bluuebunny/crossref_metadata_2025_split huggingface dataset:
Belanak Development: Batch Drilling Operations in Natuna Sea
Authors: Septiantoro A. , Bujnoch J. , Welbourn E. 
Published: December 2007

Abstract
In October 2003, development drilling of the ConocoPhillips Indonesia Inc. Ltd operated Belanak Field commenced when the platform rig was rigged up over a previously installed twenty-four slot platform. Drilling commenced with the objective of drilling and completing ten slant directional wells and six horizontal wells.
The objective of the Field development was to have high production rates available when the FPSO facilities arrived approximately twelve months later. Since the wells had to be pre-drilled before first production, it made sense to utilize a full batch drilling concept in order to minimize costs.
The 13-3/8" surface casing strings were successfully batch set on all sixteen wells. This section was completed fifteen days ahead of budget time and set several world record penetration rates for a 16" tricone bits.
The 9-7/8" hole/7-5/8" casing sections were batch set in ten wells. Most well objectives were met and the performance was exceptional in some wells, but, this section was plagued by surface and downhole equipment failures.
The 12-1/4" hole/9-5/8" casing sections were batch set in six wells. All well objectives were met including landing all wells in the reservoir at 90°. Time to complete this section was longer than expected due to inconsistent BHA response.
The 8-1/2" horizontal hole sections were then drilled and completed with a 3,500 ft average hole length for the same six wells.
This paper will focus on the drilling operations and discuss the performance and problems encountered. The Belanak drilling team was committed to continuous improvement by capturing data and immediately implementing the learning's. This commitment to maximize the learning curve resulted in minimizing cost and a successful intensive batch drilling operation.
What is the Source of Drilling and Completion Data?
Authors: Nakagawa E. , Damski C. , Miura K. 
Published: December 2007

Abstract
The industry commonly accepts that information from actual drilling, completion, and workover operations should play an important role in the analysis of performance, comparison against plans, optimization of future operations, and operational safety. It also expects that considerable operational savings would come from the effective use of such information.
In many cases, however, companies cannot experience these gains, even when using sophisticated reporting systems and software tools, basically, because of inappropriate information management processes. For example, sometimes, companies do not store planning information in their databases and, thus, cannot compare planned vs. actual; in other cases, even when planning information is kept, it is difficult to match them with actual operations; most commonly, the operations are not identified or coded properly, making it impractical for the user to perform any reasonable analysis.
This paper describes a new methodology and its practical implementation, which allows for the realization of all the benefits that reliable data can bring in. The basis of the process is the report on planning concept, which changes the current reporting paradigm used by the industry. In this process, the source of operational information shifts from the rig-site to the planning office. In addition, the process requires a detailed design of the operational sequences, levels of granularity, and operational code standards.
3D Post-Stack Acoustic Impedance Inversion Results for Kijing and Malong Fields, South Natuna Sea
Authors: Badachhape A. R. , Abdurahman A. R. 
Published: December 2007

Abstract
Post-stack acoustic impedance inversion was performed at Kijing, Malong, and Buntal fields. The results allow detailed reservoir characterization of the fields to be done, and predict the location of porous, reservoir-quality sands, and in many cases, reservoir-quality sands that contain gas. Several aspects of the inversion results prove to be useful that cannot be achieved through the use of seismic analysis alone. The removal of wavelet effects (tuning, extra events due to constructive wavelet sidelobe interference, and dimming due to destructive wavelet sidelobe interference) is one important enhancement. Seeing the impedances as layer properties instead of as interfaces allows information about the sands and shales to be observed. Increase in bandwidth, both on the low end with the introduction of a good low frequency model from the interpolation/extrapolation of well log impedance along interpreted horizons and the use of geologic constraints, and on the high end due to the use of a spectral whitening deconvolution operator and proper inversion parameters produces increased resolution.
The inversion results at Kijing, Malong, and Buntal fields may be used to discern details about the reservoir sands, especially in conjunction with the current geologic and geophysical information from conventional seismic data, well logs, analogs, etc. 3D visualization of the reservoir shows the structure of the sands, most of which are channelized.
Effect of Temperature on Relative Permeability for Heavy-Oil Diatomite Reservoirs
Authors: Schembre J. M. , Tang G.-Q. , Kovscek A. R. 
Published: December 2007

