bluuebunny/crossref_metadata_2025 huggingface dataset:
PROACTIVE SAFETY MANAGMENT
Authors: Arias Daniel , Tucker Jan
Published: December 2007

Pan American Energy (PAE) is an Oil & Gas Company with an average production as per last year figures of 44,16 MMBOE. Production areas are located in several Argentine provinces. For the year 2000 PAE's operations logged 9.250.972 man-hours, of which 80 % are allocated to Contractors workforce.

The implementation of the actions described below was the key to awake HSE conscience in our workforce. To give an example: in 1999 our Days Away From Work Cases Frequency – DAFWCF vis-a-vis 2000 was about 63% higher.

Achieving and sustaining this level involved setting clear objectives throughout the whole PAE workforce. In other words, reduction of accidents is the result of a consistent HSE performance.

Early last year we have implemented tools such as: Critical Task Analysis, Potential Risk Cards (near/hit miss report), Advanced Safety Audits, STOP Programs, Incident Investigation Reports (Root Cause Analysis), Lessons Learned Report, in-house publications (Trabajando Seguro and HSE Forum bulletin), Safe Driving Program, HSE Forum, Internal Auditing of HSE Management System, all of them based on Risk Administration, Leadership and Commitment.

These and other useful tools in use by PAE have proved to be successful. They are the evidence of the results for 2000 and 2001 YTD in HSE performance, when compared to 1999. See table in page 4.

At present, preventive actions are fully reinforced. All employees across the board are being made part of HSE, when it comes to the observation of safe and unsafe acts and conditions. This new approach has led us to set a strategy whereby our top managers are becoming full HSE players.

One of the basic principles of our awareness process is founded on the leadership and commitment shown by our managers to our workforce in the field.

Their true involvement in Safety Management System has led them to acquire a thorough knowledge of the System; to see its applicability in the field; to identify gaps and then cooperate towards its improvement.
Gas Turbine Exhaust Heat Recovery Applied To Emulsion Treating System
Authors: Andrist Calvin R.
Published: December 2007

The Seminole San Andres Unit pressure maintenance facility in Gaines County, Texas is powered by multiple 1000 hp gas turbine engines driving multistage centrifugal pumps. The exhaust gas from each of these engines contains approximately 7 million Btu/hr recoverable heat. The central treating facilities for this Unit share common sites with the injection facilities and represent a highly variable heat load, ranging from zero in the summer months when production arrives at the treating facilities at design treating temperatures, to a maximum of approximately 25 million Btu/hr during the winter months when production arrives at the treating facilities 30 degrees F below design treating temperatures.

The exhaust gas from four engines is coupled through extended surface gas-to-oil heat exchangers which transfer the rejected heat to the hot oil circulating systems. The heated oil is circulated through shell and tube heat exchangers where the heat is transferred to the emulsion streams.

Because of the large cash flow significance of the production stream the system was designed with 100 percent auxiliary natural gas fired heating capability to replace the turbine exhaust heat when engines are down due to maintenance. The system was installed in 1974 and has operated successfully since, with no major system failures.

Introduction

While the primary purpose of this paper is to discuss the application of waste heat from gas turbine engines to the dehydration of crude oil, a brief summary of the field production history is presented so that the reader can gain some understanding of the production system to which it is applied. production system to which it is applied. The Seminole San Andres Unit, operated by Amerada Hess Corporation, is located in Gaines County, Texas. The field was discovered in 1936. The discovery well penetrated the San Andres gas cap and produced at an extremely high GOR. This discouraged development until 1939, when the oil column was identified and rapid development of the field occurred.

The primary producing mechanism was solution gas expansion. Bottom-hole pressure had declined from the original 2020 psig to 1150 psig by March, 1969, when an operating unit was formed for the purpose of initiating a pressure maintenance project. The Unit encompasses 15,700 acres and contained approximately one billion barrels of oil in place. Water injection was initiated in October, 1969, utilizing two 1000 hp gas turbine engines driving multistage centrifugal pumps. The injection system has progressively been expanded to the present level of 10 pumps injecting 250,000 barrels per day. These pumps are located in three injection per day. These pumps are located in three injection plants, as illustrated in Figure 1. plants, as illustrated in Figure 1.
Microbial Problem Solving with Cost Effective and Biodegradable Biocide in the Oil and Gas Industry
Authors: Siegert W. , Lee P. H.
Published: December 2007

Standard fuel contains up to 0.2 ml water per litre, of which is more than enough for microbial activity. The development of microorganisms mainly occurred when aqueous condensate collected in oil tanks. Studies have shown that the troubles of clogged filters, fuel tank corrosion, breakdown of tank coatings and engines are connected to the microorganisms. It is important and necessary to stop the bacterial growth with specific use of biocides. This paper will describe some experiences in overcoming this problem using a cost effective and environmentally friendly biocide as well as preventive measures.
Reducing Hydrocarbon Emission : Case Study at Plumpang Terminal Indonesia
Authors: Suwasono Djoko
Published: December 2007

PERTAMINA is Indonesian State Owned Oil and Gas Company and have up stream activities (explorasion & production) and down stream activities (oil refinery, distribution & marketing and transportation).

