bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Performance of WAG in a Stratified Reservoir, Hassi-Messaoud Field, Algeria
Authors: Drid Nabil , Tiab Djebbar 
Published: December 2007

Abstract
Water Alternating Gas (WAG) process has been the subject of research, development, and field testing for a long time in Hassi Messaoud (HMD) field. There is still some disagreement in the interpretation of laboratory, field test data and in the selection of optimum parameters of injection such as (water/gas ratio, cycle period and miscibility conditions). The major reason for these problems is that the reservoir model does not mach the reference model.
This work describes a method for designing an effective water/gas flooding in a stratified reservoir, and particularly in HMD. The proposed approach is based on a more realistic numerical model that takes into account the effect of three-phase flow, gravity and viscous forces in anisotropic media, which allows the determination of optimum parameters of water/gas injection. In addition, the performances of different WAG injection options were compared with the performance of waterflooding and gas injection.
The simulation results illustrate the influence of WAG injection parameters, such as water-gas ratio, injection rates and cycle period on recovery process and select the optimum WAG ratio and WAG cycle. A more realistic reservoir model is the key to evaluate the performance of WAG injection in stratified reservoir, such as HMD.
Based on the simulation results, Water-Alternating-Gas injection is the most successful process as compared to waterflooding and gas injection. The incremental oil recovery using WAG technique can reach 7% of OOIP and the GOR is more easily controlled than in conventional methods.
Clean Up Oily Waste of Drilling and Production Operation in the VICO Field, East Kalimantan, Using Separation and Bioremediation Technology
Authors: Sauman M. , Dewandono Agus , Hasan Rochana 
Published: December 2007

Abstract
Three years ago, VICO Indonesia made the decision to minimize the environmental impact of oily wastes from its drilling, workover completion, and production operations in East Kalimantan. The waste consists of synthetic oil base mud cuttings from drilling and work-over completion operations and oily sludge from production operations.
VICO Indonesia is now applying separation and land-farming bioremediation technology to achieve zero oily waste discharge in order to minimize the environmental impact and maximize oil recovery. The project is being implemented in several stages.
The first stage of the clean-up is to separate the sludge or other oily solid waste from solid with less oil content, oil, condensate, and other liquids. As the material has a high oil content or high total petroleum hydrocarbon, a secondary objective is to maximize oil recovery. The sludge is first separated by gravity using newly built concrete pits. Using a centrifuge, the oily solid is separated as oil, water, and oily solid. All oily solid waste from the centrifuge is processed using land-farming bioremediation. The oil and condensate is sent to the production process facility to be recycled. The water coming from the pits is processed to meet the government regulations and monitored using a bio-monitoring dynamic pit before being discharged to the environment or injected into disposal wells.
The second stage of the clean-up is to process the synthetic oily waste cutting from the drilling operation and all oily solid waste from the centrifuge using land farming bioremediation technology at the Central Bioremediation Area. This technology uses aerobic microbes to degrade the toxic hydrocarbons to harmless end products. The recycled waste is rendered as nontoxic topsoil for in-house regreening.
The third stage of the project is to confirm the remediation result. The pile of re-mediated soil has been planted with a variety of vegetable and fruits. The soil, vegetables, and fruits have been analyzed to validate the process and ensure there is no contamination.
This process has zero cost as the cost of the service is offset by the value of the recycled oil. In addition approximately $1,200,000 is saved compared to disposing of the oily waste in commercial facilities.
The separation and land-farming bioremediation technology is being successfully applied to eliminate oily waste in VICO Indonesia. All treated waste is within the limits as prescribed by government regulations.
Underground Gas Storage: Issues Beneath the Surface
Authors: Dharmananda Kanaga , Kingsbury Neil , Singh Harnesh 
Published: December 2007

Abstract
The storage of natural gas by re-injection into the surface has become quite commonplace in various developed countries around the world. It is a relatively new phenomenon in Australia, and issues, not yet resolved, remain.
The ability to store gas underground has enormous implications for the competitiveness of the gas market in Australia. Underground storage allows producers effectively to manage their gas flow in times of high and low demand. For gas users, underground storage has the potential to increase the choice of suppliers. For gas commodity traders, underground storage provides increased ability to hedge gas contracts which in turn will help to foster a strong spot market for gas in Australia.
As a result of the increased interest in, and the development of, underground gas storage facilities in Australia, most of the relevant petroleum legislation in each State and Territory in Australia has been amended, or is currently being reviewed, in order to deal with the legal and technical issues that arise with underground gas storage.
Some of the issues that arise, and yet to be finally resolved from underground gas storage include: Who owns the re-injected gas? The Crown or the producer? This is particularly relevant to avoid the double payment of royalties. The issue becomes quite complex where processed gas is injected into a partially depleted petroleum reservoir.What regulatory regime should regulate underground gas storage?Who is responsible in the event that liability arises from the underground storage of gas?What rights do the owners of land affected by an underground gas storage facility have to the underground gas?
Our paper discusses these issues and provides a brief overview of the current legislative regime regulating the underground storage of gas in specific Australian jurisdictions.
Water-Alternating-Gas (WAG) Pilot Implementation, A First EOR Development Project in Dulang Field, Offshore Peninsular Malaysia
Authors: Nadeson Ganesan , Anua Nor Aidil B. , Singhal Ashok , Ibrahim Ramli B. 
Published: December 2007

