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Results
Distributed Temperature Sensing (DTS): An Attempt to Compare Multivendor Data Acquisition and Interpretation Process for Possible Standardization at Field A
Rachapudi Venkata, Subba Ramarao (Adnoc Onshore) | Patel, Dipen (Halliburton worldwide Limited) | Al Dhuhoori, Moza Saeed Abdulla (Adnoc Onshore) | Albarracin, Ruben Dario (Adnoc Onshore) | Iqbal Javid, Khalid Javid (Adnoc Onshore) | Al Jasmi, Sami (Adnoc Onshore) | Konkati, Sarath (Adnoc Onshore) | Al Mansi, Mohammad Kamel (Adnoc Onshore) | Wak wak, Amr (Halliburton worldwide Limited) | Titov, Boris (Schlumberger Middle East S.A.) | Sajjad, Fahad (Schlumberger Middle East S.A.)
Abstract In Oil and gas industry, demand for DTS (distributed temperature sensing) completions installation is rapidly increasing in recent times. Currently multiple vendors are installing the DTS completions at field A for real-time water flood conformance monitoring and to meet target production rate. This paper discusses about the insights of data acquisition process and interpretation approaches to generate a standard operating procedure specific to Field A. DTS Completions are being installed in field A for few years, and they will be key in generating the optimum water injection profiles, proactive water flooding surveillance, injection/ production optimization and better reservoir management. However, the data acquisition, conditioning and interpretation is vendor specific. Moreover, the interpretation is influenced by the procedure followed for data collection, warm back period, the fluid at down hole, reservoir rock properties as well as the models being used for interpretation. In view of this multivendor installations available at field A, there is a need to standardize the data acquisition & interpretation process that will allow all reservoir and petroleum engineers in the field to analyze the DTS profiles regardless of the type of vendor DTS completion installations. Field A has 13 DTS Completions installed in multiple reservoirs from three different vendors, and the injection profiles for these wells are being generated. This paper summarizes the influence of key parameters and/or assumptions that play a major role on the interpretation results and their variability during data collection stage. Further, the comparison of the injection profile generated by DTS with mechanical PLT will be discussed, and the use of PLT data for fine-tuning the interpretation model. In addition, time-lapse injection profile generated at a specific well will be compared to understand the reasons for variation of it over a period. Additionally, the recommendations for improving/ optimizing the injection profile in few cases will be discussed including stimulations for better conformance and injection rate adjustments. In the conclusion, the proposed unified procedure covering data acquisition, format, storage, and standardized interpretation approach will be discussed. This is an attempt to standardize the DTS data collection and to unify the interpretation process among the multiple vendors in a specific Field A.
- North America > United States (0.94)
- Asia > Middle East > UAE (0.28)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- Information Technology > Sensing and Signal Processing (1.00)
- Information Technology > Architecture > Real Time Systems (0.89)
- Information Technology > Communications > Networks > Sensor Networks (0.61)
Design for preventing or minimizing the effects of accidents is termed accidental limit states (ALS) design and is characterized by preventing/minimizing loss of life, environmental damage, and loss of the structure. Collision, grounding, dropped objects, explosion, and fire are traditional accident categories.
- South America > Brazil (1.00)
- Oceania > Australia (1.00)
- North America > Canada (1.00)
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- Summary/Review (1.00)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (1.00)
- (3 more...)
- Geology > Mineral (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Sedimentary Geology > Depositional Environment (0.67)
- Geology > Structural Geology > Tectonics > Plate Tectonics (0.67)
- Transportation > Marine (1.00)
- Transportation > Infrastructure & Services (1.00)
- Transportation > Ground (1.00)
- (36 more...)
- South America > Brazil > Campos Basin (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Viosca Knoll > Block 786 > Petronius Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 392 > Appomattox Field (0.99)
- (58 more...)
- Information Technology > Software (1.00)
- Information Technology > Sensing and Signal Processing > Image Processing (1.00)
- Information Technology > Security & Privacy (1.00)
- (30 more...)
