bluuebunny/crossref_metadata_2025_split huggingface dataset:
Multilateral Technology as a Creative Reservoir Development Strategy for New and Mature Fields Alike
Authors: Oberkircher Jim 
Published: December 2007

Abstract
Mature fields and new developments. Very different operating arenas but a common objective: produce hydrocarbons as quickly and efficiently as possible. The challenges for today's operators are many: complex geologic conditions such as compartmentalized or stacked reservoirsdifficult reservoir conditions such as viscous fluids or tight formationshostile environments, whether deep water or frontier development areasefficient and effective management of the reservoir development process.
It is important now more than ever to look for new and innovative solutions to the problems and challenges facing us in all of these areas. Multilateral technology provides just such a solution.
Multilateral technology has been successfully applied in all of these areas and has had a dramatic, step-change impact in the financial results of many. The ability to deliver an optimal reservoir development plan has been demonstrated time and again; and, in the process, new ideas in terms of equipment and reservoir development strategies have emerged. The adage of "if you can draw it we can drill it" is now more of a reality than it has ever been before. These new abilities allow for creativity to be released and for improved results to be achieved. However, in order to achieve these results, it is important to break loose of the old, self-imposed limits that have been placed on us and free ourselves from the bonds of technical restrictions. Knowledge is the key that can unlock those chains.
Successful multilateral developments will be examined from around the world including the current multilateral hot spots of the South America, and the Deep Water of the North Sea. The impact of these advances on future field developments, both mature and new, will be examined in terms of operational accomplishments and economic success. This paper will also explore the potential of new, synergistic technologies and work processes and their impact on future field development strategies.
Designing an Injection Program of Produced Water Re-Injection in Mature Fields
Authors: Rudi Rubiandini Ria S. , Fitnawan Eko A. , Singh Kalwant 
Published: December 2007

Abstract
Production of oil & gas has very big influence to mankind civilization but the excessive generation of produced water in mature fields as a by-product may have bad impact to environment. Pollution of surface water supplies or fresh water aquifers has become a serious concern in recent years. It is therefore an obligation upon the industry to handle the produced water and disposed it responsibly. This concern has focused attention on produced water re-injection into underground formation (whether it is virgin or depleted reservoir) as a promising method to discharge oilfield water without polluting potable water supplies.
As refer to regulatory guidelines, injection well for produced water disposal must be operated so that the pressure during injection does not initiate new fractures or propagate existing fractures in the confining zone adjacent to the sources of drinking water, which could damage the receiving layer or cap rock. In order to achieve that purpose, the paper describes evaluations and planning on operational aspects regarding daily activity/practical operation, which are essential to the successful of water injection project. Operational aspect especially includes working pressure along the injection system, estimated formation fluid pressure as function of cumulative injected water, estimated fracture pressure and its relation to proposed injection rate. Operational window for injection must be developed to determine the range of allowable injection pressure and its relationship with the proposed injection rate.
The paper also describe a method to determine the life time of each proposed injection well which is the compilation from the result of operational design analysis and reservoir pressure builds up data from simulation results. This study is very useful to make injection programs and scenarios to extent the injection lifetime (e.g. scenario to add new injector wells).
Combined Perforation and Sand-Control Technique
Authors: Zhao Zhengchao , Sun Houli , Zhao Ping , Liu Xiangming , Zhang Jianjun , Qin Yanhong 
Published: December 2007

Abstract
Combined perforation and sand-control technique is a new technique combining the perforation and sand control which are performed in one operation. This technique will simplify the performance, save the operating cost, reduce the formation damage and improve the well productivity. With this technique, there is no residue in the wellbore, thus providing favorable conditions for later treatments to the oil wells. It was developed by Drilling and Oil Production Technology Research Institute of Liaohe Oilfield Company, PetroChina in 1996. In-door research, physical simulation, the testing of various physical parameters, the development and design of complex perforation charges and guns, more than 1000 single target experiments and 7 times of full gun experiments were performed during the developing period. All technical specifications meet the requirements of the design. Field tests have been preformed since October 1999. By the end of January 2002, 24 well/times tests have been carried out and good results were achieved. The tests show that it is a very effective sand-control method in oil wells.
Integral Sintered Metal-Fiber Screen Sand Control Technique
Authors: Dezhu Liu , Houli Sun , Xiangming Liu , Jianjun Zhang , Ping Zhao , Shaojin Cheng 
Published: December 2007

