bluuebunny/crossref_metadata_2025_split huggingface dataset:
Walker Rig and Batch Drilling System Contribution in Reducing Moving Time and Increase Drilling Operation Efficiency in North Senoro Drilling Gas Field Development Project
Authors: Panhar Muhammad Lutfi , Rahmadona Desmawati 
Published: October 2015

Abstract
In September 2013, North Senoro development drilling of JOB PERTAMINA – Medco E&P Tomori Sulawesi operated Senoro Field – Central Sulawesi, Indonesia commenced when the rig was rigged up over a rig base in Well B Cluster with 8 new well slots available. The well slots were the 20" conductors, piled when the project was still in site preparation phase. Drilling commenced with objectives of drilling, completing and testing 6 new directional wells and 1 re-entry wells.
The objective of the Field development was to have high gas production rates available when JOB PERTAMINA – Medco E&P Tomori central processing facility and Donggi Senoro LNG Plant was completed and started in first week of January 2015. Since all wells had to be drilled before first production, and require few weeks to connect the wells with central processing facility then all effort was addressed to optimized operation, shortening operation time and avoid any incident or accident. Walker Rig and Batch Drilling System were implemented to fulfill the entire objective and minimize costs.
The Batch Drilling System was applied based by the availability of designated well slots in Well B Cluster. These well slots position were placed based on planned operation which expected to complete 4 first wells (Batch Group 1) and do well testing while at the same time, the rig was moved to the other side of 3 remaining wells (Batch Group 2) and drill the wells. In planning this system, all risk had to be considered when performing simultaneous operation of drilling and well testing (SIMOP); including when there was well control situation since North Senoro Field is a gas field with total loss reservoir and 2,900 psi reservoir pressure.
By utilizing Walker Rig and Batch Drilling System, JOB Pertamina – Medco E&P Tomori Sulawesi has been able to save moving days from 56 days to actual 15.56 days, saving at least +/− USD 1.3M and achieve HSE performance 1,923,683 man hours without loss time.
A Semi-Analytical Model for Production Simulation of Complex Fracture Network in Unconventional Reservoirs
Authors: Jia Pin , Cheng Linsong , Huang Shijun , Cao Renyi , Xu Zhongyi 
Published: October 2015

Abstract
Unconventional reservoirs, such as tight oil and shale gas reservoirs have emerged as a significant source of energy supply in the world. The technologies of horizontal well drilling and hydraulic fracturing have made it possible for such reservoirs to be developed commercially. Interacting with the pre-existing natural fractures, multi-stage hydraulic fracturing along horizontal wells creates complex fracture networks. Compared with the traditional single or multiple planar fractures, the flow process in these fracture networks is significantly different due to the complex interplay of flow between the interconnected fractures. This paper presents a semi-analytical model for production simulation of complex fracture networks in which hydraulic and natural fractures can interconnect with arbitrarily angles. To model the flow behavior more rigorously, we represent fractures within the network explicitly rather than idealize them as a dual-porosity medium. In the model transient response is obtained from coupling a reservoir flow model and a fracture network flow model dynamically. Source functions in real domain and superposition principle are adopted to model the flow process in reservoir analytically; thus, the flow equation of network is solved by finite difference method numerically. Furthermore, Star-Delta transformation is introduced to solve flow redirection and flux redistribution among the interconnected fractures within network. The validation of the semi-analytical model is demonstrated in comparison to the solution of ECLIPSE simulator. Production simulation of orthogonal and un-orthogonal fracture networks are taken by use of the semi-analytical model. In addition, with a field example from the Barnett shale, we show the capacity and practical use of the model to evaluate well performance and stimulation effectiveness of complex fracture network in unconventional reservoirs.
Well-Plant Operation Model: Case Study of Tight-Gas Sands in Sulige Gas Field, NW China
Authors: Naizhen Liu , Ming Liu 
Published: October 2015

