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Results
Advanced Well Integrity Assessment by Using the New Generation of Acoustic Analysis Tool, Multifrequency Electromagnetic Tool and Pulsed-Neutron Log in Oxygen Activation Mode: Colombia Case History
Reyes, Johana (Halliburton) | Mata, Jose (Halliburton) | Méndez, Osmary (Halliburton) | Guevara, Zunerge (Halliburton) | Falla, Jorge (Hocol S.A) | Muños, Alberto (Hocol S.A) | Trujillo, Hernando (Hocol S.A)
ABSTRACT Well integrity logs are fundamental for the optimization of production of wells, and to mitigate risks of environmental disasters. The information obtained helps identify potential problems and design correct remediation plans when encountered. This paper presents an actual example from Colombia, that demonstrates how the well integrity log data was used as input for the operator to decide future operations in a producing well that was presenting a leakage at surface. This leak could eventually lead to serious environmental issues. Two wells were analyzed to understand the issue, the first was an injector well which was suspected to have the leakage, and the second was the nearby producing well, which was showing the unexpected water production at surface which was analyzed and determined that it was coming from the injector well. The injector well was completed with 9.625inch surface casing, 7inch production casing and 3.5inch tubing. The entire well was logged in a rigless scenario with the multifrequency electromagnetic tool to determine metal loss across all strings and complemented with temperature logs. Additional diagnostics were performed opening the annulus space to stimulate the leak while running the acoustic noise tool upward. Stationary measurements were done to confirm areas where leaks were identified. In the subsequent run, a pulsed-neutron log in oxygen activation mode was logged with the annulus open to identify the water movement direction. After logging the injector well, the producer well was analyzed by using multifrequency electromagnetic and temperature log for a proactive corrosion monitoring and better define completion integrity. The integration of these three different technologies clearly indicated the location of the leak in the production casing. More precisely the vertical and radial position was determined using the acoustic and multifrequency electromagnetic tools. This analysis increased the chance of success for a safer operation after a well intervention program.
- South America > Colombia (0.86)
- Asia > Middle East > UAE (0.28)
- Well Completion > Well Integrity (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- (3 more...)
- Information Technology > Sensing and Signal Processing (0.70)
- Information Technology > Architecture > Real Time Systems (0.47)
Super Wells: Disruptive Proposal for Well Production Beyond the Established Fixed Limits (Erosional / Corrosive Limits) Case Study in High Potential Wells in Abu Dhabi Field.
Almarzooqi, Laila Sayed (ADNOC OFFSHORE) | Alqemzi, Meera (ADNOC OFFSHORE) | Cremades, Pablo (ADNOC OFFSHORE) | Lopez, Juan Enrique (ADNOC OFFSHORE) | Palacios, Carlos (CEPSA)
Abstract Early in oil field development, it is possible to discover high-potential wells that allow "thinking outside the box." However, in adverse scenarios (presence of H2S and appearance of asphaltenes), the limits appear to be very conservative. Two of these untouchable limits are the erosive and corrosive limits of fluid velocity. In particular, the use of API 14E RP based models is very conservative because it must be used safely in a wide range of applications in producing and injection wells around the world. Even commercial Nodal Analysis ® suites for their default erosion calculations take the dimensionless C factor = 100 as a reference. The objective of this work is to show a case study in which it is determined the feasibility and theoretical limits of increase production mean model the detrimental effect of erosion and corrosion to take advantage the potential of oil-producing wells with a high productivity index (higher than 8 bpd/psi) to safely optimize your production (greater than 5,000 bpd) with low risk of erosion or corrosion over a 5-year horizon under specific conditions. Alternative models were based on conservative values of 15 ft/s as the upper erosive limit (Zheng et al. at 2000) and 5 mpy (NACE SP0775) as the upper corrosive limit. Iterations of factor C were carried out up to 125 that allowed increasing the production rate of high potential wells above 5000 bpd. This study allowed to determine a list of candidate wells for a second analysis. This second study was more detailed and was based on an extended model (erosion/corrosion) developed by the University of Tulsa and confirmed that these wells could produce more than 5000 bpd over a period of up to 10 years with very low risk of failure due to erosion or corrosion failures. From 40 wells of the field evaluated, it was found that of the 12 wells with high potential, 9 wells were found to be viable to produce up to 6000 bpd during the first stage (C factor up to 125). In the second stage of the process the study concluded that it was feasible to increase the production of the 9 wells even up to 7000 bpd without causing significant risks of erosion or corrosion if the water cut was kept below 10%. Field short test was carried out in three (3) wells with satisfactory results. The application, for limited periods of time, of alternative models that allow the optimization of production of wells with high potential during the early development of large oil fields is possible. If the water cut, and solids production values remain low (water cut less than 10% and solids production less than 0.1 kg/1000 bpd and particle size between 20-50 microns).
