bluuebunny/crossref_metadata_2025_split huggingface dataset:
Turning Around Mature Field Production Performance by Finding and Producing New Pools – A Mutiara Field Case History Of Successful Grid Base Drilling Campaign In Fluvio-Deltaic Reservoir
Authors: Wibowo Icuk Dwi , Sinaga Iranta Bona , Hermawaty Irma , Rahmanto Wahyu Agung , Krisnandya Arief , Srikandi Citra 
Published: February 2011

Abstract
Mutiara-Pamaguan Field are gas - oil field, located onshore in Sanga-Sanga PSC, Kutai Basin, East Kalimantan, Indonesia, consist of numerous complex- stacked-sand of deltaic environment. The challenge to fully develop the field is lack of knowledge on reservoir distribution and geometry. A semi-statistical (grid base) drilling has been applied as development strategy to increase the near term production rate and maximize recovery from these fields. The paper will focus on the "grid base" drilling development concept and actual results.
A justification to drill the wells is used to be focused on the incremental reserves coming from the remaining recoverable reserves of the known-reservoirs that can be predicted by combining the static and dynamic modelling. Unfortunately, hydrocarbon in place and recoverable reserves from the new-pools zones can only be determined after drilling. It is a challenge to predict new-pools zones in fluvio-deltaic reservoir due to reservoir uncertainty. However, the drilling results statistic improves the understanding of relationship between the distances from the new well to the existing wells with the hydrocarbon reserves from the unknown-reservoirs. Based on the complete understanding of known-reservoir and statistical knowledge of unknown-reservoir, a grid base drilling concept was then implemented to further develop the crestal area and to add a take-off point on spares in Mutiara - Pamaguan Field.
The actual results from the last three years have successfully sustained field production. The grid base wells have delivered more than 52 bcf and 2 mmbo of incremental reserves, and turned around Mutiara- Pamaguan production rate. The production performance has increased from 100 mmscfd to 125 mmscfd whereas oil production has doubled from 4000 bopd to 8000 bopd.
Currently grid base wells contribute 75% of that production. In term of development cost ($/boe), a successful of grid bas drilling strategy in Mutiara and Pamaguan Fields is one most efficient field development in Sanga-Sanga PSC.
Using Knowledge Management Techniques and Communities of Practice to Drive Performance Improvements in Drilling Applications in Onshore China
Authors: Perry Phil , Lee Roger , Yao Yan Zhang , Clark-Moore Ross 
Published: February 2011

Abstract
Onshore drilling in China is very diverse, ranging from wells drilled relatively straightforward in a matter of days to more complex geological environments where drilling can take several hundred days. Recently, this market has increasingly opened up to international operators and service companies, presenting opportunities to introduce new approaches to drilling performance optimization. To best capture the performance potential in any given application it is necessary to gain a detailed understanding of the complex drilling and production environment. This requires an understanding of many important variables, including: ○Macro components—Operators, geographic locations, organizational structure, decision makers, drilling activity, achievable market penetration.○External factors—Technology vendors, products, service organization, market strategies, organizational strengths and weaknesses○Drilling applications—Application breakdown, drilling issues, best practices and opportunities
This enables an organization to optimize its technology and service portfolio in a holistic approach to develop system solutions that achieve its objectives and key performance indicators (KPIs), and assist operating companies to overcome drilling challenges, deliver reductions in non-productive time (NPT) and invisible lost time (ILT), and improve overall performance.
This paper demonstrates how one organization in China used a proven Knowledge Management process and award-winning KM software to build a knowledge base of expertise in the main onshore China oilfields. The authors will detail the process of knowledge extraction and the methods used to document this experiential knowledge, allowing its communication and collaborative re-use in Communities of Practice across the organization. As a first step in a long-term strategy, the authors will demonstrate through two case-studies how this knowledgebase has been re-used delivering savings to an international operator with a 25% reduction in drill bit consumption. Furthermore, the knowledge base was applied for a domestic operator, realizing drilling time of 38 days less than planned, eliminating unnecessary trips and increasing the overall percentage of productive on- bottom drilling time.
Wired Drill Pipe Telemetry Enables Real-Time Evaluation of Kick During Managed Pressure Drilling
Authors: Gravdal J. E. , Lorentzen R. J. , Time R. W. 
Published: February 2011