Abstract
Sulige gas field is a typical tight gas reservoir with the features of low-pressure, low-permeability and low-abundance. Its gas-bearing condition is bad so that the economic benefit is not good. To improve the well performance and economic benefit, an applicable well-plant operation model which includes the design optimization, the technology template, the streamline operation, the standardized regulation, the resources generalization and the integral management is established through continuous explorations and practices.
This paper describes the successful well-plant operation model conducted in block Su53 along with the pilot project in block Su11. The well-plant operation model increases the operation efficiency, shortens the drilling period and saves the cost. 8 vertical wells are drilled in the pilot project in Su11, which takes 6 days to be fractured and bring great economic benefit. In addition, the well performance is significantly improved compared with other vertical wells in the block Su11. The pilot project provides experiences for the well-plant operation model in block Su53. 13 wells which include 10 horizontal wells, 2 directional wells and 1 vertical well are drilled in a 200m×300m well pad, lining in two arrays. The target formations are H8 and S1, ranging from 3150m~3500m. The whole job including well pad construction, drilling, completion, fracturing, gas testing and production for all 13 wells is finished in only 210 days. Compared with the conventional single-well job, the well-plant operation model saves a lot of time and money. The environmental protection is enhanced. The development model of the block Su53 is very successful and the well-plant operation model receives much attention in China. The successful application of the model provides invaluable experience for the development of tight-gas sands and shales in China.
Building an In-House CMMS to Simplify Maintenance Management in an Oil and Gas Company
Authors: Handoko Bambang , Anwar Syaiful , Siswanto Hadi , Amir Mohamad Fauzan , Pribadi Rossupanji 
Published: October 2015

Abstract
In modern oil and gas industry, the use of a Computerized Maintenance Management System (abbr. CMMS) is an essential part to simplify maintenance management. Considering cost and time as crucial factors, there are two alternatives to obtain a CMMS: in-house development or by purchasing an off-the-shelf software package, where both choices have their own set of benefits and weaknesses. Commercially available software packages are usually offered at premium prices, but frequently, lack the ability to be customized to company requirements. Customizing software packages could cost the price of the program itself. Therefore, for companies with limited budget, such approach is a major concern. Moreover, if many of the features and functions left unused, the total waste of such investment would be greater.
This paper describes a CMMS implementation, called INTRAMAS (Integrated Asset Management) that has been developed in-house by some of the authors, empowering our own resources and assisted by internship students from a reputable university in Indonesia, i.e. the ITS. This software tool offers some major advantages, such as low-cost investment, increased high level of flexibility, higher potential for optimal training development and adaptability to current maintenance operations. However, to reach the desired objectives, some challenges must be dealt with, among others such as: paradigm shifting from manual to computer-based approach, personal reluctance due to lack of computer skills, asset register and document inputs, as well as management acceptance when the idea was arising initially.
Facilitated by standard features designed in a web-based environment, INTRAMAS offers a great extend of advantages. Reports and Key Performance Indicators (KPIs)/metrics can be generated automatically and useful for analysis, evaluation and decision-making in maintenance management. The software application run successfully and proven to meet its expectation. The success story encouraged SKK Migas (Special Task Force for Upstream Oil and Gas Business Activities Republic of Indonesia) to organize a workshop facilitating the knowledge sharing between Lapindo Brantas Inc. (as source reference) and other Production Sharing Contract (PSC) companies, particularly of which are yet to apply this technology. It is expected that the successful experience will endorse the companies to follow the similar approach in developing CMMS in-house, which will result in the saving of cost recovery made by the government.
High Expansion Technology Opens the Way for Enhanced Recovery
Authors: Robinson Larry Grant , Gray David , Bill Bjorn 
Published: October 2015

