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Proceedings Papers (22)
Artificial Lift Systems (5)
Gas lift (3)
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Open hole/cased hole log analysis (1)
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Production Chemistry, Metallurgy and Biology (2)
Inhibition and remediation of hydrates, scale, paraffin / wax and asphaltene (2)
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Sanjay Kumar
Production Enhancement in Intermittent Gas Lift Wells Using Sweeping Pipe Bend - Successful Case Histories from Various Onshore Fields in India
Mahendra Prasad Yadav, Sanjay Kumar Malhotra, Avinav Kumar, Sagun Devshali
Paper presented at the Abu Dhabi International Petroleum Exhibition & Conference, November 15–18, 2021
Objectives In wells which are producing on intermittent gas lift (IGL), the injected gas cannot sweep the entire liquid volume to the surface from the bottom of the tubing as there is continuously some fluid falling back in the tubing. The fallback can be described as the difference between the volume of the slug at the start of the gas injection and the volume of the actual produced slug at the surface. This fallback of liquid happens due to the fact that the gas has a tendency to flow through the liquid slug and letting the liquid to fall. The intensity of the liquid fallback increases more when there is increase in back pressure at wellhead. In order to minimize this liquid falling back in wells on intermittent gas lift, the sweeping pipe bend technology has been used in the various onshore fields operated by ONGC which has resulted in substantial gains and has been brought out in the paper. Process Gas break through and fallback are affected by three factors including the development of the gas bubble, the velocity of the slug flowing upward in the tubing, and wellhead restrictions caused due to presence of many 90-degree bends. To prevent gas breakthrough and to optimize the liquid fallback to minimum 5-7 % per 1000 feet of lift, it is recommended to maintain 1000 feet/min of minimum velocity of slug. Slower is the velocity of the slug which is moving up in the tubing, the longer time it takes for the gas to break through the liquid. At 1000 feet/min velocity, the wellhead restrictions can result in fallback losses due to breakthrough of gas in the well. In general, the flow path through the Christmas tree into the flowline is rather tortuous, moving first through a tee to the wing valve, then through other 90-degree ells before finally reaching the flowline. These restrictions further result in slowdown of the velocity of the slug thus resulting in more liquid to fallback and subsequently in significant production losses. Results In order to overcome the aforementioned problem and to reduce fallback in an intermittent gas lift well, sweeping pipe bend technology was considered and in the first phase implemented in 5 identified wells of different fields of ONGC Assets. With the help of sweeping pipe bend, the flow pattern becomes streamlined and number of 90-degree bends reduces or eliminates resulting in substantial reduction in the back pressure thus reducing the fall back. The implementation of the technology has resulted in an average liquid gain of 20.3% per well. Various guidelines for successful application of sweeping pipe bend have also been brought out in the paper. Additive Information 650 candidate wells operating on intermittent gas lift have been identified for the implementation of Sweeping Pipe Bends. As per the analysis, the implementation of Sweeping Pipe Bend is likely to result in a liquid gain of about 1000 m3/day from these wells.
Lessons Learnt from Integrated Production Modelling and Performance Analysis of Gas Lift Wells of One of the Biggest Offshore Complexes in India
Sagun Devshali, Ravi Raman, Sanjay Kumar Malhotra, Mahendra Prasad Yadav, Rishabh Uniyal
Paper presented at the SPE/IATMI Asia Pacific Oil & Gas Conference and Exhibition, October 12–14, 2021
The paper aims to discuss various issues pertaining to gas lift system and instabilities in low producer wells along with the necessary measures for addressing those issues. The effect of various parameters such as tubing size, gas injection rate, multi-porting and gas lift valve port diameter on the performance analysis of integrated gas lift system along with the flow stability have been discussed in the paper. Field X is one of the matured offshore fields in India which has been producing for over 40 years. It is a multi-pay, heterogeneous and complex reservoir. The field is producing through six Process Complexes and more than 90% of the wells are operating on gas lift. As most of the producing wells in the field are operating on gas lift, continuous performance analysis of gas lift to optimize production is imperative to enhance or sustain production. 121 Oil wells and 7 Gas wells are producing through 18 Wellhead platforms to complex X1 of the field X. Out of these 121 oil wells, 5 are producing on self and remaining 116 with gas lift. In this paper, performance analysis of these 116 flowing gas lift wells, carried out to identify various problems which leads to sub-optimal production such as inadequate gas injection, multi-porting, CV choking, faulty GLVs etc. has been discussed. On the basis of simulation studies and analysis of findings, requisite optimization/ intervention measures proposed to improve performance of the wells have been brought out in the paper. The recommended measures predicted the liquid gain of about 1570 barrels per day (518 barrels of oil per day) and an injection gas savings in the region of about 28 million SCFD. Further, the nodal analysis carried out indicates that the aforementioned gas injection saving of 28 million SCFD would facilitate in minimizing the back pressure in the flow line network and is likely to result in an additional production gain of 350 barrels of liquid per day (65 barrels of oil per day) which adds up to a total gain of 1920 barrels of liquid per day (583 barrels of oil per day). Additionally, system/ nodal analysis has also been carried out for optimal gas allocation in the field through Integrated Production Modelling. The analysis brings out a reduction in gas injection by 46 million SCFD with likely incremental oil gain of ~100 barrels of oil per day.
Revisiting Old Sands with a Different Perspective – A Pragmatic Approach for Maximizing Recovery from Gas Reservoirs
Sagun Devshali, Vinod Manchalwar, Budhin Deuri, Sanjay Kumar Malhotra, Bulusu V.R.V. Prasad, Mahendra Yadav, Avinav Kumar, Rishabh Uniyal
Paper presented at the SPE Oil and Gas India Conference and Exhibition, April 9–11, 2019
The paper describes the feasibility of revisiting old sands, for improving the recovery factors and enhancing production, which otherwise were already abandoned. The paper also outlines the systematic methods for predicting the onset of liquid loading in gas wells, evaluation of completions for optimization and comparison of various deliquification techniques. ONGC is operating in two gas fields in eastern and western regions in India. Earlier in both the fields, many sands had to be closed/isolated after the wells ceased to flow due to liquid loading in the absence of continuous deliquification. In order to predict liquid loading tendencies and identify opportunities for production enhancement, performance of 150 gas wells has been analyzed. To select most suitable deliquification technique for the present condition, all technically feasible methods have been evaluated and compared in order to get the maximum ultimate gas recovery possible. After an extensive study, 3 wells were identified in the preliminary stage and SRP was selected as the most suitable Deliquification technique. Initially, two non-flowing wells, which had ceased due to liquid loading and were about to be abandoned, were selected. After SRP installation and sustained unloading of water for about 30 days, these wells started producing 12000 SCMD gas. In the third well, one of the top sands had earlier been isolated due to liquid loading and production history indicated that the isolated sand had a very good potential. Also, production from the well was declining in the current bottom operating sand as well due to liquid loading. Encouraged by the results that deliquification had yielded in the initial two gas wells, the isolated sand interval in the third well was opened again with the aim to revive production. The well was re-completed with SRP with both the reservoirs open. Before deliquification, the well was producing about 15000 SCMD gas from the bottom sand. After SRP installation and continuous deliquification, the well started producing gas at a stabilized rate of 45000 SCMD, thereby resulting in an additional gas recovery of 30000 SCMD for nearly one year as on date. The approach of putting in place continuous deliquification techniques has not only helped in enhancing production from the existing reservoirs, but has also opened up new avenues to revisit the earlier isolated / abandoned reservoirs for possible enhanced recoveries.
A Novel Approach to Rejuvenate Brown Field by Validating Dynamic Model Response with Near-Wellbore Saturation Monitoring
Shubham Mishra, Karthik Kumar Natarajan, Akshay Aggarwal, Aditya Ojha, Alexander Rincon, Isha Khambra, Ajit Kumar, Gaurav Agrawal, Pankaj Kakoty, Neelimoy Baruah, Sanjay Kumar Dhiraj
Paper presented at the SPE Annual Technical Conference and Exhibition, October 9–11, 2017
Oil India Limited's (OIL) operational areas, in Upper Assam-Arakan Basin, are located in a seismically active thrust fault zone ( Bora et al., 2010 ). Multiple stacked layers, highly faulted anticlines and large number of compartments make the structural setting of these fields very complex. In terms of lithology, some of these reservoirs are low resistivity pays, leading to ambiguities in interpretation due to fresh water environment and complexities in evaluation of hydrocarbon-bearing and water-bearing sands ( Koithara et al., 1973 , Borah et al., 1998 ). Greater Nahorkatiya and Greater Jorajan, since the inception of commercial production in the 1950s, have been intensively studied to find prospective sweet spots, perforation intervals for new well locations and potential workover candidates. These forecasts, guided only by dynamic numerical model results, have had mixed results when implemented in the field. A validation of the dynamic model forecasts with near-wellbore saturation logs, can help to reduce uncertainty. This paper describes the success stories in field implementation of workovers, guided by dynamic reservoir model results and cross-validated with Pulse Neutron Tool ( Roscoe et al., 1991 , Schnorr, 1996 ) log recordings. The intricacy of delivering a precise dynamic reservoir model was managed by state-of-the-art seismic-to-simulation workflows, an integrated approach to improve the quality of the geological model and specific analytical techniques to fill in the data gaps. The calibrated model was analyzed for workover opportunities of zone transfer. In zones with high confidence, (i.e. high Hydrocarbon Pore Volume (HCPV), high porosity, permeability, etc., perforation intervals were recommended for hydrocarbon saturation monitoring to confirm the near-wellbore saturation predicted by the model. This workflow was followed in 8 wells which added immense value both technically and economically. The validation of model predictions with near-wellbore saturation was carried out in old wells which helped in making informed decision about tapping bypassed hydrocarbon pockets. It helped to avoid non-hydrocarbon bearing zones, which were removed from the existing workover plan. Moreover, it introduced confidence in the dynamic model which will be used in future for more aggressive economic development of the fields. This approach resulted in better understanding of the reservoir characteristics which led to identification of some potential reserves which could be characterized as "Reserve Growth".
