Breaking Paradigms in old Fields. Finding “the reservoir key” for Mature Fields Redevelopment, Part I: Reviewing infill projects in complex reservoirs.
Two field examples will be presented, where after 50 years of development; fresh oil and gas were produced by changing some reservoir paradigms.
Upsides could be overlooked due to paradigms on field development. The successful one in terms of reserves and cost effective capital expenditure could be visualized as “finding the key for the field”. But as development takes place over many years (decades), the “key” should be a dynamic concept over time, correlated with technology availability, enabling us a better understanding of petroleum resources size, quality and distribution.
Field development plan, rate of production,SYED NAWAZ
It gives you an idea about an impact of reservoir damage on production rate
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This document summarizes a study evaluating different multistage hydraulic fracturing patterns in naturally fractured reservoirs using a coupled geomechanics fracture and flow model. The study models three fracturing patterns - conventional, zipper, and alternating - in a field case with multiple horizontal wells. Simulation results show the zipper pattern provides the highest long-term production rates and cumulative oil volume over 20 years compared to the other patterns. The zipper pattern is recommended as the optimal completion strategy for this type of reservoir.
The field development plan aims to maximize oil recovery from the Sirri-A oil field located offshore Iran. Key objectives include developing a reservoir model, evaluating development strategies, and determining cash flows. The reservoir is a limestone formation from the Cretaceous period. Analysis shows it has an initial oil in place of 1.78 billion stock tank barrels and is primarily driven by water. Development scenarios include a base case, increased well counts, secondary water injection, and tertiary WAG injection. The WAG scenario recovers an estimated 52.3% of the oil in place.
PENNGLEN FIELD Development Plan (GULF of MEXICO)PaulOkafor6
A FDP designed with the goal to define the development scheme that allows the optimization of the hydrocarbon recovery at a minimal cost for project sanction
This was designed by MSc Students from the Institute of Petroleum Studies, UNIPORT/ IFP School, France
Increasing interest by governments worldwide on reducing CO2 released into the atmosphere form a nexus of of opportunity with enhanced oil recovery which could benefit mature oil fields in nearly every country. Overall approximately two-thirds of original oil in place (OOIP) in mature conventional oil fields remains after primary or primary/secondary recovery efforts have taken place. CO2 enhanced oil recovery (CO2 EOR) has an excellent record of revitalizing these mature plays and can dramatically increase ultimate recovery. Since the first CO2 EOR project was initiated in 1972, more than 154 additional projects have been put into operation around the world and about two-thirds are located in the Permian basin and Gulf coast regions of the United States. While these regions have favorable geologic and reservoir conditions for CO2 EOR, they are also located near large natural sources of CO2.
In recent years an increasing number of projects have been developed in areas without natural supplies, and have instead utilized captured CO2 from a variety of anthropogenic sources including gas processing plants, ethanol plants, cement plants, and fertilizer plants. Today approximately 36% of active CO2 EOR projects utilize gas that would otherwise be vented to the atmosphere. Interest world-wide has increased, including projects in Canada, Brazil, Norway, Turkey, Trinidad, and more recently, and perhaps most significantly, in Saudi Arabia and Qatar. About 80% of all energy used in the world comes from fossil fuels, and many industrial and manufacturing processes generate CO2 that can be captured and used for EOR. In this 30 minute presentation a brief history of CO2 EOR is provided, implications for utilizing captured carbon are discussed, and a demonstration project is introduced with an overview of characterization, modeling, simulation, and monitoring actvities taking place during injection of more than a million metric tons (~19 Bcf) of anthropogenic CO2 into a mature waterflood.
Longer versions of the presentation can be requested and can cover details of geologic and seimic characterization, simulation studies, time-lapse monitoring, tracer studies, or other CO2 monitoring technologies.
Title: Maximizing the Opportunity in Multi-Layered Tight Sand Reservoirs in a Mature Field by Hydraulic Fracturing: A Case Study of Tight Sand Development Project in Thailand
Conditioning Pre-existing Old Vertical Wells to Stimulate and Test Vaca Muerta Shale Productivity through the Application of Pinpoint Completion Techniques.
The document discusses several innovations in oil and gas technology from the January 2020 edition of World Oil Magazine. It describes how various operators have used new technologies like ultra-deep resistivity services, dual drilling operations, acoustic logging tools, formation evaluation from cuttings, and horizontal lift systems to optimize operations, reduce costs, increase production and safely drill complex wells.
Marginal oil fields present economic challenges but can be profitably developed using unconventional techniques. The document outlines various unconventional techniques like horizontal drilling, hydraulic fracturing, tiebacks, and cable deployed ESPs that have been successfully used in case studies to reduce costs and increase production from marginal fields, making them economically viable. It also discusses the data and time constraints faced in developing marginal fields and how various conventional techniques can help optimize costs.
The document provides information on prospect evaluation methodology for oil companies and governments. It discusses how prospect evaluation is used for resource assessment, contracting areas, work commitments, and investment decisions. The methodology includes volumetric and economic evaluations using seismic interpretation, mapping, cash flow analysis, and other factors. Equations and parameters involved in calculating the volumes of oil and gas in-place are also presented, such as pore volume, recovery factors, and formation properties. An example calculation of recoverable oil resources is included to demonstrate the process.
What are my 3P Reserves? Haas Petroleum Engineering Serviceshaasengineering
What is the best way to estimate your 3P reserves? President of Haas Petroleum Engineering Services Thad Toups gave this presentation on Haas' internal analytics and auditing methodology.
Culzean HPHT: Lessons Learnt From Maersk Oil UK's 1st HPHT Exploration Well &...HPHT Wells Summit
The document discusses lessons learned from the Culzean HPHT exploration well and issues related to appraisal planning. It summarizes the exploration well results, noting that while objectives were achieved there were challenges around pore pressure and fracture gradients. It recommends a "HPHT heavy" design for the appraisal well using a deeper set 13 5/8" intermediate casing to facilitate testing from multiple zones and enable setting the 9 7/8" production casing as deep as possible. The objectives of the appraisal well are to acquire sufficient key data to ascertain economic development and detailed development design.
Middle stage production period in messla fieldShakier Khalifa
Compositional gradient is important factor to determined, many signs could lead you. The paper experience some factors in Messla and hence give recommendation.
SPE 165151 - The Long-term Production Performance of Deep HPHT Gas Condensat...John Downs
Formate brines have been in use since 1995 as non-damaging drill-in and completion fluids for deep HPHT gas condensate field developments. The number of HPHT fields developed using formate brines now totals more than 40, and includes some of the deepest, hottest and highly-pressured reservoirs in the North Sea. The well completions have been both open-hole and cased-hole.
