bluuebunny/crossref_metadata_2025 huggingface dataset:
Start-up of Broom Field as Subsea Satellite to Mature Heather Field, Northern North Sea, UKCS
Authors: Morel E. H.
Published: December 2007

Broom field commenced production in August 2004. As the first subsea satellite development of Heather field, which has been on production since 1978, significant changes have had to be made to the Heather platform to accommodate the new production. Broom is now producing about 25 Mbopd from three production wells, compared to Heather's 2500 bopd from eight producers.

Broom development costs were kept to a minimum in order to minimise borrowing requirements and reduce financial exposure in case only low-case reserves were realised. This low-cost strategy has meant that post-development production has been less easy to optimise than in more conventional developments. Examples of this are the lack of inter-field fiscal metering, and use of low resolution instrumentation on the Broom manifold. However, the inclusion of a subsea multiphase flowmeter, and downhole gauges, has helped to maximise Broom production by providing information on reservoir connectivity and well lift performance. Actual performance has been close to the Development Plan's P50 expectations.

By contrast Heather production has suffered significantly as a result of the Broom development. Initial plans anticipated that Heather platform process capacity would not be much affected during topsides modifications. However, this has not proved to be the case, and the water injection and gaslift required to sustain production have not been available during much of the modifications' period. Other major factors have been manning restrictions on the platform, the lack of deck space for well intervention during platform topsides modifications, and the requirement to minimise gas flaring during commissioning. These have had the impact of reducing Heather production to about half the pre-Broom era rate, with consequential impact on field economic performance.

This paper describes the impact that the modifications required for Broom field development have had on the Heather field production, and the performance of Broom field in the first year of production. The relative benefits and difficulties created by the use of turnkey contracts for the drilling and subsea elements of the Broom development are compared to a more traditional contract for the brown-field modifications on the Heather platform.
Floating Units Integrity Management And Life Cycle Enhancement
Authors: Lanquetin B.
Published: December 2007

Floating units are an integral part of offshore field development schemes. This paper describes the tailor-made methodology developed by our Company for the integrity management of eight major complex floating units in operation worldwide and four units under construction.

This program is being progressively implemented throughout 2004-05 with the assistance of selected service companies providing efficient modeling tools as a part of life cycle management and emergency response. These units cover converted and new built FPSOs, concrete and steel structures, shallow and deep water locations, moderate and severe environment conditions, ship and box shaped units as well as one TLP and one Liquefied Petroleum Gas unit.
The Dynamic Bottomhole Pressure Management: A Necessity to Gravel Packing Long Horizontal Wells With Low Fracture Gradients
Authors: Chen Z. , Novotny R. J.
Published: December 2007

Unconsolidated formations are commonly found in offshore reservoirs where long and ultra-long horizontal wells are required to produce heavy oil economically. The main characteristics of these reservoirs include high permeability, large porosity, low fracture gradients and sand production. Gravel packing is proven as an efficient and cost-effective sand control practice for these completions and formations. The quality of the gravel pack and effective sand control play a major rule on the ultimate success of oil and gas production from these reservoirs.

Successful placement of the gravel pack completion requires that these low fracture gradient wells not be fractured during gravel placement to avoid excess leak-off and premature screenouts. This paper addresses several key factors that must be considered carefully in installing a successful gravel pack completion. The dynamic pressure management scheme becomes critical to maintain the bottomhole pressures in the required range for a successful implementation of the gravel pack. These include designing an optimal screen-wash pipe annulus during Alpha-Beta wave packing, an optimal Alpha wave height, the use of mechanical device to reduce frictional pressure during Beta wave building up, and the use of multiple Beta wave packing rates.

Several job designs and application histories are also presented in the paper to demonstrate the design considerations and valuable lessons learnt. The overall system of fluid dynamics is discussed and treatment guidelines are presented to provide the Completion Engineers the necessary information for designing successful treatments.
Acute Leukemia and Benzene Exposure—A Case Study
Authors: Al-Qahtani S. Y.
Published: December 2007

This paper discusses an actual case that occupational (industrial) hygienists may encounter during their professional career. The case involves establishing a cause and effect relationship of a medical condition that had already taken place in the past. An approach is discussed where an attempt was made to reconstruct the workplace environment within which the medical condition in question may have occurred.
Cognitive Biases in the Petroleum Industry: Impact and Remediation
Authors: Welsh M. B. , Bratvold R. B. , Begg S. H.
Published: December 2007

It has been repeatedly demonstrated [1–5] that humans are prone to what are called cognitive biases - discrepancies between calculated, optimal decisions and those made using intuition. Such demonstrations of cognitive bias in expert decision makers, however, are often criticized on the basis of their content being irrelevantto the participants.

