Tank Barrels Research Articles

Increasing the durability of large-calibre cannon barrels through strengthening them by surface plastic deformation

The paper presents a technology for strengthening the internal surface of the bore of cannon and tank barrels through surface plastic deformation. It is recommended to carry out the strengthening treatment in two stages: firstly, ball peening of the inner working surface of the barrel with hardened steel balls; secondly, application of a heat-resistant hard alloy coating using deforming bodies made of the VK6 alloy. It was established that as a result of this strengthening treatment, residual compressive stresses are formed in the near-surface layer of the bore material, its surface microhardness increases, and the resistance of the metal in the working surface of the barrel against burnout and cracking improves. Overall, the resistance of the barrel material to wear during cannon shots increases. A design of the strengthening device for this treatment has been developed. It consists of a cylindrical hardener with deforming bodies, an electric drive motor and a torque transmission mechanism from the motor shaft to the hardener. During the strengthening treatment, the device is moved along the channel of the cannon barrel, allowing the hardener to roll over the processed inner surface of the barrel and peen its material. The provided strengthening thickness is 0.15–0.20 mm, while the thickness of the applied hard alloy coating is up to a 100 μm.

Optimizing Water-Cut and Boosting Oil Recovery: Geological Insights from Mishrif Reservoir, Buzurgan Oil Field

This study utilizes streamline simulation to model fluid flow in the complex subsurface environment of the Mishrif reservoir in Iraq's Buzurgan oil field. The reservoir faces challenges from high-pressure depletion and a substantial increase in water cut during production, prompting the need for innovative reservoir management. The primary focus is on optimizing water injection procedures to reduce water cuts and enhance overall reservoir performance. Three waterflooding tactics were examined: normal conditions without injectors or producers, normal conditions with 30 injectors and 80 producers and streamline simulation using the frontsim simulator. Three main strategies were employed to streamline water injection in targeted areas. Over a 22-year forecasting period and employing seven Strategies, streamline simulation were optimized both oil and water outputs. The hybrid Strategy-7 as mixed between all three outperformed Strategy-1 that was gave highest optimization result for only one strategy, yielding the highest cumulative oil production of 1281 million stock tank barrels, the highest oil recovery factor of 24.1%, and a minimal of 2.5% water cut. This study underscores the importance of streamline simulation in managing reservoirs under challenging subsurface conditions, highlighting that a thoughtful integration of streamlining tactics can significantly improve reservoir performance even enhancing oil recovery and addressing water-related issues. The findings contribute valuable insights for optimizing waterflooding strategies in similar globally geological contexts.

3D static modeling and sequence stratigraphy using well logs and seismic data: An example of Abu Roash G member in Bahga oilfield

This research uses both three-dimensional (3D) modeling and geologic well control to piece back together the architectural parts of the Late Cretaceous formations. The goal is to figure out the sizes, directions, locations, and controls of the layers of the fluvial sandstone reservoirs. Sequence stratigraphy is essential for 3D reservoir modeling and petroleum geology understanding in the Bahga oilfield. The purpose of this work is to create a static model that shows the layers and facies distribution in the reservoir interval. We will use data from nine well logs and 22 seismic lines calibrated by the Abu Roash G Member reservoir core intervals to accomplish this. The petrophysical study discovered three parts in the Abu Roash G Member reservoir rock: channel fill that is affected by tides, channel fill that is dominated by tides (intertidal sands), and channel top with lenticular bedded sandstone. The model's findings point to the existence of an NNW-oriented sand body, which could be a prime location to produce hydrocarbons. The original oil in place (OOIP) is about 3,438,279 Stock Tank Barrels (STB), and the oil reserve reaches up to 1,031,484 (STB). Sequence stratigraphic analysis using seismic and well log information (SB) reveals that the Upper Cretaceous AR/G reservoir of the Bahga field is characterized by third- and fourth-order stratigraphic sequences, which are constrained by three Maximum Flooding Surfaces (MFS) and two Sequence Boundaries. The integration of the derived geological model and sequence stratigraphic results can lower future extraction risk by identifying the locations and trends of the geologic facies with the necessary petrophysical properties for the hydrocarbon accumulations.