Abstract
The integral sintered metal-fiber screen (hereinafter called ISS screen) sand control technique overcame the weakness of long-term and difficult operation, high cost and difficult workover caused by gravel packing mechanical sand control, as well as the formation damage and short term of validity caused by chemical sand control. With its special technical advantages, this technology is developed rapidly and its application is continuously expanding. It has become a dominant sand control technique developed for solving sand producing problem during heavy oil thermal recovery in Liaohe Oilfield, which can be applied in the vertical wells, deviated wells, sidetrack wells, open-hole wells and horizontal wells. This technology has realized its standardization and systematization, resulting in a very good application effectiveness and benefits and also contributing a lot to increasing oil production for Liaohe Oilfield. This technology has been awarded the Chinese national patent and the first prize from CNPC for technological popularization.
The Effect of Key Cement Additives on the Mechanical Properties of Normal Density Oil and Gas Well Cement Systems
Authors: Heinold Thomas , Dillenbeck Robert L. , Rogers Murray J. 
Published: December 2007

Abstract
Recent advances in oil and gas cementing technology allow for the modeling and prediction of both compressive and tensile stresses upon an annular cement sheath, throughout the life of a well. Given the knowledge of the type and magnitude of stresses likely to be encountered in a specific location in a wells annulus gives designers target parameters for designing the mechanical properties necessary in the set cement to be able to sustain those stresses without failing. Such a mechanical failure in a cement sheath can cause a loss of annular isolation. However, the authors feel the ability to model these stresses is only one-half of the information necessary to design cement systems for long-term zonal isolation. While some good work has been done on certain lower density cement systems in an attempt to develop fit-for-purpose designs with improved tensile and flexural strengths, the authors have found that some wells requiring higher density cement systems, also need cements with "enhanced" mechanical properties. Towards this end, the authors have conducted mechanical properties research of several relatively common cement additives. These included organic materials as well as non-organic materials. For this study, these materials were added to oilfield cements with water contents averaging from 50 to 66 % by weight of cement (bwoc). Besides the more common unconfined compressive strength tests, the samples are also subjected to tensile and/or flexural strength testing. While the API has long ago established procedures for running unconfined compressive strength tests, there are currently no API standards in place covering the testing methodology for tensile and/or flexural strengths of oilfield cements. Accordingly, the authors present not only the mechanical properties achieved with the use of the various materials tested, but also the methodology used to achieve their data. In an effort to more closely scrutinize the effect each individual material has on the mechanical properties of the set cement, each additive is examined independently. Armed with this information, design engineers should be equipped to propose cement systems that produce effective long-term zonal isolation at the induced annular stresses of their own wells.
The Influence of Multi-Pore Volume Water Flooding on Pore Structure and Recovery of Lacustrine Deposit Mixed Wettability Cores
Authors: Wang Demin , Guo Muchang , Wang Gang 
Published: December 2007

Abstract
Daqing Oil Field is a reservoir with lacustrine deposit pay zones of mixed wettability (slightly more oil wet). On the average, after flooding cores with 2 ~ 2.5 PV (pore volumes) of water, the water cut practically reaches 100% and the average recovery is about 40% OOIP (original oil in place). However, results from pressure coring in the field show that sometimes the recovery of high permeability streaks of the pay zone can reach 80% ~ 90% OOIP, much higher than that obtained in the lab.
Since Daqing is a very heterogeneous reservoir, the pore volumes of water that pass through high permeability streaks of the formation is much higher than the average. In order to see the increase in recovery and decrease in residual oil saturation of cores after water flooding by multi-pore volumes to check if the end point of the relative permeability curves that are drawn is the real residual oil saturation, multi pore volumes (some more than 30 thousand PV) water flooding on natural cores was performed in the lab. The results show that for mixed wettability (slightly more oil wet) cores of Daqing Oil Field's pay zones, when using multi PV of water to flood the cores, and when the effluent water cut is very high (practically 100%), oil can still slowly flow in the oil film on the pore rock surface and accumulate to form mobile oil (many cores can obtain a final recovery of more than 90% OOIP, some as high as 99%), which means that the oil has not reached "real residual oil" saturation, it is only because the oil cut of the effluent fluid of the core is extremely low, therefore it is difficult to observe the oil in the produced fluid. This paper shows many relational curves of recovery versus multi PV of water injected; it also shows the changes in pore structure of the cores. These changes are similar to those seen in pressure coring in the field. The reasons why such high recovery can be obtained and the large difference in recovery of different cores is explained.
New Insight Into Eromanga Basin Oil Saturations
Authors: Adams S. J. 
Published: December 2007