We present results of a study, based on a range of questions designed to highlight a number of well-known biases and including an extension of Capen's [1] study of overconfidence in SPE members, put to industry personnel from a variety of companies. To limit the objection raised above, all questions related to the O&G industry. The authors discuss the biases exhibited and their potential impact on Oil and Gas industry decisions with a special focus on remediation.

Despite domain familiarity, industry personnel exhibited a range of cognitive biases indicating that, in accordance with the literature, familiarity with subject material does not remove their impact; nor does industry experience alleviate it. The authors conclude that the biases demonstrated are likely to already be impacting industry decisions.

The effect of having had specific risk training is also discussed in light of the results herein with the conclusion that, if risk training does have a beneficial effect, said effects are largely eroded by the passage of time.

Finally, we argue that a better understanding of the biases that can affect decisions made within the industry, not just in terms of their existence but also their mechanism of action, will allow more meaningful attempts at remediation. It would also allow current techniques designed to lessen bias impact to be examined critically and both the strengths and weaknesses of these processes to be exposed.
Understanding the Environmental Impact of De-Commissioning; the Established Marine Ecosystem Associated with Offshore Platforms, Brunei Darussalam
Authors: Holyoak S. , Oakley S. , Elder J. , Bell D. , Miller L.
Published: December 2007

Proposal

To many, the offshore production facilities punctuating the skyline are probably seen as something of an eyesore. However, the divers who have viewed these structures beneath the waves realize that they provide the foundations for a well- established marine ecosystem.

The Platform Environmental Project commenced in early 2003. The objectives were to document the species distribution on the platforms, and develop an understanding of the controlling influences. The team of divers executing the project received training and ongoing technical supervision from the Tropical Research and Conservation Centre, based in Kuching, Sarawak.

Separate survey techniques were developed to address the following: Small Non-Mobile Species (such as small sponges, ascidians and hydroids)Large Non-Mobile Species (for example black corals, large sponges and gorgonians)Fish Species (Reef Dwelling, Reef Associated and Pelagic)

Environmental parameter surveys were combined with historical Brunei Shell Petroleum wave, current and temperature data to assist in developing an understanding of the species distribution.

The project has demonstrated that there is a diverse and well-established ecosystem beneath the platforms. Approaching 100 fish species were photographed and identified. The majority of these are resident, but pelagic species such as trevally and barracuda regularly visit. Hawksbill Turtles are often seen feeding on sponges and soft corals on the bracings. All available sub-stratum is populated by a diverse range of small non-mobile species, and certain platforms are characterized by impressive growth of black coral. A marked vertical zonation is also evident, due to variation in factors such as ambient light levels, salinity and turbidity. Large numbers of juvenile species have been recorded, pointing towards the platforms as being both producers and attractors of fish.

Ultimately Brunei's offshore structures will be decommissioned. Globally, various options exist, ranging from complete removal to leaving in place. However, opinions and legislation are strongly divided with respect to the best course of action.

With several thousand offshore structures worldwide, decommissioning will become an increasingly important issue. This project and others like it will play a role in ensuring that balanced decisions are made, based on all the available evidence.
Responding to a Potentially Trans Boundary Oil Spill
Authors: Sintian C. , Yusof M. R. , Othman A.
Published: December 2007

On 18th October 2004, crude oil leak from a sub-sea pipeline transporting crude from offshore oil fields to an onshore crude oil terminal spilled into the South China Sea, 2km off the southwest coast of Labuan Island. Within one hour, oil slick landed on a public beach, and two days later was spotted on a Marine Park beach, about 35 km from Brunei waters.

PETRONAS Carigali's Emergency Control Centers were activated, and relevant agencies were notified immediately. A Tier 1 response was upgraded quickly to a Tier 2 response coordinated by Labuan Beach Cleanup Committee, consisting of members from various government authorities, oil and gas industries, NGOs and the Petroleum Industry Malaysia Mutual Aid Group (PIMMAG). Great efforts were put in to prevent the spill from moving to Brunei waters, which could have escalated into a more complicated Tier 3 response, and activated the Malaysia National Oil Spill Control Contingency Plan and Standard Operating Procedure for Malaysia and Brunei Darussalam.

Established Emergency Response Plan, Oil Spill Contingency Plan and Notification Procedures, coupled with established working relationship with the members of Labuan Beach Cleanup Committee has contributed to the quick 18-day cleanup operations. The use of proper equipment and dispersant, deployment of oil spill response experts and more than 500 oil spill responders has also contributed to the successful cleanup operations.

A post cleanup environmental impact assessment was conducted and concluded that impacts were localized and temporary, with no significant damage to the marine environment. The presence of gastropods, crustacean and fishes at the spills sites within weeks after the cleanup operations indicates good biological recovery.

