bluuebunny/crossref_metadata_2025 huggingface dataset:
A Comprehensive Model for Predicting Internal Corrosion Rates in Flowlines and Pipelines
Authors: Garber J. D. , Farshad F. F. , Reinhardt J. R. , Tadepally V.
Published: December 2007

A computer model has been developed which is capable of predicting the physical and chemical condition inside of a flowline or pipeline. From this information it is then possible to provide a prediction of the internal corrosion rate.

This "free" software was funded by the US. Department of Energy and has undergone several revisions and is currently in Phase II. The windows based model consists of 4 modules, which calculate the temperature, pressure, phase equilibrium, flow dynamics as well as the pH, scale tendency and the uninhibited corrosion rate. An expert system has been developed which adjusts the predicted corrosion rate based on fluid parameters.

A number of field and hypothetical cases for both the flowlines and pipelines have been presented which show the utility of the model. The model has been compared to PipePhase, a commercial package, and the results have been very satisfactory.
Novel Synergistic Water Soluble Corrosion Inhibitors
Authors: McGregor William M.
Published: December 2007

Ever more stringent environmental regulations make it increasingly difficult to obtain satisfactory corrosion inhibitors which are effective while being compatible with marine life. Toxicity towards aquatic organisms is a major concern and environmental constraints have been imposed on the types of compositions used in the North Sea in order to protect marine organisms. Many available inhibitors cannot meet the environmental criteria while maintaining effective corrosion inhibition.

For sweet / carbon dioxide corrosion, imidazoline based inhibitors are traditionally effective but they have an imperfect environmental profile. Here we describe how the environmental properties have now been improved by alkoxylation of a traditional inhibitor. This not only improves the environmental aspects but also increases the hydrophilicity of the inhibitor making it more suitable for water based applications and increasing its solubility in the water phase where corrosion usually takes place.

Organic phosphate esters are also effective corrosion inhibitors with a broad field of application in sweet and sour corrosion.

Here we describe laboratory-based corrosion testing on an innovative range of mixed imidazoline / oligophosphate ester inhibitors which show synergy in corrosion inhibition ability, especially at low dosages. The alkoxyimidazoline protects the cathode of the electrochemical cell and the oligophosphate protects the anode – this dual mechanism promotes synergy and increases confidence that the inhibitor will continue to give corrosion protection even in extreme situations where one of the components might have failed.

These mixed corrosion inhibitors are therefore applicable to a wide range of water based systems used in the oil and gas industry.
The Application and Evaluation of a New Vertical and Fast Drilling Technology in Tuha Oilfield
Authors: Di Qinfeng , Chang YongDo , Zhou Hejun
Published: December 2007

Cost-effective vertical and fast drilling technology has been of great interest to drilling contractors of most oilfields, but it’s difficult to implement. Conventional anti-deviation drilling methods are of limited use when confronted with high-tilt angle geologic structure. Systems such as VDS, Power V and VertiTrak can be used to control the deviation angle of a vertical hole, but the rental costs associated with them are high, and sometimes, prohibitive. Therefore, there is great potential for developing a new anti-deviation technology that is cost-effective.

Slide steering BHA with two stabilizers and a bent PDM shows good anti-deviation effect when it is in rotary driven on the surface of low-dip wells. This working mode can be termed as coupled mode because the bit is driven by both PDM and rotary table/top drive equipment. The whirl feature of this kind of BHA can helps to eliminate the deviation force caused by the asymmetry point direction of bit axis. At the same time the lateral vibration of BHA introduces a large amount of anti-deviation force on the bit. Simulation results show that this kind of anti-deviation force 1)is much larger than that of the pendulum BHA in the same tilt angle hole, and 2) decreases with tilt angle of hole. The calculation model involved is illustrated later in the paper.