Abstract
Thermal recovery is the most utilized enhanced oil recovery method. The modeling of thermal recovery processes not only requires relative permeability functions, but also information about the effects of temperature on these functions. There are significant challenges encountered when estimating relative permeability from laboratory data, such as accuracy of measurements and generalizing assumptions in the interpretation techniques. A novel method is used here to estimate relative permeability and capillary pressure from in-situ aqueous phase saturation profiles obtained utilizing computerized tomography (CT) scanning during imbibition experiments. Relative permeability and capillary pressure functions are interpreted simultaneously including nonequilibrium effects. Moreover, the use of B-spline coefficients allows the estimation of arbitrary shaped functions. Results obtained show a shift toward increased water-wettability with increasing temperature for diatomite reservoir core. The measured changes in relative permeability are linked to the effect of temperature on surface forces and ultimately to rock-fluid interactions.
Introduction of New PDC Cutter Technology Increases Drilling Efficiency in Central US Wells
Authors: Yoosuf S. , Dunbar B. 
Published: December 2007

Abstract
In the Central US, recent application of new PDC cutter technology throughout the drilling of more than 40 wells has produced an impressive step change in drilling efficiency. The step change is clearly demonstrated by real time cost savings and a significant reduction in drilling times.
To date, more than 240,000 oil and 59,000 gas wells have been drilled in the Central US in the State of Oklahoma alone. In an attempt to improve drilling economics and reduce operational risks in the region, operators and bit manufacturers have been working as a team to develop PDC drill bits that can drill faster and deeper into harder, complex geological formations with high compressive strengths and abrasive properties. In addition, the longer runs achievable by fixed cutter PDC bits reduce the risks involved in running roller cone designs and the likelihood of problems during trips in and out of the hole. With this goal in mind, many different bit types with developmental PDC cutters recently have been run in the Central US region.
Drilling performance showed significant improvement when a drill bit design modification was introduced that replaced existing cutters with a newly developed PDC cutter designated Z3™. Introduction of the new cutter, the only bit design parameter that was changed, resulted in consistent performance improvements in penetration rate and footage drilled in applications throughout the region. For example, in South Central Oklahoma, a PDC bit design with the new cutters improved penetration rates to as high as 175ft/hr, where existing PDC bit designs averaged 90-100 ft/hr. In Western Oklahoma, a bit with the new cutters drilled more than 800 feet deeper than offsets, the first bit in the area to drill the entire section to TD. In the Texas Panhandle, the bit designs consistently improved footage performance in the hard formation applications.
This paper describes a new cutter technology which offers significantly greater abrasion resistance as well as resistance to thermal mechanical failure than have previous cutters. This paper also discusses various cases studies from the US Central area that show the performance improvements resulting from use of the new cutters. An economic analysis demonstrates the cost savings realized.
Cutting-Edge Materials Technology Elevates Drilling Performance in Soft-Formation Applications
Authors: Caraway D. , Card K. , Pullen S. 
Published: December 2007

Abstract
Drill bits manufactured using the powder forge (PF) process rather than conventional welded hard metal are setting new standards for soft formation drilling. The PF process provides unique advantages in hardmetal placement and metallurgical design thus allowing cutting structures capable of drilling a variety of formations from IADC 11 to 41 and fixed cutter type applications with superior performance. This paper will:
Explain the PF manufacturing process, highlighting lessons learned in the development learning curve. Review the benefits of producing bits using this process. Examine actual field results showing the cost savings available through application of cutting edge technologies. Discuss the improved wear characteristics of PF bits that has led to changes in operational variables such as weight on bit, rpm, hydraulic horsepower and monitoring drilling progress based on changes in rate of penetration.
Integrated Management of Water, Lean Gas, and Air Injection: The Successful Ingredients to EOR Projects on the Mature Handil Field
Authors: Duiveman M. W. , Herwin H. , Grivot P. 
Published: December 2007

Abstract
The future of large very mature oilfields relies upon the successful application of EOR techniques. This paper discusses from the Handil field case, the more useful concept and practices that are applicable to optimize oil recovery in a multi-layer, multi reservoir waterflooded field.
The Handil field, discovered in 1974, is a giant mature oilfield located in the Mahakam Delta, Indonesia. The field was developed using conventional oil recovery methods: natural depletion and peripheral water injection and produced a maximum of 200,000 BOPD in the late seventies. Currently, the oil recovery is around 50% with a 15,000 BOPD production at high watercut.
The Handil EOR lean gas injection project was started in November 1995 on five reservoirs and following its positive result was extended with six reservoirs in 2000. In 2003, an integrated study on the largest EOR reservoir was performed to assess the projects’ performance. This included 3D geomodeling, reservoir simulation and chemical tracer injection. The study permitted to track the main effects of the gas injection, to identify "bypassed oil" areas and to define reservoir management guidelines for the other lean gas injection reservoirs.
As field scale application of the gas injection technique is not sustainable since the gas is exportable, two other techniques are currently being evaluated as an alternative.
Second Contact Water Displacement (SCWD) is planned to be introduced on the maturest lean gas injection reservoirs. Simulation studies forecast potential for this technique which also allows decreasing the volumes of injected gas.
An Air injection pilot on a waterflooded reservoir was started in 2001. First results are encouraging but the injection was temporary suspended due to injector well problems after 6 months of injection. The project was comprehensively studied by compositional and thermal simulation and intends to restart early 2005.
Integrated studies of the Handil reservoirs provided in-depth understanding of EOR mechanisms. This resulted in the ability to better model field performance and to forecast tertiary oil production more accurately.
Deepwater Subsea Well Intervention – The Future Solution
Authors: Dick A. J. 
Published: December 2007

