bluuebunny/crossref_metadata_2025 huggingface dataset:
DAYA DUKUNG DAN PERTUMBUHAN POPULASI SIAMANG (Hylobates syndactylus Raffles, 1821) DI CAGAR ALAM DOLOK SIPIROK, SUMATERA UTARA
Authors: Kuswanda Wanda , Garsetiasih R.
Published: February 2017

Kawasan Cagar Alam (CA) Dolok Sipirok merupakan habitat yang diperkirakan masih mampu mendukung pertumbuhan populasi siamang (Hylobates syndactylus). Penelitian ini bertujuan untuk mendapatkan informasi tentang daya dukung habitat dan model pertumbuhan populasi siamang di CA. Dolok Sipirok, Sumatera Utara.  Penelitian dilaksanakan pada hutan primer dan sekunder, mulai dari bulan Maret sampai November 2012. Pengumpulan data produktivitas pakan menggunakan penampung serasah (litter trap) sebanyak 30 buah, pengamatan buah secara search sampling pada plot seluas 6 ha dan telaah literatur untuk data pertumbuhan populasi.  Analisis data menggunakan persamaan pendugaan produktivitas,  regresi linier, persamaan daya dukung habitat, dan model pertumbuhan logistik.  Hasil penelitian menunjukan bahwa rata-rata produktivitas daun di hutan sekunder dan hutan primer berdasarkan hasil pengukuran adalah sebesar  10,4 kg/ha/hari (BB) atau 6,3 kg/ha/hari (BK).  Nilai produktivitas buah (mempertimbangkan musim berbuah) rata-rata berkisar antara  6,9 kg/ha per hari (BB) dan rata-rata sebesar  3,2 kg/ha per hari  (BK).  Nilai dugaan daya dukung antara 579 – 2.249 individu sehingga kondisinya saat ini belum termanfaat secara optimal oleh siamang. Populasi siamang akan mencapai kondisi stabil pada 200 tahun apabila tidak ada perubahan habitat secara drastis di sekitar Kawasan CA. Dolok Sipirok.
International Demand for Palm Oil Estimated Within a Fats and Oils Demand System
Authors: Suryana Achmad
Published: February 2017

Abstrak

Sistim permintaan untuk  minyak nabati dan hewani bagi tiga pasar internasional utama dan dua negara produsen diduga dengan model Almost Ideal Demand System (AIDS). Pembahasan dititik­ beratkan pada hasil pendugaan untuk sistem permintaan minyak nabati dan hewani bagi MEE karena kawasan ini merupakan pasar ekspor yang paling penting bagi minyak sawit Indonesia. Hasil analisis menunjukkan bahwa kecuali di Amerika Serikat, permintaan untuk minyak  sawit  di pasar  interna­ sional adalah inelastis.  Telaahan ini juga menunjukkan hubungan antara minyak-minyak nabati dan hewani tidak saja bersifat substitusi tetapi antara beberapa minyak tersebut terjadi juga hubungan yang komplementer. Negara-negara yang termasuk ke dalam analisis ini adalah MEE, Amerika Serikat, Jepang, Malaysia, dan Indonesia. Sebelas macam minyak nabati dan hewani yang termasuk ke dalam analisis ini adalah lard, edible  tallow, minyak-minyak  sawit,  kelapa,  kedelai,  biji  kapas,  biji  rape, biji bunga matahari, zaitun, jagung,  dan ikan.
Penanganan Pasca Panen Menunjang Pengembangan Usahatani Lahan Kering di Das Citanduy
Authors: Irawan Bambang , Rasahan Chairil A.
Published: February 2017

ABSTRAK

Sejak 1978/1979 di DAS Citanduy telah dibentuk Usahatani Model dalam rangka meng­ introduksikan teknologi usahatani yang tidak saja berupaya menaikkan  pendapatan  petani tetapi juga mementingkan aspek konservasi laban. Tulisan ini mencoba mempelajari adakah pendekatan pemasara)l yang dapat dilakukan guna menunjang inovasi tersebut. Dengan memilih komoditi cengkeh dan kacang tanah sebagai kasus, basil analisa yang dilakukan rilenunjukkan bahwa perbaikan penanganan pasca panen merupakan pendekatan yang prospektif guna menunjang keberhasilan perluasan teknologi usahatani yang diintroduksikan. Karena itu inovasi yang dilakukan sebaiknya tidak hanya menyangkut perbaikan teknologi usahatani tetapi juga mencakup perbaikan penanganan pasca panen. Dalam rangka merangsang petani melakukan pasca panen tiga hal yang perlu diperhatikan adalah: (I) petani perlu diarahkan  untuk melakukan pasca panen secara kolektif, (2) penyaluran kredit usahatani padi perlu diperluas karena secara tidak langsung keterbatasan modal dalam usahatani ini memberikan pengaruh negatip terhadap penanganan pasca panen pada tanaman sekunder, dan (3) pembinaan mengenai penanganan pasca panen baik pada petugas penyuluhan maupun petani perlu mendapat perhatian yang lebih serius.
Sources of Major Agricultural Export Earnings Stability in Indonesia
Authors: Simatupang Pantjar
Published: February 2017