An expectation from using formate brines as reservoir drill-in and completion fluids is that they will cause minimal damage to the reservoir and help wells to deliver their full productive potential over the life-time of the field. The validity of this expectation has been tested by examining the long-term hydrocarbon production profiles of eight HPHT gas condensate fields in the North Sea where only formate brines have been used as the well completion fluids. In five of these fields the wells were drilled with oil-based muds and completed by perforating in cased hole with high-density formate brines. In another two of the fields the wells were drilled with formate brines and completed with screens entirely in open hole using the same brines. The last of the eight fields was drilled with formate brine and the wells were then completed with same fluid in either open hole or cased hole.
The results of the production analysis provide a unique insight into the impact of a single type of specialist drill-in and completion fluid on the rate of recovery of hydrocarbon reserves from deeply-buried reservoirs in the North Sea
Reserve Estimation of Initial Oil and Gas by using Volumetric Method in Mann ...ijtsrd
This research paper is focused to estimate the current production rate of the wells and to predict field remaining reserves. The remaining reserve depends on the production points that selected to represent the real well behavior, the way of dealing with the production data, and the human errors that might happen during the life of the field. Reserves estimating methods are usually categorized into three families analogy, volumetric, and performance techniques. Reserve Estimators should utilize the particular methods, and the number of methods, which in their professional judgment are most appropriate given i the geographic location, formation characteristics and nature of the property or group of properties with respect to which reserves are being estimated ii the amount and quality of available data and iii the significance of such property or group of properties in relation to the oil and gas properties with respect to which reserves are being estimated. In this research paper, the calculation of collecting data and sample by volumetric method are suggested to estimate the oil and gas production rate with time by using the geological configuration and the historical production data from CD 3700 3800 sand in Mann Oil Field. San Win "Reserve Estimation of Initial Oil and Gas by using Volumetric Method in Mann Oil Field" Published in International Journal of Trend in Scientific Research and Development (ijtsrd), ISSN: 2456-6470, Volume-3 | Issue-5 , August 2019, URL: https://www.ijtsrd.com/papers/ijtsrd27945.pdfPaper URL: https://www.ijtsrd.com/engineering/petroleum-engineering/27945/reserve-estimation-of-initial-oil-and-gas-by-using-volumetric-method-in-mann-oil-field/san-win
Four Key Considerations for Mature Fieldssusan nash
With the recent surge in new techniques and technology, as well as new plays put into production, a tremendous opportunity exists in both U.S. and international reservoirs to apply lessons learned to existing reservoirs in order to economically increase production and recoverable reserves.
This document discusses several concepts related to the behavior of materials under load including:
1. Modules of rupture describes the ability of a material to resist deformation due to an applied load using an equation involving stress and bending moment.
2. Fatigue is deformation due to cyclic loading such as repeatedly bending a steel rod.
3. Creep is slow deformation over time under a sustained load due to mechanical stress.
4. Shrinkage is the reduction in size of a material like concrete due to drying or loss of water over time with no external loads.
Oil field bids in Mexico: Round 1.3. “Onshore Fields”. Commerciality evaluati...Juan Diego Suarez Fromm
An Economical model for oil field development was built for onshore License Contracts in Mexico. Sensibility analysis for price, royalties and costs was performed. A conceptual profitability map was obtained, leading to some important conclusions for awarded Fields in Round One Bid #3. Some would be uncommercial and others would have critical performance due to very high offers in royalty. Sensibility analysis also shows that Government Revenue model promotes investments in a License Contract in oil price range between 30 and 100 usd/bbl; aiding the high royalties cases to achieve profitability under favourable costs conditions.
Upcoming Round 1.5. “Unconventionals”. Part I: Exploring contract terms and f...Juan Diego Suarez Fromm
Shale gas potential in Mexico has been identified by government, Mexican National Oil Company - PEMEX, and international petroleum industry, as a great opportunity for resources development in order to solve increasing natural gas demand.
Large gas pipeline extension and power generation projects have been launched and others are on the way according to National Infrastructure Program. In the mid-term U.S. gas exports are expected to continuously rise, which for some political parties is a threat to Mexican energy independence.
The upcoming Round One bids for onshore fields will comprise Unconventional resources including Shale Gas, Shale Oil and Chicontepec. The aim of this study is to evaluate Shale Gas development profitability for different gas prices, costs and royalties and more important to develop fiscal and contract incentives alternatives based on geological trends, current well construction technologies, technical risks and market risk.
Improved oil recovery techniques can be categorized as primary, supplemental, or enhanced recovery. Primary recovery utilizes natural reservoir energies, supplemental recovery uses external energies like water or gas to supplement primary recovery, and enhanced recovery uses external energies that fundamentally change fluid properties. Some key improved oil recovery techniques include gas injection methods, modified waterflooding, flow diversion techniques, and improved reservoir management through new well technologies and monitoring. These techniques aim to extract more oil from reservoirs and tight formations.
This document summarizes a study evaluating completion effectiveness in horizontal multi-stage fractured wells in the Pembina Cardium field. It reviews production metrics like maximum oil rate and cumulative oil after 1 year to assess completion performance. Case studies of 2006-2009 and 2014 wells show early wells were affected by offsetting waterfloods while later wells remained in linear flow for over 1 year. Cumulative oil after 365 days normalized by number of stages was selected as the production metric. A comparison of different treatment fluids found slickwater was suboptimal, while polyemulsions and foams had the best performance based on normalized cumulative oil and completion costs. Proppant concentration may impact gas well performance but is less important than fracture length for
Water Injection & Treatment for Tight Oil EOR
EOR choices for light Tight Oil
Potential damage to reservoir and well bore.
Water Specifications & Treatment
Case Studies:
1. Advanced Water Flooding
2. Frac injectors?
3. Low Salinity Water Flooding
Topics Include:
Filtration
Water Quality
Reservoir Pressure
Este documento analiza los vínculos entre el comercio y la seguridad alimentaria. Examina cómo el comercio afecta a la disponibilidad, el acceso, la utilización y la estabilidad de los alimentos, y cómo diferentes factores como los mercados y las políticas pueden influir en estos vínculos. También discute cómo los países pueden gestionar el comercio a través de políticas comerciales y otras políticas conexas para promover objetivos de seguridad alimentaria. Finalmente, argumenta que mejorar los procesos de gob
Banco de preguntas sobre los tipos de redes Kevin Lema
Este documento contiene preguntas y respuestas sobre diferentes tipos de redes. Explica conceptos como redes inalámbricas, redes de área local y amplia, direcciones IP, y servidores de red. Define una red como un conjunto de equipos conectados que comparten información y recursos. Describe una red Wi-Fi como una red inalámbrica que usa frecuencias de radio para comunicarse, y una red LAN como una red de computadoras en un área reducida como una casa o edificio.
