of Design Placement Methodologies for Horizontal Open Hole Gravel Pack in Multizone Completion Projects
A Step Change in Openhole Gravelpacking Methodology: Drilling-Fluid Design and Filter-Cake Removal Method
Greater Plutonio Openhole Gravel-Pack Completions: Fluid Design and Field Applications
Complex Through-Tubing Gravel-Pack Operation Increases Production on a Well in the Heidrun Field: A Case Study
Openhole Gravel Packing With Exposed Shales: Waterpack Case Histories From Underground Gas Storage Wells in Italy
Gravel Packing Long Openhole Intervals With Viscous Fluids Utilizing High Gravel Concentrations: Toe-to-Heel Packing Witho
Single Trip Multi-Zone Gravel Packing—Case Study at Handil, Bekapai & Sisi-Nubi Fields
Openhole Gravel Pack in the Roaring Forties for TOTAL AUSTRAL
Integrated Approach to Modeling Gravel Packs in Horizontal Wells
Openhole Gravel Packing With Oil-Based Fluids: Implementation of the Lessons Learned From Past Experiences Leads to the


Critical Conditions for Effective Sand-Sized Solids Transport in Horizontal and High-Angle Wells
First Application of Novel Microemulsion Technology for Sand Control Remediation Operations-A Successful Case History From
Effective Perforating and Gravel Placement: Key to Low Skin, Sand Free Production in Gravel Packs
Effective Perforating and Gravel Placement: Key to Low Skin, Sand-Free Production in Gravel Packs
Prediction of Sanding Using Oriented Perforations in a Deviated Well, and Validation in the Field
Determination of Optimum Perforation Design and Sanding Propensity in Long Horizontal Wells Based on Modified RP 19B Se

A Novel Technique for Determining Screen Failure in Offshore Wells: A GOM Case History
ICD Screen Technology in Stag Field to Control Sand and Increase Recovery by Avoiding Wormhole Effect

Screenless Completions as a Viable Through-Tubing Sand Control Completion
Screenless Completions as a Viable Through-Tubing Sand Control Completion
The Search for Alternative to Screen: Is Permeable Cement a Viable Option?

Evaluation of Sand-Control Completions in the Duri Steamflood, Sumatra, Indonesia
Evolution of Sand Control Completion Techniques in the South Tapti Field
Sand Quantification: The Impact on Sandface Completion Selection and Design, Facilities Design and Risk Evaluation
Sand Control Robustness in a Deepwater Development: Case Histories From Girassol Field (Angola)
                                 Author                                      Abstract
                                                                           Abstract The Campos Basin in Brazil SPE, of the
C.A. Pedroso, SPE, E.M. Sanches, and N.S. Oliveira, Petrobras, and I.J. Mickelburgh, SPE, and C.R Guimaraes, is oneSchlum
                                                                           Lim, Jit Oil Lim, and Kuo Chuan Ong, Halliburto
Sakamrin Abdul-Rahman, Brunei Shell Petroleum Co. Sdn. Bhd., and Derek AbstractJuanand gas producers have long been lo
                                                                           Abstract The Shallow Clastics Field operated by S
J.H. Terwogt, N.S. Hadfield, and A.A. Van Karanenburg, Sarawak Shell Berhad, and S. Salahudin and K. King, Halliburton Ene
                                                                           Abstract ConocoPhillips and Kenyon the Magnolia
Luke F. Eaton and W. Randall Reinhardt, ConocoPhillips Co.; J. Scott Bennett, Devon Energy Corp.; is developingBlake and Hu
                                                                           Summary SPE, Devon Energy Corporation; Kenyo
Luke F. Eaton, SPE, and W. Randall Reinhardt, SPE, ConocoPhillips; J. Scott Bennett, ConocoPhillips is developing the Magno
                                                                           Abstract Schlumberger, Tim O’Rourke, Schlum
Ibrahim Refai, SPE Saudi Aramco, Anwar Assal, SPE Schlumberger, Jeremie Fould, A number of the wells reach there econom
Robert D. Pourciau, Chevron Corporation                                    Summary Extended-reach naturally perforated w
Ian D. Palmer and Nigel G. Higgs, Higgs-Palmer Technologies; Robert M.
Mathers & Scott R. Herman, Chevron                                         Abstract A detailed sand prediction has been made
                                                                           Abstract SPE, and describes challenges test an
George Gillespie, SPE, Weatherford International; Chuck Hinnant, SPE, Chris Davis, This paperJamie Schober, SPE, Shell;equ
                                                                           Summary The Shallow Clastics field operated by
Neil S. Hadfield, Jan H. Terwogt, and Aart A van Kranenburg, Sarawak Shell; and Sharifudin Salahudin and Kimberly King, Hal
                                                                           Abstract ConocoPhillips is developing the Magnolia
George Colwart, Robert C. Burton, Luke F. Eaton, and Richard M. Hodge, ConocoPhillips Co., and Kenyon Blake, Schlumberg
                                                                           Summary ConocoPhillips is developing the Magno
George Colwart, SPE, Robert C. Burton, SPE, Luke F. Eaton, SPE, and Richard M. Hodge, SPE, ConocoPhillips Company, an
                                                                           Abstract Alpha field Udeh, T. in SPDC’s OM
I.O. Yahaya, A. Opusunju, B. Ajaraogu, G. Agbogu, O. Williams, and C. Uchendu, SPDC; and M. is situatedOyetade, and M. Ba
                                                                            and Abraham T. Faga, SPE, and Howard L. McKi
Brian T. Wagg, SPE, and Jonathan L. Heseltine, SPE, C-FER Technologies,Abstract Several operators have recently launched
                                                                        0           0
                                                                           Abstract and Open Hole Gravel Pack
Kevin Whaley, Colin Price-Smith, Allan Twynam, and David Burt, BP Exploration Ltd.,InitialPhillip Jackson, Baroid (OHGP) co