"In offshore and coastal engineering, metocean refers to the syllabic abbreviation of meteorology and (physical) oceanography" (Wikipedia). Metocean research covers dynamics of the oceaninterface environments: the air-sea surface, atmospheric boundary layer, upper ocean, the sea bed within the wavelength proximity (~100 m for wind-generated waves), and coastal areas. Metocean disciplines broadly comprise maritime engineering, marine meteorology, wave forecast, operational oceanography, oceanic climate, sediment transport, coastal morphology, and specialised technological disciplines for in-situ and remote sensing observations. Metocean applications incorporate offshore, coastal and Arctic engineering; navigation, shipping and naval architecture; marine search and rescue; environmental instrumentation, among others. Often, both for design and operational purposes the ISSC community is interested in Metocean Extremes which include extreme conditions (such as extreme tropical or extra-tropical cyclones), extreme events (such as rogue waves) and extreme environments (such as Marginal Ice Zone, MIZ). Certain Metocean conditions appear extreme, depending on applications (e.g.
- Europe > United Kingdom > England (1.00)
- Asia > Middle East > Saudi Arabia (1.00)
- Asia > Japan (1.00)
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- Summary/Review (1.00)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (1.00)
- (3 more...)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Sedimentary Geology > Depositional Environment (0.67)
- Geophysics > Electromagnetic Surveying (0.65)
- Geophysics > Seismic Surveying > Seismic Modeling (0.45)
- Transportation > Passenger (1.00)
- Transportation > Marine (1.00)
- Transportation > Infrastructure & Services (1.00)
- (36 more...)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5504/12 > Tyra Field (0.99)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5504/11 > Tyra Field (0.99)
- North America > United States > Colorado > Ice Field (0.98)
- (18 more...)
- Well Drilling > Well Planning > Trajectory design (1.00)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations (1.00)
- (53 more...)
Enabling Well and Reservoir Surveillance in Dual Water Injectors Through Distributed Fiber-Optic Sensing
in 't Panhuis, Peter (Petroleum Development Oman) | Harthi, Zena (Petroleum Development Oman) | Al Hashemi, Mohamed (Petroleum Development Oman) | Hemink, Gijs (Petroleum Development Oman) | Spivakovska, Daria (Royal Dutch Shell)
Abstract Distributed Acoustic Sensing (DAS) and Distributed Temperature Sensing (DTS) are novel surveillance technologies which are increasingly being used for in-well surveillance, including in injector wells. Some of the applications include injection profiling, acid-stimulation optimization, well-integrity monitoring, and fracturing diagnostics. Our goal here is to demonstrate how this can be applied to a particular type of water injectors that use dual injection lines to improve conformance by decomingling the injection between shallow and deeper reservoir targets. Specifically, annulus injection will be used to target the shallow reservoirs and tubing injection to target the deeper reservoirs. Several case studies will be presented from water injectors located in the South of the Sultanate of Oman. This required integrated evaluation combining data from surface meters, downhole gauges, open-hole formation evaluation, as well as DAS and DTS. It will be shown how the data was analyzed to assess the efficiency of the waterflood, to optimize the water injection operating envelope, to identify fracture initiation or plugging, but also to analyze the effectiveness of the well and completion design. Through its high sample rate and narrow spatial resolution, DAS is particularly effective at monitoring changes to injectivity in real-time. This is especially helpful for identifying the onset of fracture initiation and monitoring the growth in fracture height, which is difficult to achieve with other technologies. DTS warm-back analysis was also performed to complement the DAS interpretation and monitor changes in conformance with a deeper depth of investigation than DAS. The unique value of the fiber-optic sensing technology is that it enables the implementation of the dual annulus-tubing injection completion design without limiting surveillance capabilities, as conventional surveillance in this well design is either impractical, not feasible, or too costly.