Abstract
The objective of this paper is to examine the recent improvements in packer and plug design, minimizing packer element extrusion. Based on these changes, operators now have more intervention options at reduced risk. While applicable to both new completions and interventions, this paper will focus on intervention technology.
For many years, extrusion gap has been controlled primarily by the use of a "Gauge Ring" as a packer back up. While successful, this approach dictates a large OD packer or plug to minimize extrusion gap. As our industry has developed more tortuous well bore geometry, large ODs have led to running and pulling problems. These designs have also prevented many operators from recovering failed zones. Water encroachment, gas migration and failed sand screens have often been dealt with by re-completion. Options were limited to inflatable systems, long elastomer or umbrella types of plugs. Horizontal completions further reduced that to only inflatable solutions, due to umbrella systems dependency on cement. Recent developments in high expansion products have opened up new opportunities to recover from these types of problems.
High expansion elastomers and new design packer back-up systems allow for actual V-Rated packer, plug and straddle systems. With this benefit, comes the added value of a retrievable system. Intervention work always carries with it the risk of failure. Recovery from a failed intervention can sometimes be a return to the original work-over plan. The most successful of the new systems incorporate expanding packer back-ups. High expansion types of systems are now being used for:
Horizontal sand control in failed screens Packer failure recovery Straddles, straddles with stand-alone screens Zonal isolations, (including straddles) P&A work
This type of equipment allows for the recovery of a failed intervention, as well as recovery from a change in wellbore dynamics. If the intervention team set the high expansion style system in the wrong place, they simply recover that and re-run at the correct depth. Should wellbore changes dictate a change, all or part of that system can be recovered and modified to accommodate the change in pressure/gas/water/sand.
In conclusion, the ability to reduce extrusion gap, while at the same time reducing OD of completion / re-completion components, brings operators new avenues of success with reduced risk. Exciting new applications include, high expansion style straddles with sliding sleeves, Smart valves, and chemical injection systems.
The Effectiveness of Development Methods in the Apprenticeship Program
Authors: Widodo Untung Hendy 
Published: October 2015

Abstract
This paper aimed to evaluate the effectiveness of Apprenticeship Program implemented by ConocoPhillips Indonesia. The scope of this study is fresh graduate hires in the selection year 2010-2012. This study used a qualitative research methodology by developing strategies based on the Three Gears of Development developed by the Corporate Leadership Council (CLC) and the method refers to the Kirkpatrick's evaluation model. From the analysis performed it was concluded that the Apprenticeship Program has brought business impact, the most useful method of development is experiencing in which there are on the job training and project assignments embedded in meaningful assignment, as well as the relationship and feedback through coaching and mentoring.
The Impact of Nanoparticles Adsorption and Transport on Wettability Alteration of Water Wet Berea Sandstone
Authors: Li Shidong , Torsæter Ole 
Published: October 2015

Abstract
Wettability alteration was proposed as one of the main Enhanced Oil Recovery (EOR) mechanisms for nanoparticle fluid (nanofluid). A series of wettability index measurement experiments were conducted for water wet core plugs, which were treated by nanofluids with varied nanoparticles concentrations and types of nanoparticles. Nanoparticles transport experiments with the same nanofluids also were performed to study nanoparticles adsorption behavior. Effluent nanoparticles concentration was measured to evaluate nanoparticles adsorption and desorption inside core. Pressure drop was recorded during nanoparticles transport process to show effect of adsorption on permeability. Wettability index measurements were also performed for hydrophobic nanoparticles to investigate its effect on wettability.
The results of wettability alteration experiments indicated that hydrophilic nanoparticles have ability to make the core more water wet but not significantly. Hydrophobic nanoparticles can delay spontaneous imbibition while cannot change original wettability. For nanoparticles transport experiments, the results showed that the nanoparticles undergo both adsorption and desorption during injection. Effluent nanoparticles concentration curves were plotted to find breakthrough time. Experiments with varying concentration and type of nanoparticles showed different adsorption and desorption ability for water wet core. Permeability impairment was observed during nanoparticles dispersion injection.
This experimental study combined the effect of adsorption and transport of nanoparticles inside Berea sandstone on wettability alteration and permeability impairment. The objective of this paper is to release the influence of nanoparticles adsorption and transport on EOR of nanofluid.
Acquisition Pressure and Temperature Data without Slickline Unit
Authors: Hadi Saeful , Orryandhi Caksananda 
Published: October 2015