Abstract
The Eromanga Basin is an established Australian producing region with oil and gas found in several different Formations. At the request of an Operator, a project was undertaken to construct saturation-height functions for all the Eromanga reservoir units with a secondary objective being to define residual hydrocarbon saturations.
Initial investigations revealed many reservoirs with residual hydrocarbon columns, the significance of which had not been well understood. The residual hydrocarbons implied that imbibition, rather than drainage, capillary pressure curves were representative of water saturations in the reservoir. This insight suggested higher oil-in-place and reserves volumes than previously assumed since mobile hydrocarbons are present very close to the pressure derived Free-Water Level in imbibition systems.
When individual hydrocarbon Fields were considered, there were insufficient special core analyses to derive meaningful residual hydrocarbon or saturation-height relationships. However, on the basin scale, a significant volume of measurements had been acquired over a period of 22 years, albeit using different laboratories and a variety of measurement techniques. With knowledge of the measurement techniques and Formations sampled, the data were combined in such a way that consistent datasets were obtained for endpoint relative permeabilities and drainage and imbibition capillary pressure curves.
Interpretation of these datasets produced residual oil saturation and drainage and imbibition saturation height relationships. These relations were tested against those log-derived water saturations considered most reliable by the Operator, showing excellent matches. The model developed successfully described the water saturation distributions in the reservoirs tested in a manner not previously possible. Indeed, the use of the drainage and imbibition saturation-height functions together with residual hydrocarbon relationships provides a powerful tool to determine both static and dynamic fluid contacts, while checking the validity of wireline log-based water saturations.
The Future of Three Phase Separator Control
Authors: Charlton J. S. , Lees R. P. 
Published: December 2007

Abstract
In response to the expressed needs of Oil Producers, a novel instrument has been developed for measuring and controlling the performance of production separators. The instrument, known as a Density Profiler, provides the operator with realtime information about the vertical distributions of the various materials inside the separator: sand, water, emulsion, oil, foam and gas. This allows the operator to exercise fine control over the operation of the separator in a way never before possible. For example, the results of adding antifoam or demulsifying agents can be visualized immediately in the control room so that the effectiveness of these procedures can be monitored and appropriate action taken.
Over twenty profilers have been installed to date at locations around the world. They are highly reliable: the measurement probes have no moving parts and have no contact with the process fluids, thus minimizing the possibility of mechanical breakdown.
This paper describes the instrument and focuses on its unique mode of operation. Case studies are used to illustrate the substantial economic benefits that are realized from Optimization of the separation processElimination of unscheduled shutdownsOptimized levels of chemical additives leading to reduced costs.Elimination of oil spillsElimination of damage to downstream equipment.
Estimating Pseudopressure Function without Relative Permeability [kr(Sw)] for Two and Three Phase Gas Condensate Systems
Authors: Jokhio S. A. , Tiab D. , Baladi S. , Tunio A. H. 
Published: December 2007

Abstract
This paper introduces a new method of estimating pseudopressure function for gas condensate wells producing under two and three phase conditions. The proposed method utilizes pressure transient test data to get effective permeability as a function of pressure and then uses the definitions of two-phase and three-phase pseudopessure function and combines them to get the final pseudopressure for a given pressure value. Relative permeability as function of saturation can also be used, if available. The method is analogous to the pseudopressure of Ramey and Hussainy12 and Fevang and Whitson5. The proposed pseudopressure will help to estimate well liquid as well as gas IPR, well test analysis, well deliverability, and reserve estimation for gas condensate reservoirs. Finally a wide range of pseudopressure equations for Region-1, Region-2, and Region-3 for two-phase and three-phase gas condensate reservoirs, have been developed. Also, few examples are solved to show the use of the pseudopressure in estimating well performance.
Enhanced Gravel-Pack Completions Revitalize a Mature Sand-Producing Field — A Case Study
Authors: B. Md Noor Mohamed Zaini , Selamat Kasim B. , Salahudin Sharifudin , Kasim Abdullah b 
Published: December 2007

Abstract
The Dulang oilfield is located some 130 km offshore Terengganu in Peninsular Malaysia. The field is structurally complex. Production from the field began in March 1991, and oil production averaged 26 thousand STB/D. Production peaked at approximately 50 thousand STB/D.
As with other field developments in the Malay Basin, all the wells in Dulang field were completed without any sand control measures as sand production under normal drawdown or producing conditions was not expected. However, in the later stages of the field's life, a significant amount of sand production was observed. This condition gradually increased over time, resulting in reduced hydrocarbon production, additional costs for routine wellbore sand clean-outs, and platform shutdowns for surface vessel sand clean up.
To revitalize the field, a wellbore opportunity study was initiated in 1999. The objectives of the study were to 1) identify remaining reserves, and 2) identify new completion options to maximize recovery. The study identified three major scenarios that would improve oil production: Develop by-passed reserves behind casingReactivate idle wells that had been closed in as a result of sand production.Provide drainage points for undeveloped reserves.
From the proposed wellbore opportunities study, ten wells were identified for a workover campaign, and six wells were identified for infill drilling or sidetracks.
Sand control mitigation using a gravel-pack technique was identified as a requirement in the completion plan for the majority of the targeted reservoirs. However, the increase that would result in mechanical skin from sand control installation was also recognized. Hence, it was determined that the best approach for production optimization in these wells would be a combination of a sand control and a stimulation technique. Several technologies, which included frac and pack, extension pack with conductivity enhancer, and high-rate water pack (HRWP) gravel packing were identified. The use of a special completion tool was also identified to enable greater flexibility on short string selective production in multi-zone gravel-packed wells.
The combination of sand control and stimulation techniques (frac pack, extension pack and high-rate water pack) has successfully increased the productivity and prevented sand production in the Dulang wells.
Investigation for Mature Minas Waterflood Optimization
Authors: Hendih Agus Rahardja , Rinaldi Imran , Williams Lawrence Lee 
Published: December 2007