For distribution and marketing operation PERTAMINA have many fuel terminals such as Plumpang fuel terminal is located about 8 km north of the center Jakarta.

The storage tanks in Plumpang terminal are all cone roof tanks, and all storage tanks have no emission control system.

For an inland fuel terminal, hydrocarbon emissions are typically generated from storage tank vents, from fugitive eqipment leaks and from product loading operations.

The paper studied some aspects related emission control system, install internal floating roofs to reduce hydrocarbon emission from storage tanks and gasoline tanks truck loading also can reduce the emission losses by 80 – 95%.
Malaria a Disease we are Conversant with, but Choose to Ignore at Our Peril!
Authors: Sharples P. E.
Published: December 2007

Malaria is one of the most important causes of morbidity and mortality in the world with 90% of cases occurring in sub-Saharan Africa. Occurrences of malaria cases in travellers to these regions should be avoidable by healthcare professionals providing well-informed malaria prevention advice and medication prior to departure and such travellers complying with the advice given. Companies sending staff to work in malaria risk areas have a duty of care to ensure that their staff has access to such advice, including chemoprophylaxis, prior to departure. Delivering consistent and informative malaria advice to staff and their dependants can be challenging for multinational companies. This study surveyed the expatriate staff and accompanying spouses working for the Chevron Oil company in Nigeria. Questionnaires were sent to the 51 resident families on the company compound situated near Lagos, the 89 rotational staff that work in company operations at Escravos or Port Harcourt and all business travellers to Nigeria during the study period. The study response rate was 49.3%. Pre-travel advice was received by 95% of Chevron personnel, of which 93% was given from company resources with the home country Chevron medical clinic involved in 92% of cases. Knowledge about chemoprophylaxis was found wanting; the limits of its protection was unknown by 17%, and of those prescribed chemoprophylaxis, 72% were not aware of the correct dose regimen. Only 26% of personnel currently complying with drug prophylaxis were aware of the correct regimen. 70% of expatriates had stopped chemoprophylaxis, the average duration of compliance was 9.25 months and 87% of those who had discontinued stopped without seeking medical advice. The main barrier to long-term compliance was concern about the long-term side effects or safety of the medication in 69% of respondents. Company assignment procedures should be reviewed to ensure all personnel travelling to Nigeria receive pre-travel advice and to include improvements in information on chemoprophylaxis, particularly the standardisation of drug prophylaxis guidelines and information on the protective efficacy. Finally, this study indicated that the majority of expatriates do not comply with drug prophylaxis because of fears over long-term safety and side effects. It is recommended that further studies be conducted to obtain more information about the safety and effects of long-term chemoprophylaxis.
Sexually Transmitted Disease (STD) Evaluation and Treatment: Community Outreach Programs for E&P Projects
Authors: Moreau Jean-Marie , Krieger Gary R.
Published: December 2007

The aggressive identification and treatment of individuals with potentially curable Sexually Transmitted Diseases (STDs) is one of the most effective strategies to combat the spread of HIV. Published data indicates that overall HIV transmission in a population can be lowered by 40% by treating curable STDs in sexually active populations. The United Stated Ceneters for Disease Control and Prevention lists treatment of curable STDs as one of its main anti-HIV strategies. Since E&P projects are increasingly located in global areas that have high HIV/AIDS prevalence rates, the strategy of identifying and treating cases of curable STDs in both the workforce and as a potential community outreach program has a strong rationale.

In order to rapidly, accurately and cost-effectively diagnosis and treat curable STDs, there are several diagnostic strategies that can be considered: 1) syndromic evaluation and treatment algorithms that do not require laboratory support, 2) selective use of cheap, rapid lab tests such as urine leukocyte esterase dipsticks, gram stains and 3) use of immunochromatographic strip tests of clinical swab material (cervical, urethral). Each of these approaches has advantages and disadvantages, particularly regarding sensitivity, specificity and predictive value. Substantial screening efforts using theses diagnostic algorithms have been made in the workforce for the Chad Development Project. In addition, a large community outreach program in Cameroon for diagnosis and treatment of curable STDs was initiated as part of the same Project. The preliminary results of these efforts will be presented and discussed.
Rebuilding Environmental Impact Assessment to Deliver True Partnership
Authors: Onyeme Jonathan , Jones Murray
Published: December 2007

Environmental Impact Assessment (EIA) is a key project planning tool within the Shell Petroleum Development Company (SPDC), Nigeria. Upwards of 30 EIAs can be underway at any one time as Nigerian legislation requires an EIA for approval of projects as small as a single well site. In 1999 SPDC identified that the EIA process was not performing as efficiently as desired. There was a sense that government approval processes were too long, that EIA appeared to many as a data gathering exercise, that EIAs could not be delivered on time and the EIA process was not adding value to the business. Experts from Shell International Exploration and Production (SIEP) were asked to carry out a review of the overall application of EIA and to make recommendations for change.