Abstract
Some of the older oil fields in Malaysia can be characterized as mature water floods. Schemes for enhancing and prolonging the already declining production and diminishing reserves strategically call for timely implementation of Enhanced Oil Recovery, EOR applications.
Among various Enhanced Oil Recovery (EOR) processes and techniques, Malaysia's reservoirs appear especially amenable to gas injection. Feasibility studies showed that immiscible Water-Alternating-Gas (WAG) injection is potentially the most practical and viable option. Laboratory studies and numerical simulation study conducted on the applicability of immiscible WAG injection using high CO2 content gas indicated that an additional 5-7% of OOIP can be recovered [1]. Such a gain will result in reserves growth and extended producing life of these reservoirs. WAG application is being field tested by implementing a pilot in a sub-block, South-3 of the Dulang field, which is isolated from other sub-blocks, by major faults. One in-fill well was drilled specifically for the current pilot. Upon drilling this infill well, several geological complexities were uncovered, that called for a thorough revisit of modelling and pilot conceptual plans. The pilot area contains 6 wells, three of which are being used as producers during WAG operations.
This paper discusses detail of our first ever EOR pilot implementation (Immiscible WAG in Dulang oil field). It describes progression from conceptual design to various challenges, results and the lessons learnt during early periods of implementation.
Mature Oil Field Potential Study in Southern East Asian Countries
Authors: Zhu Jiucheng , Hu Shunxing , Zhang Rui 
Published: December 2007

Abstract
With the difficulty to discover large new oil fields in Southern East Asia, it is very challenge for this area to maintain its oil production. Thus to increase the final recovery and increase oil production from mature oil fields gets more and more concern from government and oil companies operating in this region. These fields are classified as depleted solutions gas drive, weak natural water drive with partial water injection and strong natural water drive with no water injection. General characteristics of regional large mature field are analyzed on the basis of typical field data from Southern East Asian countries.
Good reservoir property, low in situ viscosity, long production history makes these field often with high primary recovery as high as 40-60%. However, data shows that reserve potential does exist in the secondary reservoirs, in unrecognized oil interbedded zones and in untapped oil area by existing wells. Even for very homogenous reservoirs with perforation covering all oil-bearing intervals, oil has always mainly being produced from the good part of reservoirs. Recalculation of original oil in place and construction of fine reservoir model is critical to these fields for identification of infill well locations and reperforation strategies.
Water injection potential for depleted fields are studied and the major challenge is that the depleted reservoir pressure and the existence of the secondary gas cap could make the oil gain from water injections arrives only after several years of injection process. Whole field scale water injection in mature oil fields is always risky and should be only performed by satisfactory simulation and pilot results. Polymer flooding to increase the final recovery is also discussed and its potential mainly fits for the mature fields with weak natural water drive in shallow burial depth. Big potential could be tapped in mature fields for recovering more reserves while high reservoir temperature, depleted reservoir pressure, and significant investment in facilities presents challenge for EOR solutions in this area. Work over and well stimulation potential are also discussed with strong recommendation to cut corresponding investment and relevant operation cost in order to make these measures are economic for mature fields.
Intelligent Well System with Hydraulic Adjustable Chokes and Permanent Monitoring Improves Conventional ESP Completion for an Operator in Ecuador
Authors: Puckett Robert , Solano Maurilio , Krejci Michael 
Published: December 2007