ABSTRAK

Stabilitas penerimaan ekspor adalah penting untuk mengurangi premi resiko bagi eksportir. Oleh karena itu, stabilitas penerimaan ekspor dapat mempengaruhi volume ekspor, dan selanjutnya tingkat produksi. Stabilitas penerimaan ekspor juga penting bagi pemerintah dalam mengelola cadangan devisa. Stabilitas penerimaan ekspor juga mempengaruhi tingkat nilai tukar. Oleh karena itu, pemahaman akan sumber penyebab ketidakstabilan penerimaan ekspor adalah sangat penting, sehingga dapat diambil kebijakan yang tepat. Dalam penelitian ini dibahas sumber ketidakstabilan penerimaan ekspor dari empat komoditi ekspor utama Indonesia yaitu karet, kopi, kelapa sawit, dan teh dengan mempergunakan sidik ragam. Komoditi yang paling tidak stabil nilai ekspomya adalah karet dan kopi. Sumber utama ketidakstabilan penerimaan dari ekspor karet adalah harga internasional selama periode 1976-1985. Harga internasional merupakan sumber utama ketidakstabilan dari ekspor kopi pada periode 1976-1980. Namun, pada periode 1981-1985 volume eksporlah yang menjadi sumber utama ketidakstabilan. Kelapa sawit dan teh sama seperti ketidakstabilan pada kopi.
Pendugaan Dampak Kegiatan Ekspor Karet Alam Terhadap Pendapatan Propinsi Kalimantan Barat
Authors: Rivai Rudy Sunarya
Published: February 2017

ABSTRAK

Kegiatan ekspor karet alam mempunyai peranan yang besar terhadap peningkatan pendapatan Propinsi Kalimantan Barat. Oleh karenanya perlu dilakukan upaya meningkatkan nilai ekspor karet alam pada Pelita IV. Penelitian ini berusaha melakukan perencanaan alokasi produksi optimal karet alam selama Pelita IV dan menduga dampak dari perubahan nilai ekspor karet alam terhadap pendapatan Propinsi Kalimantan Barat. Hasil penelitian menunjukkan bahwa pada tingkat alokasi produksi optimal Pelita IV lebih baik dibandingkan alokasi produksi pada Pelita  III.  Pada  tingkat alokasi produksi optimal tersebut, Propinsi Kalimantan Barat setiap tahunnya rata-rata mengalami kenaikan nilai ekspor karet alam sebesar 17,6 persen. Kenaikan tersebut mempunyai dampak terhadap pendapatan Propinsi Kalimantan Barat, yaitu pada tahun 1984 sebesar Rp 79.078 juta pada akhir tahun Pelita IV mencapai Rp 158.227 juta.
Impacts of Agricultural Incentives Policy on the Rural Economy of Indonesia
Authors: Kasryno Faisal , Siregar Masdjidin
Published: February 2017

ABSTRAK

Tujuan utama dari tulisan ini adalah untuk mempelajari berbagai dampak kebijakan insen!if pertanian yang diambil pemerintah terhadap produksi, tenaga kerja, dan pendapatan masyarakat pedesaan dengan acuan khusus pada hasil penelitian Studi Dinamika Pedesaan. Keragaan yang cukup mengesankan dari sektor pertanian Indonesia selama sepuluh tahun terakhir terjadi karena kebijakan insentif pertanian yang dilaksanakan secara berdaya-guna baik ditinjau secara makro ekonomi maupun secara sektoral. Kebijakan insentif yang dicanangkan pemerintah dalam bidang pertanian telah mampu meningkatkan produktivitas dan pendapatan rumahtangga petani di pedesaan. Keadaan yang cukup menggembirakan dalam  pendapatan  rumahtangga  pedesaan  adalah  kemampuannya  mengurangi tingkat kemiskinan, dan mengubah struktur konsumsi  pedesaan  yang  membuat  bagian  pengeluaran yang lebih banyak untuk jasa dan barang-barang tahan lama. Tenaga kerja bukan pertanian menjadi lebih penting sebagai perangsang utama untuk pertumbuhan pendapatan rumahtangga pedesaan khususnya rumahtangga  berpendapatan rendah. Setelah pencapaian  swa-sembada  beras,  arah kebijakan ditekankan pada usaha diversifikasi pertanian pada tingkat regional maupun  nasional. Tulisan ini menyajikan deskripsi beberapa elemen penyesuaian dalam strategi pengembangan pertanian untuk sepuluh tahun mendatang.
Peningkatan Kualitas Biji Kakao Non Fermentasi Melalui Perlakuan Pendahuluan Sebelum Inkubasi
Authors: Atmaja M. Iqbal Prawira , Haryadi Haryadi , Supriyanto Supriyanto
Published: February 2017

The cocoa beans produced by farmers in Indonesia are mostly nonfermented with unfavourable taste and flavour. Incubating the cocoa beans in acetate buffer medium has been shown to improve the quality of non fermented dried cocoa beans. Pre-incubation treatments of non fermented cocoa beans by physical treatments such as soaking and crushing them prior to the incubation in acetate buffer is expected to improve the beans quality (i.e. fermentation index and polyphenol). The aim of the research was to determine the effect of pre-incubation treatment of non fermented dried cocoa beans in acetate buffer medium on fermentation index and total polyphenols content.The research was carried out in Process Engineering Laboratory, Food Chemical and Biochemical Laboratory, and Postharvest Technology Laboratory at Gadjah MadaUniversity from April to December 2013. The research used three treatments, first: the crushed beans size 4 mm, whole beans soaked in water (45°C; 16 hours), and beans without soaking (control). The incubation was performed in two stages, the first stage was in the acetate buffer medium at pH 2.7; 600 mM for 24 hours, then subconsequently at pH 5.5; 600 mM for 12 hours. The results showed that crushed bean treatment of non fermented cocoa beans prior to incubation increased the fermentation index values, from 1.15 to1.54 and decreased total polyphenol content from 55.69 to 24.16mg GAE/g.
Rheological Study of a Novel Sulfobetaine Surfactant-Based Acid System
Authors: Cetin S. , Nasr-El-Din H. A.
Published: February 2017