The result of this review was the establishment of a broad-based improvement process designed to deliver impact assessments meeting world class standards. This process was to improve on the legal requirement for impact statements ensuring inclusion of the social and health dimensions, enhancing consultation and community involvement, integrating alternatives evaluation with project design and building overall competency both within and outside SPDC. This ‘EIA Improvement Process' (EIAIP) was linked to the business with deliverables that would add direct value. This included more efficient and effective management, better project design, gathering and assessment of the right information, on time activities and importantly involved stakeholders who would actively contribute to the choice of best options. Further, and of key importance, the results would be tied directly to community and NGO involvement and set the basis for long-term sustainable community relations and partnerships. As the EIAIP was initiated the opportunity arose to become directly linked with an ongoing international initiative on partnerships called the Business Partners for Development (BPD) process. The BPD was initiated with a range of participants to develop and apply the practices of trilateral partnerships – industry, government and community.

This paper defines the review process that was undertaken and the various steps involved in implementing critical change in the way SPDC addresses the impacts of new projects. It addresses the steps taken to secure a long-term commitment to change, governed by a multi stakeholder steering committee. It addresses various outreach actions that were undertaken to ensure understanding of the issues within and outside the company. And it particularly provides an insight into some of the partnership activities that have taken hold to contribute to long term sustainable development through application of the new approach.
Environmental Impact of Offshore Oil and Gas Company Operations in the Southern Arabian Gulf: A Marine Environmental Survey
Authors: Geutebruck E. , Herler J. , Kikinger R. , Stachowitsch M. , Lorkin M.
Published: December 2007

A comprehensive overview of the status of the marine environment near the offshore facilities in the Southern Arabian Gulf, which was carried out for the Zakum Development Company (ZADCO) in 1999, was obtained by a marine environmental survey. This involved a team of marine biologists, chemists, surveyors and computer technicians in a multi-pronged effort including analyses of seawater and sediment, benthic sampling of hard and soft bottom habitats, a study of the fouling organisms on oil platform structures, and fish surveys.

Special emphasis was placed on in-situ multisample collection by scuba divers and detailed underwater observation and documentation with still and video cameras. Basic laboratory work was performed onboard the vessel during the survey of approximately 4 weeks. The field survey was followed by an extensive 9-month biological laboratory work.

The chemical, biological and photographic approaches yielded a very consistent picture. At virtually every site and for almost all investigated parameters, direct impacts were quantifiable only at the sampling stations directly adjoining the facilities. Parameter levels at these sites were directly correlated with the composition of the benthic communities: they differed significantly from the surrounding stations.

The fouling survey on platform structures showed well-developed communities of encrusting and mobile organisms. These structures attracted a dense fish community that differed considerably from the surrounding seafloor underlining the potential positive effect of such artificial reefs.

The diver observations showed that, as opposed to fringing reefs that had suffered a past mortality, the corals in the deeper water surrounding the facilities were largely intact and may represent a vital source of recolonisation.

Biologically, a major challenge was the poor state of knowledge about the fauna of the Gulf. Thus, many species have never been described before. Among the nemertine worms, for example, 23 of the 29 forms were new to science.
Improvements in the Analysis of Thermally Recovered Drilling Fluid Base Oils from Drilled Cuttings
Authors: Jones T. G. J. , Sanders M. W. , Chambers B. D.
Published: December 2007

Drilled cuttings generated using invert emulsion drilling fluids represent the primary waste disposal challenge facing offshore drilling operators. If this waste cannot be appropriately disposed of on-site, it is typically shipped to shore for treatment and subsequent disposal or reuse. Although several types of cleaning processes are utilised, low-temperature thermal desorption systems (TDS) are the most predominant. The recovery of base fluids from these processes has assumed increasing importance in recent years, primarily in terms of fluid economics and waste reduction. Both synthetic and mineral oil base fluids have been reclaimed for further use. However, recovery has typically emphasised the separation of solids, water and emulsifiers from the base oil, with little published information on any changes to the overall composition of the fluid through the recovery processes.

The primary objective of this paper is to describe the application of improved methods to identify and quantify potential contaminants and by-products that may be introduced into the base fluids by thermal recovery and handling processes. Contaminant and by-product identity and concentration have been determined primarily by headspace and liquid injection gas chromatography-mass spectrometry (GC-MS) techniques. To the authors' knowledge, this approach has not been documented previously, but offers significant improvements over existing analytical techniques. Particular benefits include the identification of most volatile and non-volatile contaminants that may be present in the reclaimed fluids.

