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Collaborating Authors
Results
Positive Impact of V0 Multi-Stage Cementing Tool on the Long Term Well Integrity
Hussain, M. Q. (ADNOC Onshore) | ALRashdi, A. A. (ADNOC Onshore) | ELMahdy, M. M. (ADNOC Onshore) | Mwansa, P. L. (ADNOC Onshore) | Amorocho, A. (ADNOC Onshore) | Ibrahim, A. M. (ADNOC Onshore) | Naga, H. (Weatherford) | Kaddoura, I. (Weatherford)
Abstract Weak formations which require isolation from elevated hydrostatic pressures during cementing operations have always been a challenge in the oil and gas industry. This paper will discuss the impact of deploying V0 Multi-Stage Cementing tool in terms of cement quality, well integrity and cost optimization. The losses experienced throughout the extended 9-5/8" casing strings resulted in reduction of the cement quality exposing the full well integrity to higher risks. Meetings have been held between engineering, material, production optimization and operation teams to evaluate the current performance and identify methods for improvement. V0 Multistage cementing tool was introduced as a unique solution which would assure reaching expected well integrity, overcoming hydrostatic pressure challenges, and eliminating risks of poor cement quality in the corrosive environment gas well applications. V0 Multistage cement tool has been successfully deployed for cases where elevated hydrostatic pressure was considered an issue, showing success in providing the required cement quality. Alternative methods to provide similar quality would be Liner hanger system followed by a tie back which would involve more associated cost, rig time and equipment. Wells with high differential pressures due to fluid losses have been successfully resolved avoiding risks of performing single stage cementing, compromising zonal integrity of weaker formations and poor cement quality. Qualified V0 Multistage cementing tool as per (ISO) 14310 V0 standard has been deployed, where gas-tight mechanical packer has enabled more reliable multistage cementing jobs for deep gas applications which ensured consistent and reliable gas-tight well integrity. V0 Multistage tool was considered an economical solution reducing the cost by 70% compared to alternative solutions, reducing average of 3 rig days. The paper will introduce the optimum economic solution for recurrent cementing challenges in both onshore and offshore operations. Utilizing latest technologies to retain wellbore integrity, eliminate unnecessary costs and reduce rig time.
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- Well Completion > Well Integrity > Zonal isolation (1.00)
A Holistic Approach to Achieve Zonal Isolation Improvements Across 8 1 2 Inch Hole on the in an Offshore Field
Hassan, Azza El (Drilling, ADNOC, Abu Dhabi, UAE) | Abdelatif, Mohamed Samir (Drilling, ADNOC, Abu Dhabi, UAE) | Hamidzada, Ahmedagha (Drilling, ADNOC, Abu Dhabi, UAE) | Andrews, Kerron (Drilling, ADNOC, Abu Dhabi, UAE) | Toki, Takahiro (Drilling, ADNOC, Abu Dhabi, UAE)
Abstract In an Offshore field, off the coast of Abu Dhabi, well integrity objectives are becoming more difficult to achieve as open hole sections become deeper, laterally longer and more highly deviated. In this mature field, one of the main challenges of well construction is successfully cementing long production-casing strings covering multiple reservoirs across the 8½-in sections. This paper describes some of the techniques and best practices that were applied on these wells to achieve the required zonal isolation. Achieving zonal isolation across multiple reservoirs through a single or multi-lateral configuration is a major challenge in this field. The reservoir formation is porous and requires a special gas tight design or impermeable cement system. Inadequate hole cleaning due to poor standoff attributed to complex well design is another main limitation, resulting in insufficient mud removal leading to an uneven cement distribution around the casing. Additionally multiple pressure-testing cycles are required post cement-setting and during the completion phase, a practice that can destabilize the cement system causing it to fail. Moreover, controlling loss circulation while running or after landing casing is another challenge in this field. To overcome these challenges a series of customized improvements were applied subsequently through continuous improvement and implementing lessons learnt from previous operations. The elements of this approach included introducing higher density cement systems to cover the horizontal sections, while retaining the ECD within the required margins. Another element utilized was that of two cement slurries; Lead and tail, which were designed to achieve controlled ECD. An additional element which was also implemented addressed enhancing the flexible expandable gas tight slurry by adding Latex to achieve a fit for purpose solution. The last element of this strategy included improving hole cleaning and mud removal efficiency by optimizing spacer design and volumes in addition to the loss circulation additives in the spacer systems. Throughout the operation, the cement jobs were executed successfully with no losses. Cement jobs were evaluated through running job design simulation Vs execution parameters comparison. The approach resulted in substantial improvement on log responses. Additionally, after implementing the approach, logs were compared to offset wells from the same field to track the improvement done. The paper reviews enhanced practices implemented to overcome challenges faced during well cementing. Being able to find a solution to this complex problem, delivering a comprehensive cement quality, and improving cementing integrity on these wells resulted in expanding this approach to the rest of the fields. The improvement measures that were developed are now being adopted across all jobs to yield a similar outcome.