Abstract
Distributed pressure sensors along the drill string from wired drill pipe telemetry, combined with real-time analysis of the data at the rig, may give valuable information to the drilling control system and the decision makers when utilized properly. The step change in bandwidth, reliability and availability lead to better premises for developing new technology for more advanced drilling methodology.
In this paper, improved methodology for evaluation of kick in Managed Pressure Drilling (MPD) is presented based on this step change in availability of downhole pressure measurements. The objective of the presented methodology is to improve well control for MPD by faster and better diagnostics of flow interaction between well and formation and thereby reducing formation damage and non-productive time.
A representative North-Sea well is used as test case geometry and an advanced well flow model is used as a virtual well in computer simulations that provide the basis for the presented results. The proposed methodology is demonstrated to estimate the depth of influx zones as well as the size and distribution of the kick. This will improve the handling of the influx incident, prevent the risk of hole stability problems and thereby reduce cost associated with non-productive time.
Integrated 3D Reservoir Model and Petrophysical Study to Optimize Field Development in Low Permeability Deltaic Reservoir, Badak Field-Indonesia
Authors: Gultom Luhut , Benito Jose , Negara I Made , Adi Ratno , Soenoro Amireno , Nikijuluw Robert , Benyamin _ 
Published: February 2011

Abstract
The fluvial deltaic VICO's Reservoirs are located in the eastern part of Kutai Basin, Indonesia, being Badak one of their biggest and most prolific Fields that has been producing gas for more than 35 years.
Badak, the first gas field discovered in the Basin, presents the concentrations of hydrocarbon in fluvial sediments, mainly in channels and bars deposits. These bodies are distributed through a vertical interval of thousands feet over various areas of the structure. At present, we face the challenge of developing the remaining gas reserves in these low permeability deep reservoirs. These reservoirs locally known as G and H levels are at depths between 11,000ft to 13,000ft.
During last couples of years considerable efforts have been done on developing fluvial facies model based on sedimentary environment and core data. The key factor, for better understanding the potential areas was an integrated 3D Model including also a detailed petrophysical analysis.
Based on core data cut-off values of porosity, permeability and water saturation were calculated and used for selection of the best well candidates, with the higher flow rates. The same cut-off values were applied in the 3D model in order to identify and characterize the main productive areas with high storage and flow capacity. The 3D model helped to understand the areal and vertical distribution of these petrophysical properties as well as porosity and water saturation.
As a result, confident locations for development of these low permeability reservoirs can be presented in order to increase the current recovery factor. Right applications of a reliable 3D model allows to identify of best areas and potential reservoir characteristics from limited quantity of data, obtainable from conventional cores and well logs to maximize the success of the project. Drilling in these reservoirs already contributed with 30 MMCFD of gas equivalent to 30% of field production.
Less Footprints in the Snow for Salym Field in Western Siberia
Authors: Cramer Ron , Mabian Andrew , Tulalian Robert 
Published: February 2011

Abstract
Salym Petroleum Development N.V. (SPD) is a Joint Venture operating and developing the Salym group of oilfields in Western Siberia. The fields are artificially lifted, predominantly using variable speed drive ESP's for some 330 wells (Q1 2010). Pump controllers and well head instrumentation has been tied-into a SCADA/Historian system. The basic control system is being enhanced by progressively installing Shell's integrated Smart Fields* capability based on the combination of FieldWare* suite of real time software applications (for real time monitoring, surveillance and control), electronically linked to offline Integrated Production System Models and the Hydrocarbon Accounting System. In this application FieldWare consists of four modules:
- Production Universe - real time oil, gas and water flows for all of the wells virtual flow measurement and for real time monitoring of ESP operating downhole parameters; - ESP - real time pump efficiency curves, reports, surveillance and remote control complemented by Mikon echometer fluid level measurement; - EOR – water injection optimization and real time water flows from source to injection, including real time monitoring of surface vessels levels, surface pumps and wells injection pressures and rates; - WellTest – well test optimization, enabling real time well test measurements screening, troubleshooting and automatic transfer of test data to the hydrocarbon accounting system.
The purpose of this paper is to describe/quantify Smart Fields benefits seen so-far in terms of less operator travel and hazard exposure, reduced ESP interrupts, more stable operations and faster re-starts. Benefits quantification is facilitated by meaningful comparison of automated and yet-to-be automated parts of the field, including impact from the deployment of Smart field Technologies in Salym fields.
Integrated Study for Field Development Challenge of a Brown Field with Seven Stacked Reservoirs
Authors: Kasap Ekrem , Qassabi Dawood , Lukmanov Rinat , Busaidy Rashid , Zarafi Ahmed 
Published: February 2011