מחלקת הפייסבוק שלנו הכינה מדריך מפורט על בסיס ניסיון רב מניהול קמפייינים בעולם התיירות לגבי השלבים בהפיכת ערוץ הפייסבוק לאפיק הכנסה משמעותי בענף התיירות.
This document discusses re-entry horizontal drilling for enhanced oil recovery in Indonesia. It begins by outlining drivers for enhancing oil recovery through re-entry drilling such as declining production from existing wells. It then provides background on Indonesia's oil production history and challenges in meeting production targets. The document describes Geoglide's services for directional drilling, well planning, and risk reduction for re-entry horizontal wells. It discusses factors to consider such as well selection, drilling unit selection, horizontal drilling technology options, and information needed to plan a re-entry horizontal drilling project. The conclusion emphasizes that EOR projects require cost-effective and low-risk solutions.
While America as a whole is undergoing a 'shale oil boom', the question that remains is "what do operators need to do to make it happen in California?"
The Department of Energy has estimated that the Monterey shale contains 15 billion barrels of oil - more than the Bakken and Eagle Ford shales collectively. This, combined with a mean of 6.5 billion barrels in San Joaquin fields such as the Kern River, Elk Hills, Midway-Sunset and Belridge South, around 1 million barrels in the Santa Maria basin, means California literally has the potential to become the most prolific oil resource within the US.
To fully exploit the Monterey and surrounding unconventional resources within California, the structural and lithological complexity of shale and diatomite reservoirs needs to be further understood to enable the identification of stimulation technologies that will maximize oil recovery, whether it be acid fracturing, hydraulic fracturing or steam injection.
The Tight Oil Reservoirs California 2014 Congress is the only E&P led congress with a specific focus on optimizing recovery in unconventional reservoirs within California. Leading E&P companies from the Monterey, Kreyenhagen and wider San Joaquin, Santa Maria and LA Basins will showcase optimized logging suites and seismic technologies to obtain key petrophysical, geomechanical and lithological data of California's sediments to finally be able to commercially exploit shale and to increase return on investment within diatomite.
Considering the sensitive nature of the current regulatory environment, strategies for complying with SB4 and AB32 and expediting hydraulic fracturing and steam injection permit approvals will be also examined. Finally, speakers will discuss case studies on how to source, transport and recycle water to ensure compliance with state regulations while minimizing operational costs within California.
What's new this Year?
NEW LOCATION - Hong Kong.
PLASMA FRACTIONATION TECHNOLOGY WORKSHOP.
REGULATOR’S FORUM - meet Global and Asian regulatory experts for plasma and blood products.
GLOBAL EMERGING MARKETS Self Sufficiency Case Studies: China, India, Iran and more.
INSIGHTS to the first South East Asian plasma fractionation plant.
No other Bioplasma event can get you one-to-one access to senior decision-makers from both the international and regional Bioplasma industry.
This document discusses tight reservoirs, which are reservoirs with very low permeability (less than 0.1 mD) and porosity (less than 10%). It defines tight gas reservoirs, tight oil reservoirs, and the characteristic properties of tight reservoirs, such as low porosity and permeability. It also discusses the importance of logging, factors to consider for tight reservoirs like geologic and reservoir properties, and techniques used to produce from tight reservoirs, including hydraulic fracturing and horizontal drilling. Tight reservoirs account for a large portion of remaining oil and gas reserves and require advanced drilling and completion techniques to produce economically.
Larry Shultz presents TexasEOR.com Exhaust Gas Injection CO2 Enhanced Oil Rec...Larry Shultz
Why spend >$50-$60 to produce a barrel of shale/tight oil, when new portable exhaust gas injection EOR equipment has the potential to recover oil for less than $15-$25 per barrel?
Fielding the oil industry’s next-generation fleet of fully-automated, portable exhaust gas injection N2+CO2 EOR skids to bring low-cost, variable-pressure gas injection EOR capabilities on-site to EOR-worthy mature and legacy oil fields that are too far away from and cannot be economically served by CO2 pipelines.
This document discusses shale and tight reservoir simulation using CMG software. It outlines modelling features like PVT treatments, dual porosity modelling, adsorbed components, diffusion, relative permeability, compaction/dilation tables, initial fluid saturations, and explicit gridding of propped fractures. It also discusses modelling workflows, history matching a base case model, sensitivity analysis, reference operators using CMG simulators, and SPE papers on shale modelling and simulation.
Similar to Breaking Paradigms in old Fields. Finding “the reservoir key” for Mature Fields Redevelopment, Part I: Reviewing infill projects in complex reservoirs.
This document discusses the economics of recycling, a process for separating condensate from gas-distillate gas at high pressure and returning the residual gas to reservoirs. Key points:
1) Estimating reserves, costs, and recovery factors are challenging but important for projecting recycling operations. Recovery factors are typically 60-70% rather than earlier estimates of 85-90%.
2) Plant size is determined by reserves, gas/condensate markets, and costs. Larger plants (~75 million cubic feet/day) have lower per unit costs but smaller plants (25-50 million cubic feet/day) reduce risks.
3) Operating costs per unit are affected by factors like reservoir pressure, gas richness
This document summarizes the use of a packerless, multistage fracture stimulation method called pinpoint fracturing (PPF) in Argentina. Key points:
1) PPF has been used to complete 22 wells with 193 fractures since 2006, allowing more selective stimulation and aggressive fracturing treatments.
2) The method uses coiled tubing to hydrajet perforate intervals and pump fracturing fluid down the annulus, isolating stages with sand or bridge plugs.
3) A case study describes applying PPF across 9 wells with 90 stages, reducing completion times compared to conventional methods using packers.
1) The document discusses conditioning an old vertical well drilled in 1974 in Argentina to stimulate and test productivity from the Vaca Muerta shale formation.
2) A pilot program was conducted on three wells, applying coiled tubing assisted pinpoint completions to independently stimulate small intervals, with 12 stages used over 130m.
3) The pilot was successful, with the wells producing oil naturally. It demonstrated the viability of the completion technique for stimulating older vertical wells in the Vaca Muerta shale.