This paper demonstrates the importance of collaboration between the government agencies and the industries in order to effectively respond to the spill. It also discussed the problems encountered and overcome along the way. This experience proves that an oil spill event can be responded quickly to, economically, and with minimum environmental damage if there is proper planning, effective communication, coupled with a highly cooperative response organization.
Going from "Good to Great" in a Good Industry
Authors: Burtch S. D.
Published: December 2007

The oil and gas industry has achieved safety performance beyond most other industries. Yet, the journey from "good to great" safety management can create the foundation for great business performance.

The journey goes beyond technical excellence to cultural transformation. Leadership must build the case for becoming "great", and engage their workers to create a safety vision, understand barriers and co-lead implementation.
Oil Spill Response Management and Transboundary Issues in Malaysia
Authors: Wing C. K.
Published: December 2007

With nearly 4800 kilometers of coastline, Malaysia is particularly exposed to marine oil pollution. Nearly 60,000 ships transited the Straits of Malacca annually and the depth at One Fathom Bank is barely six feet. The Malacca Straits is congested with shipping and many cases of piracy had occurred. Imagine a scenario where a laden crude oil tanker were to run aground or collide with another ship for whatever reason, and release thousands of barrels of crude oil. Unlike the Prestige incident, the littoral states cannot tow the stricken tanker to deep water and sink it there. We have seen that the action or inaction of a littoral state can jeopardise the coastline of the entire region.

The Malaysian National Oil Spill Contingency Plan (NOSCP) was formulated to control oil spill occurring within Malaysian waters, including the Exclusive Economic Zones (EEZ) located within the Straits of Malacca and South China Sea, as well as Brunei Bay, Sabah and Sarawak waters and the Sulawesi Sea. The NOSCP aligns with the ASEAN Oil Spill Response Action Plan (ASEAN - OSRAP) for regional cooperation to deal with transboundary oil spills in the Straits of Malacca and bordering Asean countries.

However, the ASEAN-OSRAP is yet to be tested under real Tier-3 oil spill conditions.
The Success Services of the Drilling HSE Networks
Authors: Yussof H. S. B. H. M.
Published: December 2007

A HSE Network team was formed early in 2003, to address a discerning trend in total recordable cases within the Brunei drilling community. The team comprised of representatives from Brunei Shell Petroleum (BSP) Well Engineering (TSW) and its associated Service companies.
Canopy Bridges Along a Rainforest Pipeline in Ecuador
Authors: Thurber M. , Ayarza P.
Published: December 2007

One of the most significant social-environmental and construction challenges for pipeline installation in primary tropical rainforest is preventing the secondary impact of deforestation and land-use conflicts. Occidental Petroleum in Ecuador and WALSH developed an innovative technique of constructing a pipeline right-of way (ROW) in the lowland rainforest of the Ecuadorian Amazon without a permanent road and leaving canopy bridges to facilitate migration of arboreal mammals.
Continuing Medical Education Incentive Program
Authors: Krigovsky P.
Published: December 2007

In today's rapidly changing world, medicine is not only changing but also expanding. The delivery of optimal patient care is dependent upon medical practitioners staying abreast of these changes as well as maintaining their current skills. One of the challenges facing medical practitioners in our industry is sufficient exposure to, and participation in, emergency medical procedures. This pilot Continuing Medical Education Incentive Program has focused on assessing active participation in emergency drills and retesting within a six month period, thus quantifying to what degree these skills have been retained. If successful, this program would be expanded to encompass the learning of new information and skills sets.
Effects of Risk Communication on the Behaviour of Workers Towards Health Risks
Authors: Farid M. Z.
Published: December 2007

The lack of awareness on Industrial Hygiene among industries is one critical factor in their performance in this area. While industrialized nations like those in Europe and the United States may have a host of regulations in this aspect, others may have a few. In Malaysia, there are specific regulations pertaining to Industrial Hygiene for example that of Lead, Asbestos and Noise exposures and more recently in 2000, on all Chemical Hazardous to Health. More often than not, these regulation and guidelines are the only means of information on health hazards available to both employers and employees.

Informing workers on noise and chemical hazards may sound trivial. However, without effective communication on the implications of these regulations, and most importantly the effect these hazards have on their personal health, information is merely passed on but not internalised via behaviour, making it a futile attempt to safeguard the health of our workers, which may result in a serious decline in health of our current workforce, later, as a result of exposures to health hazards occurring.

Behavioural intervention attempts to influence workers' attitude, knowledge, beliefs, and hence behaviour. Such interventions include sharing information or carry out educational campaigns, skills training, risk communication, and/or behaviour modification techniques. Specific examples commonly used include training workers to wear personal protective equipment and implementing behaviour modification techniques such as giving positive feedback and incentives, targeted at changing individual health behaviour and to reduce the accompanying risks.

