bluuebunny/crossref_metadata_2025_split huggingface dataset:
Novel Perforation Job Design Leads To Successful TCP Shoot In A 3000 Foot Horizontal Carbonate Producer
Authors: Shindy Ahmed M. , Khedr Osama H. , Salsman Alan Dean , Bennett G 
Published: March 2015

Abstract
A recent horizontal producer well was drilled as part of a multilateral openhole completion pair in the Arabian Gulf area. The casing of the main wellbore could not get to bottom which necessitated the bottom lateral be cased and cemented for isolation purposes and then perforated. The decision to perforate the 3000' horizontal section was unexpected so supplies were insufficient to perforate this long section using the traditional perforating method.
Rather than delaying the well completion and deferring production from this well, an effort was put into looking for alternatives. With the help of a perforation modeling tool it was shown that the horizontal section could be shot using a dynamic underbalance job design at greatly reduced shot densities and still achieve an injectivity, required for acid matrix stimulation, and subsequent productivity greater than if the well were to be shot conventionally at 6 spf. This technique of dynamic underbalance had been successfully used locally on wireline perforating jobs in short intervals but never on such a long well section nor at such low shot densities.
Another potential complication with the conventional perforating technique is the presence of a 2nd open hole lateral which was in communication with the well to be perforated. This meant that the zone would be shot in an overbalanced condition which can lead to post perforation damage and poor injectivity.
This paper will describe the process used to establish the dynamic underbalance perforation job design suitable for this well, the final job design, the execution of the job and the obtained results of this successful application. The results indicated better than expected injectivity prior to acid matrix stimulation and better than expected well productivity post stimulation. The improved well productivity is based on modeled and also nearby well production results.
A successful job design methodology and execution has been tried for the first time in this region and has potential applications to many other wells.

Background
The horizontal well that forms the basis for this case study was drilled offshore in the Arabian Gulf in 2007. The well was intended to be completed as an openhole producing well and the case under consideration here was one of 2 lateral drains (Figure 1). During the well construction process the 7" casing was set at higher than planned depth leaving a part of upper reservoir in communication with lower reservoir below the 7" casing shoe. This reservoir section would interfere with the production from the lower 6" hole so it was decided to run a 4 ½" liner and extent it up into the 7" casing to provide isolation between the two laterals. With a cemented liner in place this necessitated the requirement to perforate the liner section in order to produce the well.
Carbonate Rock Physics Issues
Authors: Liu Enru , Payne Michael A. , Xu Shiyu , Baechle Gregor , Harris Christopher E. 
Published: March 2015

Abstract

Summary
Limestone and dolomite reservoirs account for approximately 50% of oil and gas production worldwide, yet seismic responses in carbonate rocks are poorly understood. Development of a carbonate rock physics model is extremely difficult because pore systems are more complex in carbonates than they are in clastics. Carbonates can have a variety of pore types, such as moldic, vuggy, interparticle, and intraparticle. The complex pore system creates significant scatter in the porosity-velocity relationship, as indicated in experimental results (e.g., Anselmetti and Eberli, 2001). Pore shape appears to be the dominant factor in carbonate rock physics. Moldic, intraframe, and vuggy pores tend to be rounded and make the rock stronger (faster) than when the pores are interparticle. Micro pores (e.g., microcracks) tend to be flat and make the rock weaker. To effectively characterize carbonate reservoir rocks, it is critical to develop a rock physics model capable of handling different pore types.
In addition to pore types and pore shapes, other factors need to be included in a physics-based rock model. Some specific additional factors are lithology and grain shapes, multiphase fluids and wetting effects, rock-fluid interactions (poro-elasticity), stress effects, anisotropy, heterogeneity and scale effects, chemical changes to the framework, and corrections for environmental effects due to logging conditions. Any rock physics model should be calibrated and validated with controlled laboratory experiments, field measurements, and computational rock physics. In this paper, we demonstrate the impact and validation of several of these factors.