Mangala Field Tracer Data Acquisition and Residence Time Distribution Analysis: Results on the Pattern Water Flood and EOR Pilot Area
Rahul Raj, Sumil Verma, Pankaj Kumar, Sanjay Kumar, Amitabh Pandey
Publisher: International Petroleum Technology Conference
Paper presented at the International Petroleum Technology Conference, November 14–16, 2016
Paper Number: IPTC-18720-MS
DOI: https://doi.org/10.2523/IPTC-18720-MS
The Mangala field in the Rajasthan state of western India was the first major oil discovery in Barmer Basin. The heterogeneous upper Fatehgarh (FM-1 and FM-2 sand) is developed with pattern water flooding. The well fluid are produced through Jet Pump (artificial lift) and processed in a plant (Mangala Processing Terminal, MPT). The separated produced water is mixed with Thumbli aquifer water for injection and as power fluid water for Jet Pump. The injection water is heated above reservoir temperature as to prevent any insitu wax deposition. To qualify the support of injector for its pattern producers in heterogeneous multi stacked FM-1 sand, conservative tracers were strategically injected in three crestal patterns of FM-1. The paper discusses the results of inter well tracer test conducted in FM-1 sand of Mangala. The paper focuses on the Residence Time Distribution Analysis of Tracer output signal. To meet the actual field condition of tracer reinjection via processed produced water and tracer addition via powerfluid water circulation, some modification in theoretical assumptions of Residence Time Distribution (RTD) analysis are also suggested. The RTD technique is used to estimate the sweep efficiency/ swept pore volume, and to estimate Lorentz coefficient (Lc). The estimated Lc from tracer analysis matches with the Lc being used in the simulation models. For assessment of EOR potential in Fatehgarh formation, chemical EOR pilot consisting of four injectors and single central producer was conducted in FM-1. Tracers were added in water/polymer/ASP phases of the pilot. The paper compares the sweep efficiency/swept pore volume in three phases of water/polymer/ASP injection with the help of RTD analysis. Better sweep efficiency and more swept volume are observed in polymer phase injection in comparison to the water flooding phase. The paper also focuses on use of qualitative signature of Tracer output for Reservoir Management and Production Optimization.
Understanding Reservoir Fluid Dynamic Processes by Using Diffusive Models
Julian Y. Zuo, Oliver C. Mullins, Richard Jackson, Ankit Agarwal, Cosan Ayan, Kang Wang, Yi Chen, Shu Pan, Hani Elshahawi, Chengli Dong, Bernd Herold, Sanjay Kumar
Publisher: Offshore Technology Conference
Paper presented at the Offshore Technology Conference, May 2–5, 2016
Paper Number: OTC-26964-MS
DOI: https://doi.org/10.4043/26964-MS
Downhole fluid analysis (DFA) has successfully been used to delineate reservoir connectivity and fluid properties and to understand the origins of many complexities in oil reservoirs with the Flory-Huggins-Zuo equation of state (FHZ EOS). Equilibrium asphaltene gradients strongly imply reservoir connectivity, with fluid equilibration often taking tens of millions of years. However, reservoir fluids often demonstrate complicated compositional gradients from undergoing dynamic processes such active late gas charges, biodegradation, and water washing. In this paper, a simple 1D two-component diffusive model with analytical solutions is developed for taking into account dynamic processes in oil reservoirs. Two field applications of the developed diffusive model are active gas charging and biodegradation to better understand these dynamic processes. In the first field application, an active late gas charge results in huge nonequilibrium gradients in several fluid properties including API gravity, gas/oil ratio (GOR), saturation pressures, and asphaltene content (color optical density) measured by DFA and surface laboratory analysis. Because the reservoir is not in equilibrium, these fluid property gradients cannot be modeled by the equilibrium EOS model. Thus, a diffusive model is needed to account for the large GOR gradient. The diffusive model predicts the large variations of GOR gradients successfully. The asphaltene gradient is evidently under control of convective currents induced by the gas charge. The exact nature of this process is currently under investigation. The asphaltene gradient is consistent with the predictions by the FHZ EOS with the assumption of asphaltenes locally in equilibrium with the local fluids described by the diffusive model. The second field application is biodegradation occurring at oil/water contact (OWC). Compared to the predictions of the FHZ EOS, it is observed that the upper half of the oil column follows an equilibrium asphaltene distribution well. However, a much larger asphaltene gradient is found in the lower half of the reservoir, which gives rise to a huge (8×) viscosity variation and affects production. The measured asphaltene distribution in the whole oil column can be described nicely by the diffusive model along with the FHZ EOS. The diffusion of alkanes to the OWC (where they are rapidly consumed) is a control step. The consumption of alkanes at the OWC reduces the oil volume and increases asphaltene content and viscosity. Petroleum system modeling predicts initiation of reservoir charging in the Eocene matching the diffusive times required in the FHZ EOS modeling.
Field Implementation of Mangala Polymer Flood: Initial Challenges, Mitigation and Management
Pankaj Kumar, Rahul Raj, Nitish Koduru, Sanjay Kumar, Amitabh Pandey
Paper presented at the SPE EOR Conference at Oil and Gas West Asia, March 21–23, 2016
Mangala field is one of the largest onshore oil fields in India. The Fatehgarh reservoirs consist of multi-Darcy permeability sandstones with low connate water saturations and moderate reservoir temperatures (62°>C). The reservoirs contain waxy and moderately viscous crude (9 – 22 cP) resulting in adverse mobility ratio between oil and water. The field was originally developed using an inverted 9-spot, hot waterflood. Given the viscous nature of the oil, even before development of the field was initiated, it was envisaged that sweep improvement methods would have good potential to enhance overall recovery from the field. After detailed laboratory studies and a successful pilot, a full-field polymer flood has been implemented. Experience from the pilot highlighted the need for maintaining polymer solution integrity and ensuring good propagation of the flood; acquisition and analysis of reservoir surveillance data are crucial in order to implement a successful polymer flood. Initially, lab viscosity measurements of actual samples from the full-field project's injection lines conducted in aerobic conditions showed significantly lower values than what would be expected based on measurements made on polymer solutions in synthetic brine. Readings from an online viscometer, however, showed somewhat higher viscosities. Use of a stabilizer chemical during sample collection helped protect the sample from aerobic degredation, and the viscosity measurements more closely matched the online viscometer. The data re-emphasized the need to prevent oxygen from entering the system, and modificationsto the polymer preparation plant, Central Polymer Facility (CPF), to minimize oxygen ingress showed marked improvement in viscosity readings. This paper will detail the procedures followed to minimize the impact of oxygen (air) while taking samples and measuring viscosity. A detailed well and reservoir surveillance program was implemented at the start of polymer injection. Surveillance activities includedspinner surveys, fall-off tests, bottom-hole pressure measurements, and saturation monitoring. The paper also presents an analytical approach for the estimation of in-situ viscosity with fall-off surveys. These results are compared with modeled viscosity from simulation. All polymer injector wells were pre-produced for extended periods prior to start of polymer injection; previous experience showed that this improved injection (reduced skin) and conformance. The saturation monitoring survey and fall-off tests suggest good sweep and even re-saturation of oil in some sands. Integration of high resolution seismic data between injector-producer pairs and surveillance data helped the operator to take appropriate action on some under-performing producers which later showed significant improvement in performance. Initial oil production response from producers which are near to polymer injectors is encouraging, with significant increases in oil rate and decreases in water-cut. Samples collected from some of the producers show polymer breakthrough in minor quantities. This paper presents the results of the initial phase of implementing the full-field polymer flood in Mangala.