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- (3 more...)
Improving Zonal Isolation and Cutting the Water Production with the Help of an Engineered Self-Healing Cementing System: A Case Study Review of the First Implementation of its Kind in Kuwait
Al-Khayyat, Bader (Kuwait Oil Company) | Al-Mudhaf, Meshari (Kuwait Oil Company) | Saffar, Ali Hussein (Kuwait Oil Company) | Mitra, Tarasankar (Kuwait Oil Company) | Monteiro, Ken (Kuwait Oil Company) | Al-Safran, Sarah (Kuwait Oil Company) | Gholoum, Saleh (Kuwait Oil Company) | Al-Khaja, Mohamed (Kuwait Oil Company) | Ali, Jasim (Kuwait Oil Company) | Al-Rashed, Fatemah (Kuwait Oil Company) | Alotaibi, Mohammad (Kuwait Oil Company) | Almunayes, Fahad (Kuwait Oil Company)
Abstract In one of the prolific fields in Kuwait, achieving zonal isolation posed a big challenge mainly due to setting the production liner shoe close to the oil-water-contact zone. Cement bond logs from the primary cementing jobs were not acceptable due to contamination from intruding water leading to a high water-cut in the produced oil. We review the first implementation of a self-sealing Cementing System in Kuwait to improve zonal isolation and cutting the water production. A comprehensive pre-job study was executed to engineer a suitable cementing system containing a swellable elastomer for oil-water-cuts with proper test in Lab. A novel HPHT multi-function test cell apparatus and procedure were utilized to measure in-situ ability of fractured cement specimens to seal oil-water-flows under the given simulated downhole conditions. Shrinkage or expansion of the set cement was also verified under pressure and temperature with a continuous test method run over several days. Thorough lab tests and Computational Fluid Dynamics simulations were run to enable a fit-for-purpose and robust cement slurry design ensuring proper placement of the cementing system in the well. This paper will describe how this cement was designed and engineered in laboratory. It will also describe how the set up was made simulating a crack in cement specimen and injecting water cut oil reacts and provides desired results. A calculated cement engineering approach was adopted to ensure better cement slurry placement and reduce the chances of slurry contamination. The test conditions were staged to replicate the most appropriate downhole conditions of pressure, temperature and simulated micro channel in the cement sheath. After the successful implementation of the self-sealing cementing system along the 7-in production liner in 2 wells, the corresponding cement bond log images showed hydraulic isolation and the production data from the wells indicated a reduction of nearly 50% in the water cut thus allowing a favorable oil production. This technology is applied in other wells of this field and other fields also with good results. This is being continued to use in critical wells.
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- Well Drilling > Casing and Cementing > Cement and bond evaluation (1.00)
- Well Completion > Well Integrity > Zonal isolation (1.00)
- (2 more...)
