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Results
Abstract With increasing interest in non-metallic products for downhole applications, such as the fiberglass tubing, it is essential to ensure the well integrity in similar way as standard carbon steel completions. One important aspect of well integrity is the ability to routinely access the downhole condition of the tubing and perform basic intervention. This paper demonstrates the testing and validation of different mechanical evaluations of the integrity of fiberglass tubing using logging and intervention tools. In this work, two joints of Fiberglass were connected together in order to study the effect of logging and intervention tools on the integrity of these joints from inner and outer surfaces as well as the structural integrity. For inner wall evaluation, a multifinger caliper tool was run inside the two joints several times in order to investigate potential damage caused by the fingers. In addition, a tubing puncher was used to punch a hole and characterize the surface damage and any effects on the structural integrity of the fiberglass. Furthermore, a tubing cut was performed in order to confirm the performance of the cutting tool in such environment. All the tests were conducted safely and successfully at surface using two different sizes of fiberglass tubing. The tested tubulars were split cut to further investigate internal condition. The effect of applied fingertips on the inner wall surface of the fiberglass from several passes indicated minor scratches that can be further investigated using an accelerated wear test. The integrity of this non-metallic tubular can be evaluated using standard mechanical tools in order to identify defects and scale buildup. Other intervention tools such as the mechanical puncher and cutter indicated successful deployment under surface conditions. Investigation of existing downhole evaluation and intervention technologies can provide an immediate assessment of the benefits and limitations with respect to unconventional completions such as the fiberglass tubing and other non-metallic pipes. Future research and development programs can rely on such solid basis to tailor advanced solutions for any specific application or products.
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Well Completion > Completion Installation and Operations (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- (4 more...)
Restoration of High-Temperature Well Integrity via Real-Time Coiled Tubing Patch Application
Karpaya, Shaturrvetan (Petronas Carigali Sdn Bhd) | James Berok, Sylvia Mavis (Petronas Carigali Sdn Bhd) | John Peter, Brandon Joseph (Petronas Carigali Sdn Bhd) | Muchalis Utta, Arie (Petronas Carigali Sdn Bhd) | Barat, Junnyaruin (Petronas Carigali Sdn Bhd) | Ellen Lidwin, Sharon (Petronas Carigali Sdn Bhd) | Abdul Rahman, Hazrina (Petronas Carigali Sdn Bhd) | Maluan, Lilihani (Petronas Carigali Sdn Bhd) | Sidek, Sulaiman (Petronas Carigali Sdn Bhd) | Mustika Purwitaningtyas, Imania (Schlumberger) | Chin Pui Ling, Jennie (Schlumberger) | Albouy, Charles (Schlumberger)
Abstract A prolific gas producer in Sarawak waters was shut-in and idle due to a tubing leak resulting in a significant decline in the total hub production. The well remained idle and required immediate remedial action to meet the contractual sales target. Hence, an expandable tubing patch was proposed to isolate the leak and reactivate the well faster. This paper presents data gathered to identify leak location, tubing patch design, and installation using real-time coil tubing. Several logging surveys were performed to detect leak depth including caliper log, leak detection log (LDL), and downhole camera run; since no pressure build-up was observed post bleed-off tubing and casing, while SCSSV was in closed-state. Running caliper log could not indicate severe metal loss of 7-inch tubing, hypothesizing that the leak could be of a smaller dimension. Therefore, LDL was conducted, indicating temperature gradient and acoustic energy changes at a single depth location of 247 ft.THF, above SCSSV. Utilizing the leak depth marker from acoustic log, a downhole camera was staged to verify geometry of tubing leak. Root cause failure analysis (RCFA) was carried out for this tubing anomaly using diagnostics data to determine the possibility of UHP-17Cr-110 tubing failure. The likelihood of tubing failure is attributed to two main causes namely oxygen corrosion cracking and stress corrosion cracking. Based on RCFA outcome, Hastelloy C276, a nickel-molybdenum-chromium superalloy with the addition of tungsten was selected for the patch material, which is V0 rated, internal gas-tight qualification for temperatures up to 150 degrees Celsius and 5,000 psi. Moreover, this patch material satisfies the well conditions at approximately 20% CO2, 200 ppm H2S, 1000 mg/L salinity, and varying Hg concentrations from 800-2,000 ug/Nm3. The design of patch has been improved by adding AFLAS elastomer for the whole exterior of patch to eliminate contacts between the two metals: reducing the risk of galvanic corrosion. Real-time coiled tubing application was selected for setting the patch to ensure accurate depth-sensing control. Additionally, patch is a rig less intervention technique that will not disrupt the production from the existing wells sharing the same drilling platform. Generally, for high-rate gas wells, economic indicators seem lucrative with tubing patch application, where the payout can be achieved within a month of continuous production. The first step in ensuring the success of tubing patch is by running right diagnostics tools such as leak detection logging and downhole camera run, since multi-finger caliper analysis alone would not locate the leak depth and the leak geometry precisely. Valid design inputs are quintessential for the fitting recommendation of tubing patch design which includes accurate reservoir and fluid properties to ensure sustainability of the expandable tubing patch application.