Viscoelastic surfactant (VES)-based acids have been employed for acidizing jobs due to their ability to build up sufficient viscosity for acid diversion and fluid loss reduction, and to break into low viscosity after the treatment is completed. This work studied rheological properties of a new zwitterionic viscoelastic surfactant-based stimulation fluid. İmpacts of many variables on the rheological characteristics of the VES-based live and spent acids were examined.

Rheological experiments were conducted using a high pressure/high temperature (HPHT) viscometer. Viscosity measurements were performed between the temperatures of 78 to 350°F and shear rates of 10 to 935 s−1 at 300 psi. Examined acid additives included: corrosion inhibitor, formic acid, methanol, demulsifier, H2S scavenger, iron control agents, and mutual solvent. As a contaminant, the effect of Fe (III) was investigated. In addition, the impacts of surfactant concentration, salt type and salt concentration on the viscosity of the VES-based acid systems were tested.

Experimental results indicated that the new VES-based acid system exhibits a sufficient viscosity for acid diversion at temperatures up to 270°F. Apparent viscosity of the spent acid showed a strong relation with surfactant concentration, salt type and salt concentration. Corrosion inhibitor concentration above 0.5 vol% caused a notable loss in the viscosity as the temperature increased gradually. Dependency on methanol was strong enough that it resulted in a decline of the apparent viscosity of both live and spent acid solutions. H2S scavenger and iron control agents (citric acid and EDTA) did not alter the viscous behavior notably, while demulsifier and mutual solvent caused a reduction in the apparent viscosity. Fe (III) contamination caused fluctuations in the live acid viscosity due to generated VES-iron complex. In spent condition, this complex caused phase separation that resulted in loss of viscosity. On the basis of the results obtained, optimum conditions to achieve the desired rheological profile for a successful well stimulation operation are presented.
Overlooked Opportunity - Steam Traps
Authors: Khulaify M. S.
Published: February 2017

In Saudi Aramco, Abqaiq plants, steam is produced by boiling water via sever-al boilers segregated in two plants. The steam produced is connected to the main steam header supplying all Abqaiq plant users, mainly steam turbines with a 625 psig. All Abqaiq plant steam turbines are designed to receive 625 psig and produce 60 psig which is then connected to a separate steam header for further utilization before it is condensed back as water and returned to our water tanks facility. Along the steam piping network, there are drain lines con-nected to the atmosphere to release and vent accumulated condensed water to prevent hammering issues in the steam piping network. In order to prevent steam from escaping along these drains, a "Steam Traps" device is installed to allow condensed water to be released and prevent steam from leaking. Howev-er, as with most facilities worldwide, steam trap failure rates cause a nuisance to plant operations and are a major energy waste issue. After the troubleshoot-ing phase, survey completion and trialing different types of steam traps, a permanent solution was found and is planned to be implemented and will gen-erate an approximate savings of $ 828,000 per year. In this paper, trouble-shooting stages, technology trialed and results will be presented.
Effect of CO2 Content on the Natural Gas Production from Tight Gas Sandstone Reservoirs
Authors: Eliebid Mohammed , Mahmoud Mohamed , Shawabkeh Reyad , Elkatatny Salaheldin , Hussein Ibnelwaleed
Published: February 2017

The simulation of the gas flow in tight sandstone reservoir is a very complicated process. Several mechanisms contributed to the natural gas production in tight sandstone reservoirs. One of the main mechanisms is the gas desorption from the rock surface to the pore body. All the existing models did not consider the effect of CO2 content in the natural gas on the gas desorption from the rock surface. Also all the existing models used desorption models from the literature and they neglect the effect of rock type and reservoir conditions on the gas desorption behavior.

In this study and for the first time we will investigate the effect of CO2 content (0 to 20 vol%) on the natural gas desorption from the tight sandstone rocks. Accurate desorption isotherm will be developed based on the rock type and gas composition. Adsorption/desorption experiments will be carried out at different pressures and temperatures to develop a robust model for the natural gas desorption from the rock. Also the effect of tight sandstone rock mineralogy was investigated on the adsorption/desorption of the natural gas. Increasing CO2 fraction in the mixture from 0% to 10% CO2 the total gas uptake is increased to approximately 28%, 22% and 33% at 50°C, 100°C and 150°C respectively which reflects the high affinity toward CO2 from the tight sandstone core. The tight sandstone mineralogy also affected the desorption behavior of the natural gas. The presence of water bearing clay minerals such as illite exhibited a vast sensitivity to temperature causing damage to crystal structure and expulsion of bounded water which resulted in huge increase in the adsorption uptake.

The results of the experimental studies showed that the CO2 content in the natural gas has a big effect on the desorption of the natural gas from the tight sandstone rocks. The CO2 content also affected the desorption isotherm model for the natural gas. The tight sandstone mineralogy also affected the desorption behavior of the natural gas.