Mapping and Modeling Large Viscosity and Asphaltene Variations in a Reservoir Undergoing Active Biodegradation
Richard R. Jackson, Julian Y. Zuo, Ankit Agarwal, Bernd Herold, Sanjay Kumar, Ilaria De Santo, Hadrien Dumont, Cosan Ayan, Oliver C. Mullins
Paper presented at the SPE Annual Technical Conference and Exhibition, October 27–29, 2014
Viscosity is one of the key reservoir fluid properties. It plays a central role in well productivity and displacement efficiency and has a significant impact on completion strategies. Accurately assessing areal and vertical variations of viscosity will lead to more realistic reservoir simulation and optimal field development planning. Downhole fluid analysis (DFA) has successfully been used to measure the properties of reservoir fluids downhole in real time. DFA has excellent accuracy in measuring fluid gradients which in turn enable accurate thermodynamic modeling. Integration of DFA measurements with the thermodynamic modeling has increasingly been employed for evaluating important reservoir properties such as connectivity, fluid compositional and property gradients. The thermodynamic model is the only one that has been shown to treat gradients of heavy ends in all types of crude oils and at equilibrium and disequilibrium conditions. In addition, fluid viscosity depends on concentration of heavy ends that are associated with optical density measured by DFA. Therefore, mapping viscosity and optical density (heavy end content) is a new important application of DFA technology for use as assessment of reservoir architectures and a mutual consistency check of DFA measurements. In this case study, a very large monotonic variation of heavy end content and viscosity is measured. Several different stacked sands exhibit the same profiles. The crude oil at the top of the column exhibits an equilibrium distribution of heavy ends, SARA and viscosity, while the oil at the base of the oil column exhibits a gradient that is far larger than expected for equilibrium. The fluid properties including SARA contents, viscosity and optical density vary sharply with depth towards the base of the column. The origin of this variation is shown to be due to biodegradation. GC-chromatographs of the crude oils towards the top of the column appear to be rather unaltered, while the crude oils at the base of the column are missing all n-alkanes. A new model is developed that accounts for these observations that assumes biodegradation at the oil-water contact (OWC) coupled with diffusion of alkanes to the OWC. Diffusion is a slow process in a geologic time sense accounting for the lack of impact of biodegradation at the top of the column. An overall understanding of charging timing into this reservoir and expected rates of biodegradation are consistent with this model. The overall objective or providing a 1st-principles viscosity map in these stacked sand reservoirs is achieved by this modeling. Linking DFA with thermodynamic modeling along with precepts from petroleum systems modeling provides a compelling understanding of the reservoir.
Updating the Reservoir Structural Model through Integrated Interpretation of Seismic, Well, and Dynamic Data: A Case Study from the Bhagyam Field, Rajasthan, India
Arjun Tiwari, _ Harshvardhan, Supriya Mukherjee, Steve Keidel, Stephen Goodlad, Sanjay Kumar, Arnab Ghosh
Publisher: Society of Exploration Geophysicists
Paper presented at the 2014 SEG Annual Meeting, October 26–31, 2014
Paper Number: SEG-2014-1334
Summary Integration of all subsurface datasets is paramount for building robust reservoir models. These datasets include well, 3D seismic and dynamic data, which taken together form the basis of an integrated reservoir model. Of critical importance in the construction of a reservoir static model is getting the structure right. Towards that goal, we present an example of the Bhagyam field in Rajasthan, India, where horizon based illumination maps have provided both structural and stratigraphic insight where other more conventional attributes, such as time slices or dip /azimuth maps, have fallen short. The advanced workflows undertaken aided in identifying structural complexity that was not previously captured in early Bhagyam reservoir models. Part of the problem with the early reservoir models was that most of the well data used to build them were drilled above the OWC, owing to the use of screen completions. This resulted in partial penetration of the reservoir. Later, as the completion strategy changed to cased and perforated, wells with full penetration of the reservoir were drilled. These deeper wells provided insight on fault cut outs which was not previously possible. The orientation of faults were interpreted on seismic with the aid of horizon based dip illumination maps, constructed from the seismically most well defined and therefore most confidently interpreted and auto tracked seismic reflections, at or near the reservoir interval. A determination was then made as to whether key faults in the field, with the aid of time varying depletion and water cut data, acted as a conduit or a barrier to fluid flow. The final framework model incorporated all the above datasets in helping to build a robust static as well as simulation model.
Insitu Heat Generation for Near Wellbore Asphaltene and Wax Remediation
Shobhit Tiwari, Sumil Kumar Verma, Raghavendra Karthik, Atul Kumar Singh, Sanjay Kumar, Manjit Singh, Manish Dutt Kothiyal
Paper presented at the International Petroleum Technology Conference, January 19–22, 2014
Abstract Organic deposits such as paraffin and asphaltene in the near-wellbore region are common damage mechanisms in oil wells, especially in brown fields, and account for major production losses from these fields. Typical efforts to mitigate these problems include pumping of several types of remedial treatments to inhibit or dissolve deposits, pump heated fluids as in hot oil treatments, or use mechanical methods such as cleanouts with jointed pipes and coiled tubing. Most of these methods are not time and cost-efficient for two reasons. First, such treatments are usually not one-time solutions but are required at periodic intervals depending on the severity of the problem. Second, the specific requirements such as long soaking time, exotic chemical systems, large equipment footprints, safety etc., often add to the associated service costs. In some of the fields being developed in the western onshore fields of India, heavy organic deposition across screens and in the near-wellbore region is being experienced. This is suspected to be occurring due to wax appearance temperature being close to the reservoir temperature. The wax dissolution temperature is well above the reservoir temperature, due to which any effective remedial treatment necessitates higher temperature generation for dissolution/inhibition of wax problems. Different types of solvents have been used for remediation purposes and have yielded mixed result. The concept of heat generation by exothermic chemical reactions has also been applied in the field after taking a cue from oil industry application, pipeline pigging industry to tackle the similar problems. On lines of this concept, the authors designed an effective and cost-efficient in-situ heat generation treatment to be applied in oil wells for removal of organic deposits. After laboratory testing using a range of products, the regulated components from the pipeline systems were replaced with safer, non-regulated products to suit oil well treatment. A successful field trial was achieved with the chemicals in generating heat to attain temperatures beyond the wax dissolution temperature, resulting in increased production. This paper documents the steps in developing this system and using it in the field, and aims to describe the challenges encountered, lessons learnt and recommendations for future application of the system. Introduction Bhagyam field is located in western part of India. Numerous exploration and appraisal wells have been drilled in RJ-ON-90/1 block in Rajasthan North West India, primarily targeting the exceptional Fathehgarh reservoir. Many of these wells have encountered hydrocarbon bearing potential reservoir quality rock in the shallower Bhagyam formation. Figure 1 shows the field location, which is located in Rajasthan state, India. Bhagyam formation is a Shallow (300–500 m TVDSS) in general has been described as sandstone with high net to gross, high porosity about 25–30 %, permeability about 1000 md. The Bhagyam tilted fault block structure (Figure 2) is formed at the intersections of NNE-SSW and WSW-ENE faults, it contains Sand layer FB1 to FB-3. The Bhagyam Crude Oil is around 28 API having about 20 cp viscosity at reservoir condition. The source rock in lacustrine in origin, it has generated waxy oil.
A Proactive Approach Towards Optimising Drainhole Placement Using "DTB" Technology in an Area Under EOR - A Success Story from Western Onshore Field, India
R.L. Singh, Chandan Jyoti Keot, N. Sanjay Kumar, Chandan Majumdar, Amit Kumar Singh
Paper presented at the International Petroleum Technology Conference, March 26–28, 2013
Abstract Field X is located in the northern part of Cambay basin, western onshore India. Sand-1 is the main reservoir unit in this field. Primary recovery is low here because Field X is located in the region's heavy oil belt. To increase the recovery factor, thermal EOR technique - Insitu Combustion, has been implemented in various parts of this heavy oil belt. Insitu combustion reduces oil viscosity but at the same time produces residual gases. These residual gases, called "Flue gas", accumulate as pockets in the reservoir top. The thermally altered low viscous crude can be produced efficiently through horizontal drainholes by maximizing reservoir contact and sweep radius. Placing a horizontal drainhole in this field is a challenge in itself because the drainhole has to be maintained at a safe distance from the flue gas pockets on top to prevent premature gassing out and also at a safe distance from bottom shale. As a solution to this challenge, "Distance to Boundary" (DTB) technology along with LWD was introduced for the first time in Field X in Well X. "DTB" technology detects the resistivity contrast at a shale-sand interface and maps the shale boundaries while drilling. The well was landed ~10m below reservoir top using LWD measurements to maintain a safe distance from flue gas pockets on top. It was decided to place the drainhole about 3m above reservoir bottom to stay away from bottom shale. The final result was a spectacular success with 311m of drainhole drilled with 100% stay in target reservoir zone. "DTB" technology tracked lower shale from ~3m and trajectory was maneuvered in conjunction with the structural changes to maintain an average distance of 3m from bottom. LWD data was used to verify sweet zone throughout the drilled interval. This paper illustrates an exemplary case study which opens new and exciting possibilities for application of LWD and "-DTB-" technology in field X for further field development plans.