DEVELOPMENT OF TECHNOLOGY FOR IMPROVING THE WEAR RESISTANCE OF THE WORKING SURFACES OF RIFLED BARRELS OF ARTILLERY SYSTEMS AND INCREASE THEIR RESOURCE

The accuracy of the damage and the outcome of the battle depend on the durable wear resistance of the inner surface of the artillery barrels. When fired, there is close contact between the surface of the barrel and the rings of softer metal on the projectile (this is for the tightness of the system), which leads to their active abrasion. True, the softer surfaces of the rings on the projectile wear more, but with such rapid mutual movement of the surfaces, the harder materials of the barrel also wear. As a result, the tightness of the powder gases is violated and, accordingly, the power of the shot and the flight range of the projectile, as well as the amplitude of the oscillation of the projectile during its passage through the barrel increases. This in turn affects the accuracy of hitting the target, especially at long distances. For close combat, this is not a big problem, but long-range artillery systems are most important now. In this regard, the purpose of this research is to develop a technology for manufacturing a cannon barrel with the most wear-resistant inner surface. At the same time, a brief review of artillery systems, which are currently used mainly in the Russian-Ukrainian war, is made. The scheme of the manufacturing technology of rifled tank barrels with an increased resource of aiming lesions is described. The methodology is based on the technology of their surface hardening with high-frequency currents and grinding of microcracks, which appear as a result, developed by the authors. The main factors that ensure a high resource of barrels according to the technology are their high heat resistance and wear resistance. Heat resistance is achieved by optimizing the material on the samples, wear resistance by optimizing the parameters of the surface hardening technology of the inner surface of the barrel. The method of calculating the survivability of the barrel is given, when after hardening and grinding of the barrel, a micro crack remained on its inner surface.

3D petroleum reservoir modelling using seismic and well‐log data to assess hydrocarbon potential in Abu Roash (G) Member, Karama Oil Field, North‐Western Desert, Egypt

Since 2002, the Upper Cretaceous Abu Roash (G) Member in the Karama Oil Field has been considered to be one of the most important reservoirs in the Abu Gharadig Basin in the North‐Western Desert. This member is located in the Karama Oil Field. For the purpose of increasing oil production, a three‐dimensional reservoir model was developed, and the area's oil resource was determined by employing thirty two‐dimensional seismic lines dispersed in the north–south and east–west directions, in addition to five well logs. Within the Abu Roash Formation, which conformably overlies the Bahariya Formation and unconformably underlies the Khoman Formation, there are seven normal faults that allow for three‐way dip closure for oil accumulation. These faults cut through the Abu Roash Formation. The Abu Roash (G) Member is mostly composed of limestone, shale and intercalated siltstone and sandstone, and it ranges in thickness from 54 to 168 feet (16.5 to 51.2 m) in terms of its net pay. Effective porosity ranges anywhere from 20% to 30%, shale content can be anywhere from 13% to 24%, water saturation can be anywhere from 40% to 55% and hydrocarbon saturation can be as high as 60%. Through the integration of the constructed structural and property models, two new prospect areas have been presented (in the northern part of the study area). In these areas, the petrophysical parameters are good, and the Original oil in place (OOIP) is predicted to be 1107 × 106 Stock Tank Barrels (STB), which will help with the development plans for the study area.

Fast Detection and Reconstruction of Tank Barrels Based on Component Prior and Deep Neural Network in the Terahertz Regime

Terahertz (THz) regime has shown superior performance in terms of reflecting the details of target structures. However, the extended structures (ESs) may be discretized into endpoints in synthetic aperture radar (SAR) images if the observation aperture deviates from the specular orientation of ESs, which deteriorates subsequent image interpretation and intelligent imaging. Taking the tank barrels as the object, this paper proposes a novel solution to detect and reconstruct the critical ES by effectively exploiting the component prior and imaging characteristics (CPIC). The core of the proposed method lies in converting the phase matching of the multi-views methods into object detection based on CPIC and deep neural network. Firstly, the CPIC of tank barrels is analytically determined and regarded as the theoretical basis of datasets annotation. Thus, the modified multi-scale object detection network is constructed to enhance the detection performance and estimate the orientation of barrels. Finally, comprehensive simulation, anechoic chamber and field experiments are carried out to validate the effectiveness of the proposed methods. The results show that the proposed method can outperform the existing object detection networks in terms of the detection accuracy of multi-scale objects, and outperform the existing multi-view methods in terms of time need with comparable accuracy.