- Asia > Middle East > Oman (0.35)
- North America > United States > Texas (0.28)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.15)
- Geophysics > Borehole Geophysics (0.46)
- Geophysics > Seismic Surveying > Passive Seismic Surveying (0.35)
- Asia > Middle East > Oman > Dhofar Governorate > Qaharir Field (0.97)
- Asia > Middle East > Oman > South Oman > South Oman Salt Basin > Gharif Formation (0.95)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Information Technology > Architecture > Real Time Systems (0.89)
- Information Technology > Sensing and Signal Processing (0.86)
- Information Technology > Communications > Networks > Sensor Networks (0.54)
Abstract Distributed temperature (DTS) and distributed acoustic (DAS) fibre optic sensing are now commonly used as key reservoir surveillance tools. This work shows the benefit of continuous downhole monitoring during the lifetime of a well. Fibre optic cables were permanently installed in a doublet injector/monitor well system as part of a CO2 controlled released experiment at the In-Situ Laboratory in Western Australia. During the completion and injection operations various planned and unplanned events (mud circulation, cementing, drilling, wireline logging, gas and water flows) occurred. The events were monitored from surface to reservoir with DTS and DAS fibre optic cables. The DTS was recorded continuously data starting during well completion throughout the lifetime of the wells while DAS was recorded at specific points in time, mostly associated with borehole time-lapse seismic acquisitions. For the well completion stage, the interpretation of the DTS dataset acquired during mud circulation provided information about thief zones above the reservoir. During cementing and cement hydration, DTS highlighted areas of large breakouts and confirmed cement in-fill in those intervals. During the drilling of an unexpected cement infill, it provided a unique insight into downhole progression of the drill bit. During the CO2 injection stage, DTS enabled monitoring the phase behaviour at the injector using distributed temperature data combined with a permanent pressure downhole gauge. At the monitoring well, the injected gas breakthrough was clearly detected at reservoir level within 1.5 day after the start of injection. Moreover, the accumulation of the CO2 over time was captured accurately at reservoir level for a further 3 days. During an unexpected leak in the casing, gas from the reservoir started entering the monitoring well leading to cyclic release of water and gas at the surface. The DAS dataset enabled to pin-point the exact moment the casing leak occurred while the DTS dataset captured the cyclic nature of water and gas leakage. The sensitivity of the tools and interpretation methods are such that the downhole location of the event can be determined within 1 m and the timing within a few seconds. More importantly, the continuous and distributed recording allowed monitoring the events developing in time over the full length of the well. This work highlights the unique benefit of permanent distributed monitoring using distributed fibre optic sensing during the lifetime of a well. The continuous and distributed recording allowed monitoring events developing in time over the full length of the well and provides direct observations for the different events while providing near-real-time information about downhole processes.
- Research Report > Strength High (0.55)
- Research Report > Experimental Study (0.55)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Information Technology > Sensing and Signal Processing (1.00)
- Information Technology > Communications > Networks > Sensor Networks (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
Sandstone formations can be particularly susceptible to formation damage due to organic deposits, fine migration, filter cake and formation minerals. Stimulation methods for these types of formations have typically employed mud acid due to the ability to readily dissolve both formation minerals and contaminants introduced into the wellbore/formation during drilling or remedial operations. However, hydrofluoric (HF) based fluids are corrosive, fast spending and causes formation damage by side reactions precipitations, thereby limiting the efficiency of matrix stimulation treatment. A novel heat generating fluid has been developed as an alternative to conventional matrix stimulation for sandstone formation. The method entails triggering an exothermic chemical reaction in-situ to generate heat i.e. ~>400 ยฐF and localized pressure. Generated heat mobilized near wellbore damage; while the pressure provided lifting energy to flowback the well, therefore, improve well injectivity. Exothermic reactants were subsequently injected via coiled tubing and allowed to soak in the treated wells. The resulting temperature and pressure increase were captured in real-time with distributed temperature sensing (DTS) coiled tubing telemetry. DTS profiling helped in understanding the in-situ exothermic reaction and avoiding post treatment production logging costs. The treatment was executed in different phases while injectivity tests were conducted after each step for each phase evaluation. To prove the stimulation concept using thermochemicals, the treatment was applied in sandstone wells and showed superior results. DTS and downhole flow tool profiling confirmed a homogeneous treatment along the perforated interval of the well. Post treatment results showed improved well injectivity up to 50 times. Attempts to realize consistent performance of the conventional stimulation treatments with different formulations have either been cost prohibitive or relatively ineffective. The non-acidic and heat generating fluid holds promise as an economic and a technical solution to well enhancement issues in sandstone reservoirs.