Application of Latest Generation Inflow Control Devices in Non-Horizontal Wells in India, Case Study
Tim McKenzie, Andrew Wenk, Chetan Chavan, Sanjay Kumar, Parvez Khan, Gonzalo Garcia
Paper presented at the SPE Saudi Arabia Section Technical Symposium and Exhibition, April 8–11, 2012
Bhagyam is the second largest oilfield discovered to date in the Barmer Basin, India with more than 400mmb of viscous, waxy crude in place. This paper describes the evaluation, design and selection process for the use of the latest generation ICD in non-horizontal wells. Sandface completions comprise sand screens coupled with an ICD. Inflow control was highly desirable due to the oil viscosity variation, high permeability, heterogeneity and adverse mobility ratio and the fact the completions could not be easily accessed below a PCP. Oil viscosity ranges from 20 to 250cp varying with depth. The variation in reservoir thickness, produced fluid viscosity and well productivity required a field adjustable pressure drop capability in the ICD. The ICD had to perform at high viscosity and needed to be tolerant to wax and sand production. The operator's experience in nearby fields observed the benefits of ICDs for providing efficient sandface cleanup in horizontal wells. It was vital to model this system accurately however there were significant challenges as no previous examples of using these devices in non-horizontal wells could be found and the ICD completion had not been modeled in a dynamic simulator for this scale of field development. A dynamic simulation model which included the ICD completion was used to evaluate various completion options. A significant amount of work was performed to ensure the ICD was accurately modeled in the simulator. The simulations showed a long term benefit from using the ICD. To date 22 production wells have been completed with the ICD screen systems. This is one of the first applications of the latest generation ICD in non-horizontal wells particularly on a full field scale. It is also a case study of modeling the ICD completion with a dynamic simulator.
The Design and Application Of Latest Generation Inflow Control Devices In Non-Horizontal Wells in the Bhagyam Field, India
Paper presented at the SPE Annual Technical Conference and Exhibition, October 30–November 2, 2011
Bhagyam is the second largest oilfield discovered to date in the Barmer Basin, India with more than 400mmb of viscous, waxy crude in place. This paper describes the evaluation, design and selection process for the use of the latest generation ICD in non-horizontal wells. Sand face completions comprise sand screens coupled with an ICD. Inflow control was highly desirable due to the oil viscosity variation, high permeability, heterogeneity and adverse mobility ratio and the fact the completions could not be easily accessed below a PCP. Oil viscosity ranges from 14 to 250cp varying with depth. The variation in reservoir thickness, produced fluid viscosity and well productivity required a field adjustable pressure drop capability in the ICD. The ICD had to perform at high viscosity and needed to be tolerant to wax and sand production. The operator's experience in nearby fields observed the benefits of ICDs for providing efficient sand face cleanup in horizontal wells. It was vital to model this system accurately however there were significant challenges as no previous examples of using these devices in non-horizontal wells could be found and the ICD completion had not been modeled in a dynamic simulator for this scale of field development. A dynamic simulation model which included the ICD completion was used to evaluate various completion options. A significant amount of work was performed to ensure the ICD was accurately modeled in the simulator. The simulations showed a long term benefit from using the ICD. To date 23 production wells have been drilled and of these 16 have been completed with the ICD screen systems. This is one of the first applications of the latest generation ICD in non-horizontal wells particularly on a full field scale. It is also a case study of modeling the ICD completion with a dynamic simulator.
Design Charts For Rock Slope Stability Against Plane Failure Under Seismic Loading Condition
Sanjay Kumar Shukla, Md Monir Hossain
Publisher: International Society for Rock Mechanics and Rock Engineering
Paper presented at the ISRM International Symposium - 6th Asian Rock Mechanics Symposium, October 23–27, 2010
Paper Number: ISRM-ARMS6-2010-064
Abstract: Rock slope stability analysis has been a challenging problem for civil and mining engineers. There are several modes of failure in which a rock slope can fail; a plane failure is one of them. In recent past, a generalized expression has been presented for the factor of safety of the rock slope against plane failure. The expression considers several parameters that govern the stability of the slope. These parameters are: inclination of the slope face, inclination of the joint or discontinuity plane, unit weight of the sliding rock mass, shear strength parameters of joint materials, depth of tension crack, depth of water in tension crack, surcharge and seismic loadings, and the stabilizing force and its inclination. Though the analytical expression can be used to calculate the factor of safety, practising engineers generally prefer the use of design charts. A numerical example is illustrated to explain the calculation steps so that the developed design charts can be used conveniently. 1. INTRODUCTION Civil and mining engineers generally face a challenge of getting realistic values of the factor of safety of the excavated or natural rock slope against plane failure. This happens mainly because of heterogeneous and anisotropic characteristics of rock masses. The rock slopes often have discontinuities in various forms, resulting in different types of slope failures, such as plane failure, wedge failure, circular failure, toppling failure and buckling failure ([1], [2], [3], [4], [5]). A plane failure (aka block sliding) generally occurs in hard or soft rock slopes with well defined discontinuities and jointing, e.g, layered sedimentary rocks, volcanic flow rocks, block jointed granite, foliated metamorphic rocks ]3[. There are several parameters that govern the stability of the rock slope against plane failure, such as inclination of the slope face, inclination of the joint or discontinuity plane, depth of tension crack, depth of water in tension crack, shear strength parameters of the joint material at the failure plane, unit weight of rock, stabilizing force and its inclination, surcharge, and seismic loads ([1], [4], [5], [6], [7]). In view of the fact that surcharge loading caused by structures, machines, etc, is a common destabilizing force in most mining and civil engineering applications, Chukka et al. [7] developed an analytical expression considering both surcharge and seismic loadings. 2. REVIEW OF ANALYTICAL WORKS Hook and Bray [1] presented most of the basic methods of limit equilibrium analysis for rock slope stability against plane failure condition. Ling and Chang [6] presented an analytical expression for the factor of safety of the rock slope against plane failure induced by seismic force, ignoring the possibility of upward direction of vertical inertial seismic force, and without considering the surcharge and the anchoring force. Hook [5] described the idealisation of the rock slope failures in Hong King as plain failures and presented an analytical expression for estimating the factor of safety, considering many practical aspects including seismic loadings, but this expression does not incorporate surcharge and seismic force with all its possible directions.
The Application Of Attributes Derived From High Resolution Seismic Data In Horizontal Drilling. A Case Study From Shuaiba Formation, Minagish Field, West Kuwait
Sanjay Kumar, Khalaf K. Al-Anezi, Taher Mohd Nabil Gezeeri
Paper presented at the International Petroleum Technology Conference, December 7–9, 2009
Abstract In the Minagish field, the Shuaiba formation has very low porosity and permeability, However, the presence of shrinkage cracks, joints and fractures make it ideal disposal zones. Karsts feature south east of the Minagish structure, containing an abundance of fractures and dissolution channels, have been identified for disposal. Karsts are formed by the passage of meteoric water through the carbonate rock and dissolved the rock as it passed. In the areas with significant dissolution, the formation has collapsed due to weight of overburden, creating areas of massive fracture and faulting. The karsts area have been successfully targeted with 2 horizontal wells drilled within last three years, with disposal capacity of 30000 to 40000 bw/day per well. Seismic attributes are one of the most routine technologies applied in geosciences interpretation and analysis of 3D seismic data, contain incredibly rich information in terms of amplitudes, frequency, geometry and texture. Since seismic attributes are sensitive to spatial variations in subsurface, these can acts as guide for horizontal wells specially in complex and unpredictable area. The Coherency Cube quantifies the measurement of local waveform similarity. Since it provides spatial change in the seismic waveform hence it can be related to sub surface features like Geometry of the subsurface reflectors, Faults, Pinchouts, Unconformities, changes in lithology, Changes in pore fluid density, Changes in elastic properties as well as depositional environments. In present case study seismic attributes specially coherency along with other data was applied to identify the shale dominated area and limestone formation near collapsed feature. The horizontal well targeted fractured limestone near the edge of collapsed feature. The drilling data was correlated with seismic attributes to identify the shale dominated area and Shuiaba limestone near the collapsed feature. It was observed that Shuiaba limestone was severely eroded inside the collapsed feature and filled with overlying base Burgan shales and silts. With this information well was side tracked toward the limestone formation and completed with its objectives. By correlating the seismic attributes with real time drilling data, more accurate information about the spatial variation in the vicinity of well is available. In case of drilling complications these information are very useful to find out best possible trajectory for side track as done in this Shuaiba disposal well. Hence seismic attributes can be applied not only for identifying the location but also for providing support during horizontal drilling. Above technique can also be applied in planning the different legs of multilateral well.