Delivering Zonal Isolation between Reservoir Sublayers in Long, Horizontal 12 ¼-in. Hole Sections in Extended Reach Wells
Elhassan, Azza (ADNOC Offshore) | Hamidzada, Ahmedagha Eldaniz (ADNOC Offshore) | Takahiro, Toki (ADNOC Offshore) | Motohiro, Toma (ADNOC Offshore) | Orfali, Mohd Waheed (Schlumberger) | Phyoe, Thein Zaw (Schlumberger) | Salazar, Jose (Schlumberger) | Alaleeli, Ahmed Rashed (ADNOC Offshore)
Abstract Good cementing practices are required to achieve effective zonal isolation and provide long-term well integrity for uninterrupted safe production and subsequent abandonment. Zonal isolation can be attained by paying close attention to optimizing the drilling parameters, hole cleaning, fluid design, cement placement, and monitoring. In challenging extended reach wells in the UAE, different methods were employed to deliver progressive improvement in zonal isolation. Cementing the intermediate and production sections in the UAE field is challenging because of the highly deviated, long, open holes; use of nonaqueous fluids (NAFs); and the persistent problem of lost circulation. Compounding the problem are the multiple potential reservoirs; the pressure testing of the casing at high pressures after cement is set; and the change in downhole pressures and temperatures during production phases, which results in additional stresses. Hence, the mechanical properties for cement systems must be customized to withstand the downhole stresses. The requirement of spacer fluids with nonaqueous compatible properties adds complexity. Lessons learned from prior operations were applied sequentially to produce fit-for-purpose solutions in the UAE field. Standard cement practices were taken as a starting point, and subsequent changes were introduced to overcome specific challenges. These challenges included deeper 12 ¼-in. sections, which made it difficult to manage equivalent circulating densities (ECDs), and a stricter requirement of zonal isolation across sublayers in addition to required top of cement at surface. To satisfy these requirements, several measures were taken gradually: applying engineered trimodal blend systems to remain under ECD limits; pumping a lower-viscosity fluid ahead of the spacer; using NAF-compatible spacers for effective mud removal; employing flexible cement systems to withstand downhole stresses; and modeling the cement job with an advanced cement placement software to simulate displacement rates, bottomhole circulating temperatures, centralizer placement, mud removal and comply with a zero discharge policy that restricts the extra slurry volume to reach surface. To enhance conventional chemistry-based mud cleaning, an engineered scrubbing additive was included in the spacers with a microemulsion-based surfactant. The results of cement jobs were analyzed by playback in advanced evaluation software to verify the efficiency of the applied solutions. This continuous improvement response to changes in well design has resulted in a significant positive change in cement bond logs; a flexural attenuation measurement tool has been used to evaluate the lightweight slurry quality behind the casing, which has helped in enhancing the confidence level in well integrity in these challenging wells. The results highlight the benefit of developing engineering solutions that can be adapted to respond to radical changes in conditions or requirements.
- North America > United States (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.16)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- (2 more...)
Abstract Loss circulation is encountered frequently while drilling fractured carbonate reservoirs in specific field. The field practice was attempting to cure losses and if incurable, drill blind to total depth (TD) followed by run and cementing of the liner. The interval from loss zone to liner top was covered by the cement squeezed from liner top. The require time to try to cure the lost circulation zone plus squeezing cement job was approximately 15 days. Several optimization initiatives were implemented to reduce this time to less than seven days. There were at least eight round trips carried out in different ways by different operators to complete the operation of attempting to cure the losses and a liner top squeeze. The engineering team evaluated this for potential optimization, first to identify whether or not losses need to be attempted to be cured to save the time lost on unsuccessful attempts. Second, to analyze the lessons learnt and build on that optimization strategy to reduce the number of trips Lastly to rework the cement slurry design to reduce the number of attempts to squeeze liner top. As such a detailed strategy was formulated regarding when and how to cure losses followed by an optimized procedure for liner top squeeze which saves three round trips. Further, the liner top squeeze operations previously took multiple attempts of squeeze before a successful pressure test was achieved. Based on the lessons learnt, the slurry design was optimized from several aspects including, slurry density, rheology, thickening time and the pumping and displacement procedure was created which helped to reduce the number attempts from six to only one. Another optimization implemented was enabling the loggers perform pressure pass for cement evaluation by the utilization of tractor instead of conventional (Tough Logging Conditions) TLC which not only saved time but also depicted better the condition of cement behind liner. Finally, a robust risk assessment encompassing all possible contingencies for expected issues was incorporated. The optimized liner top squeeze strategy has been implemented at five wells with 100% success, reducing the overall operation time from more than two weeks to less than one week while improving cement quality behind liner to ensure zonal isolation as per requirements. This paper provides details of how the cement slurry, operations sequence and tools selection were enhanced well by well based on continuous improvement. Since cementing liners across loss circulation intervals exists in most of the carbonate reservoirs worldwide, this paper will help to achieve better zonal isolation in losses environment with lower cost and lesser time.