The output from this study is a robust model that explain the contribution of the desorption of the natural gas to the total gas production. Also, it will enhance the simulation and flow models that describe the flow of natural gas in porous media in tight sandstone reservoirs.
Sensitivity Study on the Impact of Sub-Volume and Image Resolution on the Prediction of Petrophysical Properties Using Micro CT Technology
Authors: F Alzayer Mohammed
Published: February 2017

The introduction of high-resolution micro-CT scanners in oil & gas industry has provided a cost effective approach to numerically calculate the important petrophysical properties of reservoir rocks. High-resolution rock images are acquired and later processed to capture all the pore types and mineralogy to enable accurate prediction. This study focuses on estimating the representative elementary volume (REV) of porosity and absolute permeability from micro-CT images of carbonate and sandstone formations.

Using topological representative networks and robust pore scale simulator, the effects of different volumes (100-1024 voxels) and resolutions (2.7-27 μm) on the estimation of petrophysical properties are examined. Four different formations are analyzed: Berea (medium-permeability sandstone), Doddington (high-permeability sandstone), Estaillades (medium-permeability limestone), and Ketton (high-permeability limestone). Simulation results are benchmarked to core measurements.

The results of this study are very encouraging as sandstone porosity estimates were not affected by resolution coarsening and their absolute permeability was predicted accurately at a resolution up to 18 µm in Berea and between 8-27 µm in Doddington. In limestones, the ratio of micro-pores to macro-pores can be an indication of the accuracy of pore-scale simulation results. Micro-pores in limestone are not well captured with a 2-3 μm resolution. Therefore, pore-scale simulations can be run successfully if the flow is dominated by the macro-pores. In general, results can be improved by increasing sample volume beyond 1024 voxels then coarsening it to be computationally feasible.

This study gives insights and guidance on defining the appropriate micro-CT scan sub-volumes and resolutions for different rock types when designing and testing pore-scale simulation experiments. Ultra-high resolution imaging and enhanced pore-scale simulation efficiently provide basic and advanced petrophysical data that are comparable to core lab measurements.
Production Optimization of High Temperature Liquid Hold Up Gas Well Using Capillary Surfactant Injection
Authors: Kalwar S. A. , Awan A. Q. , Rehman A. U. , Abbasi H. S.
Published: February 2017

Depletion of the reservoirs leads to a decrease in field production rate. Wells production rate continue to drop below the minimum critical velocity, at which point the liquid that was previously carried upward by the gas begins to fall back. The produced liquid accumulates in the well creating a static column of liquid, therefore creating a backpressure against formation pressure and reducing production until the well ceases production. Capillary Surfactant Injection (CSI) is installed on the wells to overcome the liquid loading symptom by generating foam, thereby reducing the surface tension, lowering the fluid density, and lowering critical rate.

This paper presents the comprehensive strategy of CSI application in high temperature gas well in Pakistan. Well 1A has been flowing under the critical conditions of liquid hold up with WGR of 82 bbl/MMscfd in high temperature (355 °F), deeper (11350 ft.), bigger tubing of size 5-1/2" and 7" Liner below the end of tubing along with compressor installed on it.

Based on nodal analysis, CSI was found the suitable Artificial Lift System (ALS) to deliquify this well. The procedure involved - laboratory analysis to monitor the temperature stability test of foamer (OMNIFOAM-HT) and defoamer (Alpha-2325) - scrutinizing the amount of foamer injected in the well to generate the foam - design of defoamer injection point and dosage to break the foam on surface - operational procedure - optimization mechanism - production enhancement and rapid payout time while executing CSI.

The lab results and field optimization showed OMNIFOAM worked successfully at high temperature and converted 350 - 400 barrels/day of formation water into foam at optimum injection rate of 4-5 gal/day. Defoamer injection (0.25-0.5 gal/day) was effectively carried from the injection point of corrosion inhibitor, around 150 feet upstream of compressor. CSI deployment significantly enhanced 15% rate of previous gas production and extended the life of the well to 4.0 years. If injection had been continued, the payback period was estimated to be 04 months. Based on these results, permanent deployment of CSI with renaissance wellhead system was recommended as promising solution for prolonging the life of well, sustaining its production in a short payout time and improving the reserve recovery.
A Comparative Study of Experimental Design Techniques in Assisted History Matching
Authors: Shams Mohamed , El-Banbi Ahmed. H. , Sayyouh Helmy
Published: February 2017

Quantifying the uncertainty of reservoir models has always been considered as a major concern. Uncertainty and sensitivity analyses provide us with information about how "incorrect" a proposed prediction scenario is. One effective approach to quantify reservoir uncertainties is to apply the concept of Experimental Design. As the name indicates, experimental design is the technique used to guide the choice of the experiments to be conducted in an efficient way. Samples are selected in the design space of the uncertain parameters in order to obtain the maximum amount of information using low number of experiments. Geoscientists and engineers are building larger models to address reservoir heterogeneity and hence reservoir simulation is usually expensive (takes significant time to run). Experimental design techniques became very useful in assisted history matching. Several experimental design techniques are introduced in literature, some must be more effective than others in typical reservoir simulation problems.