This study involves pre and post exposure monitoring of workers exposed to solvents plus observation of glove wearing, in this regards the behaviour intervention technique used was a one-on-one communication of the risk of the exposure to solvent of solvents via discussion and a take-home information leaflet. Effective communication is the key term and issue here. The right information must be given to the right people, in the right way. This paper demonstrates different reactions towards and different factors influencing effective communication as well as the means to maximise the outcome of health-risk communication.
Automatic Filtering and Monitoring of Real-Time Reservoir and Production Data
Authors: Olsen S. , Nordtvedt J. -E.
Published: December 2007

This paper addresses data filtering and compression of reservoir and production data. Up to now such filtering has been done either manually by the engineers or through filtering techniques - such as wavelets - by expert users. In both cases the data filtering and compression is quite a time consuming exercise for the engineers. It has been demonstrated that filtering and compression of data quite successfully can be done using wavelet techniques. However, automatic filtering and compression is needed in order for the wavelet techniques to be applicable for real-time reservoir and production management. The "automated wavelet" has not been available due to manual determination of filter settings and the large computational effort associated by running wavelet transform rapidly in a real-time environment.

This paper presents and demonstrates a methodology for solving all these problems, allowing wavelet-based de-noising and compression of large amount of data with a minimum of non-expert engineering effort and a minimum of computational effort. The methodology has been successfully tested on several real-time reservoir and production data sources. The filtered data can be used for real-time monitoring, and we demonstrate how transients, underlying trends, noise level and slugging (oscillations) can be monitored using the real-time wavelet transform. A slug number is introduced for slug detection, while a pattern recognition approach is applied for transient detections.
Some Insights into the Tube Blocking Test Method to Evaluate the Efficiency of Mineral Scale Inhibitors
Authors: Bazin B. , Kohler N. , Zaitoun A.
Published: December 2007

The Dynamic Tube Blocking Test (TBT) method is used to evaluate the efficiency of chemical inhibitors to prevent the formation and deposition of mineral scales such as calcium carbonate, as well as calcium, barium and strontium sulfates. The TBT method aims at (1) determining the Minimum Inhibitor Concentration (MIC) required to prevent the formation of scale, and (2) performing comparative tests with different inhibitors in the same conditions.

Inhibitor efficiency is measured by the ratio of the time needed to block the tube in the presence of inhibitor divided by the time needed to block the tube without inhibitor, i.e. blank time. Conditions for the blank test are adjusted to induce a significant precipitation in a reasonable time frame. Main adjusting parameters are solution degree of saturation of scaling species and flow rate. Other parameters such as capillary length and diameter can be chosen arbitrarily.

The purpose of this study is to check the accuracy of the TBT method and to compare the MIC values obtained in various experimental conditions. Three types of inhibitors were used, namely, phosphonates, polyacrylates, polyaspartates and a carboxymethylated polysaccharide. Scales were calcium carbonate, calcium sulfate and barium sulfate. The results show that the TBT method is very sensitive to the effect of flow rate and capillary dimension. A careful control and monitoring of the temperature is also required. The TBT method is shown to give information on the physical mechanisms acting on the scale inhibition process.
Water Control in Fissured Reservoirs–Diagnosis and Implementation of Solutions: Cases From Northern Italy
Authors: Burrafato G. , Pitoni E. , Perez D. , Cantini S.
Published: December 2007

This paper presents the results of successful applications of polymer gels to control undesirable water production in mature fissured reservoirs in northern Italy.

The presence of natural fractures creates hydraulic communication through an interval to the high-pressure aquifer. This allows the water to percolate up to the production interval causing a negative effect upon the oil production. This situation represents one of the most complex problems to diagnose and solve.

The shutoff of water produced through fissures and fracture networks involves injection of gel solutions of polymer, maturely crosslinking inside the reservoir. The ability to inject these polymers and their subsequent long-term stability under reservoir conditions are requirements for a successful treatment.

Two case studies are provided where a systematic methodology was employed to correctly diagnose and solve this type of problem.

The first case discussed is where a bottom zone was finally shut off. Diagnosis through production logs permitted us to understand the situation and treat the problem accordingly with the use of flowing polymer gels. Wellbore isolation from the upper oil-producing level was achieved with an inflatable cement retainer set in a blank casing section. The treatment and setting of the plug were performed through coiled tubing.

The second case treatment was performed under challenging technical and operational conditions due to high injection pressures (9000 psi) and elevated temperatures (165°C). The applied methodology included the use of diagnostic plots based on the historical behavior of the water/oil ratio as a function of time, cement bond logs, a pressure and temperature survey during actual production to determine the origin of the water influx, and the simulation of the bottomhole temperature (BHT) profile. Gel characteristics are also provided along with details of laboratory testing and procedures.

Both cases illustrate the use of the dual-injection technique, which involves simultaneous injection of permanent gel into the water zone and protective fluids into the oil zone, followed by a post-flush stage to eliminate gel from potentially productive fissures.