Successful cement placement in horizontal wellbores requires solutions for several technical challenges. Zonal isolation provided by cement is considered an important factor for efficient stimulation. A cement system was designed and recently introduced in unconventional developments to mitigate hydraulic isolation challenges encountered when cementing horizontal wellbores. Herein, we disclose recent results that show the efficiency of the interactive cementing system (ICS) in both laboratory and field case studies. Specifically, decreased communication between stages and improved production compared to offsets. At the 2018 SPE Annual Technical Conference, Kolchanov et al. described the ICS improving zonal isolation in wells that would otherwise contain mud channels symptomatic of the cleaning methods used in unconventional developments (SPE-191561-MS). The scaled performance tests disclosed in that publication are further evaluated to build on the relationship between the laboratory test and realistic downhole scenarios. Literature data indicate that >30% of stages have communications with previously treated zones. The ICS was shown to eliminate interstage communication during stimulation operations when compared to conventional cement systems. To investigate the effect of the ICS on completion quality, five wells cemented with the ICS and stimulated by multistage hydraulic fracturing were compared with numerous offset wells drilled, cemented, and stimulated during the last 2 years in the same producing zone within a 10-mile radius. The early normalized production data have been analyzed, and they indicate a statistically significant increase of production for the ICS-treated wells. This shows the importance of an integrated approach in well construction process, especially for challenging horizontal wells.
- North America > United States > Texas (1.00)
- Asia > Middle East (0.68)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin > Niobrara Formation (0.99)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- (33 more...)
- Well Drilling > Wellbore Design (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- (5 more...)
A Novel Approach Towards Cementing Design Achieved Significant Improvement in Long Term Zonal Isolation
Suleiman, Ala (BakerHughes, a GE company) | Hilal, Bashar (BakerHughes, a GE company) | Paila, Phalgun (BakerHughes, a GE company) | Abdelhadi, Sahir (BakerHughes, a GE company) | Alwahedi, Khalid (ADNOC) | Alkindi, Rashid (ADNOC) | Al Marzooqi, Abdulmohsen (ADNOC) | Khalifa, Mahmoud (ADNOC) | El Atrache, Bassam (ADNOC) | Singh, Rudra (ADNOC) | Ghulam, Hammad (ADNOC)
Abstract Well integrity is becoming more challenging with drilling of deeper, highly deviated and horizontal wells worldwide while the current market scenario is driving every stakeholder to execute their scope of work under ever revising AFEs. The scope of this paper is to present an optimized approach to improve quality of cement jobs while having a good long term zonal isolation across all the targeted formations and further eliminating the additional costs required for remedial jobs. There are various challenges that need to be dealt with when cementing complex wells such as uneven cement distribution around the casing due to insufficient mud removal, inadequate hole cleaning and poor casing standoff. All these challenges were addressed by in-house developed optimization methodology. The elements of this methodology that positively influenced the quality of the cement bond were (i) Optimizing the rheological hierarchy between the cement, mud and spacer design to create optimum flow during the cement job (ii) Improving hole cleaning efficiency by applying tailor-made spacer technology with aid of modeling software (iii) Optimizing the centralizer profile by including non-survey stations. The in-house developed optimized methodology has yielded excellent results with significant improvement in the cement bond logs when compared to the offset wells. This paper will present the methodology adopted in detail along with the field example of a well in an offshore island that has measured success against the key improved elements. The rheology of the fluids was adjusted to improve the fluid displacement in the analytical software which has played a big role in improving the hole cleaning efficiency. In addition, application of tailored Spacer design has not only showed improved mud removal effectiveness but also helped with reducing the channeling alongside the best optimized centralization found in the field in terms of type, quantity and placement across various formations and direction profiles along the well bore. This paper will also compare different logs in the same field to show the improvement against the new methodology and practices adopted that helped in achieving complete zonal isolation across all formations. The new optimization methodology has resulted in significant improvement in outcome of cement logs across production casing in offshore island indicating an excellent zonal isolation and adherence to well integrity requirements. The key elements that were improved are now being adopted across all the jobs in the field and nearby fields.