Yula Tang, W.S. (Bill) Huang, Chevron Energy Technology Company              Abstract Open-hole Gravel packing is increasingly
                                                                             Abstract Horizontal Open Hole Gravel and (HOHG
B.V. Loureiro, UCL - Faculdade do Centro Leste, J.V.M. de Magalh�es, SPE, M.V.D. Ferreira, A. Calderon, SPEPack A.L. Ma
                                                                             Abstract Horizontal SPE, and A. Calderon, SPE,
B.V. Loureiro, UCL-Faculdade do Centro Leste, and�J.V.M. de Magalhaes, SPE, A.L. Martins,Open hole gravel pack is the c
                                                                             Abstract The major trend and Aziz Ejan, Abdul in
Matthew Law, George W. Chao, Hafeez Ab Alim, and Elsamma Samuel, Schlumberger Well Services, of completion method Ha
                                                                             Abstract and Open Hole Gravel Pack
Kevin Whaley, Colin Price-Smith, Allan Twynam, and David Burt, BP Exploration Ltd.,InitialPhillip Jackson, Baroid (OHGP) co
                                                                             Abstract Well Heidrun Ridene, SPE, and Norweg
Ina H. Stroemsvik, Kjell Tore Nesvik, SPE, Frode Vik, and Karin Stene, StatoilHydro, and MohamedA-45 located in theDaniele
                                                                             Abstract One of the major challenges in undergrou
A. Zanchi, Stogit; G. Ripa, M. Colombo, and G. Ferrara, SPE, Eni E&P; and E. Belleggia, R. Barbedo, R.�Illuminati, J. Rezen
                                                                             Abstract Openhole gravel packing is one of the mo
M. Tolan, BG Group, and R.J. Tibbles, J. Alexander, P. Wassouf, L. Schafer, and M. Parlar, Schlumberger
                                                                             Abstract Indonesia
Mark Banman, Eric Delattre, Muhammad Sofyan, and Siswara Suryadana, Total E&P Stacked gravel-packs involve limited tech
                                                                             Abstract TOTAL AUSTRAL
P. Puyo and A. Bourgeois, Total Austral, and A. Penno and A. Oliveira, Halliburton Energy Services Inc. operates the Carina a
                                                                             Abstract Gravel packing
Samyak Jain, SPE, Rajesh Chanpura, SPE, Renato Barbedo, and Marcos Moura, SPE, Schlumbergerhas routinely been used
                                                                             Abstract M. Parlar, Schlumberger
E.P. Ofoh and M.E. Wariboko, Nigerian Petroleum Development Co., F.E. Uwaifo and A large majority of the recent deepwate
Mingqin Duan, Stefan Miska, Mengjiao Yu, Nicholas Takach, and
Ramadan Ahmed,SPE, University of Tulsa; and Claudia Zettner, SPE,
ExxonMobil                                                                   Summary Effective removal of small sand-sized s
                                                                             Abstract This paper documents a novel engineerin
F. Lavoix, P. Leschi, and E. Aubry, Total E&P, and L. Quintero, X. Le Prat, and T. Jones, Baker Hughes Drilling Fluids
                                                                             Abstract Cased-hole gravel packing is commonly
Samyak Jain, SPE, Raymond Tibbles, and Jock Munro, SPE, Schlumberger, Rajeswary Suppiah and Norhisham Safin, SPE, P
                                                                              Munro, Cased-hole gravel and Rajeswary Supp
Shahryar Saebi, SPE, Samyak Jain, SPE, Raymond Tibbles, SPE, and Jock AbstractSPE, Schlumberger,packing is commonly
                                                                             Krieger, The
I. Palmer and N. Higgs, Higgs Technologies, and I. Ispas, K. Baksh, and K. Abstract BP X-1 well in a gas field in Trinidad wa
                                                                             Abstract Gj�a Atwood, SPE, J. Heiland, SPE,
J. S. Andrews, SPE, H. Bj�rkesett, SPE, J. Djurhuus, StatoilHydro; I. C. Walton, SPE, D. C.is an oil and gas field located off B
G. Navaira, SPE, Chevron; M. Hupp, T. Palisch, SPE, CARBO Ceramics
Inc; J. Renkes, SPE, PropTester, Inc                                         Abstract Offshore completions in the Gulf of Mexic
                                                                             Abstract This paper presents
S. Wibawa, S. Kvernstuen, Schlumberger, and A. Chechin, J. Graham, and K.R. Dowling, Apache Energy the first installation o
M.R. Wise and R.J. Armentor, Chevron, R.A. Holicek, B.R. Gadiyar, M.D.
Bowman, R.A. Jansen, and S.N. Krenzke, Schlumberger                          Abstract Screenless sand control completions pro
                                                                             Abstract Screenless sand control completions pro
M.R. Wise and R.J. Armentor, Chevron, R.A. Holicek, B.R. Gadiyar, M.D. Bowman, R.A. Jansen, and S.N. Krenzke, Schlumbe
B. Vidick, SPE, S. James, SPE, and B. Drochon, SPE, Schlumberger             Abstract The search for a cost-effective alternative
David Underdown, SPE, Chevron; Henky Chan, SPE, Chevron Pacific
Indonesia                                                                    Summary The Duri field in Sumatra Indonesia sh
J.D. Holmes and M.P. Tolan, BGEPIL, and C. Hale, BJ Services                 Abstract The stacked sands of the South Tapti fie
                                                                             SEIC, H. Subhi, SEIC, J.A. Hother, Proneta
M.A. Addis, SIEP, M.C. Gunningham, SEIC, Ph. Brassart, SEIC, J. Webers, Abstract Sand Quantification involves predicting th
G. Petit, H. Foucault, and A. Iqbal, Total E&P   Abstract Wells in the Girassol field offshore Angol
s Basin in Brazil is one of the most challenging areas for completions in the world due to the lack of formation consolidation the large percen
 producers have long been looking for effective sand control methods that allow completion flexibility and improved productivity throughout a
w Clastics Field operated by Sarawak Shell targets two shallow gas-bearing reservoirs H1 and H2 at approximately 2 650 ft true vertical de
 ps is developing the Magnolia field with a Tension Leg Platform (TLP) in 4 674 ft of water at Garden Banks block 783 in the Gulf of Mexico. T
 illips is developing the Magnolia field with a tension-leg platform (TLP) in 4 674 ft of water at Garden Banks Block 783 in the Gulf of Mexico.
  the wells reach there economical production limit and are consequently abandoned or mothballed until viable solutions are available to enha
 reach naturally perforated water-injection frac-pack producing completions and frac-pack producing selective completion interventions wer

and prediction has been made for three wells at Chevron’s West Seno field based on logs/lab data and the results have been calibrated
 escribes challenges test equipment test program and results in the development of a screen product and contingency fluid-loss control (FL
 llow Clastics field operated by Sarawak Shell primarily targets two shallow gas-bearing reservoirs H1 and H2 at approximately 2 650 ft true
 ps is developing the Magnolia field with a tension leg platform (TLP) in 4 674 ft of water at Garden Banks block 783 in the Gulf of Mexico. Th
 illips is developing the Magnolia field with a tension leg platform (TLP) in 4 674 ft of water at Garden Banks Block 783 in the Gulf of Mexico.
s situated in SPDC’s OML 22 in the eastern part of the Niger delta belt some 60kM NW of Port Harcourt. The field discovered in 1986 c
rators have recently launched a new industry-wide initiative on sand control reliability. The aim of the initiative is to gain a better understandin