Water attenuation enhances tribological damage resistance in laser peened steel

In the present study, the effect of Laser Shock Peening (LSP) on wear characteristics of armor steel is investigated to mitigate the material degradation in tank barrels and prolong their service life. Tank barrels are exposed to enormous temperatures and pressures during rapid firing rounds, which invoke the material's failure and calls for a barrel replacement and the reinvestment of millions of dollars. LSP performed at different pulse energies (i.e., 450 mJ, 350 mJ, and 250 mJ) with varying attenuating media such as air, water, and silicone oil, have resulted in high wear resistance and superior mechanical properties compared to that of armor steel. Water attenuation with a pulse energy of 450 mJ has resulted in surface hardness of ∼495 ± 3 HV, compressive residual stresses of ∼319 ± 2 MPa, and exhibited minimum wear rate of ∼2.61 × 10-8 ± 0.04 × 10-8 mm3/N.m, capable of limiting wear and erosion problems, thereby enhancing the service life of tank barrels.

Ultimate expellable potentials of source rocks from selected super basins: What does “world class” look like?

An important step in the evaluation of a play or prospect is to consider the potential supply of petroleum charge, which is ultimately constrained by masses and volumes supplied by the source bed. The two factors limiting the mass of petroleum expelled from the organic matter in the source bed are (1) its initial expulsion potential and (2) the cumulative fraction of potential that has been expelled up to its maximum state of maturation. To evaluate the initial expulsion potential, we introduce a workflow to estimate the ultimate expellable potential (UEP), divided into an oil potential (UEO) and a gas potential (UEG), which represent the cumulative masses of oil and gas that can be expelled upon complete maturation of the source rock. For use in resource estimation, these masses can be converted to surface volumes of oil and gas per unit area (million stock tank barrels per square kilometer and billion standard cubic feet per square kilometer or million barrels of oil equivalent per square kilometer, respectively). The UEP (UEO, UEG) can be mapped across the depositional extent of the source bed, just as a reservoir depositional system is mapped. These potentials per unit area constitute the first level of quantitative resource estimation in the evaluation of a play or prospect. We show examples of UEP (UEO, UEG) mapping based on available public data. Three of the example source rocks are aquatic organofacies that have charged major conventional petroleum systems: the Callovian to Oxfordian marine organofacies of the Arabian Basin, Saudi Arabia; the Volgian marine organofacies Bazhenov Formation of the West Siberian Basin, Russia; and the Eocene–Oligocene lacustrine freshwater organofacies Shahejie Formation of the Bohai Basin, China. We also include an unconventional system: the uppermost Devonian–lowermost Mississippian marine organofacies Bakken Formation of North Dakota, United States. The UEPs of the studied source rocks in the Arabian Basin and West Siberian Basin, with tens of millions of barrels of oil equivalent per kilometer over large areas, define world class in marine source rocks since these basins are ranked number one and number two in the world by oil endowment. Until more data are available on other lacustrine basins, we offer the UEP of the studied Bohai Basin source rock as an example. In contrast, the UEP of the Bakken Formation source rocks (combined Upper and Lower Members) is relatively modest despite its world class unconventional oil endowment. The Bakken's effectiveness, despite its relatively low UEP, reflects the negligible migration saturation losses involved in charging the Middle reservoir Member. This illustrates that the commonly touted term world class can be rather meaningless. It needs to be considered in context given the task in hand: the greater the (vertical) migration losses incurred in charging reservoirs, the higher the UEP needed to create the charge needed to overcome them.