A variety of contaminants and possible by-products in a small number of reclaimed base fluid samples have been identified over a wide range of concentrations. Low levels of contaminants can have important implications for the reuse of base fluids, such as flash point, marine toxicity and occupational hygiene. This, in turn, will determine the fate of the reclaimed fluid. A recommendation is made for further work to assess those factors that may affect the quality of the recovered fluid.
"Oil and Gas Development in Sensitive Environments: Go or No Go?"
Authors: Kapila Sachin
Published: December 2007

There is an increasing amount of pressure being placed on the oil/gas and mining industries to commit to not operating in protected areas and other sensitive environments. In particular, oil and gas companies such as Shell have been targeted to commit to not going into protected areas designated under the IUCN Categories system, areas I–IV, otherwise they face the challenge of a public campaign. Such an undertaking however, is no easy task, as there are many issues that remain unresolved relating to the current system. For example, protected areas are designated according to their management objectives which does not include how well those areas are managed, nor is there a system yet in place, to independently review whether the designation given to a particular area is warranted.

This paper explores some of the reasons why committing to a blanket ban may not be very effective in protecting or conserving biodiversity. It goes onto present, what is perhaps a more effective approach for oil/gas companies. A framework that looks beyond just protected areas by leading one through a series of questions aimed at gauging a company's level of overall risk in relation to biodiversity. This will allow oil/gas companies to integrate more fully biodiversity considerations into their site selection processes at all relevant stages of the project cycle.
A New Approach of Reservoir Description of Carbonate Reservoirs
Authors: Shedid Shedid A. , Almehaideb Reyadh A.
Published: December 2007

This study is conducted to test and evaluate the use of current methods of reservoir characterization, namely the permeability-porosity correlation, the J-function, and the Reservoir Quality Index (RQI) concepts, for reservoir description of heterogeneous carbonate formations. These approaches were compared with a new technique developed in this paper for improved reservoir description of carbonate reservoirs. This technique is called the Characterization Number (CN) technique and it is based upon considering fluid, rock, rock-fluid properties and flow mechanics of oil reservoirs.

To compare these reservoir characterization techniques, measurements of porosity, absolute permeability, oil and water relative permeability and irreducible water saturation for 83 actual core samples extracted from eight different wells for a new oil reservoir in the U.A.E. are obtained. These experimental data are used first to develop a permeability-porosity correlation. Then, the J-function and the RQI concepts along with the newly developed CN approach are applied and evaluated for reservoir description of the UAE carbonate reservoir under investigation. The results show that the Reservoir Quality Index concept is capable of identifying the flow units while the J-function concept is quiet poor. Also, a more refined identification of flow units is obtained by using the newly-developed Characterization Number. This improved description for the Characterization Number approach may be attributed to the consideration of rock/fluid properties of flowing fluid(s) and flow dynamic conditions of its containing formation.
Innovative Completion Design and Well Performance Evaluation for Effective Frac-Packing of Long Intervals: A Case Study from the West Natuna Sea, Indonesia
Authors: Burton R. C. , Davis E. R. , Hodge R. M. , Stomp R. J. , Palthe P. W. , Saldungaray P.
Published: December 2007

This paper describes a case history of an innovative completion design and performance evaluation of a high-productivity subsea gas well in Conoco's Tembang field in the West Natuna Sea. Several completion challenges were overcome to ensure a high-deliverability completion in a thick, highly-laminated, loosely consolidated sandstone interval. The need for reliable high flowrates, high inflow area and effective sand control were the driving factors in the completion design and hardware selection. In addition, expected high fluid loss rates and gas migration were other factors affecting the design of this completion from a semi-submersible rig. A single-trip perforating and packing system was utilized to minimize fluid loss and formation damage during the completion operations. A fracpack was designed to optimize the connectivity between the multiple sand layers in conjunction with alternate path technology which provided the best option for sand placement and reducing the risk of a pre-mature screen-out in the long and highly deviated interval (322 ft MD at 50° inclination).

Evaluation of both pre-fracpack and post-fracpack reservoir and well performance results were performed. The use of a pre-fracpack surge, limited influx, and an injectivity test were chosen due to well control concerns related to completing and flow testing the well with a single-trip perforating and packing system from a semi-submersible rig. Post-fracpack flow testing to the rig immediately after the completion and subsequent production tests were evaluated to determine the well performance with time and effectiveness of the completion technique. These results, along with observations and challenges from the completion operations of the Tembang 4 well, are provided in this paper.
Compact Seawater Deoxygenation System Improvements for Floating Production Facilities
Authors: Deuel Charles L.
Published: December 2007