Pre-and post-treatment production data,analysis,and evaluation of results are included in both cases along with production and gel stability data with time.
The Environmental Benefits of Reducing Water Production
Authors: Hibbeler J. , Rae P.
Published: December 2007

Proposal

The Gulf of Thailand (GOT) has been producing oil and gas for approximately twenty four years and, at present, water production is becoming a serious dilemma for some operators. Because most of the production from the GOT is from co-mingled monobores, having multiple pay sands of highly variable permeability and natural fractures, the risk of early water production is high. Unwanted water production in Thailand has resulted in many of the classic negative effects such as, water "loading", causing lost production and reserves, bottlenecking surface facilities and increased operating costs, due to water handling. Because tourism and fishing are critical to Thailand, the environmental impact of produced water is also a major concern. Several initiatives have been undertaken to address the issue of how best to reduce water production. Companies have tried tubing patches, water shut off treatments and, most recently, Relative Permeability Modifiers (RPMs), which selectively inhibit water flow while having minimal effect on oil or gas production. Such remedial treatments, combined with top-side efforts like water injection, are being used in an effort to minimize the overall effect of produced water in Thailand.

This paper presents, in a holistic approach, the issue of produced water in the GOT. Discussion of environmental issues, costs, disposal options and various methods that have been applied to deal with water production, are covered.
Sw and Hydrocarbon Pore Volume Estimates in Shaly Sands—Routine Oil-Based-Mud Core Measurements Compared With Several Log Analysis Models
Authors: Woodhouse R. , Warner H. R.
Published: December 2007

Routine laboratory measurements of preserved oil-based-mud (OBM) cores are used to calibrate reservoir porosity (Φ) and water saturation (Sw). As well as being accurate in ‘clean’ sands, properly conducted OBM core analysis is also accurate in shaly-sand reservoirs. The water volume measured by laboratory Dean-Stark extraction includes physically-bound water within the clay, but not its chemically-bound water.

The OBM core porosity, Φcore, and Sw can be used together as a pair and will lead to an accurate evaluation of hydrocarbon pore volume (HPV) per unit rock volume. HPV evaluations from the OBM ‘core’ [Φcore (1 - Swcore)] and from log-derived ‘total’ porosity [Φt (1 - Swt)] and ‘effective’ porosity [Φe (1 - Swe)] methods should all give the same result.

Core data from a shaly-sand formation are compared with results from some widely-used log analysis models, including the Archie models. The original Waxman-Smits-Thomas model is discussed, but we had insufficient data to include it in the quantitative comparisons.

As tested, a reasonable quality match to the OBM core Swt and HPV is given by the Normalised Waxman-Smits and Dual-Water models and also by the Modified Simandoux, Indonesia, Simandoux and Cyberlook models, when their outputs are taken as total water saturation (Swt). If their output is taken as the usual Swe, together with Φe, their HPV results are significantly lower than those from the OBM core data.

The most accurate evaluation method, the OBM core analysis, can be used to calibrate shaly-sand log models. This process will lead to improved estimates of oil- and gas-in-place in shaly sands, and also to better resistivity-Sw models for worldwide application when OBM cores are not available.
New One-Trip Sand-Control Completion System That Eliminates Formation Damage Resulting From Conventional Perforating and Gravel-Packing Operations
Authors: Garfield G.
Published: December 2007

Proposal

Maximizing inflow performance for any completion involves balancing the natural forces of the reservoir with the operational limitations of the well or field. In the case of soft or unconsolidated sand, completion procedures often dictate equipment or procedures that can potentially limit the inflow area by way of various forms of formation damage. There are three major operations that induce formation damage: the filter cake and fluid loss damage associated with drilling; the skin increase due to compaction and debris associated with perforating; and, the skin added to the completion by the gravel or frac pack. While there are treatments that can remove or reduce the effects of damage, all of them involve subsequent intervention into the well, which elevates risk as well as increases rig time. This paper discusses a recently developed one-trip completion system that has been successfully used to eliminate or reduce these causes of formation damage and improve inflow area and performance. This new system provides a means of deploying a production liner, perforating, primary cementing, removing filter cake, and controlling sand production in a single trip. The one trip system is especially beneficial in wells needing sand control. The procedure utilizes a telescoping conduit that can be expanded hydraulically, mechanically, or both, to seal onto the formation face, and then cemented into place. The sand control media is inside the telescoping conduit in the form of appropriately sized stainless steel beads. The damage typically associated with the perforating phase is eliminated because there is no explosive discharge during the deployment of the system, and the well is brought on production normally. Studies have shown that decreasing initial perforation damage results in a more productive well over its lifetime. This new completion method also eliminates gravel packing, minimizes the amount of intervention into the well completion, and saves substantial rig time due to its one trip operation. Additionally, the authors will illustrate how the new completion simplifies operational logistics, especially in remote or offshore environments, because it is not dependent on large fluid pumping treatments nor does it require excessive pumping horsepower.
Oil Spill Response Organisations and Their Utilisation in Disaster Relief
Authors: Richardson C.
Published: December 2007

On the 26th December the biggest earthquake in 40 years occurred between the Australian and Eurasian plates in the Indian Ocean. The quake triggered a tsunami – series of large waves – that spread thousands of kilometres over several hours.