3-D reservoir characterization and hydrocarbon volumetric estimation of parts of Niger Delta Basin-Nigeria

Coupled interpretation and modeling of seismic and well log data, using geostatistical techniques was adopted to characterize reservoirs in a section of the Niger Delta Basin. The study was aimed at generating high resolution reservoir information such as spatial distribution of petrophysical properties, subsurface structures (e.g., faults and horizons) and estimation of hydrocarbon volume in a heterogeneous reservoir system. Five reservoirs with over twenty fault structures were delineated. The reservoir structural framework consists of antithetic and synthetic faults that influenced hydrocarbon flow dynamics within the field. Petrophysical properties were estimated and spatially distributed over the study area via variogram statistics. Both the sequential indicator and Gaussian simulations were performed to transform the pillar grids during the modeling process. Three realizations of the volumetrics were obtained for each of the reservoirs and the overall stock tank oil initially in place of the field, show low outcome of 245,720,570.40 stock tank barrels (STB) which indicates 90% probability of exceeding the quoted value, median outcome of 302,735,521.90 STB called the reality-oriented model (i.e., 50% probability) and a high outcome of 361,161,605.40 STB which has 10% probability of exceeding the estimated value. The gas zone estimate show low, median and high outcomes of 53,745.50, 56,487.60 and 60,618.50 million standard cubic feet (mmscf) respectively. Generally, results obtained show that an integration of well log and seismic data using geostatistical techniques can yield geological plausible reservoir models that can enhance production and management decisions in complex heterogeneous reservoir systems.

ANALYSIS OF DAMAGE DATA COLLECTED FOR WINE STORAGE TANKS FOLLOWING THE 2013 AND 2016 NEW ZEALAND EARTHQUAKES

The 2013 Seddon earthquake (Mw 6.5), the 2013 Lake Grassmere earthquake (Mw 6.6), and the 2016 Kaikōura earthquake (Mw 7.8) provided an opportunity to assemble the most extensive damage database to wine storage tanks ever compiled worldwide. An overview of this damage database is presented herein based on the in-field post-earthquake damage data collected for 2058 wine storage tanks (1512 legged tanks and 546 flat-based tanks) following the 2013 earthquakes and 1401 wine storage tanks (599 legged tanks and 802 flat-based tanks) following the 2016 earthquake. Critique of the earthquake damage database revealed that in 2013, 39% and 47% of the flat-based wine tanks sustained damage to their base shells and anchors respectively, while due to resilience measures implemented following the 2013 earthquakes, in the 2016 earthquake the damage to tank base shells and tank anchors of flat-based wine tanks was reduced to 32% and 23% respectively and instead damage to tank barrels (54%) and tank cones (43%) was identified as the two most frequently occurring damage modes for this type of tank. Analysis of damage data for legged wine tanks revealed that the frame-legs of legged wine tanks sustained the greatest damage percentage among different parts of legged tanks in both the 2013 earthquakes (40%) and in the 2016 earthquake (44%). Analysis of damage data and socio-economic findings highlight the need for industry-wide standards, which may have socio-economic implications for wineries.

Damage to flat-based wine storage tanks in the 2013 and 2016 New Zealand earthquakes

In-field post-earthquake damage assessment of wineries was conducted following the 2013 Seddon earthquake (Mw 6.5), the 2013 Lake Grassmere earthquake (Mw 6.6), and the 2016 Kaikōura earthquake (Mw 7.8) in New Zealand. These assessments provided an opportunity to assemble the largest database ever collected on the earthquake performance of wine storage tanks. Observations documented and discussed herein highlight detailed statistics regarding the earthquake performance of 546 flat-based wine storage tanks from the 2013 earthquakes and of 802 flat-based wine storage tanks from the 2016 earthquake. Damage data revealed that of the 546 inspected wine storage tanks following the 2013 earthquakes, 69% sustained damage, and that of the 802 inspected wine storage tanks following the 2016 earthquake, 73% sustained damage. In the 2013 earthquakes the tank base shell (39%) and anchor (47%) parts of the flat-based wine tanks sustained the largest proportion of damage, while due to resilience measures implemented following the 2013 earthquakes, damage to tank base shells and to tank anchors in the 2016 earthquakes reduced to 32% and 23% respectively, and instead damage to the barrel (54%) and cone (43%) parts of flat-based wine tanks was identified as being most significant. Indenting of the tank barrel due to impact from a catwalk during the 2013 (10%) and 2016 (24%) earthquake events was identified as the most crucial failure type that caused damage to tank barrels.