Seawater injection is a common practice for maintenance of reservoir pressure. A compact seawater deoxygenation system using regenerated nitrogen gas was introduced for offshore facilities in 1992. The original systems were based on a serpentine tube co-current mixing system. Due to the requirements of floating facilities to meet smaller footprint and weight, and to meet motion criteria in floating facilities, the third-generation system employs static mixers and a simplified control strategy. Based on experience from recent installations in offshore Thailand and Norway, troubleshooting guidelines are presented for operating turndown and debottlenecking scenarios.
Simulating Slug Flow in Hilly-Terrain Pipelines
Authors: Sharma Y. , Ihara M. , Manabe R.
Published: December 2007

A simulator has been developed to track two-phase slugs in pipelines transporting liquid and gas mixtures. The algorithm consists of close coupling of a one dimensional hydrodynamic slug flow model with an interface tracking methodology, and solving both simultaneously with an iterative procedure. The tracking scheme is based on propagating the fronts and backs of the liquid slugs to new locations during an incremental time step. New positions of the interfaces determine if a slug will enter the pipeline, exit the pipeline, collapse, merge with a slug ahead of it, or none of the above. The solution procedure determines the locations and the characteristics of all the slug units which exist in the pipeline at a given time.

Data collected in hilly-terrain and horizontal pipes in a large-scale multiphase flow loop were used to validate the slug tracking simulator. The average absolute percent errors in predicting the maximum slug length and inlet pressure were 12.6 and 0.47 respectively. A case study with field data collected on a 14,762 feet, 16 in. pipeline showed that the simulator predicted the maximum slug length and inlet pressure with absolute percent errors of 11.6 and 4.3 respectively. The comparisons are good and provide confidence in using the algorithm and the simulator to model and track two-phase slugs in hilly-terrain pipelines.

The simulator can be used to determine the characteristics of the slug unit used to design separators and slug catchers. It can also be used to analyze the impact of the flow and pressure transients on reservoirs, equipment, and structures, and study the effects of slugging on corrosion rates. The history of each slug in the pipe can be traced by determining if it will grow, shrink, collapse, or remain the same size as it traverses the pipe. During slug tracking, slug lengths are determined by the locations of interfaces instead of a correlation.
Reducing Completion Costs and Enhancing Productivity Using Nuclear Magnetic Resonance Logs and Formation Tester Data
Authors: Mengual Jean-François , Saldungaray Pablo , Artola Pedro , Riaño Juan Manuel
Published: December 2007

Using recent advances in logging technology, it is now possible to make an in-situ characterization of gas bearing sandstone reservoirs for use in optimization of the entire completion process. Dynamic reservoir information, obtained with a wireline formation tester, and continuous high-resolution porosity and permeability data, recorded using a nuclear magnetic resonance (NMR) logging tool, provide a step-change improvement in identification of productive zones. Use of this technique can result in greatly reduced operating costs because the effective completion of these low-permeability shaly formations typically requires time-consuming rigless operations.

In this paper we show how an exhaustive openhole evaluation of reservoir quality and the gas producibility index are combined as input to a completion strategy that reduces the time between spud-in and first commercial production. This integrated approach, entailing several stages, was used to optimize the hydraulic fracturing jobs for each producing interval, thereby enhancing overall gas production. The simulated performance for each interval and prediction of flow rates were used for recommendations on completion strategies. In that sense, we will first describe how this methodology, that combines wireline "in-situ" reservoir measurements, was applied on the completion design of several key wells and finally, we will present and discuss the case-history results obtained to-date.
Analytical Hindered-Matrix-Fracture Transfer Models for Naturally Fractured Petroleum Reservoirs
Authors: Civan Faruk , Rasmussen Maurice L.
Published: December 2007

The previous studies incorporating the matrix-fracture transfer functions in the naturally fractured reservoir models overlooked the effect of the fracture surface conditions on primary petroleum recovery by pressure depletion and secondary oil recovery by waterflooding and capillary imbibition. This paper presents an improved matrix-fracture transfer model and analytical solutions for rectangular shape matrix blocks in naturally fractured petroleum reservoirs by hindered interface flow between matrix blocks and surrounding fractures. The rectangular shapes are considered to represent the matrix blocks formed by intersecting fractures. The restricted and hindered matrix-fracture interface flow phenomenon is considered in order to account for the effect of the skin due to damaged matrix block surfaces by various processes, including deposition of mineral matter and other debris. The matrix fluid flow equations are formulated for multi-dimensional media, and linearized and solved analytically. The formulation is carried out in dimensionless form, leading to the same dimensionless equations and results based on the analogy between the single and two-phase flow situations involving pressure depletion and capillary-imbibition induced petroleum recovery processes. Then, full scale, and short and long-term analytical solutions are presented and validated by experimental data.

By means of these analytical models, various laboratory experimental data are analyzed, and it is demonstrated that the condition of the matrix block surface is an important factor in determining the rate of fluid flow between matrix blocks and fractures, and the skin effect may reduce the petroleum recovery factor. Comparison with previous simplified models shows that the present model can accurately predict the matrix-fracture interface fluid transfer rate over the full range of the petroleum recovery period, while the previous models can only represent either the early or the late time behavior with limited accuracy. In addition, the effect of the reservoir rock properties on the rate of petroleum recovery by hindered-flow is investigated by means of the hydraulic diffusivity coefficient, determined by correlating the experimental data by means of the new models. This study reveals that there is a strong relationship between the petroleum recovery factor and the diffusion coefficient.