This document discusses recent trends and the future of ultra deepwater oil field developments. It summarizes that developments in ultra deepwater have very high costs, prompting companies to consider more standardized and innovative solutions. Subsea wells and FPSOs have become the standard for field development below depths of around 2500-3000 meters. New technologies like subsea separation, direct electrical heating of flowlines, and subsea power distribution are being successfully implemented and will likely become more common. Future field developments are expected to utilize more standardized components coupled with innovative technologies to reduce costs and maximize recovery in ultra deepwater environments over the next 5-10 years.
The document summarizes the installation of an innovative "Capillary Conveyed" gas lift extension system in a well in Vietnam. The existing gas lift system was no longer effective due to declining reservoir pressures. The new system used a 0.75" diameter capillary string to extend the gas lift injection point deeper into the well. After installation, the well resumed production, flowing for 60 days at rates exceeding expectations before being placed on a production cycle. Cumulative production since was 43,000 barrels of oil, with an estimated payback of only 4 days for the installation. The installation demonstrated that the new technology can effectively reinstate production from wells with inefficient gas lift systems.
This document summarizes the use of liquid curable resin (LCR) systems to control proppant flowback in hydraulic fracturing operations in Argentina. Various operators applied LCR either during initial fracturing treatments by coating proppant on-site, or as remedial treatments by injecting resin into existing fractures. LCR treatments helped stop proppant flowback while maintaining production rates, reducing cleanout costs compared to untreated wells. Lessons showed resin concentration and additive selection are important to maximize proppant pack strength and conductivity. Field results demonstrated LCR treatments effectively control solids flowback to optimize well productivity.
The document discusses the use of formate brines, specifically cesium formate brine, as drilling, completion and suspension fluids for deep, high pressure high temperature (HPHT) gas wells. Cesium formate brine provides benefits such as stability at high temperatures, compatibility with reservoirs, and less corrosion and damage compared to other brines. It has been used successfully in over 50 HPHT gas field developments worldwide, enabling improved well construction methods like open hole completions.
The document discusses the use of formate brines, specifically cesium formate brine, as drilling, completion and suspension fluids for deep, high pressure high temperature (HPHT) gas wells. Cesium formate brine provides benefits such as stability at high temperatures, compatibility with reservoirs, and less corrosion and damage compared to other brines. It has been used successfully in over 50 HPHT gas field developments worldwide, enabling improved well construction methods like open hole completions.
UNDERSTANDING THE REFRACTURING IN TIGHT OIL RESERVOIRSiQHub
This document discusses re-hydraulic stimulation in tight oil reservoirs. It provides an agenda for discussing re-hydraulic stimulation pilots and case studies. The first part summarizes a pilot re-hydraulic stimulation job on Well X, including the design, execution using diverters and multiple proppant stages, and production results showing increased output. It then discusses the rollout process to additional wells, including ranking wells based on potential and workover difficulty. Case studies of successful re-stimulation on Well Z and unsuccessful on Well T are presented.
SPE 199286 - Profiling the Production Performance of Five HPHT Gas Condensate...John Downs
1. The document discusses production performance from five high-pressure, high-temperature gas condensate wells in the Kvitebjorn Field in the Norwegian North Sea that were drilled and completed using cesium formate drilling fluids.
2. Logging data obtained using cesium formate brine showed improved reservoir quality, leading to a 33% increase in estimated hydrocarbon reserves. Actual cumulative production from the field has matched or exceeded revised reserve estimates.
3. Cumulative production from the initial five wells after 14 years is now higher than the original reserves projection for the entire field, demonstrating the benefits of using cesium formate fluids for drilling and completion.
This document summarizes integrated asset modeling efforts for the mature Teak, Samaan, and Poui (TSP) offshore oil fields in Trinidad. The TSP fields are interconnected and produce via a complex network of pipelines and facilities. Integrated asset modeling of the 100 wells, gas lift network, compressors, and other infrastructure is used to identify optimization opportunities, ensure peak performance, and estimate remaining reserves. Real production and sensor data is incorporated into the integrated model to reflect changes and guide decision making. The modeling aims to maintain and potentially increase the current production rate of 13,500 barrels of oil per day from the long-producing fields.
This document provides information about cesium formate brine, including its uses, benefits, and the company that produces it. Specifically:
- Cesium formate brine is a high-density, non-toxic brine used for drilling, completing, and suspending deep gas wells. It can have densities up to 143 pcf.
- Using cesium formate brine improves economics by allowing faster drilling and completions while improving well safety. It also maximizes reservoir production and definition.
- Cabot Corporation produces cesium formate brine from pollucite ore in Canada. It has been used in over 250 deep gas wells worldwide since 1999.
The document discusses subsea processing technologies and their role in the subsea economy. It notes that subsea processing, including technologies like subsea compression, separation, and boosting, are improving production efficiencies and reserves recovery from oil and gas fields. These technologies also allow functions to be moved underwater, reducing complexity on offshore platforms. The UK North Sea provides opportunities for these emerging subsea technologies as many fields there are maturing. Subsea processing offers cost advantages after initial investment and can help develop smaller, marginal fields by improving recovery and using existing infrastructure. The East of England region has potential to supply these subsea technologies to North Sea fields but currently lacks a significant competency in subsea processing.
SPE 165151 The Long-Term Production Performance of Deep HPHT Gas Condensate ...jdowns
Maps and analyses the long-term production of eight HPHT gas and condensate fields in which formate brines were the last well construction fluids to contact the producing reservoirs
The document provides a summary of the Celeus 1 well. It drilled the first section to 587 feet with a 17 1/2" hole through the Guayabo Formation using an AQUAGEL/X-TEND II fluid system. The second section was drilled from 587 to 8,863 feet with a directional 12 1/4" bit through several formations using filtered polymer mud. The final section from 8,863 to 11,624 feet used a BARADRIL-N system. The fluid programs achieved good hole cleaning and stability. Recommendations include improving solids control equipment and signage on the rig. The total well cost was $308,448.40.
- The document discusses proppant selection and usage for hydraulic fracturing in unconventional reservoirs in Argentina, focusing on the Neuquén Basin.
- For shale reservoirs like Vaca Muerta, most treatments used white sand or intermediate strength proppant in 40/70 or 30/50 mesh sizes, with around 475,000 lbs of proppant per stage.
- For tight reservoirs like Mulichinco and Punta Rosada, most used intermediate strength proppant or resin-coated proppant in 30/60 or 20/40 mesh sizes, with around 150,000 lbs of proppant per stage.