- Asia > Middle East > UAE (0.28)
- North America > United States > Texas (0.28)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.34)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- (4 more...)
Abstract Well completions typically consist of multiple nested tubulars that provide the necessary well structure to ensure integrity for production and to protect the aquifers from contaminants. Monitoring the condition of multiple strings of tubulars is crucial in oil and gas wells and environmental management. For wells that had to drill through multiple pressure regimes, or with geomechanical and geology challenges, or those in highly corrosive environments, the number of well casings may exceed five pipes to provide better protection. Surveillance of pipe integrity in such wells is extremely challenging. A multifrequency electromagnetic pipe inspection tool with multiple transmitter and receiver arrays was designed to accurately estimate the individual wall thicknesses of multiple tubulars. In this paper, we present a workflow to process the measurements and demonstrate the performance of this tool to inspect the integrity of more than five nested pipes. The tool is based on electromagnetic eddy current principle and comprises multiple transmitting and receiving coil antennas with different spacings and operates in continuous-wave mode at multiple frequencies. To increase sensitivity to outer pipes, receiver coils are placed at larger spacings from the transmitter, and low frequency excitation is used. Feasibility studies show that the measurements are sensitive to the outer pipes beyond the fifth pipe, suggesting the possibility to inspect all nested pipes in one single logging run. An advanced data processing workflow including multi-zone calibration and model-based inversion is executed to estimate the tubulars electrical conductivity and magnetic permeability, wall thickness, and eccentricity. In the process of inversion, a regularization term is added to the cost function to obtain a more accurate solution based on the corrosion profile on the pipes as inferred from the data. The capabilities of the tool in wells with more than five pipes are demonstrated using synthetic data. The tests demonstrated accurate estimation of the location and severity of corrosion in each one of a multiple pipe configuration. This also reveals that the tool can detect various kinds of corrosion in wells with up to seven concurrent strings of pipes. This is the first time a corrosion inspection tool is shown to have the capability of estimating the individual thicknesses of well completions with more than five pipes. Such capability eliminates the necessity to pull the tubing and provides a complete picture on the integrity of the well casings. The information provided by this tool can significantly minimize inspection time and cost and improve the overall efficiency of well intervention operations.
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Production and Well Operations (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
High Resolution Solid State Acoustic Imaging for Advanced Well Integrity and Deformation Assessments in Conventional and Unconventional Wells
Littleford, Thomas (DarkVision Technologies Inc.) | Battistel, Anthony (DarkVision Technologies Inc.) | Simpson, Greer (DarkVision Technologies Inc.) | Wardynski, Kacper (DarkVision Technologies Inc.)