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Well Completion > Completion Installation and Operations (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- (2 more...)
- Information Technology > Architecture > Real Time Systems (0.75)
- Information Technology > Sensing and Signal Processing (0.72)
- Information Technology > Communications > Networks > Sensor Networks (0.72)
Innovative Process for Formation Damage Removal in Sandstone Reservoir Based on Real-Time Downhole Monitoring: A Malaysia Case History
Riyanto, Latief (PETRONAS Carigali Sdn Bhd) | Musa, Mohd Nizar (PETRONAS Carigali Sdn Bhd) | Deris, Nurul Asyikin (PETRONAS Carigali Sdn Bhd) | Yaakub, Mohd Yuzmanizei (PETRONAS Carigali Sdn Bhd) | Ghazali, Rohaizat (PETRONAS Carigali Sdn Bhd) | Hamidon, Zahaezuani Rafiq (Schlumberger) | Wijoseno, Danny Aryo (Schlumberger) | Jenie, John Rizal (Schlumberger) | Parapat, Arthur (Schlumberger) | Kasim, Mohamed Heikal (Schlumberger)
Abstract Many retrograde condensate gas wells in field A, located offshore Malaysia, are underperforming or even idle because of calcium carbonate scale deposition and near-wellbore condensate banking. Previous treatments were performed without any adjustment of fluid placement across the multiple fractured zones due to the lack of technology enabling real-time downhole monitoring. Fluids could, therefore, be lost into depleted or high-water-cut intervals, leading to suboptimal treatment. Distributed temperature sensing (DTS) technology through optical fiber installed inside coiled tubing strings mitigates the risks related to blind acid pumping. The technology makes it possible in real time to monitor and adjust fluid placement and diversion efficiency to squeeze acid into target zones and maximize the treatment success. The first worldwide implementation of sandstone matrix acidizing using the DTS technology was performed on a well completed with four perforated and propped fractured zones. The main treatment fluid was designed to remove both types of formation damage: organic acid would attack the scale and alcohol would eliminate the condensate banking. The first challenge was the cleanout of hard carbonate scale from the wellbore, which was performed with a bottomhole assembly composed of a high-pressure rotating jetting tool and a real-time fiber-optic tension-compression sub enabling the coiled tubing unit operator to maximize the slack-off on scale and facilitate its removal. The second challenge was the depleted upper perforated and propped fracture interval detected by the DTS. If diversion was inefficient, all fluids would get lost into the upper zone. A diverter fluid system formulated with degradable fiber blended into viscoelastic-surfactant-based fluid was optimized based on expected downhole conditions, and two stages were successively squeezed into the highly permeable (130-Darcy) depleted upper interval before getting a good signature on the DTS surveys showing that this zone was temporarily plugged and that the main treatment fluid would be squeezed into the lower target zones. The post-treatment gas production was double what was expected. A memory production logging tool was run after the job. This confirmed the crossflow to the upper depleted zone during shut-in and showed 86% gas production from the two bottom intervals, which demonstrates the effectiveness of both the innovative stimulation process with DTS and the diversion with degradable fiber.
- Asia > Malaysia (0.71)
- North America > United States > Texas (0.28)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 186 > Field A Field > Silurian Tanezzuft Formation (0.97)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field A Field > Silurian Tanezzuft Formation (0.97)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- (3 more...)