Abstract
Limau Field is the part of PT Pertamina EP Asset 2 that having many well intervention jobs especially reopening & work over in each years. Lack of reservoir data has been found because since in generally these wells are old well. Reservoir data (Pressure & Temperature) needed for evaluating well productivity as well as basic information to choose type of artificial lift if the well have good oil reserve.
Acquisition data carried when swab job for updating the data reservoirs. It requires Electric Memory Recorder (EMR) and Slickline unit as conveyor. Lack of Slickline unit is a problem to get the data if two or more well intervention jobs done in the same time.
This tool has been modified since 2 years ago so when the job is done in the same time, then it will receive the data at the same time. The measurement EMR by using slickline tool or IBC tool at the same well and same time is the way to find out the accuracy of the data. The results are no differences data between slickline and IBC, so to IBC could replace data using slickline units.
This paper describes about the history of the IBC modifications, design tools, configuration tools, material data, the process of testing tools and data comparisons between slickline and IBC.
Pore Pressure and Fracture Gradient Prediction for the Challenging High Pressure and High Temperature Well, Hai Thach Field, Block 05-2, Nam Con Son Basin, Offshore Vietnam: A Case Study
Authors: Nguyen Son T. , Hoang Son K. , Khuc Giang H. , Tran Hung N. 
Published: October 2015

Abstract
This paper discusses a case study of pore pressure and fracture gradient (PPFG) prediction for a development well in the high pressure high temperature (HPHT) Hai Thach field. Drilling in this field presented considerable challenges as the overpressure could reach 17.0-17.8 ppg and temperature could be as high as 185°C at well TD. Therefore, an accurate and practical approach on PPFG prediction along the planned well path is critical to prevent drilling problems (losses, gains, wellbore breathing, wellbore collapse, reservoir damage, etc.) and determine optimum placement of casing/liner strings. Before drilling, Eaton's method was used to predict the PPFG from seismic interval velocities, with calibration against measured pore pressures, Leak-Off Tests (LOT), and Formation Integrity Tests (FIT) from offset wells. During drilling, real-time LWD data, mud logging data, and newly acquired LOT/FIT measurements were used to continuously monitor and update the PPFG profiles. Critical points having big impacts on well design and execution such as entry into the overpressured zone and reservoir tops were afforded extra attention to ensure well safety, drilling optimization, and achievement of all well objectives. A geological model database for PPFG prediction was also continuously updated and validated with new drilling experiences and data such as gas readings, static mud weight, ECD, etc. Thanks to the systematic and practical approach, the PPFG profiles matched closely with field observations and the well was drilled successfully and economically.
Zonal Test and Adjustment for Low Flowrate Waterflooding Wells
Authors: Fuchao Sun , Yaning Liang , Liqiang Lu , Xiaohan Pei , Guohua Xiao , Huili Hu 
Published: October 2015

Abstract
There are more and more layers with low water injection rate in waterflooding oilfields such as daqing periphery, jilin, jidong and etc. The typical layered flowrate is usually 3-20m3/d. Layered low flowrate was still obtained by stepwise decline method no matter what downhole regulator is used. Test tolerance may reach 30% under this method for low flowrate test which result in poor accuracy. To improve low flowrate test accuracy, the method of collection flowrate test based on electromagnetic flowmeter was adopted. This paper designed a dowhnole instrument based on electromagnetic flowmeter which is used to test flowrate of waterflooding wells in oilfieds. Equipped with two active balls, the low fowrate test accuracy was enhanced through collection and increasing flow velocity which was effective to increase test accuracy for electromagnetic flowmeter. Then we did a group of laboratory tests. The results demonstrated the instrument based on electromagnetic flowmeter can keep the accuracy below 5% within the flowrate 3-20m3/d. Finally, an application case was introduced in jidong oilfieds with minimum flowrate 5.98m3/d. The application increased the accuracy and reduced the influence of interlayer interference. This technique can not only be suitable for the low permeability oilfield, but also for the conventional water injection wells.
Redesign of a Single String Packerless ESP-Gas Lift Hybrid
Authors: Rohman A. F , Arseto Y. I , Hamzah K 
Published: October 2015