Implementation of Integrated Network Optimization Model for the Mumbai High Field—Crucial to Field-Wide Optimization
Anand Kumar Jha, Santanu Barua, Vikas Agrawal, Gunja Agarwal, Ravi Kumar, Sanjay Kumar Moitra, G.S. Negi
Paper presented at the SPE Offshore Europe Oil and Gas Conference and Exhibition, September 8–11, 2009
Abstract The giant ONGC Mumbai-High offshore field produces about 250,000 bopd (60% water-cut) from 700+ wells through 110+ unmanned production platforms. The production platforms are connected by subsea flow lines to 6 processing platforms where the oil, water and gas are separated. More than 80% of the wells in the field are on gas-lift. This paper discusses an integrated-network-modeling-and-optimization approach to overcome known drawbacks of single well gas-lift optimization. The new higher fidelity model captured the interactions between wells, flow-lines and platforms, field-wide. Using this approach, previously hidden opportunities for significant production improvement were identified. The model indicated a possibility of significant production increase (2 to 4%) and production efficiency improvement (significant reduction in lift gas requirement), which could be achieved by better allocation of lift gas and repair and redesign of the sub-optimal gas-lift wells. The latest available field implementation results are also presented. Currently, in the absence of full-loop control-automation of the gas-injection rates/pressures, logistical challenges made it impractical to simultaneously implement the calculated optimum settings field-wide. The network interactions are highest at the production-platform level between adjacent wells and connecting shared flow-lines. So, from practical implementation considerations, optimum gas-injection rates were calculated and simultaneously implemented at the production-platform level, one (or a group of few connected) production platform at a time, with little or no compromise on the quality of the solution or on the validity of the approach. To date, actual optimization implementation changes in 14 of the 110+ platforms (160 of the 700+ wells) indicated immediate production increase of over 2000 bopd and significant reduction in lift gas requirement. Based on these early indications, it is envisaged that the field-wide oil production gain can possibly be as high as 6%. Additionally, this paper discusses the challenges and recommended approaches with regards to sustainable model maintenance, solution implementation and workflow. Status of control automation and on-line modeling plans (planned for implementation in future) are also discussed. Introduction Mumbai High field, a giant oil field discovered in 1974, is located W-NW offshore Mumbai in the Western Coastal shelf of India, spread over an area of 1200 sq km. The field was put on commercial production in 1976. Pressure maintenance using water injection started from 1984. The field production is currently in gradual decline with increasing water cut. The field is divided into two major blocks, Mumbai High North (MHN) and Mumbai High South (MHS). The field is a multi-layered limestone reservoir with several exploitable zones of oil and some gas. At present oil and gas is being produced from 700+ wells, 110+ unmanned wellhead platforms, 6 processing complexes and 3000 kms of networked pipelines. The bulk production from unmanned wellhead platforms is transported to one of the 6 process complexes (BHS, SHP, ICP, NQO, SCA and NA) through collector lines for separation, conditioning and subsequent transport to shore. Figure 1 illustrates the complexity of the surface pipeline layout of the Mumbai High field.
Hot Water Injection Pilot: A Key to the Waterflood Design for the Waxy Crude of the Mangala Field
Sanjay Kumar, Pankaj Kumar, Rohit Tandon, Dennis Beliveau
Abstract In 2004, the Mangala field was discovered in the Barmer Basin of Rajasthan, India. The field contains approximately 1.3 billion barrels of STOIIP in high-quality fluviatile reservoirs. The oil is waxy and viscous, with was appearance temperature and pour point within a few degrees of the reservoir temperature. The base development plan is waterflooding, and a major concern identified during the field appraisal stage was reservoir damage due to in situ wax dropout because of cooling if ambient temperature water was injected. Both 'hot' and 'ambient' water injection trials were done in Mangala during 2005 to evaluate injection performance. The injection trials demonstrated that a successful base waterflood program for Mangala requires injection water to be heated, at least during the first years of operations. Compatibility studies on water samples acquired during the program indicated the need for chemical treatments (scale inhibitorss, biocides and oxygen scavengers) during the field development program. Formation fracture pressures were estimated, and degrees of reservoir connectivity were established through pressure interference effects seen in observation wells. The next stage of the study will involve thermal modeling and will help determine the necessary duration of hot water injection. Introduction In 2004, the Mangala field was discovered (Yashwant, et al, 2006) by targeting a simple, tilted fault-block trap in the rifted, Tertiary Barmer Basin ( Figure-1 and Figure-2 ). Mangala wells encountered gross oil columns in excess of 150m within the Late Palaeocene Fatehgarh Group. The type log on Figure - 3 shows that the Fatehgarh Group is a series of interbedded sand and shales that has been divided into the Lower Fatehgarh (contains ~40% of the STOIIP) which is dominated by well-connected sheetflood and braided channel sands, and the Upper Fatehgarh (contains ~60% of the STOIIP) which is dominated by sinuous, meandering, less well-connected fluvial channel sands. The Upper Fatehgarh can be further sub-divided into two distinct members called FM1 and FM2 (from the top down) while the Lower Fatehgarh is sub-divided into three members called FM3, FM4 and FM5, respectively. Figure 4 shows that both Upper and Lower Fatehgarh sands have excellent reservoir properties with porosities that range from 17–33% (average 26%) and in situ permeabilities of 200md to more than 30 Darcies (average 5 Darcies). Obviously, in a fluvial environment such as this, the net-to-gross and reservoir continuity of the Lower Fatehgarh braid belts will be higher than that of the Upper Fatehgarh meander belts. The Mangala oil is a waxy, sweet crude, with gravity ranging from ~23°API near the oil-water contact (OWC) where the oil has been slightly biodegraded, to 29°API higher in the oil column (average of ~27°API). The crude has a low gas-oil ratio of ~180 scf/bbl and the in situ oil viscosity above the biograded zone ranges from 9–22 cp (biodegraded oil ~50 cp). Test rates in excess of 3,500 bopd have been achieved under limited drawdowns (less than 200 psi) from Mangala wells, thus confirming the high reservoir deliverability as inferred from logs and core data. Data from these single-well production tests helped to bracket the range of results expected from any multi-well interference tests. Some individual well tests results are given below in Table 1, and a typical pressure transient analysis from one of the Mangala well tests is shown in Figure 5.
New Wireline Sampling Technique Enables ZERO Contamination Sampling: A Case Study In A Challenging Sampling Environment
Dibyatanu Kundu, Sameer Joshi, Sanjay Kumar
Paper presented at the Asia Pacific Oil and Gas Conference and Exhibition, October 30–November 1, 2007
Abstract Cairn Energy India Pty. Ltd (CEIL) discovered Bhagyam field in RJ-ON-90/1 Block in July, 2004. With objectives to provide better bore hole stability and to determine accurate Sw (water saturation) from the cores collected while drilling, CEIL used Oil Based Mud to drill wells in this field. The sandstone formations in Bhagyam are characterized by high permeability both in vertical and radial directions. There is a high degree of variation in the properties of formation fluid as one progresses from the oil water contact to the crest of the structure. The formation fluid is very high in wax content. Sampling of formation fluid using traditional wireline formation testers becomes very complicated in view of these factors. In fact, 20 samples were acquired from this region and the laboratory deemed all of them non-representative. The OBM contamination levels in all these samples were more than 15%. It was thought that a focused sampling concept could be applied under such circumstances. Quicksilver* probe, which enables focused sampling, was used for acquiring representative formation fluid samples in two wells in Bhagyam field. A total of 18 samples were acquired in these two wells. Out of these 18 samples, 6 were contamination free and most of the samples were suitable for carrying out further PVT analysis. This sampling technique is one of the very first to be used in India and in fact results delivered by this technique are one of the very best as compared to other sampling techniques employed world wide. This paper deals with the operational and interpretational aspects of the Quicksilver* tool. It also brings out the comparison between contamination results obtained from SOCM (Synthetic OBM Contamination Monitoring method) and actual laboratory data. Introduction Bhagyam field, discovered by Cairn in July, 2004 in the Barmer Basin is a narrow NNW - SSE oriented rift basin, formed during the Paleocene in NW India. The oil is contained in fluvially dominated Fatehgarh Group units which consist of about 250m of medium to thickly bedded fine to coarse grained sandstones interbedded with iron-rich mudstones. Pressure-Volume-Temperature (PVT) data indicate a near-saturated reservoir with compositional grading of oil from crest to OWC. The API and viscosity varies from 31 deg/10 cp at the crest to 21 deg/120 cp at the OWC. Early in the exploration and development cycle, high-quality, representative reservoir fluid samples provide essential information about the properties of hydrocarbon fluids, such as saturation pressure, density, viscosity and gas/oil ratio (GOR). During the early development phase determination of actual reservoir fluid properties is critical for optimization of well completions and production facility designs. However, the formation characteristics and highly varied, highly viscous oils at Bhagyam presented challenges in acquiring representative, PVT quality samples. The high wax contents also made sampling difficult with both traditional formation testers and wireline conveyed DST samplers, particularly because of contamination by Synthetic Oil Based Mud (OBM) for drilling.