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.50)
- Asia > Middle East > Kuwait > Jahra Governorate (0.40)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Satah Al-Razboot SARB Field > Arab Formation (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Abu Dhabi Field (0.99)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- (5 more...)
- Information Technology > Sensing and Signal Processing (0.93)
- Information Technology > Architecture > Real Time Systems (0.46)
- Information Technology > Communications > Networks (0.46)
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)
- (11 more...)
- 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)
- (16 more...)
- 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 Producers find a considerable amount of their operating expense (OPEX) comes from managing risks associated with corrosion and scale. Monitoring and chemical adjustment workflows are typically manual, and performed at low frequencies, leading to delays in event detection. As a result, the potential for negative events such as production shutdowns and well failures increase. This project's scope integrates chemistry domain experience with edge analytics, machine learning models, and intelligent equipment, to transform manual processes into an autonomous solution. The goal is to optimize operations, reduce well failures and workover costs, and maximize production. This solution is currently deployed in an oilfield, that has been historically challenged with a high number of electric submersible pump (ESP) failures due to corrosion and scale that resulted in significant production losses and unforeseen workover costs. The designed digital architecture supports autonomous management of scale and corrosion through remote monitoring and automated chemical injection. Real-time data is acquired from connected equipment, processed in an edge device running artificial intelligence, and autonomously sent to chemical pumps. Data from sensors, connected devices, and models are visualized in cloud applications, or integrated into existing client systems for end user analysis and full visibility of the entire process. The results show highly accurate models, precise chemical injection, and a reduction of well failures.
- Asia > Middle East (0.94)
- North America > United States > Texas (0.68)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Maverick Basin > Eagle Ford Shale Formation (0.99)
- Asia > Middle East > Bahrain > Awali Field (0.99)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- (4 more...)
- Information Technology > Sensing and Signal Processing (1.00)
- Information Technology > Artificial Intelligence (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
- Information Technology > Communications > Networks > Sensor Networks (0.48)
Abstract Challenges in the design of efficient EOR field pilots have been discussed and documented in the industry, particularly when it comes to optimization of monitoring plans for technical and economical perspectives. This paper explores the benefits of pilot planning where the monitoring/control strategies are included in the early stages of the design to reduce risk of measurements ambiguity and ensure good quality pilot results evaluation. It addresses the use of new and existing technology in monitoring by highlighting the advantages and challenges of each alternative including potential pairing of complementary options to achieve the pilot objectives including illustration of the use of continuous and sporadic measurements on the evaluation. The proposed approach starts with a review of reservoir performance, heterogeneity and pilot objectives to ascertain the plausible monitoring technologies/strategies to aid during the pilot de-risking, followed by the identification of adequate novel and mature monitoring options, which are specific to EOR type and measurement nature (permanent, time lapse, etc.). Advantages of incorporating the monitoring strategy as integral part of the pilot design, as well as evaluation of the effectiveness/viability in the presence of uncertainty of the selected monitoring alternatives are discussed providing a reference of suitable/plausible EOR specific technologies. The paper illustrates the importance of selecting monitoring alternatives that feed off each other and the importance of using fit-for-purpose evaluation algorithms and a digitally enabled, structured approach to analyze and democratize pilot results and enable actionable decisions in operations.