Hole Gravel Pack (OHGP) completions that have been installed in Greater Plutonio to date have all achieved complete annular packs and ze

Gravel packing is increasingly becoming a standard practice in the deep-water subsea completion environment. A Chevron offshore gas res
 pen Hole Gravel Pack (HOHGP) is the conventional sand control technique for offshore non consolidated reservoirs in Brazil. Gravel pack p
Open hole gravel pack is the conventional sand control technique for offshore non consolidated reservoirs in Brazil. Gravel pack placement re
 rend of completion method in offshore reservoirs with sand control requirement is Horizontal Open Hole Gravel Packing (OHGP).� Thoug
Hole Gravel Pack (OHGP) completions that have been installed in Greater Plutonio to date have all achieved complete annular packs and ze
 n A-45 located in the Norwegian Sea was completed in an unconsolidated sandstone reservoir that required sand control. The lower zone w
major challenges in underground gas storage wells in Italy is to maximize the sand layers exposure by drilling slanted or sub-horizontal wells
 ravel packing is one of the most popular completion techniques due to its high reliability along with the ability to deliver high-productivity well
avel-packs involve limited technical risk but require considerable rig time when completing deep multi-zone sand control wells. Four field dev
 STRAL operates the Carina and Aries fields which are located in offshore Tierra del Fuego in the most southern region of Argentina. These
 king has routinely been used as a sand control method in open-hole horizontal wells. With the advances in drilling technology in recent years
ajority of the recent deepwater developments in West Africa require sand control applications. Openhole gravel packing is the preferred sand


emoval of small sand-sized solids is critical for successful drilling and completion operations in sand reservoirs. Recent experience in extend
 ocuments a novel engineering approach and the operational methodology used to achieve high efficiency remediation on two offshore applic
e gravel packing is commonly utilized to control sand production from oil and gas wells. The success of a cased-hole gravel-pack job depend
 gravel packing is commonly utilized to control sand production from oil and gas wells. The success of a cased-hole gravel-pack job depends
ell in a gas field in Trinidad was designed to be a high-rate gas producer from a 65� deviated well through the S1U S1L and S2U sands a
 n oil and gas field located off the Norwegian Coast that is due to be developed with subsea infrastructure tied back to a floating production fa

mpletions in the Gulf of Mexico must typically address sand control. Our industry has made significant progress with respect to sand control e
presents the first installation of nozzle-based passive inflow control devices (ICD) for Apache Corporation in Australasia. This recent technolo

 sand control completions provide a cost-effective means of completing wells in the Gulf of Mexico by eliminating the need to have a rig on lo
 sand control completions provide a cost-effective means of completing wells in the Gulf of Mexico by eliminating the need to have a rig on lo
 for a cost-effective alternative to screens has been intensive in the sand control field. Different systems have been proposed in the past incl

 eld in Sumatra Indonesia shown in Fig. 1 and operated by Chevron Pacific Indonesia (CPI) is one of the largest onshore steamflood opera
d sands of the South Tapti field have presented completion challenges from field start-up in 1997 to the present-day. A large part of these ch
 fication involves predicting the volumes of sand which can be produced at the sandface completion and transported to the surface facilities f
Girassol field offshore Angola are situated in very deep water and have being completed in unconsolidated sandy turbiditic reservoirs. Toda
 ation consolidation the large percentage of fines present in the reservoir the heavy oil the low frac gradients the low net-to-gross ratio the
d improved productivity throughout a well’s lifecycle. This paper discusses the many challenges encountered during the planning and com
 pproximately 2 650 ft true vertical depth (TVD). An appraisal/early-producer well with a deviated wellbore was drilled through the H1 H2 targ
nks block 783 in the Gulf of Mexico. The wells target multiple zones resulting in complex directional wells with 50�-60� maximum hole-a
nks Block 783 in the Gulf of Mexico. The wells target multiple zones resulting in complex directional wells with 50–60� maximum hole a
viable solutions are available to enhance there production to an economically feasible level. The Hawtah field (see Figure 1) discovered in th
elective completion interventions were successfully implemented in the deepwater Gulf of Mexico Petronius field setting both Gulf of Mexico

and the results have been calibrated with production data. Both maximum allowable drawdown and depletion increase with depth. Additionall
 nd contingency fluid-loss control (FLC) pill formulation to withstand 4 600-psi burst resistance pressure. In maturing deepwater fields such
nd H2 at approximately 2 650 ft true vertical depth (TVD). An appraisal early-producer well was drilled with a deviated wellbore through the
                                                                                      OnePetro
 s block 783 in the Gulf of Mexico. The wells produce primarily from thick fine-grained Pleistocene-age reservoirs. Due to the long lengths o
nks Block 783 in the Gulf of Mexico. The wells produce primarily from thick fine-grained Pleistocene reservoirs. Because of the long lengths
 court. The field discovered in 1986 currently has 9 wells completed and 13 drainage points. Well A-4L is one of the completed intervals on t
                                                                                        equipment
 ative is to gain a better understanding of Sand Control Completion (SCC) systemsOnePetro performance and reliability in a variety of app

eved complete annular packs and zero mechanical skin factors resulting in well productivity indices that are significantly greater than expect

 onment. A Chevron offshore gas reservoir will be developed with high-angle near-horizontal wells with openhole gravel packs completion (O
ed reservoirs in Brazil. Gravel pack placement requirements include the design of pumping pressures inside the operational window formed b
 s in Brazil. Gravel pack placement requirements include the design of pumping pressures inside the operational window formed by the minim
                                                     OnePetro
  Gravel Packing (OHGP).� Though gravel packing is a proven method to stabilize the well bore controlling sand and maximizing productiv
 eved complete annular packs and zero mechanical skin factors resulting in well productivity indices that are significantly greater than expect
                                                     OnePetro
quired sand control. The lower zone was completed with a gravel pack completion and the upper zone was left unperforated. To enable produ
 rilling slanted or sub-horizontal wells through several shale bodies to obtain high gas rate performances during the production and the injecti
ability to deliver high-productivity wells. Currently there are two techniques used for gravel placement one utilizing low-viscosity carrier fluids
one sand control wells. Four field developments are challenging the conventional approach to completing long sand control zones by using ne
  southern region of Argentina. These fields are prolific gas producers and are being developed with a reduced number of wells with departu
  in drilling technology in recent years horizontal wells with lengths ranging from 2 000 to 6 000 ft have become more common. Executing the
e gravel packing is the preferred sand control technique adopted by many operators in this region. It is considered one of the proven method