The objective of this paper is to compare different experimental design techniques and to introduce two efficient ones (Halton and Sobol sequences) to reservoir engineering problems. To show the potentiality and efficiency of the Halton and Sobol sequences design techniques, a comparative study is conducted to compare between their performance in solving assisted history matching problems and the performance of the most widely used experimental design technique, Latin hypercube. Other conventional techniques were compared too, but found to be less efficient than Latin hypercube. Two different scale reservoir models are used as test problems. A performance indicator is developed to compare between the three studied techniques in terms of the relative error between the estimated values of history matching parameters calculated using the proposed assisted history matching procedure and their exact solutions.

The results of this work indicate that the Sobol and Halton sequences experimental design techniques are superior to Latin hypercube method.
An Overview of Experimental Studies Examining the Reliability of Hollow Glass Spheres as a Density Reduction Agent in Oil Field Applications
Authors: AlBahrani Hussain I. , Wagle Vikrant , Al-Yami A. S.
Published: February 2017

Hollow glass spheres (HGS) present a novel solution and a practical tool for the drilling industry. HGS can function as a density reduction agent for various types of fluids and slurries used in drilling. A major advantage of HGS is that they are an inert additive to drilling fluids and slurries that can perform their function without affecting other properties of the composition. Another advantage is that the field application of HGS require no extra equipment for maintaining compressibility or extra training for rig personnel. These attributes are vital when drilling using techniques such as underbalanced drilling or managed pressure drilling. HGS are also extremely beneficial for drilling through depleted or naturally fractured formations. In spite of these positives, HGS are still considered as newcomers for drilling applications and they still require an extensive investigation of their ability and reliability to perform as density reduction agents.

A wide range experimental and theoretical study was conducted to examine the performance of HGS from different aspects. Theoretically, HGS should perform their function as drilling fluids density reduction agents readily. Consequently, the downhole environment can present a grueling challenge to HGS as it can subject them to elevated temperatures, elevated pressures, a wide range of chemical environments, and a wide range of dynamic and physical interactions. This highlights that there is a necessity to examine HGS in terms of their chemical, mechanical, and thermal stabilities before confidently employing them in the oilfield applications. To achieve this, a comprehensive set of experimental procedures and theoretical studies were performed.

The overview of the results of the experimental and theoretical studies showed that HGS performance can significantly vary based on the environment they experience. For theaspect of chemical stability, it is shown that HGS can perform their function reliably in a pH range that is typical for drilling operations. As for downhole environments with abnormal pH range, HGS exhibited minor degradation. For the aspect of mechanical stability, it is shown that some ratings or classes of HGS can degrade significantly when subjected to dynamic and physical forces mimicking the downhole environment. In the most extreme cases, the mechanical degradation of HGS is shown to be able to reach a limit where they no longer can function as density reduction agents. Finally, for the aspect of thermal stability, the theoretical study showed that HGS are generally reliable, even in conditions simulating the most extreme temperature typically experienced in a drilling downhole environment.
Nahr Umr Classical Waterflood: From Pattern Pilot to Peripheral Waterflood, Bahrain
Authors: Al Janahi Ahmed , Buali Yusuf , Nemmawi Nadia , Al Saati Fahad
Published: February 2017

Tatweer Petroleum completed the first successful Bahrain Field waterflood in 2014. The waterflood pilot and ultimate peripheral development was completed in the NahrUmr "CC" Reservoirs and demonstrates classical and economic waterflood performance. This paper describes the initial pilot and ultimate peripheral design and results. The paper also describes the systematic effective and efficient Tatweer pilot management approach which allowed an impressive pilot to peripheral time frame less than two years.

Early in 2013, a 30 acre waterflood pilot was initiated in Cc reservoir in the central structural area, consisting of an inverted 5-spot pattern; one injector and four surrounding producers. The pilot was selected in a confined area where there was good pressure data coverage, relatively low GOR and WC, good reservoir continuity, high productivity and good reservoir characteristics (So, Net Pay). Initial pilot results showed classical reduction of gas production and increase gross production within a couple of months of injection. Based on this observation, the pilot team reassessed overall structural reservoir performance and determined the structure would benefit from a peripheral waterflood to augment natural water influx.

The peripheral design covered 870 acers and was completed with 11 injection wells and 21 producers. The analytical approach designing the peripheral flood fell into five categories listed below: Re-assessed natural water influx; This was done by comparing voidage pulled from the reservoirs vs. pressurePetrophysical and Geological revision to the area of interestRe-evaluated the size of the prize; using analytical and simulation modelsInterpreting results and observations from the inverted 5-spot pilotRe-assessed development costs and reserves impact for pattern vs. peripheral considerations.

Since the peripheral waterflood implementation in late 2014; 170,000 barrels of incremental oil has been recovered through February 2016 and reservoir pressure has increased by 50 psi. Current injection rate is 18,500 BWIPD in 11 injectors. Current incremental oil production is nearly 400 bopd from 21 producers.

In this paper, the key elements of waterflood surveillance and assessment are described and used to help Tatweer Reservoir Management Team (RMT) to effectively and efficiently determine that the structure would benefit from a peripheral waterflood rather than a pattern design. An impressive multi-disciplinary work was done in order to change the plan and still execute the project in less than two years. In addition to that, this paper covers the process followed by the RMT to manage the waterflood conformance and monitor the injection and production simultaneously.
Near Real-Time Return-on-Fracturing-Investment ROFI Optimization for Shale Fracturing by Integrating Anisotropic Acoustic Interpretation, 3D Fracture Modeling, and Neural Networks
Authors: Gu Ming , Quirein John , Chen Dingding
Published: February 2017

Current fracturing designs based on 3D fracture modeling have two major issues. First, most current commercial simulators do not account for shale mechanical anisotropy. Second, running fracture simulation coupled with reservoir simulation for the purpose of return-on-fracturing-investment (ROFI) optimization is time consuming, particularly if numerous cases have to be run for parametric study of multiple stimulation treatment parameters including perforating/staging parameters, pumping parameters, proppant and fluid properties, etc. This paper proposes a robust, near real-time workflow with improved prediction of fracture geometry in anisotropic formations for shale fracturing optimization.