This document summarizes the development of piston rod seals for Stirling engines in Sweden over the past 40 years. It describes how earlier Stirling engines operated at near-atmospheric pressures but modern designs require pressures of 10-20 MPa. This necessitates a rod seal between the high-pressure working space and low-pressure crankcase. Early Swedish designs included the "Leningrader" and "Pumping Leningrader" seals, which Cleanergy still uses. The document outlines Cleanergy's efforts to analyze operating conditions, improve materials, and increase seal service life from the original 1980s design. Measurements of pressure, temperature, and friction help characterize the environment and guide simulations. The goal is to
Far East Energy - Corporate Presentation January 2014Company Spotlight
Far East Energy Corporation is a leading developer of coalbed methane resources in China. The company's large block in Shouyang has high permeability and gas content, making it one of the few large CBM blocks in China with this important characteristic. The block has over 440 Bcf of net proved and probable reserves and a post-tax NPV of over $2 billion based on a long term gas sales contract with favorable pricing. The block benefits from excellent infrastructure including multiple pipelines and markets with over 325 MMcf/d of potential offtake capacity, positioning Far East Energy for strong production and cash flow growth.
Foam Assisted Surfactant-Alternating-Gas Injection for Heavy Oil Recovery thr...Antonio B. Mejia Jr.
This document proposes a method for producing heavy oil through permafrost in Alaska's North Slope region. A vertical well will be drilled and completed with two deviated laterals, one for injection and one for production. Carbon dioxide injection will be used to reduce oil viscosity and interfacial tension. Special casing, cementing, and insulation techniques will maintain permafrost integrity. Foam assisted surfactant-alternating gas injection combined with artificial lift will enable heavy oil production while preserving the permafrost layer.
Similar to Breaking Paradigms in old Fields. Finding “the reservoir key” for Mature Fields Redevelopment, Part I: Reviewing infill projects in complex reservoirs. (20)
I am Dr. T.D. Shashikala, an Associate Professor in the Electronics and Communication Engineering Department at University BDT College of Engineering, Davanagere, Karnataka. I have been teaching here since 1997. I prepared this manual for the VTU MTech course in Digital Communication and Networking, focusing on the Advanced Digital Signal Processing Lab (22LDN12). Based on, 1.Digital Signal Processing: Principles, Algorithms, and Applications by John G. Proakis and Dimitris G. Manolakis, Discrete-Time Signal Processing by Alan V. Oppenheim and Ronald W. Schafer, 3.Digital Signal Processing: A Practical Guide for Engineers and Scientists" by Steven W. Smith. 4.Understanding Digital Signal Processing by Richard G. Lyons. 5.Wavelet Transforms and Time-Frequency Signal Analysis" by Lokenath Debnath . 6. MathWorks (MATLAB) - MATLAB Documentation
An Internet Protocol address (IP address) is a logical numeric address that is assigned to every single computer, printer, switch, router, tablets, smartphones or any other device that is part of a TCP/IP-based network.
Types of IP address-
Dynamic means "constantly changing “ .dynamic IP addresses aren't more powerful, but they can change.
Static means staying the same. Static. Stand. Stable. Yes, static IP addresses don't change.
Most IP addresses assigned today by Internet Service Providers are dynamic IP addresses. It's more cost effective for the ISP and you.
Natural Is The Best: Model-Agnostic Code Simplification for Pre-trained Large...YanKing2
Pre-trained Large Language Models (LLM) have achieved remarkable successes in several domains. However, code-oriented LLMs are often heavy in computational complexity, and quadratically with the length of the input code sequence. Toward simplifying the input program of an LLM, the state-of-the-art approach has the strategies to filter the input code tokens based on the attention scores given by the LLM. The decision to simplify the input program should not rely on the attention patterns of an LLM, as these patterns are influenced by both the model architecture and the pre-training dataset. Since the model and dataset are part of the solution domain, not the problem domain where the input program belongs, the outcome may differ when the model is trained on a different dataset. We propose SlimCode, a model-agnostic code simplification solution for LLMs that depends on the nature of input code tokens. As an empirical study on the LLMs including CodeBERT, CodeT5, and GPT-4 for two main tasks: code search and summarization. We reported that 1) the reduction ratio of code has a linear-like relation with the saving ratio on training time, 2) the impact of categorized tokens on code simplification can vary significantly, 3) the impact of categorized tokens on code simplification is task-specific but model-agnostic, and 4) the above findings hold for the paradigm–prompt engineering and interactive in-context learning and this study can save reduce the cost of invoking GPT-4 by 24%per API query. Importantly, SlimCode simplifies the input code with its greedy strategy and can obtain at most 133 times faster than the state-of-the-art technique with a significant improvement. This paper calls for a new direction on code-based, model-agnostic code simplification solutions to further empower LLMs.
Ludo system project report management .pdfKamal Acharya
OpenGL is a library for doing computer graphics.By using it, we can create interactive applications which
render high-quality color images composed of 3D geometric objects and images. OpenGL is window and operating
system independent. As such, the part of our application which does rendering is platform
independent.However,inorderforOpenGLtobeabletorender,itneedsawindow to draw into. Generally,
The Project OpenGL Ludo-Board Game is a computer graphics project. The computer
graphics project used open source library – OpenGL with the c++. This c++ project is based on
one of the oldest Board Game – the Ludo. This OpenGL Ludo game is of two player game and
not the regular four player.
Ludo is a board game for two to four players,in which the players race their four tokens from
start to finish accordingly to die rolls.Like other cross and circle games,Ludo is derived from the
Indian game Pachisi but simpler.The game and its variant are popular in many countries .
Introduction And Differences Between File System And Dbms.pptxSerendipityYoon
An introduction to file systems and a database management system. This document provides a free powerpoint presentation about the differences between a file system and database management system. Advantages and disadvantages of file system and database management system.
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FINE-TUNING OF SMALL/MEDIUM LLMS FOR BUSINESS QA ON STRUCTURED DATAkevig
Enabling business users to directly query their data sources is a significant advantage for organisations.
The majority of enterprise data is housed within databases, requiring extensive procedures that involve
intermediary layers for reporting and its related customization. The concept of enabling natural language
queries, where a chatbot can interpret user questions into database queries and promptly return results,
holds promise for expediting decision-making and enhancing business responsiveness. This approach
empowers experienced users to swiftly obtain data-driven insights. The integration of Text-to-SQL and
Large Language Model (LLM) capabilities represents a solution to this challenge, offering businesses a
powerful tool for query automation. However, security concerns prevent organizations from granting direct
database access akin to platforms like OpenAI. To address this limitation, this Paper proposes developing
fine-tuned small/medium LLMs tailored to specific domains like retail and supply chain.These models
would be trained on domain-specific questions and Queries that answer these questions based on the
database table structures to ensure efficacy and security. A pilot study is undertaken to bridge this gap by
fine-tuning selected LLMs to handle business-related queries and associated database structures, focusing
on sales and supply chain domains. The research endeavours to experiment with zero-shot and fine-tuning
techniques to identify the optimal model. Notably, a new dataset is curated for fine-tuning, comprising
business-specific questions pertinent to the sales and supply chain sectors. This experimental framework
aims to evaluate the readiness of LLMs to meet the demands for business query automation within these
specific domains. The study contributes to the progression of natural language query processing and
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Breaking Paradigms in old Fields. Finding “the reservoir key” for Mature Fields Redevelopment, Part I: Reviewing infill projects in complex reservoirs.