Carbonate Rock Physics Model
We prefer an analytical rock physics model rather than empirical ones due to both the predictive power that it provides without having to acquire so much analog data and its physics-based nature. Empirical rock physics models are widely used due to their simplicity in fitting a relationship between parameters. The advantage of an analytical model is that once the parameters describing the physical controlling factors are determined, the model can be applied anywhere that the controlling parameters can be estimated. This achieves better predictions and deeper understanding of the subsurface than empirical models with less data. Nonlinear physics-based inclusion models (e.g., Kuster and Toksoz, 1974) are attractive because they handle various factors that impact seismic response in an internally consistent manner.
Integrated Field Development - Improved Field Planning and Operation Optimization
Authors: Serbini Feroney , Kok Wee Low , Wong Lee Hin , Bustamante Nicolas Gomez 
Published: March 2015

Abstract
Field development, operation optimization, production system de-bottlenecking, reservoir management and field re-development involve studies and analyses from multidiscipline engineers and experts that require effective communication of the impact of the results from one discipline to another. Through an integrated subsurfaceto-
surface-to-economic modeling technology, the team members are able to model all components of the production system simultaneously and evaluate potential development scenarios, thus resulting in optimal decisions. The Integrated Asset Modelling technology integrates reservoirs, wells, surface infrastructure, and process facilities as well as the asset's operating parameters, financial metrics, and economic conditions into a single production management environment.
This paper presents a case study of an Integrated Asset model for a brown field re-development study project. The field has been producing over 25 years and is going through a field re-development plan with the implementation of Immiscible Water Alternate Gas scheme (iWAG). One of the primary aims of the project is to improve recovery factor through the debottlenecking of the surface system and EOR implementation of Immiscible Water Alternate Gas (iWAG) scheme. The Integrated Asset Modelling technology was used to perform a multi-disciplinary modeling and simulation environment to take into account new system mass balance by integrating the different components of the production system with the dynamic behavior of the reservoir.
The study showed the following results:• The impact of the facility bottleneck was identified and a debottleneck scenario was proposed• The suboptimal conceptual design was identified and a revised design was recommended• Production losses were evaluated averting significant impact to project financial metrics

Introduction
The Integrated Asset Model simulation case study described, herewith, was performed on a field that contains seven reservoirs that produce from more than 100 production wells and facilities. The original field layout consists of three production platforms, a separation and liquid handling platform, and a gashandling platform. In the re-development program for EOR Scheme, two tripods and one central processing platform are proposed to be added. The introduction of new infill wells and iWAG Enhance Oil Recovery scheme are expected to increase the liquid production.
An Integrated Asset model was created based on the conceptual design of the re-development program and was used to simulate and analyze the field planning scenarios. The integrated model was also used to identify the constraints within the entire production system that consists of Reservoir Simulation models and Well-Network models.
Multiphase Metering in Siberian Gas and Condensate Fields - Lessons leant in Multiphase Well Testing Operations since 2006.
Authors: Theuveny Bertrand C. , Romashkin Sergey Vyacheslavovich , Shako Valery , Rymarenko Konstantin , Afanasyev Vitaliy , Nukhaev Marat , Sultangareev Rustem 
Published: March 2015

Abstract
A number of multiphase flowmeters were recently deployed in the Yamal peninsula in Northern Siberia to perform multiphase measurements of the rates of gas and condensate wells. The utilization of multiphase flowmeters in wet gas and condensate wells is relatively new, and significant progress have been made in the understanding and the quantification of multiphase flowmeter uncertainties in flow loop. Little field experience is documented to date and this paper presents field data in this very challenging domain.
The operating environment combines an exceptional set of constraints ranging from high Gas Volume Fraction (up to 99.5%), water and hydrates, a large permafrost zone, tough environmental regulations, and a range of logistical constraints including difficulty of access to remoteness and communication challenges.
The paper describes the metrological evaluation of the full operations - not limiting itself to the dual energy gamma Venturi multiphase flowmeter that is being used, but also to the fluid property estimation. A discussion of the specific regulatory reporting in Russia for gas wells also presents some of the particularities of these operations.
The paper presents the results of testing over 50 wells since 2006- comparison to traditional and other multiphase flow metering devices are presented. Some unexpected behavior of these condensate wells are presented - confirmed by other instruments, resulting in a series of recommendations that provide a significant modification to the traditional guidelines used for the measurements of rates of gas, condensate and water in similar wells.
A brief discussion on the applicability of the multiphase measurements to condensate allocation workflows concludes the paper.