Well Clean up Issues in Field with Co-Sand Production Philosophy in Oman
Rafliansyah Andika Putra, Ahmed A.S. Azkawi, Sanjay Kumar Bharti, Stella Nneamaka Oyemade
Paper presented at the European Formation Damage Conference, May 30–June 1, 2007
Abstract The case reservoir is a field in South Oman and produces high viscous oil from well sorted unconsolidated formation sand with a small average grain size (40 microns). Initially the wells were completed with downhole sand control but suffered from extreme plugging due to very fine nature of formation sand. After performing some trials it was proved that, it is better to produce the wells without downhole sand control. A pre-drilled liner is used for downhole completion and Progressive Cavity Pump is for artificial lift as it is the most sand tolerable available pump. Sand co-production (i.e. sand removal at surface) is the optimal development for this field. Sand fill up in the well bore however became an issue in the high producers that are impacted by nearby water injection wells. This phenomenon caused a reduction in well productivity. Few methods were trialed to remedy this issue. Sand clean out with a wash string by reverse circulating didn't work because the reservoir is sub-hydrostatic. Coiled Tubing clean out with foam was trialed but somehow the result was not effective to bring the well back to previous productivity especially on long horizontal wells. The annular velocity was probably not high enough to lift up sand from the well bore. Concentric Coil Tubing was trialed also which does not require foam or nitrogen for sand clean out. This unit and its special tool (i.e. jet pump) uses water to create a vacuum in the well bore to have fluid return while lifting loose sand or debris to surface. This method bring the well back to its actual productivity when no hard obstruction is encountered during clean out. This paper presents WRM team experiences in dealing with sand clean out and sand co-production issues. Introduction The subject field is located on the Eastern flank of South Oman basin (Fig. 1). The reservoir is a fine-medium sandstone formation. The formation is divided into upper and lower zones each consisting of several layers. These zones are separated by a shale marker. The lower zones have a moderate bottom aquifer and the upper zones have a weak aquifer which provides some edge drive support. This resulted in a pressure differential between upper and lower zones. The reservoir crude characteristics are moderate to low API, i.e. 22 deg API oil and 90 cp viscosities. Whereas the original reservoir pressure was 9300 kPa and bubble point pressure is 7670 kPa. Currently the pressure has depleted to 4000 - 8000 kPa. The reservoir has been on production since 1980 and currently has around 78 active wells which consist of 15 water injectors and 63 oil producers.
Effective Well and Reservoir Management Reverses Production Decline in a Major Brown Field in South Oman
Biswajit Choudhuri, Ibrahim Saif Qarshubi, Ehab Sadek, Sanjay Kumar Bharti, Salim Mohd Al-Mahrooqi
Paper presented at the Abu Dhabi International Petroleum Exhibition and Conference, November 5–8, 2006
Abstract A large brown-field in South Oman showed decline in production despite moderate level of in-fill drilling over the last few years. The field has four major reservoirs distributed across three stratigraphic horizons and contains moderate to highly viscous oil (60 to 400 cp). The reservoirs comprise unconsolidated fluvial, fluvial deltaic and glacial sandstones of Palaeozoic age. The geologically complex field due to large number of faults and fractures has been on production for more than 25 years and has been developed using vertical and horizontal wells during different phases of development. Water-flooding is in operation in two of the major reservoirs for more than 5 years. Well and Reservoir Management in this field poses a formidable challenge due to: Significant well-stock (more than 450 wells) of different types (vertical, horizontal, multi-lateral) Problem associated with data acquisition as all the wells are completed with pumps (beam pump, progressive cavity pump and electrical submersible pump) and most of them are completed with some sand-control device Water-flood management under very adverse mobility conditions in presence of faults and fractures often resulting in premature breakthrough of injected water Logistical problems associated with large distance between the Well and Reservoir Management team at corporate office and the operational team at field location. The case study presented in this paper describes how a sustained well and reservoir management strategy implemented across the entire value chain starting from the planning to operation stage in this field could not only arrest but literally reverse the field production decline trend using the existing well stock. The paper clearly illustrates that success of reservoir management rests not only on the application of right technology but more on close integration among various disciplines in a cohesive work environment. Introduction The field under discussion is located on the Eastern flank of South Oman salt basin (Fig.1). The field comprises a NE-SW trending anticline about 14 km long and 8 km wide. To date, more than 450 wells have been drilled in the field encountering oil producing reservoirs in the Mahwis formation (the Haima group of Cambro-Ordivician age) and the Al Khlata and Gharif formations (Haushi group of Carboniferous/Permian age) at depth ranges of 550–675 m sub-sea (ss). The field comprises 4 major reservoirs: Al Khlata, Mahwis (Haima West), Gharif North Rim and Gharif South Rim. The field is unconformably overlain by Cretaceous Nahr Umr shale which acts as the cap rock (Fig.2) The Al Khlata is the largest of these reservoirs followed by Haima West. Oil in Al Khlata, Haima and Gharif South Rim is heavy, 22 deg API with viscosity of 90 cp. The Gharif North Rim contains more viscous oil (100–400 cp). The original reservoir pressure was 9300 Kpa at datum of 610 mss. Porosities range from 25% to 30%. The permeability of the reservoirs vary widely from about 10 md in some shaly Haima sands to over 5 Darcy in parts of Al Khlata and Gharif North Rim reservoirs. Table 1 shows the basic rock and fluid properties of the major reservoirs in the field. Production from the field commenced in 1980. The field production history is shown in Fig.3. A chronological description of the major events in the field is presented in Table 2.


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Posted: Feb 22, 2021 in News
Alberta's next biotech star, Hepion Pharmaceuticals, is rising thanks to success of FDA-approved voclosporin, discovered in Edmonton
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Dr. Robert Foster, CEO of Hepion Pharmaceuticals
February 22, 2021 – Edmonton, Alberta
A drug discovered in Edmonton has just been approved by the FDA — nearly 28 years after a University of Alberta professor first started the pharmaceutical company in a room in his basement.
Dr. Robert Foster, an adjunct professor in the Faculty of Pharmacy and Pharmaceutical Sciences, founded Isotechnika Pharma in 1993 and discovered voclosporin, which was approved in January by the U.S. Food and Drug Administration (FDA) as Lupkynis to treat patients with lupus-related kidney disease.
"My role was in the early stages in getting the drug and the company off the ground. There wouldn't have been anything to develop if I hadn't left a tenured faculty position to develop this molecule," says Foster. "But getting a drug to this point takes a village. At one point, Isotechnika had about 150 employees in Edmonton."
Isotechnika licensed the rights of voclosporin to Aurinia Pharmaceuticals, and eventually it bought the company and name. Foster was CEO until 2014.
In 2018, Foster was appointed CEO of New Jersey-based Hepion Pharmaceuticals and he immediately made Edmonton the primary site for the company's research and development. Foster recruited former Isotechnika staff members Daren Ure, Daniel Trepanier, and Patrick Mayo, to his senior executive team and contracted Applied Pharmaceutical Innovation to enhance the company's capacity. Foster and his team are committed to creating life- saving treatments for serious disease and continue to work with molecules that they first discovered with Isotechnika.
Their focus now is liver disease, including non-alcoholic steatohepatitis (NASH), a disease that causes liver inflammation and damage by a buildup of fat in the liver. It is part of a group of conditions called non-alcoholic fatty liver disease.
"The NASH market potential is huge," says Foster. It's estimated NASH affects 17 million adults in the U.S. and 1.5 million Canadians.
Hepion is currently in phase two trials, and has raised well over $200 million US to fund its research and Foster expects this to continue to grow. It closed its latest public offering on Feb. 18, raising about $88 million US in less than a week. The amount brought in by the company is one of the largest raises in the province for a company with a significant presence in Alberta.
Many people are unaware of the exciting scientific research and development in Edmonton, says Foster, and he credits the world-calibre expertise at the University of Alberta and the support of the Applied Pharmaceutical Innovation (API) in the success of Hepion and the province's broader research community.
Every person who worked on the earlier development of Lupkynis all the way up to FDA approval had a U of A connection at one point.
"This is an Edmonton story. And we're going to do it again."
Hepion is getting a lot of profile in New York for its work, Foster notes, but few in Edmonton are aware of its research. There are clinical trials going on now in 10 different sites in the U.S., and in the fall there will be broader trials in Canada, the U.S. and Europe.
"API is thrilled to be working closely with Hepion, and we look forward to seeing their continued success. Alberta's next biotech star is rising thanks to the leadership of Dr. Foster and the team of life sciences experts in the region," says Andrew MacIsaac, CEO of API.
More About Hepion Pharmaceuticals: The Company's lead drug candidate, CRV431, is a potent inhibitor of cyclophilins, which are involved in many disease processes. CRV431 is currently in clinical-phase development for the treatment of NASH, with the potential to play an important role in the overall treatment of liver disease – from triggering events through to end-stage disease. CRV431 has been shown to reduce liver fibrosis and hepatocellular carcinoma tumor burden in experimental models of NASH; and has demonstrated antiviral activities towards HBV, HCV, and HDV through several mechanisms, in preclinical studies. Hepion has created a proprietary AI platform, called AI- POWR™, which stands for Artificial Intelligence – Precision Medicine; Omics (including genomics, proteomics, metabolomics, transcriptomics, and lipidomics); World database access; and Response and clinical outcomes. Hepion intends to use AI-POWR™ to help identify which NASH patients will best respond to CRV431, potentially shortening development timelines and increasing the delta between placebo and treatment groups. In addition to using AI-POWR™ to drive its ongoing Phase 2a NASH program, Hepion will use the platform to identify additional potential indications for CRV431 to expand the company's footprint in the cyclophilin inhibition therapeutic space.
More About Applied Pharmaceutical Innovation (API): With a network of over 30 pharmaceutical scientists, clinicians, regulatory, patent and market experts, Applied Pharmaceutical Innovation (API) helps bring life-saving research to the real world. API is a not-for-profit institution with an expert interdisciplinary team that works with a network of collaborating organizations to provide the expertise, services, and infrastructure of a pharmaceutical company. API helps innovators launch their ideas into the real world, connects industry to the services they need for commercial success, and accelerates all aspects of the drug development process. API provides industry partner access to translational science in a framework that supports commercial success, as well as provides the services and resources by delivering expertise in drug development.