The workflow has four key steps. The anisotropic models are used to predict an isotropic elastic moduli and closure stress from sonic and density logs. Based on the existence of the Stoneley wave velocity, one can choose Stoneley methods such as ANNIE (Schoenberg et al. 1996) and M-ANNIE 1 (Quirein et al. 2014) or non-Stoneley methods, (Murphy et al. 2015) such as V-reg, M-ANNEI 2, or their combinations. The log interpreted mechanical properties are then input into a 3D fracture simulator to run different cases by varying the treatment parameters. The critical conductivity concept is used to determine the effective propped area (EPA) from the simulation results. Third, input (treatment parameters) and output (EPA) pairs are used to train and validate the neural network (NN) model. Finally, analytical solutions for the linear transient flow regime and boundary dominant flow regime (Wattenbarger et al. 1998) are applied in combination with NN predicted EPA to estimate time-dependent productions and ROFI. Parametric studies can be conducted through NN modeling to investigate the impact of each treatment parameter on the ROFI. Finally, the workflow is applied to optimize one shale example. The results show that the first year ROFI can be improved by 50% after optimizing the perforating and pumping strategy through the workflow.
Next Generation Well Integrity Evaluation through Cross-Segment Integration for Saudi Aramco
Authors: Amri Faisal , Hababi Ayedh , Ramirez Andres , Faraj Omar , Shankar Rohit , Alshafai Ali , Martanto Roni , Elmarsafawi Youssef , Abdurrahman Riefky
Published: February 2017

With the advent of the API RP 65 – Part 2 (post-Macondo), the concept of well integrity evaluation has been given an entirely new meaning and importance. Watching acoustic logs in isolation without sufficient correlation with the formation evaluation logs and cement placement simulation yields a lot of unanswered questions.

It was at this stage that Schlumberger (SLB) was approached by Saudi Aramco's drilling optimization team to evaluate the zonal isolation between the Formations Shale A and Sandstone B in Well-A, which was a well from the unconventional resources group. The objective was to assess the zonal isolation with a high level of assurance and provide feedback for obtaining better results in subsequent wells.

The paper showcases the technique applied to assess the well integrity through an integrated holistic approach for the first time in the Middle East that looks all data available rather than being confined to looking up the acoustic logs in isolation that many times provides only part of the answer.
The Future of Petrotechnical Leadership: Developing Young Innovators for Tomorrow's Challenges through Volunteer Leadership
Authors: Barker D. C. , Girgawy L. , Tillmann N.
Published: February 2017

The EIA 2015 Annual Energy Outlook predicts great uncertainty in crude oil prices over the next 25 years; estimates range from $76/bbl to $252/bbl by the year 2040. Rapidly advancing technology is creating new opportunities and risks for the industry, ranging from automation to cybersecurity and more. Additionally, nearly 50% of the industry's employee base is anticipated to retire in the next 5-10 years. Of the 76 million baby boomers retiring over that time period, only 46 million younger professionals are predicted to be available to fill the gap. In light of these trends, how will the next generation of energy and drilling professionals prepare to lead when they are inevitably thrust into such an uncertain environment?

Clearly, such uncertainty will demand adaptive, agile leaders with broad experience and diverse backgrounds. However, gaining that experience is a protracted process; a balance must be struck between providing opportunities for young professionals to develop as leaders while also managing the inherent business risk. One well established solution to mitigating this problem is to encourage aspiring leaders to seek such opportunities outside the office in volunteer and nonprofit roles. However, while often cited, such vague instructions can leave these aspiring leaders in the dark about how to apply this experience to leadership within the industry.

In this paper, young industry and nonprofit leaders recount their experience partnering in local projects with a global impact, and how a rigorous approach to developing such partnerships and initiatives provides an ideal platform for future industry leaders. Results are detailed of how these partnerships directly address critical industry needs such as fostering an entrepreneurial culture, developing new technology, and promoting cross-cultural business exchanges. Parallels are drawn between this collaborative leadership experience outside the industry and its relation to solving key challenges faced within the industry.

While corporate career planning and leadership development programs typically value community service and nonprofit work, it is frequently a simple check-box in a list of desirable career growth categories. This studygoes one step furtherby detailing a structured approach to create collaborative relationships between industry and nonprofits that will help forge tomorrow's petrotechnical professionals, and ultimately build a more sustainable ecosystem for the energy industry in a high-tech, globalized world.
A New Method for Applying Natural Sand in High-Stress Reservoirs
Authors: Suzart Walter , Davis John , Khalifa Mohamed , Morad Aljlaidi , Buenrostro Adrian , Leal Jairo
Published: February 2017

Increased exploration and development of unconventional reservoirs is one of the main contributing factors to increased hydraulic fracturing activity. The primary aim of hydraulic fracturing is to provide a means for hydrocarbon productivity in tight formations at economic levels. The use of natural sand in high stress zones (greater than 5,000-psi closure stress) is known to lead to increased fines generation and subsequent migration. Thisresults in a detrimental decrease in hydrocarbon productivity, which reduces the value of and could even negate the purpose of conducting hydraulic fracturing. Manmade proppants are able to withstand elevated closure stress environments and have been a widely accepted means of overcoming the limits of natural sand as a propping agent for fracturing operations in medium to high stress environments.