A number of the major oil companies around the world utilised their own oil spill response aircraft, from the East Asia Response unit in Singapore, for the International Federation of Red Cross (IFRC) to use for delivering of aid material to victims of the Tsunami disaster.

The oil spill response industry have an obligation to respond immediately to international oil spill disasters, we are quick to react and have the environmental benefit as our main driver, why should this be any different in responding to other major environmental disasters? This paper will investigate the utilisation of global oil spill response equipment and personnel in aid of disaster relief. Oil spill response units like OSRL and EARL, and many more around the globe run as not for profit cooperatives, thus the commercial need will not be a driving factor in a venture of this type.

Although analysis of the practicalities involved in using such specialised equipment and personnel will be examined.

The author also hopes to investigate into the possible adaptation of such spill response resources but will also ask the question of who will pay if this new venture is considered.
Latest Developments of the Updated Fire and Explosion Guide From UKOOA and HSE
Authors: Galbraith D. N. , Terry E.
Published: December 2007

The updating of fire and explosion design guidance has been a significant project for UKOOA and HSE. The collation of best practices and latest Joint Industry Project (JIP) information has presented a challenge to provide information in a consensual way and yet push at the boundaries of known and accepted knowledge.

In 2004, the project team successfully issued Part 1 of the new guidance, dealing with design considerations for explosion hazards and a generic hazard management approach constituting a revision to the previous UKOOA Fire and Explosion Hazard Management Guide (retrospectively designated Part 0). The team are now finalizing Part 2, dealing with design considerations for fire hazards. Part 2 will be concluded later this year in parallel with the effort to develop Part 3, which will cover the implementation of the 3 previous "philosophical" documents, and as such is probably the most wanted part of the guidance, thus completing a "4 part" trilogy of documents.

This paper describes the history and intent of the guidance and the ways in which it should assist all sectors of the industry. The paper summarizes the development of ideas that have been included and are currently under consideration as well as describing some areas that have been excluded at this time as they are not sufficiently mature for general acceptance.

The paper explores the relationship with other standards and endeavours to show how a wider application may result from the accumulated "wisdom" from both Aberdeen and Stavanger, the two most prominent offshore technology centres in Europe, which are also rapidly becoming international support centres for worldwide design and operations.
Competency-Based Training and Development
Authors: Fassihi M. R.
Published: December 2007

Professional training in the oil and gas industry has traditionally focused on course requirements without emphasizing the role of competency. This, in turn, has caused an inflation of courses due to subject overlaps whilst wasting the students’ time whose skills were not considered before taking the course. In this presentation, a new training framework is introduced in which a set of required competencies for an E&P business are selected and the skill levels of 1-5 (Awareness to expert) are described for each competency. Then, by mapping the learning offers against this set, course rationalization and streamlining can be accomplished. Subsequently, a Learning Map can be created containing the core training offers. Based on this competency set, the competency requirements for a job type are specified and a job profile is created. Then, staff is assessed against the relevant job profiles. Based on the identified gaps, appropriate training or experiential activities are recommended. The sum of individual staff competency gaps represents an organizational capability gap. The business urgency may require recruiting people with the identified competencies instead of training the individuals. Thus, a targeted recruiting strategy based on organizational capability gaps could be implemented.

Petroleum Engineering Universities could potentially adopt competency based training and align their undergraduate and graduate trainings with the required job profiles by the Industry. If the latter is accomplished, students’ chances of being recruited are greatly improved. The consequential impact of this action would be potential saving of millions of dollars by the industry as part of their annual in-house training program.
Drilling Waste Management: Case Histories Demonstrate That Effective Drilling Waste Management Can Reduce Overall Well-Construction Costs
Authors: Browning K. , Seaton S.
Published: December 2007

The increasing environmental legislation surrounding drilling operations has led to a rapid rise in drilling waste management spending by operators. The traditional perception has been that this increased spending adds to well construction costs. While it true that new technology comes with a price tag, and much of the technology used in drilling waste management has been introduced in the last 10 years, many technologies now available to operators are clearly cost effective when the entire well construction cost is evaluated.

The cost of making a mistake and having either an expensive remediation project or a potential liability nearly always significantly outweighs the cost of a good preventative drilling waste management program. Further, compliance with current environmental regulations does not always guarantee immunity in the future.