- North America > United States (0.68)
- Europe > United Kingdom > North Sea > Central North Sea (0.24)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.15)
- Geology > Geological Subdiscipline > Geomechanics (0.68)
- Geology > Rock Type > Sedimentary Rock (0.46)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Time-Lapse Surveying > Time-Lapse Seismic Surveying (0.69)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.46)
- North America > United States > Texas > Permian Basin > Cogdell Field > Fuller Sand Formation (0.98)
- North America > United States > Texas > Permian Basin > Cogdell Field > Area Formation (0.98)
- Well Completion > Completion Monitoring Systems/Intelligent Wells (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (20 more...)
- Information Technology > Sensing and Signal Processing (0.93)
- Information Technology > Architecture > Real Time Systems (0.68)
- Information Technology > Communications > Networks (0.46)
- Information Technology > Artificial Intelligence > Representation & Reasoning > Uncertainty (0.34)
Abstract In a deviated well in Caspian Sea gas oil ratio (GOR) increased rapidly in 2017. The result was an oil rate decline with several choke backs to manage GOR build-up. After performing two production-logging jobs, it was confirm that 76% of the gas production was coming from four upper perforations. The main objective was to perform a Gas Shut off (GSO) treatment in two stages to reduce gas production by squeezing polymer into the formation and setting packers at 59° deviation inside 9-5/8 in. casing for temporarily isolation of middle and lower production sands. Fifteen runs were perform with a tube wire-enabled CT telemetry (CTT) system which consists of a customized bottomhole assembly (BHA) that instantaneously transmits differential pressure, temperature, depth data to surface through a non-intrusive tube wire installed inside the CT. For the first time in the region, a tension, compression and torque (TCT) sub-assembly was deploy to control the entire set/retrieve process with accurate downhole upward/downward forces. CTT technology was a key element to successfully set two Thru Tubing Inflatable Retrievable Packers (TTIRP) by doing casing collar locator (CCL) correlations at tubing end which was 133 m and 228 m (MD) shallower from setting depths. In addition, during second GSO operation, polymer crosslink time was modify based on actual bottomhole temperature recorded with CTT system. Finally, during third GSO treatment placement was improve spotting more GSO system in casing section avoiding further treatments. After successful placement of the GSO system, a drop from 15.5 to 4.5 MMscf/day in gas production was observed along with GOR reduction from 11,000 to 750 MMscf/bbl and oil rate increment from 1.4 to 6.04 Mbpd. Furthermore, after gas reduction operator was able to produce between 1.5 to 2.0 Mbpd from other wells that were choke back based on gas handling capabilities limitations The novelty of using the CTT system and TCT sub-assembly for real-time monitoring of BHA data was proven for not only positioning two TTIRP, modifying polymers crosslink design, placing polymer precisely across target intervals and retrieve two TTIRP that at the end provide direct and positive financial impact for the operator.
- North America > United States > Texas (0.69)
- Asia > Middle East (0.68)
- Well Drilling (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 (0.68)
A major challenge of Arabian heavy‑oil development is the problem of generating competitive advantages through deploying technological innovations while making cost-effective solutions a crucial part of a firm's strategy for rigless interventions. The purpose of this paper is to examine coiled-tubing (CT) -stimulation and -logging technologies used in the timely project execution of one of Saudi Arabia's largest field developments to enhance matrix-stimulation success in a cost-effective manner. The Manifa field is located in Saudi Arabia and measures approximately 45 km in length and 18 km in width, encompassing both onshore and offshore areas with water depths between 4 and 6 m. It was discovered in 1957, with first sustained production in 1964. However, because of low demand, the field was shut down in 1984.
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Installation and Operations (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- (6 more...)
- Information Technology > Architecture > Real Time Systems (0.74)
- Information Technology > Sensing and Signal Processing (0.48)