Assessment of CO2‐enhanced oil recovery and associated geologic storage potential in the Michigan Northern Pinnacle Reef Trend

AbstractThis paper provides an improved estimate of CO2‐EOR (where CO2 is carbon dioxide and EOR is enhanced oil recovery) and CO2 storage potential for depleted oil fields in Michigan's northern pinnacle reef trend (NPRT). Our methodology is based on capturing data on reservoir performance from reefs currently undergoing CO2‐EOR operations in the NPRT (referred to as ‘monitored reefs’), and then applying them to other reefs within the NPRT (referred to as ‘catalog reefs’). For each monitored reef, we calculate fractional primary recovery, fractional incremental EOR recovery, net utilization ratio, and storage efficiency factor. The corresponding incremental oil recovery from EOR, storage capacity until end of EOR, and total CO2 injection needs are then estimated for each catalog reef and combined (over all monitored reefs) using a weighted averaging procedure. These weights are related to a statistical similarity measure that is calculated between each monitored reef and each catalog reef based on a number of variables related to production data, formation type, or descriptive geologic attributes. For the entire NPRT catalog of 383 reefs as used in this study, our results indicate 118 million (MM) stock tank barrels (STB) (1.88 × 107 Sm3) of incremental oil from EOR operations, corresponding to 49 MM metric tons (MT) of CO2 storage and 266 MM MT of total CO2 injection. However, approximately one‐third of the reefs provide two‐thirds of the potential for CO2‐EOR and geologic storage, assuming an economic threshold of 0.5 MM STB (80 000 Sm3) of incremental oil from EOR. © 2020 The Authors. Greenhouse Gases: Science and Technology published by Society of Chemical Industry and John Wiley & Sons, Ltd.

Tribological Wear-Preventive Coatings

This article discusses wear-preventive tribological coatings that increase the operational life of artillery, tank, and rifle barrels. Studies have been conducted using some of them. The presence of a sufficiently large scientific and technical reserve in the field of material science of heat-resistant alloys and antifriction antiwear coatings is noted.

Assessment of CO2 - EOR and Storage Capacity in South Sumatera and West Java Basins

A study of carbon dioxide-enhanced oil recovery (CO2-EOR) and storage capacity in South Sumatera and West Java Basins, Indonesia has been conducted in conjunctions with the project plans of Indonesia National Electric Company to build carbon capture and storage ready coal power plants in Bojonegara of West Java and Muara Enim of South Sumatera. The Bojonegara power plant comprises 2×1000 MWe Ultra Super Critical Units, while Muara Enim consists of 2×300 MWe subcritical units. Those two power plants will produce approximately 11 and 4 million tons of CO2 per year. The geology of South Sumatera and West Java Basins are proven to have kept oil and gas in place safely for long time periods and there are many oil and gas companies production still active in those basins. Those basins are confirmed to be used as storage of CO2, where capacity, injectivity, and confinement will be suitable to keep CO2 in place for a period of time. CO2 production from those power plants in South Sumatera and West Java may be offered to the nearby oil companies and transported to oil fields for CO2-EOR flooding to get additional revenue. A preliminary CO2-EOR screening has been done for the oil fields surrounding the power plants. There are two types of mechanisms for CO2-EOR, which depend on the nature of the oilfield: immiscible EOR and miscible EOR. Immiscible EOR occurs where the injected CO2 does not mix with the oil but instead displaces the oil from the area where the CO2 is injected and increases the pressure of the oil at the production wells so that it can be pumped out. Miscible EOR occurs where the supercritical CO2 mixes miscibility with the residual oil to make it less viscous and facilitating its flow to the production wells. A total of 127 oil fields in South Sumatera has been analyzed to select which of those fields fulfill CO2-EOR injection criteria. EOR reservoir screenings were performed on those oil fields on which detailed information was available using the screening criteria proposed by Taber et al. The criteria include a set of parameters such as API gravity, oil viscosity, current pressure, temperature, oil saturation, remaining oil, formation depth, thickness, porosity, permeability, and rock type which help to determine whether or not a reservoir is suitable for CO2-EOR injection. 96 fields are classified as miscible displacement while the remaining 31 fields are categorized as immiscible. The result shows that the potency of additional recovery from those fields is around 661 million stock tank barrels with CO2 requirement of approximately 243 million tonnes. In addition to EOR, pure CCS to inject the CO2 emission into depleted gas fields in West Java and South Sumatera regions is also considered. The maximum storage capacity of West Java gas fields is approximately 395 million tonnes, while the storage capacity of South Sumatera is around 537 million tonnes. The potential for storing CO2 in the saline aquifer was also calculated theoretically. The depleted gas fields and aquifers are considered enough to store the CO2 emission from the power plants as long as 25 years.