Introduction
Recent focus on gas condensate testing in the Yamal peninsula has pushed a number of operators to consider alternative way to perform such measurements. The operating are is quite challenging and located slightly north of the arctic circle in Northern Siberia as shown in Figure 1.
A Recipe to balance 'Black Box' and Deterministic Methods when designing Geological Models
Authors: Kuhn Oliver , Descamps Rien 
Published: March 2015

Abstract
This paper presents and discusses an experience based working approach and philosophy for geological modelling. The aim is to encourage a discussion on how to best balance and synergize powerful modelling technologies available today with bright thinking of scientists working for the petroleum industry. This method consists of (1) proper model framing in order to meet business objectives, (2) analysis of a suitable modelling technique to enable effective delivery of results, (3) in-depth uncertainty analysis through a dissection of the subsurface into its individual components, (4) selection of appropriate range of subsurface scenarios which cover uncertainties and risks (5) a variety of manipulative tools which can help to implement subsurface concepts which cannot easily be addressed with geostatistics and (6) a threefold tactic ("self-criticism" - "supervision" - "peer review") to facilitate quality control.

Introduction
This paper provides some nontechnical and technical methods which may help to achieve static geological modelling results faster and with a stronger link to business objectives.
The challenge today is not to fall prey to the "menace of the black box" by over-using powerful computer programs. Now-adays, with statistical algorithms being quite advanced, different models can be run in a very short time and the temptation is large to mechanically advance pushing buttons beyond the objectives and the aim of the modelling exercise planned. Modelling should not be chasing a "holy grail", but use the computing power efficiently and in a fit for purpose way to improve subsurface understanding, to plan and execute development projects in a safe and successful manner and to keep geological information and interpretation understandable and auditable.

Model Framing and Initialization

Call for a Conference
Before the start of every modelling exercise a generic framing exercise should be organized. Framing the planned modelling effort is aimed at (1) ensuring the modelling exercise is set on the right track from the start (2) avoiding misunderstanding between different parties involved and (3) to identify gaps in input data/concepts, manpower/funding, technical infrastructure available.
Evaluation of LNG, CNG, GTL and NGH for Monetization of Stranded Associated Gas with the Incentive of Carbon Credit
Authors: Khalilpour Rajab , Karimi Iftekhar A. 
Published: March 2015

Abstract
Associated gas is estimated to account for 17% of global gas reserves. However, majority of associated gas resources are small or located offshore which have made the utilization uneconomical. Operators have thus preferred either flaring or re-injecting the gas rather than utilization. Currently, none of these two options are favored as it is proven that gas re-injection has reverse effect on well recovery over time. Gas flaring is also not pleasant (even not permitted) because of stringent environmental regulations such as carbon tax. These reasons and the elevating energy prices have increased attentions towards utilization of associated gas resources.
There are a number of gas utilization technologies that have the potential to make the development of stranded gas resources economically viable. Some of these however have not yet been fully developed and proven on a commercial scale, though being conceptually feasible. The most advanced among these alternative technologies include LNG, CNG, GTL and NGH. These processes are highly capital-intensive and require considerable gas reserves to justify their deployment. Accordingly, these technologies are challenged to be economical when the size of the field is small (like most of the associated gas resources) or the markets are located far away from the field.
In this study, we have investigated each of these processes based on different variables such as reservoir capacity, distance to market, process CAPEX & OPEX, safety, etc. This paper discusses the pros and cons of these processes and presents the sweet spot for each of the technologies based on gas reserve and distance to market.