The method above has been validated through experiments and applications in Tuha oilfield. 12 vertical wells in easily deviated geological structures have been successfully drilled applying this technology. As a result, not only the deviation angle is controlled effectively, but also penetration rate improves significantly. In particular, drilling period is reduced by 9.26 days, a 25% reduction as compared to the whole working time needed when conventional method was used.
Prospects of Casing while Drilling and the Factors to be Considered During Drilling Operations in Arabian Region
Authors: Hossain M. M. , Amro M. M.
Published: December 2007

Casing While Drilling technology is one of the greatest developments in drilling operations. The Casing While Drilling involved drilling and casing a well simultaneously and hence, overall cost of drilling may be reduced significantly by lessening drilling time and drillstring problems encountered during conventional drilling process. This technology is highly applicable in depleted reservoir as an alternative to the underbalanced drilling, which requires special equipment.

This paper presents the applicability of the concept of Casing While Drilling in context of the Arabian (Middle East) drilling operations. Attempts are made in order to overcome some unscheduled hole problems, such as lost circulation, differential sticking and casing stuck due to tight hole during running casing after drillstring pulled out.

This paper also presents simplified method that has been developed to predict the torsional and drag forces subjected to the casing string. Method of evaluating fatigue life of casing string has also been developed using simplified analytical techniques based on prevailing drilling conditions in Arabian fields. Both the static and dynamic cyclic loads as encountered in vertical and deviated wells are considered for the evaluation of fatigue life of casing string used for Casing While Drilling. Valuable guidelines are provided based on field representative case studies in order to minimize the various problems of conventional drilling operation through using the Casing While Drilling approach for Arabian field condition.
E-Business Partnership within Operating and Service Companies
Authors: Hodges Steve , Needham Donnie , Hartman Ken , Welsh Chris , Rand Roger , Luna Rudy
Published: December 2007

E-business in the upstream oil and gas industry is becoming increasingly strategic. While E&P companies are not yet buying a large percentage of their goods online, momentum to do so is building as E&P companies move beyond simple Web-based self-service applications toward Internet-aided information gathering and participation in true collaborative electronic interaction and relationships with service companies. Concomitantly, service companies are designing interrelated e-business strategies that focus on customer relationships, resource planning, order management, and supply chains.

Rather than a totally different, more complex way of doing business, as some fear, e-business is a more effective way of doing business as usual. E-business integrates and extends conventional business process strategies through the convergence of computing, networking, and communications technologies. It enables new and more efficient models of business interaction and streamlined enterprise operations. Like any technological enhancement, its goal is to improve business processes to benefit the bottom line.

This paper will discuss the rationale and benefits of online communication and collaboration via Internet implementation. It will also highlight some of the latest developments and trends going forward and address what the future holds for e-business in the oil industry.

Looking beyond the fundamental implementations, such as setting up a web site to market products, we will discuss a working model for launching far-reaching e-business initiatives that deliver products and services to the E&P arena.
Overcoming Deepwater Cementing Challenges in South China Sea, East Malaysia
Authors: Hampshire Kenneth , McFadyen Mike , Ong Dominic , Mukoro Patrick , Elmarsafawi Youssef
Published: December 2007

There are many factors to consider in the design and execution of a cement job for deepwater operations in the South China Sea. These factors include the abnormally pressured sands with high probability of shallow flows, presence of gas hydrates, low-fracture pressure formation, low bottomhole circulating temperature, and low seabed temperatures.

There have been 14 deepwater wells, offshore Sabah, Malaysia, that were successfully drilled to objective under these challenging conditions. This paper presents a few selected case histories from the project, describing the solutions-oriented approach to these problems. Also included is a discussion of the extensive laboratory tests performed to formulate the lightweight, gas-tight cement slurry at low bottomhole and seabed temperatures, and recommended practices for drilling and cementing.

Due to low-fracture-gradients associated with the deepwater environment, lightweight slurries were required to complete the cementing operation without losses. To reduce the risk of destabilizing gas hydrates, the slurries were designed to generate low heat of during their hydration and setting. Slurries were also designed with low porosity, using special additives to prevent gas migration through them during the setting process. Because of the low temperature at the seabed 1.7 °C (35 °F), special additives were required to obtain a short critical hydration period (CHP), early compressive strength development, low set-cement permeability, low fluid loss, and zero free water and sedimentation. An engineered solution was used to predict and simulate the temperatures during the cementing operation, and the simulated results were applied to improve the design.
Next Generation Expandable Liner Applications
Authors: Innes Gareth , Metcalfe Paul , Hillis David
Published: December 2007

Expandable tubular technology is gradually becoming mainstream. However, many of the early products released to the industry utilized basic expansion concepts and their designs were compromised by the reliance on conventional techniques such as cementing.