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On Feb 22, 2021 in News
Dr. Michael Houghton, Recent Nobel Prize Winner, on Life Sciences Sector in Alberta
Applied Pharmaceutical Innovation and Antimicrobial Resistance – One Health Consortium partner to bolster the intersection of antimicrobial research and drug...
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API is headquartered in Edmonton, Alberta on Treaty 6 territory and the home of many First Nations, Metis, Inuit and other First Peoples of Canada whose histories, languages, and cultures are integral to the vibrance of communities across Canada.
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Migraine headaches are throbbing, pulsating headaches that usually occur unilaterally (on one side of the head). The condition, which can be quite debilitating, affects millions of people worldwide. Migraines are often announced, so to speak, by sensory warning signs, or auras. These can be a flash of light, a tingling of the extremities and/or blind spots. They are accompanied by nausea and/or vomiting, sensitivity to light and sound and intense pain. Migraines can last for minutes, hours or even days.
Women are more likely to develop migraines than men are. This fact causes some experts to theorize that there is a hormonal component to the condition. While it's true that there is a type of migrains related to menstruation and hormone levels can trigger migraines in some people, migraines can not be attributed to any one factor alone. Besides, other things such as stress, anxiety, lack of food and/or sleep and exposure to light, chemicals and other environmental factors can also trigger migraines.
In the past, doctors thought that migraines were caused by the opening and narrowing, or constricting, of blood vessels in the brain. Now, they know that there are many other factors involved in the development of a migraine such as genetics, gender (as was previously alluded to) and certain allergies and/or sensitivities.
Migraines tend to develop in the younger years and generally decline as a person ages. Migrane headaches are chronic. To secure a diagnosis of migraine headaches, a doctor needs a full medical history. He/she will also give the patient a thorough physical examination and may opt to run some neurological tests to rule out the existence of other conditions. Treatment is based upon these results and takes a variety of factors in account.
Common migraine treatments include prescription and over the counter medications ads well as preventative techniques such as stress management. In some cases, naturopathic or holistic remedies may be employed like acupuncture, biofeedback, hypnosis and more.


Several Fox Chapel Area High School students recently placed at the Annual University of Pittsburgh Model UN Conference. The team of seniors Emilia Bianchini and Bridget Wang; sophomores Alyssa Carnevali, Hannah Drum, Gavin Hitchens, Zeynep Ozkaya, Aaron Santilli, Sina Shaikh, Helene Tracey, and Felix Veser; and freshmen Harrison Calig and Bennett Marsh were awarded first place overall in the large delegation category. Winning other first-place awards were senior Andreas Paljug, junior Zachary Lakkis, and sophomores Sina Shaikh and Felix Veser. Second-place winners included junior Tristan McClelland; sophomores Rajeev Godse, Gavin Hitchens, and Aaron Santilli; and freshmen Jackson Romero and Anthony Nguyen.
Nearly 500 students from 23 high schools from Western Pennsylvania participated in the University of Pittsburgh Model UN Conference. The conference was held November 13 at the University of Pittsburgh.


This article originally ran at Capital & Main, an award-winning publication that reports from California on economic, political, and social issues.
For almost an hour, Laura, Moises, and I drove through the dusty neighborhoods of Tecate, looking for Kikito. Tecate is a small border city in the dry hills of Baja California. It's famous for a huge brewery, although today most workers find jobs in local maquiladoras.
When we asked for directions, a couple of people had heard of Kikito, but couldn't tell us where he was. Most didn't know who we were talking about.
We figured that if we kept driving along the border fence, we'd find him. In these neighborhoods, the second stories of large comfortable homes, mostly built in the 1940s and 1950s, rise above adobe walls enclosing their courtyards. But unlike downtown, with its colorful bustle, there was no street life on the hot streets here, hardly anyone on the sidewalk.
Finally, we passed the one man who could surely tell us how to find Kikito—the cable guy. He even volunteered to lead us in his van part of the way. Using his directions, we bumped along a dirt road next to the border fence, up and down a couple of hills where the city fades into scrubland. Then we found Kikito.
He was much larger than I'd imagined.
Kikito is an enormous photograph of a 1-year-old child, pasted onto plywood sheets. The assemblage is mounted on a huge, complex metal scaffold, 65 feet high, much like what painters erect to embrace the buildings they work on. Kikito's scaffolding, however, doesn't embrace anything. Instead, it pushes the enormous photograph toward, and above, the border wall's severe vertical iron bars.
The "Kikito" art installation at the U.S.-Mexico border wall, created by French artist JR. Laura Velasco stands on a little hill near the structure, giving an idea of its huge size.
The structure is so big that to bring the photo into position, part of the hillside had to be excavated, and a hole dug deep into the ravine at the bottom. I felt like Dorothy going behind the curtain to confront the Wizard as he manically pulls levers to present his fierce, disembodied face to the world. Like the Wizard's, you can only see Kikito's visage the right way from the other side of the curtain—in this case, the metal fence separating Tecate from the United States.
Viewed from the U.S. side, Kikito becomes a giant black-and-white toddler, his chubby hands appearing to grip the top of the border wall as he looks over it, into the mysterious United States. He has a slight smile.
If we'd been on the U.S. side, driving east from San Diego, we could have followed the directions that Kikito's creator, the French artist JR, posted on his website. There you can even see JR's photograph of two U.S. Border Patrol agents staring at the baby. Apparently, they often help visitors find the right spot.
At this spot along the border wall between Mexico and the U.S., Border Patrol agents fired through the wall and killed Ramsés Barron-Torrés. His portrait and a cross are on the wall of the building in Mexico below, where he fell. Agents say they were justified in shooting because people were throwing stones at them, but the street is far below and there is little danger that a stone could even pass through the iron bars at such a distance.
We now have 20,000 Border Patrol agents, whose parked vans dot the desert all along the border wall from California to Texas, as they wait to grab someone trying to cross. Helping visitors find Kikito must provide a welcome break in the tedium of watching and waiting, and sweating in vans on shadeless hills, where the temperature climbs to 105 degrees and above.
That's one reason she liked Kikito. "He shows us to be human beings," she said, looking up at his half smile. "That's a good message for people in the U.S. And he does it without shouting, just by being who he is." If people in Mexico can't see him properly, she thinks, they're not the ones who need to get the message anyway.
WHEN THE INSTALLATION went up, President Trump had just issued his threat to terminate the Deferred Action for Childhood Arrivals (DACA) program, withdrawing the legal status of 800,000 young people brought by their parents to the United States without visas as children. Many of those youth—the Dreamers—saw a baby looking over the border wall as a symbol of their own humanity in the face of fear and possible deportation.
Migrants found dead on the border between the U.S. and Mexico, in the area of the Imperial Valley and Colorado River, are buried in a potters field graveyard in Holtville. The identities of many are not known, and are buried as "John Doe" or "Jane Doe." Immigrant-rights and religious activists have made crosses for many of the graves, most of which say "No Olvidados," or "Not Forgotten."
Yet my visceral reaction, as I looked down the hillside at this immense toddler, was more skeptical. In a desert where hundreds of people die every year of thirst and exhaustion, trying to dodge Border Patrol agents, trekking on foot across the wall in the intense heat, is it enough to simply say, "Immigrants are human beings"? Why such a soft message in such a harsh context?
The wall, and the border militarization of which it is a part, is exacting a terrible cost. It's paid by uprooted Oaxacan farmers needing work and money to send home, by parents and children desperate to reunite families fractured by earlier migrations, by Honduran refugees fleeing violence. When many die crossing the desert (232 in the first seven months of 2017), they're buried in the Holtville cemetery, 89 miles east of Kikito in the Imperial Valley.
Successive U.S. administrations have beefed up the Border Patrol's numbers, built multiple walls, handed out contracts for high-tech surveillance devices, detained hundreds of thousands of people in for-profit detention centers and then deported them. It's a big media story, and produces a fascination with the border among U.S. photographers and artists, who then create photodocumentaries and art projects currently popular in the mainstream media. The border sells, in other words. Kikito is part of a growing genre.
Luisa, a homeless woman, collects cans and plastic from garbage dumpsters, near the Tijuana River, in downtown Tijuana, just south of the U.S.-Mexico border.
Richard Misrach, a well-known photographer, produced a large book of photographs, Border Cantos, which shows the absurdity of a wall of iron bars that suddenly stops at a golf course, allowing real-estate agents to play through. He communicates an atmosphere of violence in images of spent shells on the range where Border Patrol agents practice shooting, and the possibility of death from thirst in images of flags signaling the water cans left by immigration activists and Good Samaritans along the migrant trails. But like Kikito, his audience is in the United States. The photographs, almost all without people, look at the border wall from the northern side.
The New Yorker labeled Drake's work "Haunted Photographs of America's Borderlands," a phrase that signals that we're only looking at the border from the U.S. side. "Our obsession with the border has a lot of fantasy involved," Drake explained to Blitzer. "You're searching for something, but it's not really there." Her 22 photographs on the magazine's website are all taken in the United States—Mexicans only exist once they've arrived in the north.