The analytical models developed here can be utilized for rapid and accurate prediction of gas recovery from naturally fractured reservoirs undergoing a pressure depletion or waterflooding process.
Subsea Development of Shallow, Low-Pressure Gas Reservoirs Using High Performance Well Designs
Authors: Burton R. C. , Davis E. R. , Hodge R. M. , Gilbert T. , Stomp R. , Abdelmalek N. , Bailey M.
Published: December 2007

In the summer of 2000, Conoco began a program to develop a series of shallow, low-pressure gas reservoirs in the Indonesian waters of the West Natuna Sea. The project consists of a series of subsea wells linked by pipeline to a central mobile gas processing and compression unit which feeds a sales line to Singapore. Overall project life is 20 years and will require development of 8 small fields with reserves of the order of 1 TSCF gas.

Initial project planning used conventional well designs to deliver rates of the order of 20 MMSCFD/well from a number of gas reservoirs. This type of well productivity required 10 wells to meet Conoco Indonesia's maximum contract supply rate with several wells allocated to each reservoir. To improve project economics, a reduced well count employing high performance completion designs was developed. The high performance completions were designed to provide flow rates of the order of 100 MMSCFD at initial reservoir pressures ranging from 1250 psi to 1900 psi. These flow rates allowed well counts to be reduced to one well per reservoir.

This paper will review Conoco's methodology for design and implementation of the first 4 high performance completions in the West Natuna Sea Gas Project. Well deliverability and initial project results will be discussed.
Integrated Study Workflows for Field Development and Rehabilitation in the Burgos Basin
Authors: Cocker Mark A. , Mendoza Aurelio
Published: December 2007

Since the mid 1990s, when an ambitious program to rejuvenate the Burgos Basin was undertaken, Pemex Exploración y Producción (Pemex) has embraced many of the technologies responsible for increasing gas production in South Texas. These include 3D seismic acquisition and processing, improved drilling and hydraulic fracturing technologies, new logging tools, and comprehensive core studies. However, a critical component to the success of these new technologies is the rigorous application of workflows that integrate the myriad elements required to identify reserves growth opportunities.

Key steps in the workflow involve generating and integrating 3D seismic and well depth structures; seismic attribute tests, depositional architecture maps from logs and core, well logderived rock properties calibrated to routine core and SCAL data, volumetric mapping; comprehensive well history and completion analysis, EUR and drainage area bubble mapping; per-fault block recovery efficiency determination, offset analog comparison, and location selection, risking and ranking.

Two such integrated studies conducted by Pemex with assistance from The Scotia Group (Scotia) identified substantial future reserves potential and demonstrated the effectiveness of this integrated approach. At Corindon-Pandura, in the northwest corner of the Burgos Basin, for example, integration of the depositional systems interpretation, seismic and structural mapping and analysis of EUR bubble clusters revealed an obvious structural component to reservoir performance that is contrary to the depositional architecture. The integrated analysis also indicated that the effective drainage radius of most wells was much smaller (21-115 acres) than the existing 300 acre well spacing. Comparison to contiguous production in Texas confirmed the need for closer well spacing and indicated that improved drilling and completion practices could increase per completion recoveries by 0.5Bcf. Numerous infill and step-out locations were identified at Corindon-Pandura, with reserve growth potential totalling189 Bcf. Drilling to date includes more than 16 successful completions with initial rates averaging 2.8 MMcfd per well.

Similar results were achieved at Mojarrenas-Santa Rosalia where opportunities depended on identifying better primary porosity trends as well as resolving the complex structural influence on reservoir performance. The recent drilling results from the Corindon-Pandura and Mojarrenas-Santa Rosalia field complexes show dramatically the effectiveness of the integrated study workflows being implemented by the Pemex's Reynosa production teams. Characterization of the structural and reservoir complexities of the field areas has enabled Pemex to predict with reasonable certainty the development of target sands. More than 90% of the 72 wells drilled since completion of these studies have been completed and are producing.
Natural Gas-Lift: Theory and Practice
Authors: Betancourt S. , Dahlberg K. , Hovde Ø. , Jalali Y.
Published: December 2007