Abstract
Installing an intelligent well system in an existing completion can help operating companies accelerate production, increase ultimate recovery, and reduce interventions. It is of particular interest when all three of these benefits can be achieved in the same well.
This paper focuses on such a well, the two-zone oil producer EY-D11 located in the Eden-Yuturi field of Ecuador&#39;s Block 15, in which an intelligent well system (IWS) was installed in conjunction with an electric submersible pump (ESP) during the workover of an existing completion. The two main value drivers for implementing the intelligent completion were 1) the ability to commingle production from two zones to meet accelerated production goals while fulfilling governmental requirements of properly allocating production and 2) the ability to regulate water production from both zones during commingled production. Secondary drivers included reducing the need for well interventions, the desire to pull the completion easily to repair or replace the ESP, and the acquisition of additional knowledge regarding the performance of the upper zone. These value drivers were satisfied with a system whose key components included remotely operated hydraulic adjustable chokes controlled by a semi-automated surface control system; and a field-proven suite of downhole sensors composed of a venturi-type single-phase flow meter and pressure / temperature gauges with all sensors controlled via a single surface data acquisition unit. The intelligent well system satisfies the drivers by commingling flow from multiple zones while dealing simultaneously with the different characteristics of each zone to optimize production.
The EY-D11 well currently has commingled production from an upper and lower zone utilizing a single ESP, gaining incremental production of 3,500 barrels/day over the previous single-zone ESP completion. Based on the successful installation and results from this well, a second identical intelligent completion system was installed in the EY-D15 well in the Eden-Yuturi field in April 2004. Three additional completions are scheduled for the field in 2004 using essentially the same system.
Case History: Innovative Slimhole Techniques Resolve Completion Problems for a Major Operator in the Gulf of Mexico
Authors: Coats Catherine G. , LeBoeuf Gerald , Dupont Richard , Wilson Bradley 
Published: December 2007

Proposal
A major operator in the Gulf of Mexico had planned to run a cased, slimhole completion. The formation was sandstone, and thus, gravel packing would be required. The well was drilled, but the liner became stuck at 1500 feet from bottom. The operator did not want to pursue the sidetrack option, and unless another solution could be developed, the well project would have to be abandoned. The service/engineering company working with the operator felt that a solution could be developed that would allow the well to be completed.
The operator and service company representatives formed a dedicated team and developed a plan that would provide the perforation needs, solve the packer problem, and perform the gravel pack satisfactorily from a service vessel. This paper will discuss how an unusual solution was planned and executed and was successful in resolving the problems.
This case history is an example of how a service company and operator can work together to resolve difficult completion scenarios and provide win/win solutions for all parties. With regards to innovative completion techniques, the completion configuration that was developed using a smaller liner, the small bore tools and compatible gravel-pack design for the smaller liner as well as the unusual use of an enhanced low-profile prepacked (ELP) screen were significant to the success of this completion.
The unusual completion was run as planned. The gravel pack was successfully performed with returns throughout the treatment. The well is on line and performing better than expected.
Career Development for a Sustainable, Safe and Competitive Petroleum Industry
Authors: Starling Steve , Robertson John 
Published: December 2007

Abstract
The Australian upstream oil and gas industry faces many staffing challenges, including Shortages of skilled personnel to staff new developments and expansion projects,Retirement of an aging workforce with consequent loss of experience, andLow enrolments in university courses predicting a diminished pool of geologists, engineers and technical staff.
APPEA's Workplace Competency Initiative has been addressing these challenges by devising and promoting a Career Development strategy to encourage the recruitment and retention of staff. This Career Development strategy also addresses the competent workforce provisions and duty of care requirements of APPEA's safety case guidelines. The principle components of the Career Development strategy are; Competency Standards – the development of competency standards for production operators and drilling crews.Career Guide – a promotional publication to attract new recruits, retain current staff, and to promote lifelong learning.Coach's Handbook – A manual for team leaders, supervisors and managers to encourage staff coaching, competency based training and career development.Coach the Coach Courses – practical one day sessions to promote staff coaching, competency formation and career development.Group Training Scheme – an industry sponsored scheme to recruit, place and train production operators, and aCompetency Register – development of a competency register to encourage & record workforce safety certificates, workplace inductions and vocational qualifications.
Ultimately this Career Development strategy will create a sustaining pool of skilled workers, contribute to safer workplaces, and improve the competitiveness of the Australian petroleum industry.
Peer Review Process: Adding Value, Enhancing Operations and Building Collaborative Teamwork Spirit in Production Engineering
Authors: Vo L. , Al-Sahhaf A. A. , Gilani S. K. 
Published: December 2007