Abstract An advanced high-resolution acoustic imaging technology was deployed for well integrity and deformation assessments in both vertical and horizontal wells. This high frequency acoustic tool collected three-dimensional data quantifying deformation and wall thickness with resolution unobtainable by existing multi-finger caliper, magnetic flux leakage, and rotating single element ultrasonic systems. Several novel imaging methods are enabled by the high number of transducers (up to 512) on the imaging probe. These methods, including beam forming, beam steering and semi-stochastic multipulse imaging, are outlined and discussed in this paper. In addition, multiple types of standardized visualizations enabled by this high-resolution 3D data capture tool are introduced and examples of each are shown. Lab qualification and imagery generated by the high-resolution solid-state imaging technology, when applied to various precision machined geometric anomalies, are presented. In addition to lab validation results, several field studies are showcased including assessments of ovalized casing, complex downhole corrosion, and isolated minor pitting. Leak paths, splits, and damaged regions within threaded casing collars were also identified, imaged, and quantified using the acoustic technology. Until now, these collar regions have been very difficult to image using legacy downhole tools due to fundamental limitations at the threaded connection geometry. Lastly, various downhole completion equipment case studies are presented showcasing several applications of acoustic imaging used to validate the set-position or condition of specialty downhole equipment. This paper outlines the usage of the solid-state acoustic technology to generate three dimensional geometry and wall thickness datasets with sub-millimetric resolution, providing operators with a holistic and actionable assessment of their well integrity.
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Well Drilling > Casing and Cementing > Casing design (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Well Completion > Completion Selection and Design > Completion equipment (1.00)
- (5 more...)
Combination of New Acoustic and Electromagnetic Frequency Technologies Detects Leaks Behind Multiple Casings. Case History
Mata, Jose (Halliburton) | Guevara, Zunerge (Halliburton) | Quintero, Luis (Halliburton) | Vasquez, Carlos (Halliburton) | Trujillo, Hernando (Hocol S.A) | Muñoz, Alberto (Hocol S.A) | Falla, Jorge (Hocol S.A)
Abstract Although leakages in well tubulars have always existed, their occurrence has become very frequent as the number of active wells in mature fields increases. The catastrophic risk of these leaks is an increase in the number of environmental accidents in the oil and gas industry. One of the fundamental causes of leaks is corrosion, which plays a negative role in the productive life of the wells. Generally, these environmental events are associated with surface or near-surface sources. Since multiple casing strings exist within this depth range, the identification of the leak location becomes extremely difficult. In view of this, the industry has put much effort in improving and new technology to be more precise and comprehensive in diagnosing these leaks. The evolution of two of such technologies will be addressed in this paper. The first one is a new electromagnetic high-definition frequency tool for pipes and multiples casing for metal loss detection. This state-of-the-art technology is a noticeable improvement over existing tools, due to an important increase in the number of sources, number of detectors and wide range of working frequencies. The combination of these changes allows for the evaluation of metal loss in up to 5 concentric casings in a single run. Furthermore, the tool is small in diameter which makes it compatible with production pipes without the need of a workover rig. This versatility obviously helps in the preworkover diagnosis before deciding to move a rig to location to eventually remedy any leak problems. The electromagnetic technology is complemented, with the latest leak detection acoustic technology. A spontaneous audio source is normally associated with downhole fluid movements. The tool has an array of 8 hydrophones with a working frequency range from 100 Hz to 100 KHz. These two different technologies based on independent fundamental principles, allows for the detection of leaks in multiple concentric pipes with great vertical and radial precision to identify the exact location of leaks as small as to 0.02 L/min. the depth of investigation of the system is up to 10 feet. Therefore, it is possible to detect fluid movement within the formation. Pulsed neutron technology was included in the study to detect water movement behind the casing to establish the flow path to the surface in addition to the leak point. A very complex acquisition program was established that was undoubtedly a key success factor in the results obtained. The electromagnetic tool determined the depth of severe casing metal loss in 7-inch casing, also the acoustic tool detected the noise of fluid movement in the 7-inch annulus, and the pulsed-neutron tool showed the beginning of water movement at the same interval the temperature log, also included in the same tool string showed a considerable change that correlated with all these logs, indicating the point of communication in this well. After establishing the uniqueness of the solution, this diagnosis helped the operator define an intervention plan for this well, and to make the appropriate corrections in the field development strategy.