Associated Gas Problem
Associated gas is natural gas found in association with crude oil. According to the latest data from EIA, the total gas reserves in the world are about 6200 tcf. However, some studies have estimated that global associated gas reserves without commercial value exceed 1000 tcf (around 17% of total gas) [1].
National Geographic Data Center (NGDC) through collaboration with World Bank's Global Gas Flaring Reduction (GGFR) partnership is carrying out a project to develop a methodology to estimate global gas flaring volumes based on satellite sensor observations. The center has reported the global volume about 4.9–6.1 tcf per annum within the period of 1994 to 2008 with maximum amount of 6.1 tcf in year 2005 and minimum of 4.9 tcf in 2008 [2]. Such amount of gas accounts for about 5–6 % of total world's natural gas consumption [3].
Relative Sea Level reconstruction and time calibration of the Burgan-Mauddud-Wara of the Greater Burgan Field, Kuwait
Authors: Al-anezi Bashar Khalaif , Burman Kishore , Datta Kalyan , Le Guerroue Erwan , Filak Jean-Michel 
Published: March 2015

Abstract
The Albian Cenomanian sea level curve is fairly understood, at the 3rd order, in the Middle East region. We present here an exhaustive stratigraphic framework for the Burgan, Mauddud and Wara formations of the Greater Burgan field of Kuwait that is constrained in terms of accommodation depth of deposition and then relative base level variation.28 stratigraphic sequences (of 4th order) are recognized and propagated over 45cored wells throughout the entire field. Each of these sequences is characterized in terms of sedimentary facies and fossil / ichnofossils content from detailedcore description. For each sequence, an accommodation depth of deposition is then assigned taking into consideration facies changing along the slope of the basin. This process enables relative base level variation to be reconstructed vertically for 45 wells and average to account for intra-basinal tectonic forcing. The last step consists of addressing the basin subsidence history and the duration of the hiatus encountered in the basin using correlation with the global eustaticre cord (Miller et al., 2005; Haq and Al-Qahtami 2005; Haq et al., 1987) and absolute stratigraphic tie (calibrated palynological content).Direct comparison of the reconstructed relative sea level curve with reference curves allows to correlate the falling and rising cycle by picking main flooding surfaces and sequence boundaries. Results show that the Kuwait relative base level variation is in conformity with international chart allowing to constrain the stratigraphyin time. Burgan Formation was deposited during most of the Albian, whereas Mauddud is of late Albian age. Wara Formation and basal Ahmadi are Cenomanian age, as evident from Palynological data.

Introduction:
In Greater Burgan Field a new Geological model was built to capture the heterogeneity in the reservoirs. This called for a study of the depositional model from a Sequence Stratigraphic standpoint. This study has been done on the Albian-Cenomanian Burgan-Mauddud-Wara Formations of the Greater Burgan Field in Kuwait. An exhaustive stratigraphic frame-work for the Formations was built constrained in terms of accommodation, depth of deposition and then relative base level variation. Reconstruction of the historical variation in relative sea level through geological time is key to the understanding of the stratigraphy in proper perspective and prediction of facies in a basin.28 stratigraphic sequences (of 4th order) are recognized based on sedimentary facies associations studied in 45 cored wells across the field. The fourth order cyclicity is corroborated with bathymetry changes interpreted from palynoflora and ichnofossils. Several known methods were tried to reconstruct the sea level variation history in the Greater Burgan Field of Kuwait, which is the world's largest clastic oil field. (Figure1).
Combining Conventional and Wireline Formation Testing for Improved Reservoir Characterization
Authors: Ramaswami Shyamalan , Elshahawi Hani , El-Battawy Ahmed 
Published: March 2015