EOR Potential from CO2 Captured from Coal-Fired Power Plants in the Upper Cretaceous (Cenomanian) Woodbine Group, East Texas Basin, and Southeastern Texas Gulf Coast, USA

The East Texas Basin and southeastern Texas Gulf Coast contain a variety of co-located CO2 sources and sinks that may facilitate development of new clean-coal facilities. These facilities can be linked to mature oil fields with potential for enhanced oil recovery (EOR) from miscible CO2 floods. Twenty-three reservoirs in the East Texas Basin and southeastern Texas Gulf Coast, assuming a 15% recovery factor of original oil in place (OOIP), have a CO2-EOR potential for recovery of ~9,697,000 m3 [~62.2 million stock tank barrels] of oil. A network of new CO2 pipelines can link these fields to existing power plants near lignite mine mouths in east and southeast Texas. Representative oil fields in the Woodbine Group illustrate fluvial and deltaic facies variability and different sandstone-body architectures with varying controls on potential CO2 capacity. Reservoir heterogeneity, fluid flow, hydrocarbon production, and potential CO2 capacity in the Woodbine Group in the structurally simple East Texas field are mainly a function of facies architecture. The Woodbine Group in East Texas field contains a lower section of narrow and lenticular sandstone bodies in a fluvially dominated deltaic system. Pressure and production data indicate that additional oil recovery in the lower Woodbine deltaic section in East Texas field is low in muddy, low-permeability prodelta, and distal-delta-front facies. In contrast, oil recovery is greater in sandy distributary-channel sandstones. Core-plug data show that distributary-channel and channel-mouth-bar sandstones in the field have high median-permeability values, and therefore a greater potential for CO2 capacity. These deltaic deposits are overlain disconformably by an upper section of continuous, coarse-grained fluvial deposits that favor high CO2 capacity owing to Darcy-class permeability and extensive vertical and lateral reservoir continuity. In contrast, Woodbine fields in southeast Texas represent distal-deltaic facies. CO2 capacity and EOR potential in these fields are limited by thin distributary-channel and crevasse-splay deposits that contain abundant mudstone beds that may serve to segregate-injected CO2 into small reservoir compartments.

Geologic and Economic Criteria for Siting Clean-Coal Facilities in the Texas Gulf Coast, USA