Abstract
A brown field consisting of NE and SW accumulations has stacked six clastic and one carbonate reservoirs with fluid contacts per reservoir per accumulation. Depositional environment changes from shallow marine at the bottom to deltaic lacustrine at the top. Average rock properties and connectivity deteriorate from bottom to top.
Borehole rugosity and low resistivity contrast between hydrocarbon and water bearing intervals made petrophysical evaluations difficult that may have led to STOIIP overestimations. Production allocations for commingled horizons were not carfully done. The tests in some wells have suffered from packer leak and/or flow behind the casing. These sealing issues have drastically increased uncertainty in aquifer support for upper reservoirs and in oil production for lower reservoirs.
An integrated study with static and dynamic models was conducted to minimize uncertainties, risks and to optimize field development options. Well logs, and seismic, production, pressure, core, and PVT data in addition to well events are all incorporated into the models. Several IFT measurements were obtained at the start of the study and the results greatly reduced uncertainty in the height of capillary transition zones defined through 4 poro-perm and 5 capillary pressure models.
Multiple static model realisations were constructed based on sequence stratigraphic correlations, facies geometries, porosity distributions and analogue depositional systems. These realizations were input to dynamic models to establish Base, High and Low cases with historically possible range of uncertainty and risks for the field development options.
In conclusion, uncertainties were reduced from 120% to 10% after modeling and history matching identified active and passive STOIIP. Uncertainties in past production allocations were minimized via model well bore communications. Unconstrained development options lead to the optimum number of wells. After including drilling and surface facility costs, economics screening indicated that infill-drilling for the north-east and infill drilling supported with dump flooding for the south-west were the best options.
The study is completed in 2008 and the resultant plan has been being implemented in phases. Phase I involved one NE producer in 2009 and one SW water injector in 2010. Producer W-12 was a success and has been producing with an initial rate that was three times the discounted expectation rate due probably to 5m shallower structure and twice thicker bulk thickness and better permeability.
Transient Testing of CBM Wells
Authors: Stewart George 
Published: February 2011

Abstract
A review of coal bed methane (CBM) drill stem tests (DST) in Queensland has shown that complex reservoir behavior is common. In particular radial composite or multiple boundary effects have been diagnosed on log-log derivative plots. In this paper the treatment of stress dependent permeability and porosity (SDPP) in pressure transient testing and production forecasting is addressed. The application of a pseudopressure transform, which is the traditional method for tackling the problem, is described. The SDPP pseudopressure method presumes that the rock mechanics model is already known. In this study an alternative procedure termed pseudo model is proposed where the rock mechanics parameters can be determined by the nonlinear regression facility available in well test software. The application of this methodology is illustrated by a field example of an injection falloff from the US. One of the main effects of stress dependent permeability is a magnification of the effect of mechanical skin from formation damage and the origin of high total skin in CBM wells is attributed to this mechanism. Gas block due to the pressure falling below the critical desorption pressure is also a problem and typical gas-water relative permeability curves are used to assess this effect.
Evaluation of Mechanical Performance and Stress-Corrosion-Cracking Resistance of Post Expanded Carbon Steel and CRA Casing Grades
Authors: Bufalini A. , Morana R. , Nice P. I. , Nasvik H. , Kjørholt H. , Bailey B. M. , Adam M. K. , Jiral D. G. , Ross R. C. , Smith R. C , Ueda M. , Ohe T. 
Published: February 2011

Abstract
While expandable tubular technology significantly increased traction within the oil&gas industry in the last few years, materials behavior knowledge for expandable casing has not progress sufficiently. This is due to the lack of a diffused definition of the most appropriate procedures to verify post-expansion material performance and to the difficulties in performing investigation activity. These investigations rely on post-expanded material, which is costly and time-consuming to obtain, especially for the range of very large plastic deformations applicable to Monobore applications.
Consequently, an extensive testing program was started by Statoil to define an appropriate testing procedure for the evaluation of material performance after expansion and to characterize candidate materials. This paper presents the testing methodologies developed and the results obtained for several carbon steel grades and CRAs. These evaluations included tests of the mechanical performance and the resistance to aggressive environments.
The assessment of mechanical performance was carried out through several conventional and innovative tests and evaluation activities. Conventional tests included tensile tests in longitudinal and transverse direction, at room and elevated temperature, impact tests and residual stress evaluation. Collapse tests were performed on expanded pipes. Novel methods with optical strain measurements were adopted for improved tensile tests. Finite Element Analysis of the expansion process was also used to further investigate post-expansion mechanical performance. The resistance to stress corrosion cracking or sulphide stress corrosion was evaluated by means of FPB and C-ring tests. Carbon grades were tested in a mild sour environment while CRAs were tested in aggressive environments representative of possible field conditions. All experimental tests were carried out on materials before and after expansion. The effect of strain aging was also evaluated for carbon steel grades applying a defined aging cycle to expanded material.
The experimental methods adopted are described and discussed. The test results highlighted the main mechanical parameters to be considered and allowed ranking the different materials tested. At least one carbon steel grade and one CRA possess adequate mechanical and environmental performance even after 30% expansion. The test methodology adopted was therefore considered adequate for the aimed purpose.
Saving 70% Rig Completion Time in 13 Multizone Wells with Single Trip Multizone System in Mahakam Delta Offshore Indonesia
Authors: Suryanada Siswara , Wahyudhi Fransiskus , Garcia Euro , Landry Jed , Li Chunming , Hansen Cody , Daulton Dan 
Published: February 2011