- Information Technology > Architecture > Real Time Systems (1.00)
- Information Technology > Sensing and Signal Processing (0.89)
- Information Technology > Communications > Networks > Sensor Networks (0.35)
Combining Distributed Temperature Sensing with Inflow Control Devices โ Provides Improved Injection Profile with Real-Time Measurement in Power Water Injector Wells
Hembling, Drew (Saudi Aramco) | Berberian, Garo (Saudi Aramco) | Watson, Mark (Tendeka) | Simonian, Sam (Tendeka) | Naldrett, Garth (Tendeka)
Abstract Passive ICDs (Inflow Control Devices) have been used in the past to enhance performance of producing horizontal wells in unfavorable environments such as non-uniform permeability and/or pressure variations along horizontal sections. This is the first ever attempt, to the best of our knowledge, at using ICDs combined with a fiber-optic DTS (Distributed Temperature Sensor) to manage the water injection profile across a horizontal reservoir horizon. The cost of the permanent monitoring installation is comparable to a single coiled tubing deployed PLT intervention. This paper addresses how a passive ICD completion, utilizing DTS technology, was used to optimize and monitor well performance. In addition, the operational aspects of permanent vs. intervention monitoring are addressed while highlighting the opportunity for additional value creation using real-time monitoring combined with ICD technology. This field trial demonstrates the effectiveness of the ICD system when used in an injection well for injection profiling and fluid diversion during acid stimulation. In addition, the DTS proved to be an effective alternative to production logging in this horizontal water injection well. The key factor in the success of this project was the use of the 3-1/2" ICD completion along with a DTS system to monitor and passively control the injection sweep across the entire reservoir section. DTS data were also obtained during pre-injection and acid stimulation operations. This was the first occasion in which an operator was able to evaluate stimulation efficiency of an ICD completion using permanent real-time monitoring methods.
- Asia > Middle East > Saudi Arabia (0.49)
- North America > United States > Texas (0.46)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.31)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Flow control equipment (1.00)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- (2 more...)
- Information Technology > Sensing and Signal Processing (1.00)
- Information Technology > Communications > Networks > Sensor Networks (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
SPE Gulf Coast section Electrical Submersible Pump Workshop, 29 April - 1May, 2009, The Woodlands, Texas Abstract In the last 8 years, coiled-tubing-deployed ESP (CTDESP) systems have developed into a proven technology marrying the cost-effectiveness of coiled-tubing conveyance with the benefits of electrical submersible pumping(ESP) systems. Simultaneously, great strides have been made in the form of real-timemeasurement of reservoir and production data such as pressure, temperature, and flow rate, by means of permanent gauges placed in the completion string and theuse of fiber-optic distributed temperature systems. CTDESP technology with real-time monitoring and control results in analternative deployed intelligent completion that is able to optimize pumpperformance and run life, control injection rates, and maximize ultimaterecovery. Such a system was developed specifically for a Shell Sabah Berhad (SSB)medium oilfield, offshore Sabah-Borneo, East Malaysia. This particular reservoir is a mature depleting field, requiring pressure maintenance toextract more of the reserves. After 2 years of production, the oil rate of the primary reservoir had declined by about half. Studies showed that pressure maintenance by water injection (WI) was feasible and beneficial. However, high capital cost and long lead times prevented the implementation of a conventional WI scheme because the existing, unmanned platform was too small to accommodate a WI facility. The lithology of the area is conducive topressure maintenance with a large natural aquifer dumping from an upper zone into the lower producing zones (i.e., dumpflood). Two horizontal wells were drilled and completed, allowing natural dumpflooding of an estimated 3,000bbl/d/well. It was clear that augmenting the natural dumping ability of theupper zone aquifer with an inverted ESP would boost production (up to 10,000bbl/day per well), accelerate the reservoir pressure maintenance, and increase the sweep in the main producing reservoir. With anticipated tubing-deployed ESP run lives of 1 to 3 years, the ESPdumpflood strategy would not be a cost-effective solution because of the cost of rig mobilizations required for ESP workovers. Therefore, a CTDESP system wasselected to allow installation and subsequent change-out without rigassistance. Such a system was evaluated to be USD 25 million more cost-effective than a conventional surface injection system over the life of the project. In the past 3 years, the assisted intelligent dumpflood strategy has shown its value. By boosting the reservoir pressure, the ultimate recovery factor is believed to have increased from 24 to 48%, adding approximately 10million bbl of additional reserves. Additionally, one of the nearby production wells has shown a net increase of 600 bbl/d of oil since the start of assisted dumpflooding operations.
- Well Completion > Completion Monitoring Systems/Intelligent Wells (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- (3 more...)
- Information Technology > Sensing and Signal Processing (1.00)
- Information Technology > Communications > Networks > Sensor Networks (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)