1. 1
Breaking Paradigms in old Fields. Finding “the reservoir key” for
Mature Fields Redevelopment, Part I: Reviewing infill projects in
complex reservoirs
Juan Diego Suarez Fromm
Jun 29th 2016
KW: Infill, Managed Pressure Drilling, HPHT gas, Chicontepec
“Progress is impossible without change, and those who cannot change their
minds cannot change anything”. George Bernard Shaw
Z140-85 Z140-85
Z70-45 Z70-45
400 m Seven spot patern 1000 m x 400 m Horizontal pattern
400 m 1000 m
800 m
Tight oil case
Field development strategy with 7 spot and horizontal paterns
2. 2
1. Introduction
The Oil and Gas industry has probably endured a permanent change: oil prices might
never recover to 2010-2014 boom prices [1,2]
.
From the Oil and Gas Operators’ point of view, reengineering processes, layoffs,
projects delays, contract negotiations with service providers and operating cost
reductions has been put in action and will likely continue in the near future [3]
.
During this year, the focus has changed from Exploration / Development to that of cost
& production optimization and the upcoming years will probably require greater efforts
in Mature Fields redevelopment.
A well-known technique is that of infill optimization [4,5]
- a field development strategy
that can be defined as “well spacing reduction in order to accelerate and increase
petroleum recovery factor through optimal cost effective and wellbore placement in a
reservoir”.
Some advantages for infill strategy are as follows:
Minimum petroleum system uncertainty. The Petroleum accumulation is proved,
petrophysical / geo-mechanical rock properties, reservoir fluids, downhole
pressures, and base productivity are usually known within a limited range. So
we should be working with 2P reserves development.
Minimum operational risk for specific wellbore designs and some completions
standards used in the field.
On the other hand, some disadvantages include:
Paradigms on field development to be changed;
Field history data availability;
In general, greater subsurface team effort is needed for integration and
evaluation of reservoir models, compared to Appraisal / Initial Field
Development.
Upsides could be overlooked due to paradigms on field development. The
successful one in terms of reserves and cost effective capital expenditure
could be visualized as “finding the key for the field”. But as development
takes place over many years (decades), the “key” should be a dynamic
concept over time, correlated with technology availability, enabling us a
better understanding of petroleum resources size, quality and distribution.
Two field examples will be presented, where after 50 years of development; fresh oil
and gas were produced by changing some reservoir paradigms.
3. 3
2. Gas & Condensate case
First case is about Mature Gas & Condensate Field in North Argentina. It belongs to
Tarija basin, a Palaeozoic deep thrust belt deposits from Carboniferous geological age
[6,7,8]
.
The reservoir has 3 stratigraphic units, gross thickness is about 400 meters of altering
tight sandstones and shales, in multi faulted anticline structure.
Exploration and appraisal phase started in late 50’s, where main development took
place in 60’s decade with about 60 wells drilled, 70% gas reserves were delimited and
80% were put onto production, achieving 5 years plateau of 180 MMpc/d gas and 7500
bpd condensate. During 70's decade, field production declined as a mature field.
Finally a reinjection gas project was implemented from early 80’s over 20 years due to
low commercial gas value in the region, shutting field production. Meanwhile, field
operator changed in 90’s and started to produce condensate wells, keeping dry gas
injection.
During this time, operators applied good practices reservoir management by
monitoring downhole static and flowing pressures in open and closed wells, producers
and injectors during almost 50 years of history.
After detailed structural settings reinterpretation (integration of surface geology,
seismic markers, well logs and section restoration analysis), the redevelopment started
in late 90’s with the successful appraisal well placement in a new deeper block,
allowing the operator to booked new gas, condensate and oil reserves.
Over 1990 decade, only 5 wells were drilled and put onto production with relative
success due to formation impairment associated with partially depleted regions,
resulting in halting the drilling campaign in 2005.
In the subsequent years, the lack off a consistent productivity / reserves model, turned
out to inconclusive postmortem, increasing technical risk and therefore lowering
economical attractiveness for new wells. So, field started again to decline production,
undergoing for second time the mature stage.
4. 4
Two concepts remained as key factors for the project continuation:
Formation damage due to reservoir compaction and depletion, increasing potential
of pore throat blocking, leading to new drilling process requirements (reservoir
stimulation was not possible due to high fracture pressure about 12.000 psi
combined with low reservoir pressure).
Material balance upside due to massive bottom hole static pressure recovery in dry
gas producers and closed wells; and relative low final recovery factor forecast.
Resulting in 20/30% increase in material balance OGIP and 2P reserves.
Two years of reservoir engineering data integration leaded to infill, sidetracks and
replacement wells proposals. Among several technologies, the “Managed Pressure
Drilling” (MPD) was selected for production stage drilling, in combination with slotted
liner completion instead of standard cemented casing perforations.
Inter spacing was reduced from 800 m to 400 m, in the crest of anticline central block,
where 80% of effective gas cumulative production had been released (net from gas re
injection). Also side tracks were proposed in recently damaged wells due to issues with
casing integrity.
In 2010 first side track well was drilled, reaching very good gas and condensate
productivity. Initial rates were achieved 40 years later with 30/50% of initial reservoir
pressure, reinforcing the hypothesis of formation damage sensibility and the
importance of the mud weight management in these kinds of reservoirs.
Up to date 4 new wells from original campaign were drilled, completed and put onto
production with good results. One possibility for near future is the extension to flanks
where tight rock, lower productivity and lower recovery factor take place.
5. 5
Chart 1. Gas & Condensate Case: Tarija Basin location and geological column.
Chart 2. Gas & Condensate Case: Wells, 2D seismic cross section and 3D structural
model.
6. 6
Chart 3. Gas & Condensate Case: Field production & gas re injection history.
Chart 4. Gas & Condensate Case: Ultimate Recovery Factor areal distribution, and
bottom hole reservoir pressure history.