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Management > Asset and Portfolio Management (1.00)
- (3 more...)
Development and Testing of a Wireline-Deployed Positive-Displacement Pump for Late-Life Wells
Romer, Michael Christopher (ExxonMobil Upstream Research Company) | Spiecker, Matt (ExxonMobil Upstream Research Company) | Hall, Tim James (ExxonMobil Upstream Research Company) | Dieudonne, Raphaël (Hydro Leduc) | Porel, François (Hydro Leduc) | Jerzak, Laurent (Hydro Leduc) | Ortiz, Santos Daniel (KSWC Engineering & Machining) | King, George Randall (KSWC Engineering & Machining) | Gohil, Kartikkumar Jaysingbhai (KSWC Engineering & Machining) | Tapie, William (Deteq Services) | Peters, Michael (MTI) | Curkan, Brandon Alexander (C-FER Technologies)
Summary What do you do after plunger lifting? What if lift gas is not readily available or your liquid level is around a bend? What can you do with a well that has low reservoir pressure, liquid-loading trouble, and fragile economics? Do you give up on the remaining reserves and advance to plugging and abandonment? These questions were considered, and the answers were found to be unsatisfactory. This paper will describe the development and testing of a novel wireline-deployed positive-displacement pump (WLPDP) that was invented to address these challenges. Artificial-lift (AL) pumps have historically been developed with high-producing oil wells in mind. Pumps for late-life wells have mostly been repurposed from these applications and optimized for reduced liquids production. The WLPDP development began with the constraints of late-life wells with the goal of addressing reserves that conventional AL methods would struggle to produce profitably. Internal and industry-wide data were first reviewed to determine what WLPDP specifications would address the majority of late-life wells. The primary target was gas wells, although “stripper” oil wells were also considered. The resulting goal was a pump that could deliver 30 BFPD from 10,000-ft true vertical depth (TVD). The pumping system must be cost-effective to be a viable solution, which led to several design boundaries. Pumps fail and replacement costs can drive economics, so the system must be deployable/retrievable through tubing. The majority of new onshore wells have tortuous geometries, so the system must be able to function at the desired depth despite them—without damaging associated downhole components. The system should use as many off-the-shelf components and known technologies as possible to reduce development costs and encourage integration. Finally, the pump should be able to handle a variety of wellbore liquids, produced gases, and limited solids. The WLPDP was designed to meet the established specifications and boundary conditions. The 2.25-in.-outer-diameter (OD) pump is deployed through tubing. and powered with a standard wireline (WL) logging cable. The cable powers a direct-current (DC) motor that drives an axial piston pump. The piston pump circulates a dielectric oil between two bladders by means of a switching valve. When each bladder expands, it pressurizes inlet-wellbore liquids, pushing them out of the well. Produced gas flows in the annulus between the tubing and production casing. The intake/discharge check valves and bladders are the only internal pump components that contact the wellbore fluids. The WLPDP system was able to meet the design-volume/pressure specifications in all orientations, as confirmed through laboratory and integration testing. Targeted studies were conducted to verify/improve check-valve reliability, gas handling, elastomer suitability, and cable-corrosion resistance. The results of these and related studies will be discussed in the paper.
- North America > United States > Texas (1.00)
- Asia > Middle East (1.00)
- Europe (0.67)
- North America > Canada > Alberta (0.67)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (28 more...)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Well Completion > Completion Installation and Operations (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- (8 more...)