Abstract
The Kaji-Semoga fields in South Sumatra, Indonesia, are mature, waterflooded oil fields with ESP's in more than half the wells. To minimize oil deferment due to down-hole ESP problems, an ESP-gas lift hybrid was implemented in 2009. The idea was to install gas lift as a backup so the well could be kept on production, albeit at reduced rate, until the ESP could be serviced or replaced. During the period 2011-2012, 97 wells had the hybrid lift system installed and ESP problems occurred 23 times in these wells. The availability of the ESP-gas lift hybrid minimized oil deferment and allowed approximately 24,000 bbls of oil to be produced while waiting for the ESP to be serviced or replaced.
However, the previous hybrid design used just a single gas lift valve as an unloader and injection point. Performance analysis of the previous design showed that the gas lift performance could be optimized if the injection point was, on average, about 300 feet deeper. But that would be too deep for unloading, so the gas lift hybrid system was redesigned by incorporating two gas lift valves, one a shallower unloading valve and the other a deeper injection valve.
Between April 2013 and March 2014, twenty-four wells had the redesigned ESP-gas lift hybrid installed. Performance analysis of the design was conducted at KS-XXX well when it had an ESP down-hole problem. After the redesigned gas lift was activated, it increased drawdown by 121 psi compared to the previous design, kept the liquid lifting to 57% of ESP production rate (compared to 25% of ESP production rate with the previous gas lift hybrid design) and minimized oil deferment leading to 540 bbls of additional oil production in this one instance. Analysis of the overall performance of the redesigned ESP-gas lift hybrid is onging, but results are similarly good.
The Influence of Fracturing Fluid on CBM Desorption-Diffusion-Seepage Capacity of Coal
Authors: Li Xiangchen , Chen Defei , Zhou Yu , Kang Yili , Meng Xiangjuan , Zhang Xinxiu 
Published: October 2015

Abstract
The production process of coalbed methane (CBM) includes desorption, diffusion and seepage, and the production is controlled by these three processes together. The permeability of coal reservoir is generally low. To increase the coalbed methane production, well stimulation needs to be applied, in which the contact between fracturing fluid and coal seam is inevitable. Developed micro-fractures, large specific surface area and high capillary pressure of coal generate serious damage easily caused by fracturing fluid, which can affect the production of coalbed methane. Therefore, the multi-scale mass transfer ability damage evaluation method considering CBM desorption-diffusion-seepage capacity was put forward based on the coal reservoir microscopic pore structure and coalbed methane migration output mechanism. Taking the NO.9 coal from Ningwu basin and fracturing fluid in site as the research object, comprehensive damage evaluation experiment of fracturing fluid on CBM desorption-diffusion-seepage were conducted in order to optimizing the fracturing fluid in construction site. Combining the methods of infrared spectrum, wettability, scanning electron microscope and coal mechanical experiments, the impact mechanism of fracturing fluid on CBM desorption, diffusion and seepage were analyzed. Results show that both the coalbed methane desorption rate and the diffusion coefficient of samples treated by fracturing fluid decrease compared with that of treated by formation water; compared with formation water, fracturing fluid can decrease the mechanical strength of coal and strengthen its stress sensitivity, microcracks close further under the action of geostress which will make the flow channel more narrow, eventually the seepage capacity decreases. Through the results of infrared spectrum, wettability and scanning electron microscope we can get the conclusion that fracturing fluid can change the surface structure, wettability and pore connectivity of coal, and affect the migration ability of coalbed methane. The field test of optimized fracturing fluid were conducted, the results are consistent with that of indoor experiment. This study can provide theoretical guidance for fracturing fluid optimization in the operation of coalbed methane wells fracturing.