The correct deployment of both new and traditional drilling waste management technologies is reviewed in several case histories taken from the global operations of a major service company. The paper demonstrates that the correct application of these technologies combined with a holistic approach to drilling waste management and drilling fluid operations results in a net reduction in well construction costs and a reduction in the potential for environmental liability.
Accounting for Earth Curvature in Directional Drilling
Authors: Zinn N. D.
Published: December 2007

In an important contribution to the geodesy of directional drilling (SPE 56013, "Directional Drilling and Earth Curvature", Ref. 1) authors H. S. Williamson and H. Wilson cite seven errors of Earth curvature often found in current oil field practice. Four of those errors relate to the use of map projections to convert cubical coordinates (e.g., those computed from Minimum Curvature) to geodetic coordinates. This paper offers an algorithm that converts cubical coordinates directly into latitude and longitude without an intervening map projection, thus avoiding these four errors plus one other of the seven cited.
Comparison of Fracture Geometries Utilizing Ultralightweight Proppants Provide Evidence That Partial Monolayers Can Be Created: A Case History
Authors: Chambers R. , Meise K.
Published: December 2007

Recent successes in hydraulic fracturing with ultra-lightweight proppants have led to much discussion and many debates as to why they have been so successful. The theoretical partial mono-layer and the difficulty associated with designing and defining a partial mono-layer in-situ has led operators to examine more fundamental explanations for the success of ultra-lightweight proppants. However, based upon careful examination, highly conductive fractures associated with very low concentrations of proppants, can provide ample evidence that partial mono-layers can be created.

This paper will compare four hydraulic fracture geometries from two wells located approximately 1,700 feet apart. Two fracture treatments were performed on each well, in Clearfork and Glorieta dolomites. The first well was stimulated with conventional fluids and proppants. The second well was hydraulically fractured with a 10 lb/gal brine water and an ultra-lightweight proppant at low concentrations. The objective of the side-by-side comparison was to determine optimal treatments for offset production and injection wells that were to be in-fill drilled.

Fracture geometries for both wells were determined from fracture mapping using microseismic imaging and pressure matching utilizing a 3D hydraulic fracture simulator. Total fracture face surface area, estimated conductivities, and effective fracture half-lengths were compared. The results of the comparisons suggest that there is strong evidence that highly conductive fractures, perhaps even partial mono-layers, can be created with the use of ultra-lightweight proppants in fluids of similar specific gravity.
Laboratory Testing and Well Productivity Assessment of Drill-in-Fluid Systems in Order To Determine the Optimum Mud System for Alaskan Heavy-Oil Multilateral Field Developments
Authors: Davis E. R. , Beardmore D. , Burton R. , Hedges J. , Hodge R. , Martens H. , Svoboda C.
Published: December 2007

The North Slope of Alaska has billions of barrels of heavy original oil in place (OOIP) residing in largely undeveloped reservoirs. Despite this large volume of heavy oil in place, the majority of reserves development on the slope to date has been focused on light crude. However over the past few years, operators have begun to develop the North Slope's vast heavy oil resource base. Recently, an optimum drill-in-fluid/formation damage minimization study was undertaken by ConocoPhillips, BP, and its partners in order to determine the optimum reservoir drilling fluid for the heavy oil sands in order to maximize well productivity and project value.

This paper will provide an in-depth look at the drilling fluid design, laboratory testing, and productivity analysis associated with determining the optimum reservoir drill in fluid (RDF) for the West Sak, horizontal, multi-lateral, extended reach, field development.

Lab test results to be reviewed will include:

Crude Compatibility Lubricity (steel to steel & rock to steel) Shale Stability General Rheology Mud Filtrate invasion tests with core to determine Return Perm Filtercake Removal tests w/ceramic disk tests to determine return permeability and removal effectiveness

With the lab test results, well productivity calculations will illustrate why an oil based mud (OBM) was determined to be the optimum drill-in-fluid for West Sak. Lab tests and inflow performance modeling show injectivity and productivity improvements associated with reducing water based filtrate invasion and permeability reduction due to water and ineffective filtercake removal.

Results show that the overall process of integrating the drill-in-fluid, completion design, inflow performance modeling, and operations procedures should be considered a best practice and an example of how an integrated study ultimately provides a field development with the best project value. Using the current field development economic model, this process added reserves, improved project NPV & IRR and maximized project economics
Light-Oil Air-Injection Performance: Sensitivity to Critical Parameters
Authors: Adetunji L. A. , Teigland R. , Kleppe J.
Published: December 2007

The objective of this study is to determine parameters that have major impact on the recovery from air injection into low permeable fractured chalk reservoirs that produce light oils, such as the Ekofisk field in the Norwegian North Sea.