An Integrated Geomechanics and Corrosion Assessment Approach to Analyze Tubular Degradation in Brownfield X
Sajjad, Farasdaq Muchibbus (PT Pertamina Hulu Energi) | Wirawan, Alvin (PT Pertamina Hulu Energi) | Chandra, Steven (Institut Teknologi Bandung) | Ompusunggu, Janico Zaferson (PT Pertamina Hulu Energi) | Prawesti, Annisa (PT Pertamina Hulu Energi) | Suganda, Wingky (PT Pertamina Hulu Energi) | Muksin, M. Gemareksha (PT Pertamina Hulu Energi) | Amrizal, Amrizal (PT Pertamina Hulu Energi)
Abstract Tubular engineering design is essential for production operation, especially in the mature oil and gas fields. The complex interaction among oil, natural gas, and water, complemented with wax, scale, inorganic compound, and deformation brings complexity in analyzing tubular integrity. This challenging problem will be more severe if the wells are located in offshore environment, therefore finding the cause of tubing deterioration is a challenging. Field X, which has been in production for 30 years, cannot avoid the possibility of tubular thinning and deformation. The degradation is slowly developed until severe alterations are observed on the tubing body. The current state of the wells is complicated since the deformation inhibits the fluid flow and increases the risk of wellbore collapse and complications during sidetracking, infill drilling, workover, and other production enhancement measures. The risks can be harmful in the long run if not mitigated properly. The current condition encourages us to conduct more comprehensive study on tubular degradation. It is to model the multiple degradation mechanisms, such as corrosion, scaling, and subsidence, under the flowing formation fluid. The model is then coupled with reservoir simulation in order to provide a better outlook on tubular degradation. We used multiple case studies with actual field data to identify the dominant mechanism on tubular degradation. The case study cover various reservoir and fluid characteristics and also operations problems to develop general equation and matrix for risk analysis and field development considerations. We present the degree of tubular degradation and its effect to overall field performance and economics. Current field practices do not encourage a thorough tubular assessment during early life of the wells, which create complex problem at later stage. The study indicates that a proper planning and preventive action should be performed gradually before tubular degradation becomes severe. The paper presents a field experience-based model and guideline matrix that is useful in developing new areas from the perspective of well and facilities integrity, so that the degradation-related issues could be recognized earlier.
- Asia > Indonesia (0.29)
- Asia > Middle East (0.28)
- North America > United States > Texas > Coleman County (0.24)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- (8 more...)
Abstract A state-of-the-art time-domain electromagnetic tool is presented that is capable of quantifying four barriers individually, and inspecting a fifth barrier qualitatively. The working physics and salient features of the tool and its underlying technology are described. The new tool uses time-domain electromagnetic (TEM) or pulsed eddy current (PEC) technology, which has set the benchmark for individual quantitative tubular corrosion evaluation in multi-annular well systems (multiple concentric tubulars) in recent years. Time-domain electromagnetic tools widely used in the industry are currently capable of quantifying the individual metal thickness/loss in up to three barriers. The new tool employs three highly sensitive sensors to provide high-resolution analysis of the inner barrier, while providing sufficient radial depth of investigation for up to five barriers. The above features and advantages of the new tool are supported by modeling and fixture test results. Additional modeling is shown to compare and contrast the resolution and radial depth of investigation of the three sensors. Case studies from actual wells are also presented that illustrate how three sensors enhance the performance of this technology. Corrosion evaluation of multi-barrier systems is a major component of well integrity management because it can provide timely and cost-effective information for planning well repairs if needed. The ability of the new tool to inspect more barriers is important because it gives the operator better information for more proactive well integrity management. The novelty of the tool is in its ability to exploit the information-rich wideband pulsed excitation using three sensors that enhance the sensitivity to multiple barriers.
- Geophysics > Electromagnetic Surveying (1.00)
- Geophysics > Borehole Geophysics (0.93)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
- (2 more...)