                                                                                        transport OnePetro
servoirs. Recent experience in extended-reach drilling also indicates that inefficientOnePetro of smaller cuttings is a main factor for excessive
cy remediation on two offshore applications. Results are presented detailing specific placement procedures in-situ treatment design and pro
a cased-hole gravel-pack job depends on the ability to effectively pack perforation tunnels which act as conduits between the reservoir and th
 cased-hole gravel-pack job depends on the ability to effectively pack perforation tunnels which act as conduits between the reservoir and th
ough the S1U S1L and S2U sands at ~9200 ft TVD. After a pre-drill sand prediction the well was cased and perforated without sand contro
e tied back to a floating production facility. Nine horizontal oil producers and four S-shaped gas producers are planned and all will require som

ogress with respect to sand control equipment and implementation. However even properly designed and executed completions are subjec
n in Australasia. This recent technology was simultaneously applied in a production well and a water injection well and served as a demonst

minating the need to have a rig on location. To date six screenless completions have been performed for a major operator in the Gulf of Me
minating the need to have a rig on location. To date six screenless completions have been performed for a major operator in the Gulf of Me
                                                                                 OnePetro
have been proposed in the past including various solutions based on permeable cement but none of them have made a real breakthrough.

he largest onshore steamflood operations in the world. Producing heavy oil (approximately 25�API) from an essentially unconsolidated res
present-day. A large part of these challenges have been caused by reactive shales interbedding the sand bodies. This has had a persistent i
 transported to the surface facilities for different operational scenarios. Sand quantification estimation is still novel in the industry and this pa
ated sandy turbiditic reservoirs. Today in Girassol which includes also Jasmin reservoir 29 wells have been completed and connected to pro
 dients the low net-to-gross ratio the low bottomhole temperatures and the requirement for pressure maintenance. The development of the
ountered during the planning and completion of two wells in the Egret Field in Brunei operated by Brunei Shell Petroleum (BSP) how the ch
 e was drilled through the H1 H2 targets and a completion design consisting of a cased and perforated commingled completion inside 9-5/8-
s with 50�-60� maximum hole-angles. The wells are completed using dry trees from the TLP and are producing primarily from massive
 lls with 50–60� maximum hole angles. The wells are completed using dry trees from the TLP and are produced primarily from massive
h field (see Figure 1) discovered in the late 1980s is located 180 km south of Riyadh the capital of Saudi Arabia (figure 1). Hawtah is one of
  ius field setting both Gulf of Mexico and world records. Success was achieved through careful planning of procedures and specification of e

etion increase with depth. Additionally oriented perforations offer an improvement to perforation stability against sanding: the maximum allow
 In maturing deepwater fields such as Shell Ursa/Princess where depleted reservoir pressures are significantly below the hydrostatic pressu
with a deviated wellbore through the H1/H2 targets and a completion design consisting of a cased perforated and commingled completion i

servoirs. Because of the long lengths of the producing reservoirs and large variations in sand-grain sizes/permeabilities premium screens w
s one of the completed intervals on the S7000E horizon. Production from this interval began in April 1997 and oil recovery averaged 2000 ST


t are significantly greater than expected. The success of the Greater Plutonio OHGP completions has been attributed primarily to the rigorou

penhole gravel packs completion (OHGP) for its first phase development. The ultra high rate for individual well could be up to 320 MMSCFD
side the operational window formed by the minimum pump rate to avoid premature rat hole screen-out and maximum pump rate to avoid form

olling sand and maximizing productivity it entraps the filtercake formed by the reservoir drilling fluid.� This results in low production rate a
t are significantly greater than expected. The success of the Greater Plutonio OHGP completions has been attributed primarily to the rigorou

 during the production and the injection cycles. This challenge has a significant effect in selection of the completion technique in these wells
ne utilizing low-viscosity carrier fluids and low gravel concentration. In this technique the gravel is placed in two waves commonly called Alph
g long sand control zones by using newer technologies. A typical well in the Mahakham Delta has five zones and installing conventional grav
educed number of wells with departures of up to 3.5 km at approximately 1000 m TVD. This paper discusses the issues surrounding the T
 ecome more common. Executing these open-hole gravel-pack jobs (alpha-beta packs) has been a challenge. Although scattered attempts
 onsidered one of the proven methods of sand control from both reliability and productivity standpoints and allows access to larger reserves



ures in-situ treatment design and productivity improvements. Two wells were recently drilled and completed for the Rosa deepwater project
conduits between the reservoir and the wellbore for hydrocarbon production. This project presents a system approach for removal of perfora
 onduits between the reservoir and the wellbore for hydrocarbon production. This project presents a system approach for removal of perfora
d and perforated without sand control but the perforations were oriented in the vertical plane (ie topside and bottomside perfs) to limit sand
rs are planned and all will require some form of sand prevention. Extensive rock mechanical work using Statoil’s finite element modeling

 nd executed completions are subject to mechanical failure with the first indications often being production of solids into a common separatio
ection well and served as a demonstration of its potential benefits in the development of Stag oilfield. Located offshore in the North-West she

or a major operator in the Gulf of Mexico. Each of the six treatments provided significant cost savings as well as excellent return on investm
or a major operator in the Gulf of Mexico. Each of the six treatments provided significant cost savings as well as excellent return on investm