1953 55 57 59 61 63 65 67 69 71 73 75 77 79 81 83 85 87 89 91 93 95 97 99 01 03 05 07 09
10
1
10
2
10
3
10
4
10
5
Date
AREA: CD RESERVORIO: TUP(62)
Gas Rate (Cal. Day) ( Kscm/d )
Oil Rate (Cal. Day) ( m3/d )
Water Rate (Cal. Day) ( m3/d )
Ginj.Cum ( Mscm )
Cumulative Gas Production ( Mscm )
Ginj.CalDay( Kscm/d )
Gas
Condensate
Water
Gas re injection
Main development First Natural decline Gas re injection – condensate prd
Gas & Condensate case
Field gas, condensate and water production & gas re injection history
North
58 – 69 %
R.F. Upside: ≈10%
Central
62 – 69 %
South
57 – 67 %
Yacimiento Campo Durán - Fm Tupambi
Evolución Pws POZOS SELECCIONADOS
(PR 3000 TVDSS)
0
50
100
150
200
250
300
350
400
1/50 12/53 10/57 9/61 8/65 7/69 6/73 5/77 4/81 3/85 2/89 1/93 12/96 11/00 10/04 9/08
Fecha
Pws[kg/cm2]
0
4000
8000
12000
16000
20000
24000
28000
32000
Gef:Gp-Giny[MMm3]
Pws YPF
Pws reiny de gas
Pws Tecpetrol
G efectiva [MMm3]
año 2007: Se produjo todo el gas reinyectadoReinyección de gas 1982 - 2000
año 2009: Extraídos 1000 MMm3 desde el
inicio de la reinyección de gas
1950/77: gas production 1978/2008: gas reinjection/prod
2008: balance
R.F. @ Economic Limit Bottom hole static pressure history
OGIP Upside: ≈25%
Gas & Cond case
7. 7
Chart 5. Gas & Condensate Case: Structural model for well placement in faulted and
folded reservoir.
8. 8
Chart 6. Gas & Condensate Case: Example of reservoir redevelopment:
Replacement well response after 40 years from initial original well production, and
Sidetrack well response after 15 years from initial replacement well production. Initial
productivity of 11 MMpc/d is achieved in spite of reservoir depletion due to successful
mud pressure management during the drilling stage.
Yac. Campo Durán - Fm. Tupambi
Perforación 'Near Balance' en Campo Durán. Proyecto ST CDxp-1001
0
100
200
300
400
500
600
700
1-57 12-60 12-64 12-68 12-72 12-76 12-80 12-84 12-88 12-92 12-96 12-00 12-04 12-08 12-12 12-16 12-20 12-24
Qg[Mm3/d]Qo[m3/d]Np[Mm3]
0
500
1000
1500
2000
2500
3000
3500
Gp[MMm3]
CD-15 Bloque II
(YPF)
ST CDxp-1001
(cuña perforada - pz original)
Julio 2008 CDxp-1001 (merma)
Rotura somera en el casing de producción 9 5/8” (aprox. 500 m) pincha tubing y descarga fluído E/C
csg 13 3/8”-9 5/8” con lodo inverso 1900 g/l – baritina (etapa de perforación de Los Monos)
CDxp-1001 Bloque II & III
(Tecpetrol)
Febrero 2008 CDxp-1001 (recup. Prd)
Limpieza con CTU CaCO3 - pozo vivo HCl 15%+N2
Replacement well after 40 years. Sidetrack after 15 years
First well
(1957)
Reservoir impairment (cement bond break)
Replacement well
(1997)
Live well perforations clean up
HCl jetting with CTU (2007)
Sidetrack well
(2012)
Peak 11 MMpc/d
Gas:Millionscubicmetergas/d,Cond:cubicmeters/d
CondCum:1000cubicmeters
GasCum:Millionscubicmetergas
Gas & Condensate case
9. 9
3. Tight Oil case
Second case is a tight oil field located in North Veracruz, Mexico. “Chicontepec Medio”
is a Tertiary reservoir from Tampico-Misantla basin, an important onshore play, and
well known by its low recovery factor and marginal cash flow [9]
.
The reservoir is very complex from structural, stratigraphic and diagenetic point of
view. Extensive and compressive faults systems coexist due to tectonic activity during
deposition of sediments. Characterized by 300 m gross thickness of shallow turbidites,
alternating sandstones and shales, where petro physical properties have been affected
by pore cementing and other diagenesis processes [10]
.
Leading to high vertical and horizontal heterogeneity, the scale of reservoir variations
runs from metres to centimetres.
Some rock quality predictive methods as seismic inversion have been applied with
some success. But appraisal wells are still needed in some regions many decades later
from discovery in order to delimit the reservoirs.
Seven spot pattern with 400 m well spacing has been the field development strategy
for 50 years, showing a great variation on productivity in the same reservoir unit
between adjacent wells, even with good reservoir continuity, according to seismic and
wells correlation. Due to low permeability, hydraulic fractures are needed, leading to
relative low initial productivity and reserves.
These factors motivated the evaluation of multi fractured horizontal wells, following the
concept of shale gas development strategy.
Challenges for horizontal wells compared to vertical wells:
Shallow reservoirs (low cost for vertical wells).
Reserves distributed in 200 m of layered reservoir (one fractured horizontal well
cannot reach and drain the entire column).
Lateral heterogeneity for horizontal wellbore placement.
Geo mechanical issues in some shale zones. Lack of experience in horizontal
drilling and multifrac completion.
In order to mitigate technical risks, the first horizontal well was planned in the central
part of the field, where higher production and recovery factor has been achieved after
50 years of exploitation. A detailed reservoir characterization and production
performance assessment was achieved due to existing wells.
With this scenario, reservoir pressure was the main risk; keeping in mind that reservoir
target was one of the champion units from the field, leading to potential depletion
issues during drilling, completion, stimulation, and production performance for
horizontal wells.
10. 10
Large amount of data were available but not yet integrated.
An extensive review and reinterpretation took place:
Material balance and decline analysis review.
Update of static model.
Dynamic model construction. History matching for main productive block.
Geo mechanical model was built from compression test in plugs, Young
Modulus, Poisson Modulus, Brightness calculations from logs, fracture gradients
from pre pad test and micro seismic mapping results from previous vertical
wells, seismic inversion correlation with logs (gamma ray, sonic and density).
Main outputs were:
More confidence on final recovery factor for vertical fractured wells and for
projected horizontal multi fractured new wells.
Principal horizontal stress directions and minimum horizontal stress gradients
distributions. Current reservoir pressure distribution.