This paper looks at the evolution of various expansion concepts and how increased understanding of such techniques is now being fed into the next generation of expandable tubular based products. The paper discloses newly developed expansion techniques, discusses the FEA and analytical test results, which have allowed improvements in design, and shows how the restrictions synonomous with conventional expansion techniques have been removed.

Field case histories are discussed to illustrate progress made with these next generation expandable liners.
Making Steerable Bits: Separating Side-Force from Side-Cutting
Authors: Gaynor Tom , Chen David C-K.
Published: December 2007

PDC bits are often designed to side cut for a better steering capability. However, these high side-cutting bits come with the costs of bit whirl and hole spiraling, resulting in bit and BHA/MWD failures and poor hole quality. Long-gauge bits are known to reduce bit vibration and produce high quality wellbores. The question is then "can long-gauge bits – which by their nature do not side-cut – be used to drill directional wells?" To solve this puzzle, Halliburton Energy Services has been studying the use of long-gauge bits with steerable motors and rotary steerable systems. The results show that BHA steerability is mostly determined by the side force of the BHA, not the side-cutting capability of the bit. Therefore, with an appropriate BHA design long-gauge bits can perform as well as the short-gauge bits.
Simulation Analysis of Microbial Well Treatment of Bokor Field, Malaysia
Authors: Ibrahim Zahari , Omar Mohd Ismail , Foo Khor Siak , Elias Ezrin Johanna , Othman Mohamad
Published: December 2007

A total of eight wells in Bokor field, Sarawak were subjected for microbial treatment using the huff and puff method. All treated wells responded differently to the treatment. Increased gross liquid production and reduced water-cut were the primary means of net oil gained in some of the wells while others showed no significant changes after treatment. Well production performances and laboratory analysis are insufficient to conclude these discrepancies.

To further evaluate and understand the well performances, an extensive simulation study has been conducted using the CMG-STARS simulator on two treated wells, which are B-1 and B-3. The simulation results were compared and matched to the actual well production trends to verify the well model built. Sensitivity analysis was performed to quantify various possible treatment impacts. The approach developed successfully represents the well responses and gives an insight look at the microbial behavior responsible for oil recovery.
Looking Behind Casing: Evaluation and Application of Cased-Hole Resistivity in Saudi Arabia
Authors: Ma S. M. , Al-Ajmi F. A. , Al-Shahri A. M. , Al-Behair A. M.
Published: December 2007

Logging through casing is an important measurement for reservoir surveillance in mature fields. In the last 70 years, thousands of producers have been drilled in Y field, Saudi Arabia, and many are producing water. Successfully identifying by-passed oil and monitoring oil/water movements are critical for successful management of the Y field.

In this study, cased-hole formation resistivity (CHFR*) was field tested and evaluated in two wells in the Y field and in a third well in Z field. The three tests cover the following conditions; carbonate and shaly sand reservoirs, vertical and horizontal wells, and oil producing and water injection wells. In general, the CHFR measurements agree well with the open-hole wireline and LWD logs. In low and high resistivity reservoir intervals, differences were observed. To address these differences, CHFR theory is reviewed and application conditions of CHFR logging are discussed. Guidelines for future CHFR jobs are presented.
Applications of Stress Field Modelling Using the Distinct Element Method for Petroleum Production
Authors: Camac Bronwyn A. , Hunt Suzanne P.
Published: December 2007

The distinct element method was first introduced in 19711 and has been progressively developed over the past two decades. It is described as a finite difference distinct element, numerical modelling method (DEM). The method was implemented in the computer program UDEC (2D and 3DEC (3D)2 and its major application to date has been in the field of rock mechanics and mining engineering. In this paper we demonstrate the applicability of this method to the production of hydrocarbons.