Abstract
The Peer Review (PR) concept is a widely practiced process used in various organizations all around the world, and though it is not new, it is very necessary. The Saudi Aramco - Southern Area Producing Engineering Department has taken the initiative to adopt and apply this unique concept to its organizations for more than a year.
The PR process has demonstrated to improve production and cost savings/avoidance, to ensure safety issues being in compliance and most importantly, to share with and pass on knowledge among the technical workforce.
The intent of this paper is to share our experience with respect to the PR process within the Production Engineering organization. This paper presents the PR processes, including its history, rationale, definition, purpose, scope, benefits, guidelines (including member's qualifications and how the PR session is conducted), flow process, structure, PR qualities and characteristics, tracking system, selection of PR projects and a number of actual case examples accomplished by the PR groups.
Champion West Field Development, Brunei: A Study in Seal, Compartmentalisation and Fluid Fill Uncertainty
Authors: Schulz-Rojahn J. P. , Walshe P. , Suhaili Hj. I. 
Published: December 2007

Abstract
This paper addresses the management of contact uncertainty in thin multi-layered, intensely faulted reservoirs characterised by overall complex fluid fill distributions. This uncertainty can be significantly reduced through the integration of geological scenario, compartmentalisation and sub-seismic fault prediction, seismic QI (quantitative interpretation) and material balance studies. The appliance of this integrated team approach is in volumetric risk quantification and optimisation of development well planning.
A Case Study of Carbon-Oxygen Logging Through Multiple Tubular Strings Offshore Indonesia: Reservoir Model Verification With Emphasis of Fluid Contact and Bypass Oil Identification
Authors: Rourke Marvin , Prabowo Wahyu E. , Winarti Susi 
Published: December 2007

Abstract
Over the producing life of a typical reservoir, evaluation and verification of the reservoir model is critical. Through-casing formation evaluation can provide very important input data to the model. Carbon-Oxygen (CO) logging has proven an effective method for through-casing evaluation in the low salinity, medium to high porosity, oil reservoirs typical in Indonesia. However, logging from inside the tubing and evaluating the near wellbore fluid conditions can be challenging. This case study shows how Carbon-Oxygen logging with an advanced pulsed-neutron tool can be successfully applied even in extreme logging conditions.
High water production in some of the wells in the Belida Field, Natuna Sea offshore Indonesia, led the operator to seek ways to confirm the reservoir model prior to embarking on possible workover programs. The Belida field is a mature field with 26 wells producing oil with average water cut exceeding 80%. The wells are completed with 4 1/2-in. or 5 1/2-in. tubing inside 9-5/8-in. casing with the original open hole drilled with 12 1/4-in. bits. The limited depth of investigation inherent to the CO measurement makes these logging conditions difficult. However, in this paper we demonstrate that the increased signal to noise (S/N) ratio of a new advanced pulsed-neutron tool makes logging these wells possible. By careful job planning of each of the target wells and by controlling the well bore conditions while logging, the data collected in the CO logging program has proven valuable input to the reservoir model.
Hybrid Monobore Completion Design: An Application for Multilayer Reservoir
Authors: Ibrahim Indra C , Joenoes Krisjahbana , Otten Howard 
Published: December 2007

Abstract
Completion Design is a key factor, especially in Gas field management, and completion design can have a large affect on gas deliverability and the liquid production through out the lifetime of a well. This paper describes a novel solution to producing gas from multi layered gas intervals, such as encountered in VICO Indonesia's operating area in East Kalimantan. The paper is focused on a completion in the Semberah Field, which utilises a novel combination of both conventional and monobore completion types. Essentially having a selective single string completion dedicated to producing the shallower reserves, whilst following a monobore concept for the second string to deplete deeper reserves.
Historically the conventional completion type in VICO was either dual or single string (23/8", 27/8" or 31/2") with several selective zones. These completions consisted of multiple components, SSD, multiple packers, single packers, dual packers that had numerous sealing areas. Some completions became very complicated and the completion materials themselves became a significant part of the cost of rercompleting or drilling the well.
To address this issue a special team was formed in 1997 to review completion procedures on a holistic basis. A 41/2" monobore concept was developed to reduce the initial completion costs and to initiate low cost rigless well interventions to access future reserves. This change was pursued and has reducing the drilling and recompletion costs by up to 20%, and VICO has benefited from implementing the mechanically simpler, rigless interventions. However with many reservoirs depleting in pressure and producing significant water volumes as well as the monobore requiring a bottom up perforating strategy it was apparent that the best of both scenarios might be a compromise for future wells. This was especially relevant for wells, which had significant shallow rate potential, along with significant volumes of low rate productivity deeper in the well. Also liquid loading was becoming more of an issue in the 4 1/2" producers so reducing tubing ID enables wells to produce longer and improve ultimate recovery. For the above reasons, the subject well was completed as 3-1/2" monobore as long string and 3 1/2" dual selective in short string to optimize the production gas and oil.