The Texas Gulf Coast (TGC) contains the greatest number of favorably co-located CO2 sources and sinks in Texas that favor new potential clean-coal facilities. Areas in the TGC with clean-coal potential were delineated by mapping spatial linkages between coal- and lignite-bearing formations and geologic and infrastructure factors that include proximity to existing fields from mine-mouth power plants for enhanced oil recovery (EOR), length of new pipelines to transport CO2 from new clean-coal facilities to either EOR fields or to brine formations for deep storage, proximity to centers of electric load, and depth to subsurface coal for enhanced coalbed methane recovery. Other factors include thickness of brine formations for deep storage of CO2, groundwater and surface-water availability, and proximity to railroads for haulage of western U.S. coal feedstock. Geospatial analysis of maps portraying the distribution of these factors, together with data on volumes of oil recoverable from miscible CO2 flooding of oil fields, indicates that optimal areas for new clean-coal sites in the TGC are in east and southeast Texas. CO2 pipeline networks linking these sites to EOR fields are integral components of systems that can typically recover 5–50 million stock tank barrels from miscible CO2 flooding from each EOR field. Many of these fields with EOR potential (for example, Neches, Long Lake, Conroe, and Livingston) have a great potential for stacked CO2 storage, in which multiple reservoir zones can undergo EOR development and deeper zones in the field can accommodate excess CO2 from EOR operations.

Polygenic formation model of the planet’s bituminous belts

In recent years, much attention has been paid to nontraditional hydrocarbon sources. Today the portion of nontraditional gas in the world extraction is 15% or 450 billion cubic meters, which hat makes up the volume of total gas exports from Russia. As is known, the easy-prospecting oil has been already found. The innovative technologies in geophysics, drilling, and excavation and the increased extraction coefficient expect further development and industrial compliance with these requirements. Based on calculations, the world oil reserves are now one trillion of stock tank barrels and one trillion barrels have been already extracted. The evergrowing demand for energy gives rise to the necessity of searching for and extracting more oil resources, and both these aspects are unique problems. The search for profitable petroleum deposits has become more and more difficult even in the leading companies. The increment of the world resources is a key vital question; therefore, the elaboration of criteria for the discovery of nontraditional deposits take on special significance in the economic respect. The authors are working out a conception that will be a guideline for future finding of the richest oil deposits in active geodynamic zones. For the first time, we suggest the polygenic formation model of the planet’s bituminous belts.

Northwest McGregor field CO2 Huff ‘n’ Puff: A case study of the application of field monitoring and modeling techniques for CO2 prediction and accounting

Northwest McGregor field CO2 Huff ‘n’ Puff: A case study of the application of field monitoring and modeling techniques for CO2 prediction and accounting

Using time-lapse seismic for field development at Nembe Creek, Nigeria

Nigeria is the largest oil producer in Africa and the 11th largest in the world. The majority of reserves are found along the country's coastal Niger River Delta. Nembe Creek Field, southwest of Port Harcourt (Figure 1), was discovered in 1973 and started production in 1977. This land/swamp field has a large STOIIP with an ultimate recovery of about 50%. Cumulative production as of January 2006 is about 643 million stock tank barrels (stb), thus leaving a huge opportunity that technologies such as time-lapse seismic and smart wells can impact, in addition to unlocking bypassed reserves.

MORE WELLS, MORE OIL—A CASE STUDY OF RESERVES GROWTH IN THE KENMORE FIELD

The Kenmore oil field in the Eromanga Basin of southwest Queensland was discovered in 1985. Since then, a further 32 wells have been drilled and more than 12.5 MMSTB of oil has been produced from the Birkhead Formation/Hutton Sandstone. Oil production over the last year has averaged 1,220 barrels per day totalling some 0.45 million stock tank barrels (MMSTB)Oil reserves in Kenmore were originally estimated at 2.2 MMSTB following the Kenmore–1 discovery well drilled in 1985. In the following 20 years, infill drilling, a 3D seismic survey, various reservoir studies and better -than-expected recovery efficiency, have steadily increased the ultimate recoverable reserves to the current estimate of 14.3 MMSTB.The growth of reserves at Kenmore is primarily attributed to better drainage of the complex reservoir framework within the lower Birkhead Formation resulting from recognition of the variable lateral connectivity of the reservoir. Due to the initial estimate of the ultimate field reserves being significantly smaller than now recognised and the resultant conservative drilling program, the economic value of the field was not maximised. This experience has implications for the ongoing development of the Kenmore field and suggests that other Birkhead/Hutton oil fields should be developed more aggressively to prevent history repeating itself.