Abstract A multi-frequency electromagnetic pipe inspection tool with multiple transmitter and receiver arrays was designed to accurately estimate the individual wall thicknesses of as many as five nested pipes. The new tool enables monitoring well casing integrity without having to pull out production tubings, therefore minimizing inspection time and cost. This paper demonstrates the performance of the tool using yard mockups with known defects. The principle of tool operation and the methodology for data processing are also detailed in the paper. The tool relies on eddy current principle in its operation. It comprises two sections of transmitting and receiving coil antennas and operates in continuous-wave mode at multiple frequencies. The configuration of strategic transmitter-receiver spacing and multi-frequency operation delivers a suitable range of information to evaluate individual pipes for the majority of well configurations. An advanced inversion-based data processing workflow is executed to estimate pipe parameters, including electrical conductivity and magnetic permeability, wall thickness, and eccentricity. The proficiencies of the technology are confirmed by performing yard tests with two long test mockups. Each mockup has multiple combinations of overlapping and non-overlapping man-made defects distributed along sections consisting of three, four, and five nested pipes, which mimic typical corrosion progression. The measurement data from the mockups are validated against synthetic data generated from a 2D electromagnetic forward solver. Then, a procedure including pipe material property estimation, calibration, and inversion algorithms is performed to retrieve pipe thickness. Results from the yard tests reveal that this tool is fully capable of detecting various kinds of corrosions concurrently across five strings of pipes, even on the outer pipes with high severity. The impact of pipe eccentricity on the accuracy of thickness estimation is also shown by deliberately decentralizing the innermost pipe over a length of the testing setup. The information provided by this tool can improve the efficiency of well intervention operations, especially in areas with high-corrosion rates, and could result in significant cost savings to the operator.
- Well Drilling > Casing and Cementing (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- (3 more...)
Looking at the Bigger Picture - Better Understanding of Well Behavior through Integration of Petrophysical, Production Logging and Corrosion Evaluation Data in a Challenging Environment, Ensuring Maximum Well Life and Overall Productivity
Chitre, Sunil (ADNOC Offshore) | Mustafa, Hammad (ADNOC Offshore) | Anurag, Atul Kumar (ADNOC Offshore) | Bazuhair, Ahmed Khalid (ADNOC Offshore) | Kuliyev, Myrat (ADNOC HQ) | Javid, Khalid (ADNOC Offshore) | Anjum, Usman (Schlumberger) | Sookram, Neil (Schlumberger) | AlHaji, Latifa (Schlumberger) | Al-Kindi, Zaid (Schlumberger) | Afeefi, Baraka Said (Schlumberger) | Jabour, George (Schlumberger)
Abstract This paper describes optimal field development and appraisal in complex reservoirs and challenging environments in field ‘ABC’. Most of the wells are laterals with ICD (lower) completions across heterogeneous carbonate reservoirs. Highly corrosive environments i.e. up to 20% H2S present an added risk, particularly in the event of water encroachment. Optimal development needs a multi-disciplinary surveillance approach involving an integration of input form stakeholders, including geoscience and petroleum engineering, to ensure productivity optimization during the whole life of the field. Field ABC is an offshore field with extremely heterogeneous carbonate reservoirs and acid stimulation is usually done to improve production. The wells in the field are mostly horizontal, oil producers with ICD lower completions. The upper completion uses carbon steel L80 and for corrosion mitigation, inhibitors are injected through chemical injection valves. In this paper, a pilot well is reviewed where a methodical approach was used for evaluation. Baseline production logging and reservoir saturation monitoring were done in the lower completion and a corrosion log was acquired in both the upper and lower completions. Data acquired was integrated and observations show that the measurements correlate well with each other. This case study integrates and correlates downhole zonal contribution, phase holdups, pressure and temperature data from production logging with metal loss data from a high-resolution multi-finger caliper tool. Well trajectory shows a depression across the heel of the well which is incidentally between the EOT and the topmost ICD. Although there is no water production at surface, a static water sump is observed across this depression on the production logs. This static water is possibly completion fluid or unremoved fluid from the acid job. Minor localized corrosion is also observed across the same depression on the corrosion logs, also confirming presence of some water. The H2S production and the presence of water is an added risk to completion integrity as it creates a corrosive environment. Therefore, in such cases it will be necessary to monitor the production and corrosion at regular intervals of time. This case study shows that by applying a multi-disciplinary approach and integrating various measurements, well conditions can be viewed not just as pieces of a puzzle but as a complete picture to improve the understanding of the well behavior. Time-lapse monitoring of production and corrosion along with reservoir saturation is also necessary to prevent surprises and help in making informed decisions towards better field development.
- Geology > Sedimentary Geology > Depositional Environment (0.46)
- Geology > Rock Type > Sedimentary Rock (0.46)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Well Completion > Completion Selection and Design > Completion equipment (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- (3 more...)