Greater fracture vertical growing was reinterpreted from old fractured vertical
wells, due to brittleness of rock.
With the above considerations a new static, dynamic, and geo mechanical reservoir
model was built, allowing the ranking of new locations with lower geological risk for
horizontal wellbore placement, along the Minimum Horizontal Stress direction. A robust
fracture design was matched with micro seismic fracture geometry. Also mud weight
window was optimized, allowing better casing depths.
Sensibility scenarios were run with different horizontal length and number of fractures,
finding that 1000 m horizontal length, 400 m spacing between horizontals, and 150 m
fracture spacing are optimal from technical, economical and risk points of view.
The first horizontal drilled well showed excellent results. The second and third
horizontal well were drilled in undeveloped regions, obtaining similar results [11,12,13]
.
The main conclusions were:
Field development:
Initial productivity x 10 times vertical frac well.
Projected ultimate recovery x 8 times vertical frac well.
Projected final oil Recovery Factor increased from 5% to 7%.
Total well cost reduction: 5% respect to seven spot pattern.
Operative Expenditure Costs reduction (including minor workover): 30%
respect to seven spot pattern.
In addition, first horizontal well showed that significant undeveloped reserves
can be produced in drilled zones, in spite of lower reservoir pressure.
11. 11
Fracture geometry:
Micro seismic mapping allowed fracture geometry understanding for lower frac
spacing, where a complex micro fissures net is also created among principal
fractures geometries.
Chart 6. Tight oil Case: Geographical location of Chicontepec basin and general
geological column.
Tight oil case
SIERRA
MADRE
ORIENTAL
PLATAFORMA
DETUXPAN
CAMPO
COYOTES
Field
“Paleocañon de Chicontepec” location General geological column
JurassicCretaceousTertiary
12. 12
Chart 7. Tight oil Case: Horizontal wells locations, structural configuration, and
reserves categories distribution. First horizontal well was drilled in P1 main block
affected by partial depletion. Second and third horizontal wells were drilled in SW and
N regions.
Unit Z140 – Faults & Depth contour lines
P3
P2
P1
P2
P2
P3
P3
P3
P2
P1
P3
P1 Block Main developed
region with 7 spot pattern
(depleted)
(1)
(2)
P3
(3)
(4)
(5)
T
J-K
P1/P2 Blocks Variable
vertical well results
P1: Proved reserves
P2: Probable reserves
P3: Possible reserves
First Horizontal
Second Horizontal
Third horizontal
P3 Block High productivity &
connate water risk (multiple OWC)
Tight oil case
Horizontal wells locations, structural configuration
and reserves categories distribution
Deeper zone: lower rock quality
13. 13
Chart 8. Tight oil Case: Knowledge evolution over field development for fracture
geometry. Interpretation in old vertical fractured wells showed greater fracture length
compared to microseismic results in fractures from vertical and horizontal wells
(conventional fracs).
Chart 9. Tight oil Case: Field development strategy with 7 spot and horizontal
patterns. Shaded areas are equivalent.
Tight oil case
Knowledge evolution over time (fracture geometry)
Former frac design
1990-2000 Hf/Xf: 0.7
Micro seismic 2008:
Vertical Wells Hf/Xf: 1.0
Micro seismic 2011.
First Multifrac Horiz
Hf/Xf: 1.6
Micro seismic 2012.
Second Multifrac Horiz
Hf/Xf: 0.90
6000 sks
(60 BPM,
conventional)
6000 sks
(60 BPM,
volumetric)
Z140-85 Z140-85
Z70-45 Z70-45
400 m Seven spot patern 1000 m x 400 m Horizontal pattern
400 m 1000 m
800 m
Tight oil case
Field development strategy with 7 spot and horizontal paterns
14. 14
Chart 10. Tight oil Case: Reservoir characterization for wellbore placement.
4. Final comments
Two field cases were presented, both from 1960’s, where operators changed
subsurface paradigms, allowing them to increase recovery factor in drilled and
exploited regions.
This can be characterized as finding the “key for the reservoir”, where efficient and
intelligent technology usage plays a central role.
Nevertheless, the real paradigm is inside the professional´s mind, the aversion to
change from the “obvious path or follow the historical trend”.
So, the final challenge relies on management - at the end of the day it will not only
allow new ideas development, but it will also push them to flourish and grow.
5. Acknowledgments
Special thanks to Diego Lenge for his useful comments on this paper.
Tight oil case
Reservoir characterization for wellbore placement
Lateral heterogeneity in horizontal well
Seismic cross section. Pseudo Gamma Ray
from Inversion & wellbore trajectory
15. 15
6. References
1. Macrotrends.net, 2016. Crude Oil Price History Chart.
2. Worldoil.com, 2015 .Petrobras sees “great wave” of 100 $ oil never coming
back.
3. Worldoil.com, 2015. Iraq asks oil companies to cut spending after drop in
prices.
4. Total E&P, 2006. Mature Fields. Inventing the future.
5. Norwegian University of Science and Technology / Statoil E&P, 2012. Improved
Oil Recovery with Infill drilling.
6. D. Starck, L. Constantini, A. Schultz., 2002. Sub Andean Thrust belt
Geometrical and evaluative analysis for North Argentina and South Bolivia.
7. D. Starck, A. Schultz, M. Cohen, 2002. Carboniferous and Tertiary traps from Sub
Andean North West Basin.
8. Different authors, Argentinian Institute of Gas and Oil (IAPG), 2002. Reservoir rocks
from Argentina.
9. National Commission of Hydrocarbons (CNH), National Secretary of Energy
(SENER), Mexico, 2010. Aceite Terciario del Golfo. First Revision and
Recommendations.
10. Daniel A. Busch, Amado Govela, 1978. The American Association of Petroleum
Geologists Bulletin. Stratigraphy and Structure of Chicontepec Turbidites,
Southeastern, Tampico-Misantla Basin, Mexico.
11. Juan Diego Suarez Fromm, 2011, 2012. Primeras Jornadas Tecnológicas -
Laboratorio de Campo Coyotes. Segundas Jornadas Tecnológicas - Laboratorio de
Campo Coyotes. AIATG. Design and development of Multi fracture horizontal
well in Tight Oil reservoir – Chicontepec.
12.Juan Diego Suarez Fromm, 2012. Mexican Oil Institute – AI ATG. New
technologies application for Coyotes Field – Chicontepec.
13. Juan Diego Suarez Fromm, Juan Martin Migliavacca, Neptalí Requena. Mexican Oil
Institute. First Non Conventional Completion in Chicontepec using Multi
fracture horizontal Wells.