The method can be used to model 3D stress fields in a petroleum basin or field setting. It has been shown previously that stress field model data is consistent with actual borehole breakout data and hydro-fracturing measurements3. The modelling methodology can be used to calculate fluid potential and hence used to associate crustal stress, hydrocarbon migration and accumulation. By monitoring disturbances to the syn-production stress field estimation of the residual oil potential can be achieved.

The work initially presents via sensitivity analysis the generic effect of faults and horizon boundaries on the mean local in-situ stress field. A case study is presented whereby the fault geometry for the Big Lake Field in the Cooper Basin of South Australia is modelled using DEM. Predictions of the spatial distribution of hydrocarbon accumulations and pressure gradients using the model were found to be accurate. Subsequently the model is adapted to account for production and the resultant pressure changes over time, which can lead to the prediction of residual hydrocarbon distributions.
The Performance of WAG in a Stratified Reservoir, Hassi-Messaoud Field, Algeria
Authors: Drid Nabil , Tiab Djebbar
Published: December 2007

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

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

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

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

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

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'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

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

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

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

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

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.
New Technologies Enhance Operational Efficiency in Difficult Gravel-Pack Operations
Authors: Lima Everaldo , Pounds Rob , Borin Gustavo Ribeiro , Pereira Alexandre Zacarias Ignacio
Published: December 2007

Although extended reach and horizontal wells in deepwater fields have presented many difficult challenges, operators have been willing to accept the challenges because of the substantial net reserves that the deepwater fields offer. Unfortunately, although promising new technologies that target the more extreme conditions inherent to deepwater completions have been introduced, many operators have hesitated to try them because they lack proven track records. Fortunately, this has not been the case with one operator, and this paper will discuss the innovative technologies that were employed to successfully perform two "firsts" in gravel pack completions in complicated wellbore scenarios in a deepwater subsea field.

The first job is the longest deepwater horizontal gravel pack (HZGP), run in Brazil. 75,000 pounds of gravel was placed in a 2,730-ft openhole section in 2,621 ft of water from the Ocean Alliance rig. The technologies that were instrumental in the success of this completion included special packer technology, a multi-position weight down tool with a HZGP pressure maintenance assembly, and a new type of sand control screen. Despite the long slant section (6560 ft @ 60 degrees) and openhole length, installation of the sand control completion was smooth, never reaching more than 10,000 pounds of drag.

The second job used a realtime operations (RTO) data acquisition and visualization system during a gravel pack procedure. The system employs advances in traditional data management and networking to allow the personnel at the wellsite as well as all remotely stationed personnel to monitor critical well parameters so that immediate decisions on procedural changes can be made. The system allowed the service personnel and operator to monitor the job's execution and adjust pumping parameters as needed. This job illustrates the enhanced capabilities that can be gained from adapting innovative techniques to traditional procedures.

The best practices from these completions will be used in all future jobs. This paper illustrates the importance and gains possible from considering new technologies and applying them where feasible.
Apache Energy – Knowledge Management System
Authors: Attwell Shane , Moses Michelle
Published: December 2007

Apache Energy has implemented a system which provides data from real-time well head process data to continuous month to date production information available to head office and joint venture partners over the internet.

Apache is one of the largest gas produces in Australia with assets in Australia and overseas. There are several different Joint Ventures (JVs) involved in the various fields and processing plant. The operations are spread between Offshore, Varanus Island, Perth and Houston. Joint venture partners are located in Adelaide, US, Perth and Kuwait and gas customers are located throughout Western Australia. Such diversity requires effective information distribution.

Over the last 5 years, Apache has implemented a process information management system, which enables production data to be transmitted securely all over the world, minutes after the end of each production day.