This paper examines the concept of "natural gas-lift" or production of oil by in situ gas. This process involves the commingled production of an oil reservoir and a contiguous or non-contiguous gas zone in a controlled mode as an alternative to artificial gas-lift. Besides the normal conception of gas-lift as a remedy to high water-cut flow, lift assistance may be required at startup to commission production, and can also be required at low to moderate water-cut, when the wellhead pressure requirements are stringent. The latter is typical of subsea installations and platform installations with high-pressure processing. Contiguous gas-lift is a more complex process, due to the interaction of the oil column with the overriding gas-cap, but can be envisaged more easily than non-contiguous gas-lift which requires the presence of a suitable gas zone or depleted oil zone. We present results of numerical modeling of the contiguous gas-lift process for horizontal wells, for the case of a conceptual reservoir model with characteristics similar to certain North Sea provinces. Results show the applicability of natural gas-lift dependent upon standoff (with respect to the initial gas-oil and water-oil contacts) and target production rate. We also address design considerations for natural gas-lift applications and report the operational experience gained in the Troll field with contiguous or gas-cap gas-lift applications. Finally we examine a gas-lift application of the non-contiguous type.
Acquisition of Directional Survey Data with Adapted Logging Tools
Authors: Rosas R. Rodriguez , Uresti J. A. Niño , Zeegers E. J. , Lips J. P.
Published: December 2007

In the PEMEX Southern Drilling and Producing Region, which includes all land wells drilled in the southeastern states of Mexico, directional drilling has gradually increased to 75% of wells drilled. Producing zones in the region are also deep with difficult targets under high pressure and temperature. These factors have led PEMEX to seek out new technology in an effort to optimize drilling and producing operations.

One of the special projects defined for the year 2001 was to evaluate the application of running a high-accuracy gyroscopic directional survey instrument in tandem with PEMEX logging systems. In the process, the Southern Region engineering group and the PEMEX wireline logging division worked with a local survey company to build a special housing to run the gyro probe on top of several different logging instruments.

This paper describes the development of the tandem gyro-logging combination tool and tests in three wells. System performance is analyzed and comparisons are made between gyro survey results and other survey instrumentation. Conclusions indicate that the success of running two services in one run in the well saves substantial rigtime and eliminates the costs of additional wireline runs. Furthermore, the application of high-accuracy survey information may prove valuable in more accurate wellbore placement and reservoir mapping—leading to enhanced production. In the future, the combination run may also have value in detecting the orientation of imaging logs in both cased and open hole to determine fracture orientation and formation dip angle.
Omani Oil Fields Produced Water: Treatment and Utilization
Authors: Hirayama Akihiko , Maegaito Masaki , Kawaguchi Masato , Ishikawa Akira , Sueyoshi Mark , Al-Bemani Ali Soud , Mushtaque Ahmed , Esechie Humphrey , Al-Mazrui Salim Ali , Al-Haddabi Mansour Hamed , Al-Khanjari Sulaiman Said
Published: December 2007

Joint research between Sultan Qaboos University, Oman, and Petroleum Energy Center, Japan; sought to develop and establish a process whereby the large quantities of produced water from Omani oil fields can be effectively treated and utilized for irrigation. During pilot plant operation, oil contamination ranging from 50-300 ppm, was reduced to below 0.5 ppm. Irrigation with treated water showed no significant detrimental effects on the growth of three different salt tolerant species of plants.
Developments in Completion Technology and Production Methods
Authors: Betancourt S. , Shukla S. , Sun D. , Hsii J. , Yan M. , Arpat B. , Sinha S. , Jalali Y.
Published: December 2007

This paper contains a condensed description of recent developments in completion technology and relates how these technologies have enabled novel production methods. Field applications reveal the geological, reservoir and surface characteristics that favor the application of these methods.
Depositional Environment Interpretation Using NMR and Core Data
Authors: Syngaevsky Pavel E.
Published: December 2007

This study is based on data from Gulf-of-Mexico (three wells) and West Siberia, Russia (two wells). We find a clear correlation between the NMR signal and depositional environments that also were identified on conventional log diagrams and in cores. Key sediments associated with the regressive bar and coastal fluvial sand sequences (distributary mouth bar, distal bar, delta-front, and pro-delta facies) were defined by predominant type and distribution of porosity and recognized on NMR diagrams. Corresponding distribution of total and effective porosity, permeability and amount of capillary bound water characterized the major depositional environments.

Seven rock types (lithofacies) were defined using statistical analysis of porosity/permeability laboratory data, SEM and thin-section description and mercury injection results; four of them were clearly correlated to various shapes of NMR response. The mixed type of porosity (associated with kaolinite cement) and interbeds with carbonate concretions (hardstreaks) were not recognized. The dissolution of feldspar grains in distal mouth bar facies results in significant enhancing effective porosity and permeability. An abnormally height porosity values (higher than 26 pu.) were formed as the result of feldspar and rock fragments total dissolution. Partial dissolution produces a micro-porosity that contains bound water. Results from both processes were recognized on NMR T2 distribution diagram. A dual porosity system was also identified on porosity-permeability cross-plot as two parallel areas.

NMR signals characterize the spectral porosity distribution and therefore could be used for various facies differentiation.