om an essentially unconsolidated reservoir with a depth that ranges from 300 to 700 ft using steam injection at 300 to 400�F poses a uniq
d bodies. This has had a persistent influence on the sandface completion design and in particular on the drilling and completion fluid system
still novel in the industry and this paper describes its application in completion selection and design facilities design and operation and faci
een completed and connected to production facilities and pressure maintenance is coming from 13 water injectors and 2 gas injectors. The c
  intenance. The development of the Albacora Leste Field in the ultra deep water Campos Basin was a key component of Brazil’s drive to
  i Shell Petroleum (BSP) how the challenges were addressed and the best practices identified for future operations. Sand-control technique
 commingled completion inside 9-5/8-in. casing was implemented. The sand-face completion design consisted of a large-OD expandable san
are producing primarily from massive fine-grained Pleistocene-aged reservoirs. These reservoirs require sand-control to prevent sand prod
 re produced primarily from massive fine-grained Pleistocene reservoirs. These reservoirs require sand control to prevent sand production
 i Arabia (figure 1). Hawtah is one of several small fields located along the Hawtah Trend (others are Ghinah Hazmiyah Nisalah and Umm J
   of procedures and specification of equipment. This paper describes the planning for these challenging extended-reach completion and inter

  against sanding: the maximum allowable drawdowns and depletions are increased for all sands. Finally an analysis is presented on the eco
nificantly below the hydrostatic pressure of a seawater column a modified screen design was required since screen products currently availa
orated and commingled completion inside 95/8-in. casing was implemented. The sandface-completion design consisted of a large-outside-d

s/permeabilities premium screens with shunt tubes in conjunction with cased-hole frac packs have been used to complete the wells. The th
 7 and oil recovery averaged 2000 STB/D. Sand production was anticipated under normal drawdown from production onset and as such the


een attributed primarily to the rigorous design and field application of the fluid systems used at all stages of the well from drilling the reservoi

ual well could be up to 320 MMSCFD and the non-Darcy effect is too significant to overlook. The objective of this investigation is to build an a
 nd maximum pump rate to avoid formation fracture. Some special projects require additional equipment to provide selective completion –

 This results in low production rate and consequently leads to the requirement of high drawdown pressure. �Hence it is imperative that the
een attributed primarily to the rigorous design and field application of the fluid systems used at all stages of the well from drilling the reservoi

completion technique in these wells which require an effective and reliable sand control for long term and open-hole and large tubular size t
 in two waves commonly called Alpha/Beta packing. The second method utilizes a viscous carrier fluid and high concentrations of gravel in c
ones and installing conventional gravel pack completions would consume up to 30 rig days. This represents a significant capital cost. To redu
 cusses the issues surrounding the TOTAL AUSTRAL Carina field development project and the innovative processes that were used to add
lenge. Although scattered attempts have been made to separately understand different parts of the gravel-pack process the industry still lac
 and allows access to larger reserves through fewer wells. Since most of these reservoirs contain reactive shale streaks they require synth



 eted for the Rosa deepwater project Block 17 offshore Angola using a Non-Aromatic Oil-Based Mud (NAOBM) weighted with sized calcium
stem approach for removal of perforation damage effective gravel placement and packing of the perforation tunnels. It was found that surgin
tem approach for removal of perforation damage effective gravel placement and packing of the perforation tunnels. It was found that surgin
 e and bottomside perfs) to limit sand production. Perforations were shot at 4 spf and 180� phasing with ~1 000 psi underbalance.�Th
 Statoil’s finite element modeling method suggests that oriented perforations can prevent sand production in the horizontal wells. This wa

on of solids into a common separation facility. In many offshore completions particularly sub-sea or multi-zone completions it is often difficu
cated offshore in the North-West shelf of Australia Stag field is a shallow and unconsolidated glauconitic sandstone reservoir with a top and

s well as excellent return on investment for the operator. Screenless completions are an integrated solution that involve many field-proven te
s well as excellent return on investment for the operator. Screenless completions are an integrated solution that involve many field-proven te


 tion at 300 to 400�F poses a unique challenge in designing an effective yet economic completion. One of the biggest problems associat
he drilling and completion fluid systems. The completion design has evolved from stacked cased hole gravel pack to open hole gravel pack d
cilities design and operation and facilities risk evaluation with reference to a high rate gas field development. The estimation of sand produc
er injectors and 2 gas injectors. The completion strategies employed have included mainly stand alone screens in open hole and cased hole
 ey component of Brazil’s drive to achieve petroleum self sufficiency by 2006. Because of the challenges presented by the heavy oil and
e operations. Sand-control techniques such as an extension packing and hydraulic fracturing were evaluated to help minimize the risk of fine
 sisted of a large-OD expandable sand screen with 150 micron weave across the 2 zones. Upon completion the reservoirs were cleaned up
re sand-control to prevent sand production at the expected drawdowns planned during the life of the wells. To help ensure high rate long life
d control to prevent sand production at the expected drawdowns planned during the life of the wells. To help ensure high-rate long-life comp
 inah Hazmiyah Nisalah and Umm Jurf). The Trend runs approximately 30 km east to west and 50 km north to south. Production in Hawtah
extended-reach completion and intervention operations along with the lessons learned while implementing these case-history jobs. Introduc

y an analysis is presented on the economics and trade-offs of vertically-oriented perforating (with possibly managed sand production) versus
 nce screen products currently available were limited to <3 500 psi. FLC pill formulations also required modification because they were only v
design consisted of a large-outside-diameter (OD) expandable sand screen with a 150-�-weave opening across the two zones. Upon com

n used to complete the wells. The third well A1ST1BP1 was completed using the same techniques as were used successfully on the first tw
m production onset and as such the well was completed with sand-control measures in place. After about ten years of production a significa


s of the well from drilling the reservoir through to the gravel pack itself and subsequent completion. An integrated approach was adopted for

 e of this investigation is to build an accurate model to validate and quantify the non-Darcy mechanical skins for the high-angle OHGP gas w
 to provide selective completion – External casing packers (ECP) installed at different positions along the production screen aim the isolati

re. �Hence it is imperative that the filter cake be removed uniformly to ensure lower drawdown pressure and even flow distribution throug
s of the well from drilling the reservoir through to the gravel pack itself and subsequent completion. An integrated approach was adopted for

 nd open-hole and large tubular size to minimize friction losses. Until now standard open-hole gravel packing was the common completion in
and high concentrations of gravel in conjunction with alternative path screens which mitigate problems caused by unpredicted downhole even
ents a significant capital cost. To reduce costs the Operator has completed 19 wells with Single Trip Multi-zone (STMZ) technology. Two diff
 ive processes that were used to address these situations.�Through careful planning the processes selected to facilitate the completions
vel-pack process the industry still lacks a tool that accurately models the complete process and aids in successfully designing these jobs. Th
 ve shale streaks they require synthetic/oil-based drilling fluids (S/OB). Considering that the openhole gravel packing in the industry deals p