Abstract
Reducing recurrent pipe trips offer significant time savings easily translating directly into improved well and/or project economic benefit. Utilizing a reliable multizone single trip method that reduces additional pipe trips compared to performing conventional stacked cased-hole Frac-Pack (FP) or High Rate Water Packs (HRWP) has a major impact on the overall completion costs associated with reservoirs containing multiple completion intervals. This multi-zone single trip system improves operational performance and stimulation effectiveness by incorporating an innovative service tool sealing mechanism with complete independent zonal isolation for each treatment interval. Additionally a selective zonal opening/closing tool offers an added degree of well performance control. This paper provides a summary of multizone single trip system introduction and utilization beginning in 2007 to Bekapai and Sisi Nubi field projects in Mahakam Delta offshore Indonesia for sand control in mutlilayer reservoirs.
To date, a total of 74 zones with FP/HRWP's on 16 wells have been successfully installed. An average of 5.3 days completion installation time has been achieved on 13 wells with 3-6 zones at an average depth of 12,000 ft (3,657 m). This compares to a completion installation time of 20 days per typical 5 zone stacked FP/HRWP well. As a result of efficiencies gained utilizing multizone completion technology greater than 70% rig time reduction has been achieved with $US 30 million dollars savings on the project thus far. This paper will also present lessons learned, application concerns when considering multizone single trip as a completion option and challenges going forward to improve implementation of multizone completion technology.
Thirty Years of Gas Shale Fracturing: What Have We Learned?
Authors: King George E. 
Published: February 2011

Abstract
Although high gas flow rates from shales are a relatively recent phenomenon, the knowledge bases of shale-specific well completions, fracturing and shale well operations have actually been growing for more than three decades and shale gas production reaches back almost one hundred ninety years. During the last decade of gas shale development, projected recovery of shale gas-in-place has increased from about 2% to estimates of about 50%; mainly through the development and adaptation of technologies to fit shale gas developments. Adapting technologies, including multi-stage fracturing of horizontal wells, slickwater fluids with minimum viscosity and simultaneous fracturing, have evolved to increase formation-face contact of the fracture system into the range of 9.2 million m2 (100 million ft2) in a very localized area of the reservoir by opening natural fractures. These technologies have made possible development of enormous gas reserves that were completely unavailable only a few years ago. Current and next generation technologies promise even more energy availability with advances in hybrid fracs, fracture complexity, fracture flow stability and methods of re-using water used in fracturing. This work surveyed over 350 shale completion, fracturing and operations publications, linking geosciences and engineering information together to relay learnings that will identify both intriguing information on selective opening and stabilizing of micro-fracture systems within the shales and new fields of endeavor needed to achieve the next level of shale development advancement.
Real Time Production Surveillance and Optimization Solution Implementation in an Offshore Brownfield in Malaysia
Authors: Wong Lee Hin , Grigorescu Ramona , Whitney Patricio , Arifin Azahari Mohd , Midun Romionson , Salim Muzahidin Muhamed 
Published: February 2011

Abstract
Gas lift optimization and design has traditionally used single-string analysis to perform optimization. This required time consuming exercises and lengthy processes that never achieved the global reach of field constraints management. In a dynamic brown field where field interruptions and process upsets are common, response time is a key performance indicator. These challenges were effectively overcame by introducing a Real Time Production Surveillance and Optimization system capable to perform dual string gas lift optimization field-wide and in real-time.
The implementation was the first Real Time Production Surveillance and Optimization system in the country. The system links up real-time operational data historian system and corporate production information management system (PIMS) and is coupled with the Well-Network suite of simulation tools to provide an integrated suite of production surveillance, diagnostic and optimization application modules that increase the efficiency of daily oil and gas operations activities.
The goal of this paper is to underscore the advantages and benefits that can be drawn from the utilization of Real Time Production Surveillance and Optimization System during the operational phase of production optimization process.