Abstract
The Expro Group has embarked on the development of subsea intervention technologies that extend far beyond the limits of current technology. This paper provides an up to date picture of this development, the markets that will be served and how this ground breaking innovation can now deliver operators with the capability to produce subsea assets by reducing CAPEX and efficiently controlling wells remotely without concern of lower field recovery (&lt;20%) rates. Expro can achieve this by swiftly mobilising solutions, which are low cost (up to 75% savings on current rig solutions) whilst also highly reliable.
Applications of this solution fall into several key categories:
Subsea Wells - whether vertical or horizontal trees, the technology being developed can enable improved subsea well intervention, a primary concern being prohibitive costs offsetting intervention that reduces absolute recovery Deepwater - increasing the subsea sector's growth whilst providing new challenges that further highlight the need for more cost effective solutions Extended Reach - when subsea wells and tie-backs become prohibitively risky and costly, there is increasing demand for extending from existing templates, Rigless intervention solutions may tip the balance back. Low Cost Wells - as above, why invest in a smart well when a low cost simple intervention can provide the necessary solution.
In summary, this paper will give a high level overview of the challenges ahead and the way forward - Expro's vision, incorporating the engagement of key ‘supermajor’ players / technology users through a Joint Industry Project (JIP).
Specialised Designs for Complex and Record Drilling Project
Authors: Beiriger C. , Bujnoch J. , Bealessio T. , Hudson C. , Farrar J. D. 
Published: December 2007

Abstract
The Belanak field in the Natuna Sea of Indonesia is located 253 miles northeast of Singapore in 300’ water depth (Figure 1). The field development consists of two wellhead platforms, with 16 wells drilled from platform A, and 18 wells planned for platform B. Due to the remote location of the development, and the space and storage limitations inherent to a platform rig, logistics and equipment design were the major front-end engineering issues of the drilling project. The early concerted effort of the operator and contractors to front-end planning and design led to the realization of several drilling records and first-time accomplishments in the Natuna Sea.
Using Third-Party Certifications to Deliver HSE Performance
Authors: Kraus B. 
Published: December 2007

Proposal
There is rising concern that current approaches to environmental management systems are yielding little in the way of meaningful environmental performance improvement. No small concern because the scale of the investment in EMS is colossal, but often underestimated. Over 95% of the real economic cost of EMS is attributable to factors which are difficult to measure - time inputs from personnel working within organizations on program development (drafting and reviewing policies, procedures and the like), training (most personnel will be trained), auditing (internal and maybe 3rd party) and very especially the pre-audit blitz that precedes most audits by 3rd parties.
Concerns about the value derived from implementing and certifying EMSs have not impacted growth in the field. Indeed there has been a significant uplift in the level of activity with the European Commission, EU Member State governments, US State and Federal government agencies joining with industry sector associations and others in the call to promote – and in many cases require - the uptake of management systems and third party certification of them.
US regulators in the state of Texas and other US states are offering meaningful incentives to organisations who meet a defined set of EMS requirements The American Chemistry Council is requiring all of their members to implement certified EMSs by the end of 2006. The US EPA has included requirements for 3rd party approved EMS’s in sentencing guidelines.
Those who are voicing concerns about the value of EMS point to an increasing body of anecdotal and empirical evidence which has found little or no correlation between certified EMSs and a variety of environmental performance metrics. The findings of these studies are surprising for many: the broad-based uptake of management systems in the environmental field was seen as a natural progression away from end-of-pipe thinking and most expected it to lead to significant operational efficiencies and other environmental performance gains.
Mature Field Development - A Review
Authors: Babadagli T. 
Published: December 2007