Abstract
With a recovery factor of ~51% and watercut in excess of 97%, the Minas Field in Sumatra Indonesia can certainly be categorized as mature field. Recently, the field has experienced a steep production decline, along with increased operating costs. As a result, a waterflood optimization study was initiated. This paper discusses the reservoir simulation to optimize the waterflood operations. The simulation, a sector model for sections 8C, 8D, and 8E, was used to test various prediction schemes such as pattern realignment and infill drilling. A seven well infill program is in progress to test for unswept oil.
Possible Utilisation of CO2 on Natuna's Gas Field Using Dry Reforming of Methane to Syngas (CO & H2)
Authors: Hanif A. , Suhartanto T. , Green M L H 
Published: December 2007

Abstract
One of the major natural gas reserve in Indonesia is found in the Natuna "D-Alpha" gas field. This is not only a large gas deposit (222 TCF) but is also interesting because it is composed predominantly of CO2 (71%). The last development scheme proposed by the oil companies Exxon and Pertamina for the utilisation of this gas, before the crisis of 1997, was for the CH4 to be sold as LNG, while the CO2 was to be injected back below the ocean floor. However, the marketing of natural gas depends on long-term and high-risk contracts or requires strong commitment between the producer and the buyer, even long before the development stage.
An alternative marketing strategy would be to convert the natural gas mixture to syngas (CO + H2) by the partial oxidation and dry reforming of methane with carbon dioxide or steam reforming and CO2 reforming; the syngas can then be used for the production of a wide variety of chemicals and fuels using gas-to-liquids (GTL) technology, e.g. Sasol or Shell's SMDS.
This has three major advantages compared with the LNG route: i) less separation stages will be needed and the cost of gas injection below the sea floor will be lower, since there will be much less CO2 remaining after the reforming process; ii) dry reforming is an effective way of incorporating CO2 in the products, which will eventually end up, for example, as fuel powering an engine; and iii) the price of the end products are much higher and easier to market as compared with LNG. In this study, it will be shown that molybdenum and tungsten carbide catalysts are active and stable for the process of partial oxidation and methane dry reforming to syngas using a feedstock of high CO2 content natural gas, such as that found in the Natuna ‘D Alpha’ field, Indonesia.
Transforming Conventional Wells in Mature Basins to Modern Bigbore Producers by Applying Solid Expandable Tubulars (SET)
Authors: Nor Norlizah Mohd , Huang Edmund , Hon-Voon Chin 
Published: December 2007

AbstractConventional gas development wells in prolific carbonate reservoirs before bigbore completions were introduced do not produce to full potential due to tubing constraints. This phenomenon is observed today in several mature, carbonate basins offshore Malaysia developed back in the early 1980s. At that time, the typical tubing configuration was a 7" completion string run in 9 5/8" production casing. This configuration limits subsequent tubing change out workover options to 7 5/8" tubulars resulting in only a modest 10% gain in well capacity through improved outflow performance.The advent of solid expandable tubular (SET) technology in the new millennium has opened up a revolutionary possibility for transforming a conventional well with 7" tubing to a modern bigbore producer. The concept involves installing and expanding a long section of 7 5/8" solid expandable tubulars inside 9 5/8" casing and using the SET as a gas flow conduit. For a mature gas field offshore Sarawak where this concept was applied in a pilot well, such a well transformation yielded a production conduit with an internal diameter 24% larger than conventional 7" tubulars, a 61% increase in flow area, and a significant increase in well production.Results of this field trial carried out to test this novel re-completion concept in a gas field offshore Sarawak showed a 40-50% increase in well deliverability. The technical concept was proven successful, and it is now planned to implement this novel SET re-completion design in other tubing constrained gas wells in the area.This paper will present the results and economic benefits of this field trial, which is the first of its kind in the world. Details encompassing the conceptual solid expandable completion design, modifications and improvisation required for this first-of-its-kind SET gas well workover, and the required SET installation sequence will also be discussed.