A novel engineering procedure using natural sand to withstand higher stresses in proppant fracturing operations was evaluated both in the laboratory and at field scale. This methodology successfully demonstrated the ability of natural sand tokeep fractures open and support formation stresses while simultaneously allowing access to a highly conductive path typically achieved using intermediate- to high-strength manmade proppants in the associated stress regime. This technique also has shown to drastically reduce fines generation and migration along propped fracture geometry, maintain acceptable conductivity of the fracture throughout the stress process, and minimize diagenesis effects typically observed on existing proppant materials. This novel technique can be used to increase the conductivityof hydraulic fractures in unconventional reservoirs.

The paper describes a methodology to increase the strength range of natural sand to enable its use in high stress zones without risk of losing fracture conductivity resulting from fines migration. A laboratory scale model was designed to simulate the high temperatures and stresses present at reservoir conditions. The associated model showed natural sand can be used in elevated reservoir conditions up to 12,000 psi stress, resulting in increased hydrocarbon production and reduced costs as well as providing new opportunitiesfor economic fracturing applications in conventional and unconventional reservoirs.
Applications of Nanotechnology in Oilwell Cementing
Authors: Deshpande Abhimanyu , Patil Rahul
Published: February 2017

The primary objective of oilwell cementing is zonal isolation (i.e., restricting fluid movement across various zones within formations). Another equally important function is to support casing from various operationally induced mechanical and thermal stresses. To achieve successful zonal isolation, the cement sheath should possess important properties, including low permeability, high early compressive strength, good tensile strength, etc. This article presents a detailed experimental investigation of the effects of various nanomaterials on cement slurry properties.

Nanomaterials are used in several fields, including catalysis, polymers, electronics, and biomedical applications. Because of their small particle size, these materials have high surface energy and hence higher reactivity. For this reason, nanomaterials are often necessary in small quantities for enhancing specific properties of the base material. The development of high-performance fluid systems for oil and gas applications is possible through nanotechnology. In recent years, many studies have shown the usefulness of nanomaterials in enhanced oil recovery (EOR) and drilling fluid applications. Investigations have also shown the use of nanomaterials in oilwell cementing.

The experimental investigation of the effects of various nanomaterials on cement slurry properties shows that the addition of a mere 1.5% of halloysite increased tensile strength by approximately 141%. Similarly, the addition of nano-alumina resulted in achieving early compressive strength at temperatures as low as 40°F. Hence, these nanomaterials can act as nonchloride-based accelerators for low-temperature applications. Additionally, it was observed that, to obtain the greatest benefit of using nanomaterials, it is necessary to disperse them in desired media before use.

The results of this study on the applications of nanotechnology in oilwell cementing provide an opportunity to use nanomaterials for enhanced cement slurry properties with minimal cost.
Scale Inhibition: A Challenge and a Mitigation Study in Fracturing with High-Brine Water
Authors: Vo L. K. , Cortez J. , Hoeman K. , Rahal R. , Biyani M.
Published: February 2017

Mineral scales frequently form during oil production as the result of changes in temperature, pressure, or the mixing of incompatible formation and injection waters. For hydraulic fracturing, there has been an ongoing effort to replace the use of fresh water with seawater or produced water to address the fresh water shortage issue in many areas in the world. When seawater is injected into the formation, the scaling tendency is inevitable. Among many different types of scale, barite scale, which is a product of the encounter of sulfate ions (typically abundant in seawater) and barium ions (exist at high concentrations in various formations), poses a serious problem. To effectively mitigate this serious scale issue, a combination of water treatment and chemical scale inhibitor is recommended. Nanofiltration (NF) technology has proven to be a reliable water treatment method that specifically removes sulfate ions from water sources with high sulfate content. This paper presents the results of a NF water-treatment process and discusses how the treatment process is a feasible method for barite scale inhibition. In addition, a comparative study of different organic polymers as scale inhibitors was also conducted. For barite scale inhibition in particular, sulfonate polymers were more effective than phosphonate polymers. Scale inhibitor development was conducted using standard evaluation methods, including static bottle testing and a dynamic scale loop. A new, quick laboratory method using ultrasonic vibration was also developed to evaluate scale inhibitor performance during the bottle testing. A combination of NF technology and the new scale inhibitor enabled a new technology to help prevent scale formation during fracturing with seawater or heavy brine water.
Implementation of Lean Thinking in Planning Piping Hydro-Testing Activities
Authors: Ibrahim Mohamed Walid
Published: February 2017

The scope of work for this study is to implement lean management concepts while supervising contractor's hydrotesting activity in a NGL plant construction project and present the outcomes. The obtained results can be utilized as an indication that introduction of lean thinking into day-to-day project management can enhance time management resulting into up to 50 % reduction in initial projected time to complete a specific task. Then, continuous improvement will lead to significant tangible and intangible results.

Applicable lean principals were utilized as methods to achieve targets. The lean method included: Visual management of the 5 Ss, team (PMT, PID, Contractor, and Sub-Contractor) involvement, and Muda (defects) Elimination as a process improvement practice. This whole lean thinking introduction was introduced as a project management improvement process. The core objective was not only to achieve target by safely completing the activity on time and within the company required quality standards but to achieve that with minimum to zero new allocated capital investment.