NAOBM) weighted with sized calcium carbonate. After installing the Stand-Alone-Screens (SAS) across the production intervals and allowing
ation tunnels. It was found that surging the perforations greatly increased the ability to pack the perforation tunnels and improved the connec
ation tunnels. It was found that surging the perforations greatly increased the ability to pack the perforation tunnels and improved the connect
with ~1 000 psi underbalance.�The X-1 well produced up to ~150 MMCFD and was taken to depletion without any sand being produced
 uction in the horizontal wells. This was offered as an alternative to mechanical sand control in the long horizontal wells due to traverse sever

 ti-zone completions it is often difficult and expensive to determine which well or specific completion interval has failed most times requiring
 c sandstone reservoir with a top and bottom sealing shale. The reservoir pressure is low and it contains heavy and viscous oil of 19� API

ution that involve many field-proven technologies such as reservoir characterization perforating coiled-tubing intervention matrix acidizing r
ution that involve many field-proven technologies such as reservoir characterization perforating coiled-tubing intervention matrix acidizing r


One of the biggest problems associated with the production of the crude oil in this environment is the production of massive amounts of solids
 ravel pack to open hole gravel pack designs. Non-gravel pack open hole designs are also being considered for the future to meet the challen
ment. The estimation of sand production volumes for openhole and cased and perforated completions is presented for the high rate gas wel
creens in open hole and cased hole frac-packs. A review of the design for both producers and injectors along with the criteria related to the
 nges presented by the heavy oil and the large geographical extension of the reservoir the decision was made to develop the field with horizo
uated to help minimize the risk of fines plugging because of the high fines content (10 to 15%). To minimize well interventions while maximizi
tion the reservoirs were cleaned up through a temporary well clean-up and test facility to test productivity and evaluate integrity of the downh
 ls. To help ensure high rate long life completions the producing zones are frac-packed. The average perforated interval during the initial co
help ensure high-rate long-life completions the producing zones are frac packed. The average perforated interval during the initial completio
north to south. Production in Hawtah comes from the Unayzah sandstone and consists of Arabian super light (50� API) sweet crude oil. H
 ing these case-history jobs. Introduction Chevron and Marathon each have a 50% working interest in the Petronius project which is operat

 ly managed sand production) versus frac-packing. Sand onset prediction agrees fairly well with the observed drawdown/depletion for horizon
 odification because they were only validated to 1 000 psi in the current laboratory test apparatus. A series of burst tests were conducted on
ing across the two zones. Upon completion the reservoirs were cleaned up through a temporary well-cleanup and test-facility to test product

were used successfully on the first two wells. The A1ST1BP1 completion failed during initial unloading allowing unacceptable rates of sand p
ut ten years of production a significant amount of sand was observed during routine sampling of the well. This condition resulted in the closu


ntegrated approach was adopted for the design of the fluid systems involving extensive formation damage and fluid compatibility testing. To t

skins for the high-angle OHGP gas wells and finally to develop a recommendation for the optimized design. A comprehensive semi-analytic
the production screen aim the isolation of certain reservoir zones. In these cases gravel pack placement present an additional constraint â€

ure and even flow distribution throughout the producing interval of the well.� A review of the completion methodology in poorly sorted unc
ntegrated approach was adopted for the design of the fluid systems involving extensive formation damage and fluid compatibility testing. To t

 cking was the common completion in a single sand body however in presence of shales open-hole expandable screens with annular barrier
aused by unpredicted downhole events. In this paper we present a new approach for gravel packing long high angle openhole intervals witho
 lti-zone (STMZ) technology. Two different STMZ techniques have been applied because of differing well characteristics and objectives. To d
selected to facilitate the completions were successful in achieving the project goals of the operator.�These goals included not only the pr
successfully designing these jobs. This paper presents a pseudo-3D modeling tool which models the complete gravel-pack process and acc
gravel packing in the industry deals primarily with water based fluid environments new challenges for gravel packing of the associated wells



the production intervals and allowing the wells to cleanup the Productivity Index (PI) measured on each well was very disappointing. A diagn
on tunnels and improved the connectivity to the reservoir. Guidelines to surging the formation and executing the perforation packing job are
on tunnels and improved the connectivity to the reservoir. Guidelines to surging the formation and executing the perforation packing job are p
on without any sand being produced. A production log showed that all three payzones were open. The well did not produce any water. A mo
 orizontal wells due to traverse several shale and sand bodies of varying quality. Perforation tunnels with optimal “structural stability for th

 rval has failed most times requiring production to be shut in for diagnosis. Not until that point can a remedy be evaluated. One GOM produc
 heavy and viscous oil of 19� API - 9 cP. This causes sand production high water cut wormhole development and requirement for artificia

ubing intervention matrix acidizing resin consolidation optimized fracturing with proppant flowback control and fines migration prevention. T
ubing intervention matrix acidizing resin consolidation optimized fracturing with proppant flowback control and fines migration prevention. T


 duction of massive amounts of solids. In addition to the cost of the recompletions problems associated with disposing of this amount of sand
ered for the future to meet the challenges of drilling and completion at higher well angle. The field requires a mix of all these techniques to me
s presented for the high rate gas wells along with the workflow used for the selection and optimisation of the completion design based on th
along with the criteria related to the sand characteristics and off-shore implementation of the completions will be described. Production str
  made to develop the field with horizontal openhole gravel packs for both producers and injectors. Fifteen production wells and eleven injecto
mize well interventions while maximizing data gathering an intelligent-well completion using surface-controlled sub-surface variable chokes fo
 y and evaluate integrity of the downhole sand-exclusion installation. Fines production possibly due to a failure of the expandable screens co
 erforated interval during the initial completion program was 310 ft with a maximum perforated interval of 571 ft. The typical production casing
 ed interval during the initial completion program was 310 ft with a maximum perforated interval of 571 ft. The typical production-casing strin
  light (50� API) sweet crude oil. Hawtah field is a mature and depleted reservoir and in order to maintain economical levels of production
 he Petronius project which is operated by Chevron. The field is located in the Gulf of Mexico 150 miles south of Mobile Alabama. The proje

erved drawdown/depletion for horizontal perforations. This benchmarking appears to support the validity of the shear-failure model. This is im
 es of burst tests were conducted on a wire-wrap screen design direct wrapped to 4-in. base pipe. The objective was to determine if the scree
eanup and test-facility to test productivity and evaluate the integrity of the downhole sand-exclusion installation. Fines production possibly ca