Earlier works on air injection into light oil reservoirs mainly focused on mathematical modeling of air injection and also on laboratory studies. In this paper, we present results from numerical simulation study.

Results show that when recoveries from low permeability and high permeability reservoirs are compared, recovery is accelerated in the former. In addition, for maximum recovery, air should be injected into all layers containing hydrocarbons. The ultimate recovery from air injection was observed to be insensitive to the amount of water injected during the secondary recovery phase. Also, for optimum recovery, there exists a minimum temperature at which air should be injected, this temperature being a function of the injection rate. Lastly, we observed that residual oil saturation to gas does not have any significant effect on the recovery factor from air injection.

These results are only valid for single porosity systems and may not all apply to dual porosity systems. Also, no economic analysis was undertaken in this study.
Dynamic Flow Analysis of Probe-Type Formation Tests
Authors: Sheng J. J. , Georgi D. , Lee J.
Published: December 2007

Conventional techniques to analyze probe-type formation test data have been based on the principle of pressure transient analysis or on the equations of steady-state flow. The typical techniques are those associated with the spherical and cylindrical flow regimes and with steady-state drawdown solutions. Due to the intrinsic features of probe-type formation tests, such as the flow line storage effect, variable rate history, and short test duration, these techniques in practice have proven difficult to apply or inappropriate. A better suited analysis is based on the simultaneous analysis of both pressure transient and formation rate data. One technique proposed earlier is the dynamic flow analysis with the Formation Rate Analysis (FRA1,2). FRA is based on the linear relationship between the measured pressure and the calculated sand-face formation rate during the test. In some complex flow conditions, however, non-linear relationships have been observed in actual probe tests.

This paper investigates what conditions could cause the non-linear relationship, propose how to analyze such tests, and provide guidelines for repeat tests. To this end, a number of simulated probe-type tests performed under different practical test conditions are used to generate, typical non-linear pressure versus formation rate plots. These non-linear plots may resemble a skewed ellipse, an upward pointing "hockey stick", a downward pointing hockey stick, or a skewed "figure-8". Actual field tests are combined with simulation test data to investigate the conditions that could give rise to such nonlinear plots. Analytical solutions are used to justify the findings in this paper. A number of effects are investigated, including low permeability (mobility), high compressibility, high permeability anisotropy, permeability heterogeneity, upper and lower shale boundaries near the probe, duration of the drawdown, test operation parameters, and plugging and cleaning-up processes.

The methodology and findings presented in this paper can enhance the post-job analysis of formation tests from challenging environments. Based on these findings, test operation parameters can be optimized for repeated tests in real time if the first test reveals pecial non-linear dynamic flow.
An Innovative Geoscience and Reservoir Training Passport for New Recruited Engineers Worldwide as per Sustainable Development
Authors: Coste J. F. , Estival J. , Lecanu H. , Beauchamp M.
Published: December 2007

Proposal

The Oil industry has to face a significant aging of its E&P task force and its correlative retirements in a few years.

In preparation for this crew change, a consistent hiring programme of hiring is being implemented within Total both at the Headquarters and in the affiliates worldwide. Giving these new engineers the required skills quickly poses a big challenge.

Once recruited, every new engineer in Geosciences and Reservoir disciplines is given a Training Passport. In other words, he will follow a personalised curriculum corresponding to about 6 months training distributed over a 2 to 4 year r period.

This road book is designed to fill the gap between initial – on hiring - and expected skills.

For each discipline – i.e. Geophysics, Geology, Reservoir – the technical skills as well as the Personal and Management development objectives are exhaustively listed. An accurate training path comes from a skill list and the training proposal, both in-house and externally. For the Reservoir Engineering discipline, the list contains: HSE, Induction, G&G basics, Well Data acquisition and Interpretation, Well Performance, Reservoir geo-modelling and simulation, Uncertainties integration, Field Monitoring and Management, Economics, Project Management, etc…

During the Passport implementation, the new engineer is assigned to a Technical Department where he can apply what he has just learned through the specific training courses. The training effort represents on average up to 15% of the yearly working time.

Launched in 2003, the Training Passport approach is being extended to all affiliates starting with Western Africa.

The Young engineers Training Passport generates consistency in professional disciplines, and increases visibility and anticipation for all actors involved. It provides the young Headquarters engineers with required autonomy before being assigned in affiliates worldwide.

Because it is a skill driven and a long term process, the Training Passport represents a significant cultural change that efficiently allows us to meet the needs of the Company strategy.

In the Affiliates, the national engineers are trained according to Total international standards. Due to the remoteness from Headquarters, we are experiencing new training technologies, i.e. blended learning, video-conferences, for which the quality of distance coaching is essential for success.

The Training Passport approach contributes efficiently to the Sustainable Development of Hydrocarbon Producing Countries.