A memorial at the border fence for those who have died trying to cross.
I'm sure JR doesn't see Mexicans as 1-year-olds. But the way the border is objectified and used can make people in Mexico suspicious about how people on the other side of the wall see them, when they see them at all.
A worker is deported back into Mexico at the border gate in Mexicali, under the stare of a Border Patrol agent.
AFTER LOOKING AT KIKITO, we drove over to Tecate's new municipal art center for the presentation of a book about California farmworkers, published jointly by COLEF in Tijuana and the University of California Press in Oakland. Afterward, we went to drink wine at a local restaurant with friends—poets and artists.
Juan Manuel Barragan Corona, left, and his friend are homeless men who live in the Tijuana River flood control channel. Many deported homeless people live in the concrete river bed.
Morales isn't angry at Kikito in particular, but like many of his colleagues believes Tijuana's vibrant culture is ignored in U.S. media coverage of the border. Mexican artists create their own art about the migration experience, because it is such a fundamental aspect of Mexican life. Virtually every family has a member or friend who's crossed to the United States, where more than 9 percent of the country's population now lives. One famous work mounted crosses on the border wall's metal plates, where it runs along the road past the Tijuana airport. Gallon jugs symbolizing the water carried by border crossers were stacked against it, each with the name of someone whose body had been found in the desert.
At the ironically named Friendship Park (Parque de la Amistad) in Playas de Tijuana, the graffiti on the wall's bars is itself an art project. The wall, both there and on the fence leading to Mexicali's crossing gate, has become a venue for photographers and artists. Their art is sharp, critiquing mass deportations and the hard lives of migrants on the other side. And these works can only be shown on the Mexican side—the Border Patrol will not allow art installations on the side they control.
Art or photography can help change the world, if it arises from the political commitment and involvement of the artist and photographer. "We should strengthen solidarity on all the borders of the world," Botello urges, "so that that someday all those borders will disappear." Therefore, photography projects, he believes, should be produced in cooperation across the border, in active solidarity.
A man on the Mexican side of the border wall between Mexico and the U.S. looks through the bars, where the wall runs into the Pacific Ocean.
While there are few examples of this today, it is an idea with historical precedent. In the 1930s and 1940s, Mexican muralists Diego Rivera, David Alfaro Siqueiros, and José Clemente Orozco came to the United States and created radical murals that were cultural weapons of that era in movements for social change. They inspired a generation of radical U.S. painters in the process. Rivera's Rockefeller Center mural, "Man at the Crossroads," was viewed as so dangerous that its patron, Nelson Rockefeller, had it demolished. Tina Modotti, born in Italy and raised in San Francisco, and Mariana Yampolsky, born in Chicago, created photographs that became part of the revolutionary cultural upsurge in Mexico from the 1920s to the 1950s.
In making Kikito, a Mexican child visible to the United States, JR has created a border-focused project. But if part of its purpose was to make the invisible visible, other subjects carry a sharper critical edge, and pose deeper questions about the reality people experience on the border. What happens, for instance, to those pushed back through the gate in the border wall, once they're deported from the United States?
Today, scores of young people live in the concrete channel built to contain the floods of the Tijuana River, which runs through the middle of the city near the border between Mexico and the United States. Like the Los Angeles River channel, it is mostly a featureless cement expanse, but in Tijuana it is filled with deportees with no money and no homes.
looking for migrants through the wired.
fears and mastiffs are after feeble dogs.
How many fences they build!
for so many nomadic skeletons!
a wall rises upon us.
no groans come from it.
or a private lilies swamp.
giving birth to new sarcasms.


MORE AMERICAN RED CROSS BLOOD DRIVES ARE BEING HELD IN THE AREA. ALL BLOOD TYPES ARE NEEDED. TODAY, A RED CROSS BLOOD DRIVE WILL BE HELD AT JACKSON COUNTY CENTRAL HIGH SCHOOL FROM 8:30 UNTIL 1:30. ALSO TODAY, THERE WILL BE A BLOOD DRIVE AT RED ROCK CENTRAL HIGH SCHOOL IN LAMBERTON, WITH HOURS FROM 8:00 UNTIL 2:00. DONORS SHOULD BE AT LEAST 17-YEARS-OLD, OR 16 WITH PARENTAL PERMISSION. DONORS SHOULD WEIGH AT LEAST 110 POUNDS AND BE IN GOOD GENERAL HEALTH.
A REGULAR MEETING OF THE JEFFERS CITY COUNCIL WAS HELD LAST WEEK. A REPRESENTATIVE FROM AMBOY TOWNSHIP DISCUSSED A PROPOSAL TO EXTEND A STREET; THE COUNCIL INDICATED SUPPORT FOR THE IDEA. THE COUNCIL APPROVED A WARRANTY DEED WITH THE RED ROCK RURAL WATER SYSTEM. A FUND TRANSFER WAS APPROVED FROM THE GENERAL FUND TO THE SEWER FUND. THE COUNCIL APPROVED TOBACCO, LIQUOR AND CIGARETTE LICENSES FOR THE SLIPPER INN, AND APPROVED A CHARITABLE GAMBLING PERMIT.
A REGULAR MEETING OF THE WESTBROOK-WALNUT GROVE SCHOOL BOARD WAS HELD THIS WEEK. AN OPENING WAS POSTED FOR A 5TH AND 6TH-GRADE TEACHER. THE BOARD APPROVED A PLAN TO EXTEND THE SCHOOL DAY BY 30 MINUTES A DAY, FROM MARCH 11TH THROUGH THE 29TH, TO MAKE UP TIME LOST DUE TO BAD WEATHER. NEW CONTRACTS FOR SERVICES WERE APPROVED WITH THE SOUTHWEST-WEST CENTRAL SERVICE COOPERATIVE.
THE HERON LAKE-OKABENA SCHOOL BOARD MET THIS WEEK. THE SCHOOL CALENDAR WAS ADJUSTED TO MAKE UP TIME LOST DUE TO BAD WEATHER. TWO ADDITIONAL DAYS WERE ADDED TO THE END OF THE SCHOOL YEAR. A NEW THREE-YEAR CONTRACT WAS APPROVED WITH SUPERINTENDENT PAUL BANG. NEW CONTRACTS FOR SERVICES WERE APPROVED WITH THE SOUTHWEST-WEST CENTRAL SERVICE COOPERATIVE. THE COST WILL GO UP SLIGHTLY. AN AUTISM CONSULTANT WAS HIRED. THE BOARD APPROVED A FUND-RAISER FOR THE SENIOR CLASS TRIP.
THE TOTALS HAVE BEEN ANNOUNCED FOR THE 2018 WINDOM UNITED DRIVE. THE DRIVE BROUGHT IN A TOTAL OF JUST OVER 16-THOUSAND-800-DOLLARS IN DONATIONS. AFTER EXPENSES, THE UNITED DRIVE WILL BE DISBURSING JUST OVER 14-THOUSAND-400-DOLLARS TO 36 DIFFERENT GROUPS AND ORGANIZATIONS. AMONG THE HIGHER AMOUNTS, THE WINDOM SHARING CENTER AND 'BARC' WILL EACH RECEIVE JUST OVER 1-THOUSAND-DOLLARS. COTTONWOOD COUNTY 4-H, MEALS WITH WHEELS, AND THE YOUTH HOCKEY ASSOCIATION WILL RECEIVE MORE THAN 900-DOLLARS.
THE FEDERATED RURAL ELECTRIC ASSOCIATION HAS ANNOUNCED THE GRAND PRIZE WINNER IN ITS YOUTH TOUR CONTEST. LYDIA STEINHAUS OF FAIRMONT WILL RECEIVE A FREE TRIP TO WASHINGTON, D-C THIS SUMMER. STEINHAUS IS A JUNIOR AT MARTIN LUTHER HIGH SCHOOL IN NORTHRUP. 2ND PLACE, WITH A $150 CASH PRIZE, WENT TO AMBER RUTHENBECK OF OKABENA, A SOPHOMORE AT HERON LAKE-OKABENA HIGH SCHOOL. 3RD PLACE, WITH A $100 CASH PRIZE, WENT TO EMILY STAUTER OF WELCOME, A SOPHOMORE AT GRANADA-HUNTLEY-EAST CHAIN HIGH SCHOOL.
THE COMMUNITY BLOOD BANK WILL HOST A BLOOD DRIVE MONDAY AT WINDOM AREA HEALTH. DONATIONS WILL BE ACCEPTED ON MONDAY FROM 10:00 UNTIL 1:00, AND 2:30 UNTIL 5:00PM. DONORS MUST BE 17, OR 16 WITH PARENTAL PERMISSION. DONORS MUST WEIGH AT LEAST 110 POUNDS AND BE IN GOOD GENERAL HEALTH. YOU WILL NEED TO SHOW IDENTIFICATION AT CHECK-IN. THE COMMUNITY BLOOD BANK, BASED IN SIOUX FALLS, IS THE SOLE SUPPLIER OF BLOOD AND BLOOD PRODUCTS FOR WINDOM AREA HEALTH AND OTHER LOCAL MEDICAL FACILITIES.