allowing unacceptable rates of sand production. The well was worked over and the tubing with eight control lines and a premium-sand-contro
 ll. This condition resulted in the closure of the well for high sand production. To restore production from the well current economic realities f


ge and fluid compatibility testing. To translate the robust design into a fluid system which can be applied effectively in the field a thorough fit

sign. A comprehensive semi-analytical model was developed based on modification of the horizontal well model. The additional pressure dro
nt present an additional constraint – operational pump rates should be high enough to avoid alpha wave sedimentation around the packers

 ion methodology in poorly sorted unconsolidated sands with high fines content in Brunei also indicates that the situation is not much different
ge and fluid compatibility testing. To translate the robust design into a fluid system which can be applied effectively in the field a thorough fit

 andable screens with annular barriers and blanks between each section of sand is the only completion option except in fine sand environme
 g high angle openhole intervals without the need for alternative flow path screens but retaining the advantages of high gravel concentration s
 l characteristics and objectives. To date 14 wells have been equipped with Dual Sting - STMZ completions and five wells have the new Sing
 These goals included not only the production of gas at relatively high rates from the shallow unconsolidated sand-stone reservoir at approx
omplete gravel-pack process and accounts for fluid flow and gravel settling in different flow paths. The presented simulator tracks the fluid flo
 avel packing of the associated wells are thus introduced. A significant level of progress has been made in recent years towards overcoming



  well was very disappointing. A diagnosis study concluded that the severe productivity impairment on these wells was related to either screen
uting the perforation packing job are presented. This study also discusses the current practices commonly employed in cased-hole gravel pa
 ting the perforation packing job are presented. This study also discusses the current practices commonly employed in cased-hole gravel pac
well did not produce any water. A more thorough analysis has been made of the onset of sanding in the X-1 well to understand the benefits
h optimal “structural stability for the given inherent material strength of the formation rock can be achieved by targeting perforations in the

 edy be evaluated. One GOM producer engaged the services of a proppant supplier to determine whether a suite of proppants/gravel could
 elopment and requirement for artificial lift increase drainage area and improve sweep efficiency. In the early stage of field development a re

 rol and fines migration prevention. The proper candidate selection treatment design treatment execution production management and co-
 rol and fines migration prevention. The proper candidate selection treatment design treatment execution production management and co-


 with disposing of this amount of sand--and the effect the produced solids have on the facilities such as stabilization of emulsions--are a larg
es a mix of all these techniques to meet well objectives. Introduction The South Tapti gas field is located 160 km north north-west of Mumba
 f the completion design based on these estimates. The optimum completion aims to delay the onset of sand to surface for the first 18 years
ons will be described. Production strategy recommendations to minimize the sand risk during well start-up and ramp-up and also well steady
 n production wells and eleven injector wells were drilled and completed in the field. As a result of the perceived technical complexity of the d
rolled sub-surface variable chokes for internal gas-lift and surface controlled sub-surface fixed chokes was proposed. Another design challe
 failure of the expandable screens commenced almost immediately upon well bean-up and steadily increased to the extent that the well was
 571 ft. The typical production casing string for the wells consists of 10-3/4 in. casing with an 8-1/16 in. production liner. Drift diameter throug
 . The typical production-casing string for the wells consists of 10 3/4-in. casing with an 8 1/16-in. production liner. Drift diameter through the
ntain economical levels of production a combination of several technologies is being applied. Due to the poor natural production from the ver
 south of Mobile Alabama. The project was sanctioned in August of 1996 after both compliant-tower and subsea-development options were

of the shear-failure model. This is important because the model while fairly simple has many different inputs including depth profiles for un
bjective was to determine if the screen could withstand at least 4 600 psi without damage. The wire-wrap design selected to improve the pre
llation. Fines production possibly caused by a failure of the expandable screens steadily increased to the extent that the well was deemed u

 trol lines and a premium-sand-control screen with shunt tubes were retrieved/fished from the well with minimal problems. The retrieved scre
  the well current economic realities favored through tubing intervention. Two major types of through tubing remedial sand control solutions w


effectively in the field a thorough fit for purpose QA/QC system for all drilling and completion fluids was developed requiring extensive fluid

ell model. The additional pressure drop is added to consider the mechanical skin and non-Darcy flow in the near-wellbore zones of drilling da
ve sedimentation around the packers to assure sealing after the packer inflation process. Traditionally design criteria consider a minimum cr

hat the situation is not much different from above demanding to lower production drawdowns while delivering production quotas.� The low
effectively in the field a thorough fit for purpose QA/QC system for all drilling and completion fluids was developed requiring extensive fluid

option except in fine sand environment. In this paper we present experimental data of shale stabilizer treated-brine and three open-hole gra
ntages of high gravel concentration slurries. This is supported by 2 field case histories from a field in India where two gas wells were drilled
ons and five wells have the new Single String-STMZ technology. These 19 wells embody 77 frac packs / gravel packs. The average comple
 ated sand-stone reservoir at approximately 1000 m TVD but also minimization of impact to the environment. To minimize cost and still acc
 resented simulator tracks the fluid flow and gravel concentration from the wellhead down through the workstring crossover ports open-hole
  in recent years towards overcoming the challenges through new developments in fluids application tools and techniques. These developm



ese wells was related to either screen plugging by mud particles while running the screens to bottom in the NAOBM and/or the plugging induc
 ly employed in cased-hole gravel packing to pack perforation tunnels and the potential limitations of these practices. Incomplete packing of
 y employed in cased-hole gravel packing to pack perforation tunnels and the potential limitations of these practices. Incomplete packing of p
  X-1 well to understand the benefits of oriented perforations and to benchmark the sand prediction against field observation. The method e
 ieved by targeting perforations in the most stable direction with respect to the in-situ stress field. For high angle wells this normally equates t

er a suite of proppants/gravel could be developed that could be uniquely identified and placed in each completion interval. In the event of pro
early stage of field development a reservoir failure was observed. A documented investigation indicated that the failure mode appeared to be

on production management and co-ordination of all services are essential to the success of the screenless completion. In this paper the co
on production management and co-ordination of all services are essential to the success of the screenless completion. In this paper the co