It provides a unique information on diagenetic alteration especially about total or partial grains dissolution. Best results on quantitative interpretation could be achieved by combining analysis of core data (SEM) and NMR logs.
Field Application of Near-Balanced Drilling Using Aqueous Foams in Western Venezuela
Authors: Rojas Y. , Vieira P. , Borrell M. , Blanco J. , Ford M. , Nieto L. , López G. , Atencio B.
Published: December 2007

This paper presents operational results of the pilot test under near balanced conditions of a new foam drilling fluid developed by PDVSA-Intevep in an inclined well drilled in La Paz Field in Western Venezuela. The target formations were a fractured, depleted limestone formations of low pressure, and the reservoir contains highly fractured and hard rocks, known for deferred oil production due to flushing by lost circulation. Similar wells drilled with aerated fluids in the vicinity have shown very low rates of penetration, short bit lives, and instability drilling fluid in presence of contaminants such as salts and crude oil. Results indicated that the foam formulation provided a high stability in presence of crude oil and cement contaminations, and an excellent cleaning capacity in a 12-1/4" hole wherein minimum annular velocities of 45 ft/min were obtained. The physico-chemical properties of the foam allowed regenerating the fluid 76 times with minimal amount of additives. Besides, the average rate of penetration was greatly increased compared to wellbores drilled conventionally and the bit used lasted much longer than in a conventional well in the same reservoir. Finally, this formulation specially developed to withstand high volumes of contaminants proved to be an excellent drilling fluid for near or underbalanced operations with adequate characteristics and very good performance.
Considerations Given to Land Rig Design for Versatility of Operations
Authors: Isinger Ron
Published: December 2007

This paper discusses factors that were considered in the design of the first generation Super Single™ rig. The initial design concept was driven by certain drilling requirements for a slant drilling operation of PanCanadian Petroleum. The discussion also includes examples of the rig's application, operating data and results and safety benefits achieved from the new rig design.

PanCanadian first applied the Super Single rig to a slant hole drilling under Lake Newell in southern Alberta. This application and subsequent projects, which represent a total of more than 5,000 wells drilled, have proven that the Super Single rig is more efficient and safer than conventional double, telescoping double and single rigs in the overall completion of a drilling well.
Multistring Casing Design for Deepwater and Ultradeep HP/HT Wells: A New Approach
Authors: Samuel G. Robello , Gonzales Adolfo , Ellis Scot , Kalil Issa
Published: December 2007

Drilling operations in deep water and ultra-deep water are increasing around the world. The development of these substantial prospects is very challenging and requires integration of knowledge with prudent designs at different stages of the well development. However the cost premium imposed by deep water and ultra deep wells are higher and many of the discoveries are marginal in terms of the commercial viability. With the increase of developing and operating costs, there is a growing need to reduce the cost of drilling and other allied operations. The casing program constitute a significant portion of the well cost and this calls for an alternate approach to the casing design criterion particularly relevant to high temperature and high pressures are encountered in ultra deep wells. Challenges associated with extreme depth, pressures and temperatures where annular fluid expansion is a problem translate to additional problems in casing design. It is therefore required to align design objectives closer to the changed requirements, which necessitates changes in traditional casing design methods. The design implemented should be without sacrificing the safety and integrity of the well.

This paper presents a study on the new approach and the alterations proposed to the casing design to adapt to the new criterion for the deep water and ultra deep high-temperature high-pressure wells. This paper will examine some of these proposed changes, while asserting that it is necessary to integrate this new approach, so that cost effective solutions can be derived as a result. This new design encapsulating annular fluid expansion and pressure provides a simple, practical way to view the severity of the composite well system during the course of drilling as well as the production phase of the well. The practical usefulness of the theory, backed by the fundamental analysis is demonstrated with three numerical examples.
A New TAML Level 3 Multilateral System Improves Capabilities and Operational Efficiencies
Authors: Fipke Steven , Oberkircher Jim
Published: December 2007

In recent years there has been a dramatic increase in the pace of the evolution of multilateral systems. Many systems with new features and improved functionality have been introduced which have enhanced the success and growth of multilateral technology. The MACH-3™ system is among the latest of these offerings. This innovative hybrid system is an example of RMLS™ technology that has been re-designed to provide a simpler and faster method of completing TAML Level 3 multilateral junctions. This system will greatly reduce the amount of rig time required for multilateral junction construction by simplifying the installation process and minimizing the number of trips to complete. It also provides increased functionality with large diameter, selective re-entry access to either the lateral or main well bore. Primarily designed for heavy oil applications where the cost of installation is a major issue, the system has potentially far reaching applications in this and other markets.

The paper describes the mechanical and operational principles of the system in its potential applications. The basic functionality of the MACH-3™ system will be analyzed, and some simple guidelines and limitations will be put forward for the selection of a Level 3 multilateral system. These guidelines are based on some of the lessons learned from multilateral experience in Canada, Venezuela and the U.S.A.