Production data business flow commences with Apache's customers placing orders or "nominations" via the web based gas nominations system. The nominations are validated against the customer contracts, collated and the total gas production for the day is electronically issued to the operator. At the end of the gas day, production, well, and facility performance data is collected automatically and presented to the operator for validation. Once validated by operations, the data is loaded into the Production Reporting System (PRS) database and a series of applications are executed such as; Well allocationSales gas reconciliationJoint Venture partner splits.Environmental calculations

The data is then released to the Apache users and the Joint Venture partners shortly after the end of the 08:00 production day. The data is also released on to the Internet under a security system which allows Joint Venture partners to view production, inventory/lifting and monetary splits between the JVs for the month. Environmental reports are issued to the government via internet pages. In addition to production data, the system provides engineers and management with remote adhoc real-time process data.

Use of this system has enabled the engineering groups to identify well problems resulting in production benefits. Apache has been able to significantly reduce the amount of time required to provide JV reports and JV payments and double handling of data has been virtually eliminated. The goal of entering data once, at the source, has largely been met.

This paper will address the processes and business benefits Apache have observed from this knowledge management system.
Real Time Geosteering of High Tech Well in Virtual Reality and Prediction Ahead of Drill Bit for Cost Optimization and Risk Reduction in Mumbai High L-III Reservoir
Authors: Mitra Partha P. , Joshi T. R. , Thevoux-Chabuel Hugues
Published: December 2007

The Geosteering of high tech horizontal wells through thin reservoir sections is always a challenge. If the entire operation of real-time LWD Geosteering is monitored in a virtual reality environment, a near reality wellbore drilling situation can be simulated through stereoscopic projection within a modeled reservoir for better understanding and interpretation of a complex problem. This has significant benefits in reducing the rig wait time for critical decisions. Additionally, it provides the tremendous advantage of using the expert multi-disciplinary team at the base thus reducing the risks of drilling a less than optimal well.

The Mumbai High L-III reservoir is a highly heterogeneous multilayered carbonate reservoir on the continental shelf of western India in the Arabian Sea. As a part of ongoing redevelopment program, multiple horizontal wells are being drilled through thin productive layers. This paper describes a successful Geosteering application using the latest technologies to transfer, edit and analyze information in real time. Real-time LWD data were transmitted via the INSAT 3B satellite from the offshore drilling rig to the Virtual Reality Centre in Mumbai City, India. Seamless sharing of data between the service company and the Reality Centre was achieved using the recent WITSML 1.2 data transfer standard. Real-time LWD, seismic and drilling data were integrated to monitor the drilling progress. A pre-defined geological model was used to model the LWD data. The planned and actual well trajectories were continuously updated while drilling. The geological model was updated based on the comparison between real-time and modeled logs. Instructions regarding mid course corrections were conveyed to the drilling engineer at the rig. The technology helped to optimize the well path, maximize the productive interval and avoided unproductive rig time.
Balancing Recovery of Upside Reserves Against Subsurface Uncertainties, West Patricia Field, Offshore Malaysia
Authors: Prasetyo Teguh , Lasman Mohd. Reza , Firth Andy , Jamiran Mohd. Khalid
Published: December 2007

Oil was discovered at West Patricia Field in December 2000, thirty-seven years after the first exploration well was drilled. A fast track three-well appraisal and six-well development program followed the discovery, which led to oil production in May 2003.

The initial interpretation of logs, core and image data from the first four exploration and appraisal wells suggested that the West Patricia oil reservoirs were deposited as stacked channel sands in a lower coastal plain setting. However additional data from wells drilled during the initial phase of development, suggested that these reservoirs were more widespread and that they were stacked river mouth bar sands deposited in an estuarine lagoonal setting. This change in depositional concept has resulted in a reserves increase of 50%, which led to an increase in development scope in order to ensure optimal reserves recovery. A field development plan was recently concluded to further develop the field in 2004.

Despite this upside, several uncertainties remain. Pressure data and fluid distribution indicate that the field could be more compartmentalized than can be interpreted from seismic and that multiple gas-oil-contacts and oil-water-contacts may be present.

This paper describes the integration of sedimentological, stratigraphic and fluid pressure data to optimize reserves recovery from the West Patricia field whilst managing the remaining uncertainties.