stabilization of emulsions--are a large cost to operations. A program was initiated in 2002 to evaluate the effectiveness of the completions in
d 160 km north north-west of Mumbai in the Arabian Sea off the west coast of India. The field is operated by a joint venture between BG Exp
sand to surface for the first 18 years of production whilst maintaining high gas productivity (>300mmscf/d/well). The selection of contingency
up and ramp-up and also well steady-state production will be given. This paper will provide an overview of the behavior of both sand control
erceived technical complexity of the development and requirement to maximize completion efficiency the operator chose to maximize the in
was proposed. Another design challenge was that conventional wire-wrapped screens would have insufficent clearance to accommodate inte
 eased to the extent that the well was deemed unproducible to the facilities.� The failure of the first well caused a re-evaluation of the sand
 production liner. Drift diameter through the tapered production casing is 9-1/2 in. and 6-1/2 in. respectively. The 6-1/2 in. drift diameter allows
ction liner. Drift diameter through the tapered production casing is 9 1/2 and 6 1/2 in. respectively. The 6 1/2-in. drift diameter allows using co
  poor natural production from the vertical cased and perforated completions in Hawtah and little associated gas electrical submersible pump
d subsea-development options were evaluated. The compliant-tower alternative was selected because of its greater well-intervention capabil

 nputs including depth profiles for unconfined compressive strength (UCS) and in-situ stresses which involve sophisticated prediction techni
 p design selected to improve the pressure rating was substantially heavier than what has been used in traditional sand-control completions.
 he extent that the well was deemed unproducible to the facilities. A re-evaluation of the sand-exclusion method that included more extensiv

minimal problems. The retrieved screens had collapsed around the perforated base pipe. The well was reperforated new screens run and a
ing remedial sand control solutions were considered namely mechanical and screen-less (chemical consolidation) methods. A proprietary HD


  developed requiring extensive fluids testing and reporting at the well site. The paper describes in detail the reservoir completion philosophy

 he near-wellbore zones of drilling damage mud-cake gravel packs and the sand screen. This investigation indicates that the non-Darcy eff
 esign criteria consider a minimum critical velocity to avoid sand deposition. The specification of minimum flow for cleaning the ECP and pre

 ering production quotas.� The lower drawdown extends the integrity of sand control completion jewelry reduces water influx fines migrat
 developed requiring extensive fluids testing and reporting at the well site. The paper describes in detail the reservoir completion philosophy

reated-brine and three open-hole gravel packing case histories from one UGS field in Italy. In the three case studies the wells were gravel pa
 ia where two gas wells were drilled with an oil-based drill-in fluid and gravel packed with a viscous water-based fluid. The packing mechanis
  gravel packs. The average completion time has been 11.3 rig days/well for DS-STMZ wells. SS-STMZ completions have averaged of 22.2
ment. To minimize cost and still accomplish the project goals the wells were drilled from a single platform. Introduction Project Challeng
orkstring crossover ports open-hole and screen-washpipe annuli and then back to the surface through the washpipe and casing-workstring
 ols and techniques. These developments have resulted in successful gravel packing of wells drilled with oil-based (OB) fluids which have y



he NAOBM and/or the plugging induced by a mixture of formation sand mud and filter cake when draw-down was applied during cleanups.
se practices. Incomplete packing of perforation tunnels is mostly encountered in gravel-pack jobs completed with brine as the carrier fluid (w
 e practices. Incomplete packing of perforation tunnels is mostly encountered in gravel-pack jobs completed with brine as the carrier fluid (w
ainst field observation. The method estimated sand strength from logs in the X-1 well. A correlation between log-predicted UCS and lab-me
h angle wells this normally equates to shooting in the vertical plane through the well path. Over a decade of production experience with this t

ompletion interval. In the event of proppant production to surface (mechanical failure) the surface samples would be analyzed to directly det
 that the failure mode appeared to be wormhole-like failure2. To date there have been several failures with similar characteristics occurred in

 ess completion. In this paper the common sequence of events for a screenless completion is presented as well as the key technologies inv
 ess completion. In this paper the common sequence of events for a screenless completion is presented as well as the key technologies inv


 e effectiveness of the completions in the Duri field. This effort involved evaluated field data such as the frequency and type of workovers th
 d by a joint venture between BG Exploration & Production India Limited (BGEPIL) ONGC and Reliance Industries Limited (RIL). In 2002 BG
 /d/well). The selection of contingency sandface completions is also discussed along with mitigation measures in the event of unexpected san
of the behavior of both sand control techniques after 5 years of production and injection. An in depth analysis of the different productivity/inje
he operator chose to maximize the integration of the services by bund
 icent clearance to accommodate intelligent-well completions. A feasibilit
ell caused a re-evaluation of the sand exclusion method employed which inclu
ely. The 6-1/2 in. drift diameter allows using common size screen
6 1/2-in. drift diameter allows using common-sized screens and p
 ted gas electrical submersible pumps (ESPs) have been used in Hawtah to enhan
of its greater well-intervention capability less-complex seawater-injection-system desi

nvolve sophisticated prediction techniques themselves. Continuous sand rate
 raditional sand-control completions. Initial burst tests with availab
n method that included more extensive core analysis and the types of wells

eperforated new screens run and a second frac pack pumped. When laying down
solidation) methods. A proprietary HDR squeeze pack technique (mechanical method)


il the reservoir completion philosophy drilling and c

ation indicates that the non-Darcy effect could significantly affect the product
m flow for cleaning the ECP and prevent the deposition of sand in the annular

ry reduces water influx fines migration and increases recovery factors
il the reservoir completion philosophy drilling and c

case studies the wells were gravel packed using shale stabilizer
 r-based fluid. The packing mechanisms and efficienci
  completions have averaged of 22.2 rig days/well inclusive of NPT and the upper completi
 orm. Introduction Project Challenges.�The Carina field contains a cons
 the washpipe and casing-workstring annulus. In the open-hole section flow th
h oil-based (OB) fluids which have yielded well productivi



-down was applied during cleanups. Based on collaborative laboratory work between the
leted with brine as the carrier fluid (water packs). The proposed
eted with brine as the carrier fluid (water packs). The proposed t
ween log-predicted UCS and lab-measured thick-walled cylinder strength (T
e of production experience with this technique on the

 les would be analyzed to directly determine which interval had fai
with similar characteristics occurred in Stag field. Water i

 d as well as the key technologies involved from perforating to p
 d as well as the key technologies involved from perforating to p


 frequency and type of workovers the amount and size of produc
 Industries Limited (RIL). In 2002 BGEPIL acquired the interests of Enron
 sures in the event of unexpected sand production. The impact
nalysis of the different productivity/injectivity characteristics suc

				
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