Abstract
Well testing has long been a valuable tool for the petroleum industry. The practice continues to be widely used today, but an increasing number of situations arise in which conventional well tests can be impractical due to cost, logistical or environmental constraints. For instance, in Arctic areas, weather conditions may dictate a time window beyond which operations must cease. In such cases, a wireline formation tester (WFT) test may present a viable alternative to acquire formation fluid samples and pressure transient data (WFT-PTA).
WFT-PTA uses a probe or a straddle packer to test a selected reservoir interval. Downhole pumps are used to clean up mud filtrate invasion and flow formation fluids at a stable rate. Downhole fluid analysis (DFA) is used simultaneously to monitor clean up and measure fluid properties such as fluid color, density, and Gas-Oil ratio (GOR) in real time. As part of the sequence, one or more pressure build up periods may be performed on each WFT-PTA station. Similar to classic well test analysis, transient pressure interpretation of the drawdown and buildup responses is used to derive the mobility thickness product and skin relevant to the rock volume investigated by the test. The permeability of that flow unit can be then calculated using the thickness of the flow unit and viscosity of the formation fluid as inputs.
In this paper, we present field data in which the integration of WFT-PTA results and fine-scale permeability indicators such as petrophysical log and core data are compared with conventional well testing using drillstem test (DST) results. We show that, as long as the scale of measurement is taken into account, and appropriate upscaling methods are used, reservoir parameters obtained are in close agreement over the same interval. In addition, the WFT-PTA reveals differences in permeability between individual flow units.
Two case studies are presented to compare independently derived permeability of the reservoirs. Permeability from WFTPTA derived from discrete intervals where WFT-PTA tests were carried out, is used to upscale continuous permeability measurements, such as Nuclear Magnetic Resonance (NMR) or Porosity-Permeability (K-PHI) derived permeability, in order to provide a better estimate of permeability over a zone to be perforated and well tested, or produced.
This integrated approach can be used to complement and calibrate well testing (DST) results or to acquire sufficient reservoir information when a full well test is not feasible and/or not required. The advantages and limitations of this approach are discussed to assist the proper selection of test types depending on desired objectives.
Multi-Azimuth, Coil Shooting And Dual Sensor Streamer Acquisition: Step Change Seismic Imaging Results In Deep Water Indonesia
Authors: Buia Michele , Tozzi Emanuele , Ravasio Alessia , Brown Peter 
Published: March 2015

Abstract
While wide-azimuth seismic surveys represent a routine in land environments, in marine environments things go differently. Conventional offshore 3D acquisition is still being performed mainly using narrow azimuth streamer configurations, even in structurally complex areas. Attempts at breaking this paradigm have been recently made by the industry with good results, through the acquisition of some unconventional "Multi Azimuth" (MAZ), "Wide Azimuth" (WAZ), "Rich Azimuth" (RAZ) and Coil Shooting marine surveys. Here we are presenting planning, acquisition and processing results of the advanced marine surveys, a Multi-Azimuth and a Coil shooting (Full azimuth), recently acquired by Eni e&p in Indonesia. We are also presenting a 2D test and successive 3D acquisition of a broad bandwidth (dual sensor) seismic in West Timor area, aimed at exploiting sub thrust geology. At the end we demonstrate that advanced acquisition techniques effectively provide improved geophysical images and more geological insight for exploration compared to traditional techniques.

Introduction
Towed Streamer Marine seismic acquisition generates a dataset with a limited azimuth range, of the order of 10o. In areas of complex geology, this limited azimuth collection, can result in very poor illumination of the reservoir by the seismic wave-field, due to bending and scattering of the ray-paths in the over-burden. Over the last five years, efforts to mitigate this poor illumination effect, with marine towed streamer surveys, have focused on acquisition solutions to generate seismic datasets with better azimuth distribution. The efforts included multi-direction and multi-vessels geometries to acquire surveys rich in azimuth. These techniques have proven to provide significant value in complex imaging environments; however they are constrained by the cost and availability of the multi-pass, multi-vessel operations.