AbstractDevelopment of mature oil fields has been, and will increasingly be, an attractive subject. Mature field development practices can be divided into two major groups: (1) well engineering and (2) reservoir engineering. This paper focuses on the reservoir engineering aspects.An extensive review of previously reported reservoir management practices for mature field development is provided. After the definition of mature field and an overview, different aspects of mature field development are outlined. The first issue covered is the estimation of remaining reserves focusing on the determination of the amount and location of the residual oil after primary and secondary recovery using field, log, and core data. After valuing the remaining oil, methods to recover it are classified. They include tertiary recovery, infill drilling, horizontals, optimal waterflooding design for mature fields, optimal well placement and other reservoir management practices. Suggested or implemented field application examples for big fields owned by majors and small fields owned by independents are presented.Special attention is given to tertiary oil recovery. An extensive review and critical analysis of tertiary recovery techniques covering the theoretical, practical, and economical aspects of it are provided. The emphasis is on their applicability in mature field development in terms of effectiveness (incremental recovery) and efficiency (cost and recovery time). Laboratory and field scale applications of different tertiary recovery techniques, i.e., gas (double displacement, WAG, and miscible-immiscible HC, CO2, and N2), chemical (dilute surfactant, polymer, and micellar injection), and thermal (air and steam) injection, conducted to develop mature fields are included. Specific examples of big/giant fields, fields producing for decades, and mid to small size fields were selected. Differences in reservoir management strategies for majors, independents, and national oil companies are discussed.
Well-History-Based Prediction of Injectivity Decline (Accounting for Oil-Water Mobility Variation During Waterflooding)
Authors: Bedrikovetsky P. , Fonseca D. R. , Da Silva M. J. , Da Silva M. F. , Siqueira A. G. , de Souza A. L. S. , Furtado C. 
Published: December 2007

Abstract
Injectivity decline during sea/produced water injection is a wide spread phenomena in offshore and onshore waterflood projects. It happens due to capture of solid and liquid particles from the injected water by the rock resulting in permeability decline and also due to formation of low permeability external filter cake on the wellbore. Both phenomena result in injectivity impairment.
The field injectivity decline history is used for characterisation of the formation damage system and for the consequent well behaviour prediction.
The injectivity index increases M times during the damage-free displacement of oil by water (M is the water-oil mobility ratio). It affects the well injectivity prediction during poor quality water injection and changes the results of injectivity decline curve interpretation.
The combined effect of injectivity impairment by internal and external cakes and of the total oil-water mobility variation can be described by an analytical model. The model contains four injectivity damage parameters: the filtration and formation damage coefficients, the critical porosity ratio and the filter cake permeability.
The reliable modelling-based prediction of injectivity decline from a well injectivity index history requires knowledge of the four above-mentioned parameters.
In the current paper we develop a method for determination of the four injectivity damage parameters from the well injectivity history. Seventeen well data from eleven different oilfields have been treated, and the values of the four parameters lie in the same intervals as that obtained from laboratory tests. It validates the proposed method for injectivity decline system characterisation and allows recommending this method for prediction of injectivity decline from a well injectivity history.
Well-History-Based Prediction of Injectivity Decline During Seawater Flooding
Authors: Bedrikovetsky P. , da Silva M. J. , Fonseca D. R. , da Silva M. F. , Siqueira A. G. , de Souza A. L. S. , Furtado C. 
Published: December 2007

Abstract
Drastic loss of injectivity during waterflood using sea/produced water has been reported worldwide. It happens due to capture of solid and liquid particles from the injected water by the rock resulting in permeability decline, and also due to formation of low permeability cake on the wellbore. Both factors result in injectivity impairment.
Reliable prediction of injectivity decline should be based on mathematical modelling using coefficients that are well known for a specific well/field.
The mathematical model for injectivity damage contains four parameters: filtration and formation damage coefficients, critical porosity ratio and filter cake permeability. Nevertheless, just three constants can be extracted from two-piece-wise-linear injectivity decline curve.
In the current paper we propose the correlation between the formation damage coefficient and the critical porosity fraction to be used as a fourth equation allowing for characterization of injectivity damage system.
Eighteen well data have been treated, and values for four parameters of injectivity damage have been calculated. The obtained values have the same order of magnitude as those obtained from laboratory corefloods. It validates the proposal to use the correlation between the formation damage coefficient and the critical porosity fraction for characterisation of injectivity damage system from well history for the purpose of further prediction of well injectivity.
The Direct-Drive Variable-Speed Drive Head for PCPs Saves Big Bucks
Authors: Boyles G. A. , Stinson J. E. 
Published: December 2007

Abstract
Implementing a new configuration for the drive head for progressive cavity pumps can solve many operational problems and lower operational costs.Capable of handleing high sand loads keeps the pumps on and reduces downtime.Simplicity of design makes them easier and cheaper to build and maintain.Simple design of inline motor to a gear reducer coupled to the polish rod eliminates the problems and dangers associated with conventional belt and pulley configurations.When coupled with a power inverter the drive head speed can be reduced to 50% of capacity, allowing for quick pump saving adjustments.