The original proposal by contractor was to put the whole (Flaring) area hydrotesting activity on hold until the arrival of control panels to be shipped from the States. This would have resulted into a minimum of 3 months’ delays. While the turning around of the status and introducing lean thinking and planning, the hydrotesting activities was not postponed and were resumed instantly after root cause analysis and 5 Whys concepts implementation and re-planning, accordingly. The result was; by the time the panels arrived, 75.6 % of the test packages were completed, tested, and approved. Quality control and maintenance of the tested lines were also conducted successfully complying with Company recommended Standards and approved by PID.

It was observed that the performance of the team was significantly improved. Off course, as time passes, we were achieving targets that was originally scheduled for freeze. But it can be mainly attributed to the fact that every member of the team (PMT, PID, Contractor, and Sub-Contractor) was involved. The gravity of listening to suggestions and creating a 2-way communication channel from PMT made all team members take ownership into the process and keen on its success.

It can be concluded that planning and scheduling activities utilizing critical path analysis and PERT is essential as an initial planning step. Then, continuous improvement of the plans and schedules utilizing lean thinking can secure a completed project within budget and on a shorter projected period compared to projected periods estimated by standard scheduling tools alone.
A New Approach to Improve Recovery Efficiency of SAGD
Authors: Guo Erpeng , Jiang Youwei , Gao Yongrong , Shen Dehuang , Zhigang Chen , Yu Pengbo
Published: February 2017

SAGD (Steam Assisted Gravity Drainage) is commercially adopted as a main development methods for heavy oil reservoirs and oil sands. Improving recovery rate and heat efficiency of SAGD process is the main pursuit of all researchers. This paper aims to utilize a new additive with carbamide to reduce the steam consumption and lower down the residual oil saturation, hence to improve the recovery efficiency of this method.

Study on improving recovery efficiency of SAGD with carbamide in super heavy oil reservoir was carried out. 1-D flooding experiment were carried out at 50°C and 150°C to compare the sweep efficiency between different additives including carbamide, CO2 and alkali. Then simulation were run to evaluate the influence of carbamide to SAGD process. Different additives were compared and influences of different products from carbamide were analyzed in detail.

Study reveals that SAGD process can be greatly influenced by carbamide. Carbamide can gradually decompose into ammonia and CO2 in steam chamber. Great solubility of ammonia in water can effectively increase PH value of reservoir liquid and decrease residual oil saturation. The core flooding test results show that the oil displacement efficiency can be improved by 17.7% when 25% mass percent of carbamide was added at 150°C. And at 50°C, NH4OH showed 9% improve of sweep efficiency comparing to water. Solution of CO2 into oil can improve oil water mobility ratio. And in the simulation case the oil saturation in the core part of steam was reduced to 0.12 by ammonia (this value is 0.2 for steam). Distribution of CO2 and ammonia shows that oil drainage maybe start with viscosity reduction with CO2 solution and ends with ammonia flooding in steam chamber. With the result of this paper, the recovery factor of SAGD process can be improved by 15.4% and SOR can be improved by 20% when carbamide was co-injected with steam.
Reviving a Fractured Water Injection Well: The First Use of Clay Acid Stimulation in a Major Oil Field in Algeria
Authors: Shady Mohammed , Okafor Charles , Pazzi Jorge , Thomas Oluyinka , Sule Ayuba , Ali Ahmed Moge , Hamdane Toufik , Hachelaf Houari , Allal Abdelhalim , Collela Luigi , Latronico Roberto , Marfella Ferdinando
Published: February 2017

Berkine basin is one of the main oil producers in Algeria. The upper, middle, and lower TAG-I are the target oil-bearing sands. In this basin, the ROD field is under pressure maintained mainly through water injection together with, to a lesser extent, gas injectors. The southern part of the field, "ROD Tail" has four water injectors targeting the middle TAG-I. In recent evaluation conducted through pressure measurement and an interference test, reservoir pressure was found to have declined by 35 bar within 2 years. This has prompted questions about reservoir management, mainly about the effectiveness of injector well capacity in maintaining reservoir pressure. Extensive data were gathered through well intervention; cleanout, perforation, and a caliper log. Many failed acid jobs were also noted in the history of these wells. An engineered high-pressure jetting operation via coiled tubing was executed, but injectivity could not be restored.

A methodology and workflow were adopted to identify the source of formation damage and scale deposition in the near-well area and around perforations. Solid samples were collected from the well and sent to laboratory to characterize formation damage type. The injection water was also analyzed by performing a standard 12-ion concentration analysis. An aqueous model simulator was used to confirm that the water was supersaturated with CaSO4 and CaSO4.2H2O. Finally, clay acid treatment was found to be effective. The treatment fluid was designed to prevent proppant dissolution and to clean fracture matrix interface. This was the first time this type of operation was executed after many unsuccessful conventional acidizing operations.

Excellent results were obtained after the acid stimulation treatment. The injection rate was found to increase significantly from 120 m3/d to 360 m3/d. Water injection pressure was also found to decrease from 243 bar to 220 bar, and the injectivity index increased by three times. Near-wellbore formation damage was removed, and formation permeability recovered. The clay acid treatment was applied to other wells in the field and similar results were obtained.