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- Well Drilling > Casing and Cementing > Cement and bond evaluation (1.00)
- Well Completion > Well Integrity > Zonal isolation (1.00)
Innovative Engineered Approach to Improve the Hydraulic Isolation and Wellbore Integrity Across Production Zone in Challenging HP Wells
Bugrayev, Amanmammet (Schlumberger) | Nafikova, Svetlana (Schlumberger) | Taoutaou, Salim (Schlumberger) | Timonin, Andrey (Schlumberger) | Gurbanov, Guvanch (Schlumberger) | Rovshenov, Gadam (Schlumberger) | El Sayed, Mohamed (Dragon Oil) | Hay, Kevin (Dragon Oil)
Abstract Complete and durable zonal isolation is the foremost goal of the cement job. In the deep and high-pressure environment, obtaining such goal is particularly critical, but also challenging due to the additional factors associated with the high drilling fluid densities that limit mud removal efficiency, narrow margins between fracture and pore pressures that cause loss circulation and differential sticking, and cement sheath exposure to downhole stresses during construction and production phases that compromises its integrity. Careful planning is required to ensure all risks are captured and mitigated during the design stage, taking into consideration not only the construction phase, but also post-placement downhole conditions changes caused by temperature, pressure fluctuations, and mechanical shocks during perforation and stimulation operations. Data analysis of the offset wells located in the eastern section of the Caspian shelf showed that conventional cement systems and previously applied cement job designs had limited success in addressing those challenging complex requirements. Thus, a new approach was required. This approach was used in 20 wells in the field with excellent results. Two wells were used to demonstrate the improvements obtained in zonal isolation behind production liners upon implementation of new engineered methodology. The innovative complex approach involved not only the revision of the previously used cement and spacer fluid designs, but also required revisiting and evaluating every aspect of cementing practices to achieve the desired results. Fiber-based spacer technology was introduced to enhance mud displacement and an engineered flexible and expanding cement system to achieve and maintain well integrity. Numerical analysis modelling was used to simulate the stresses that the cement sheath will experience over the well's life and calculate the minimum required mechanical properties of cement to be able to withstand these stresses. The set cement mechanical properties were then customized using a proprietary trimodal particle-size distribution technology to accommodate the expected downhole stresses. Hydraulic isolation improvement was achieved and confirmed by downhole logs.
- Asia > Middle East > UAE (0.28)
- North America > United States > Texas (0.28)
This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 189350, “Unlocking the Economic Potential of a Mature Field Through Rigless Remediation of Microchannels in a Cement Packer Using Epoxy Resin and Ultrafine Cement Technology To Access New Oil Reserves,” by Manu Khanna, SPE, Phanijyoti Sarma, SPE, Krishna Chandak, SPE, and Apurv Agarwal, SPE, Cairn Oil and Gas, a vertical of Vedanta, and Animesh Kumar and James Gillies, SPE, Halliburton, prepared for the 2018 SPE/IADC Middle East Drilling Technology Conference and Exhibition, Abu Dhabi, 29–31 January. The paper has not been peer reviewed. Well RXY is located in Cairn’s Ravva offshore field in the Krishna-Godavari Basin in India. One goal for the field was significant crude production by means of a secondary reservoir section. This paper presents a case study concerning rigless remediation of microchannels in the cement packer (placed in the annulus of production tubing and casing to isolate the producing zone) and discusses laboratory development of a customized epoxy-resin system, simulations to estimate channel size, 3D displacement modeling, drillout after placement, and evaluation post-placement. Introduction The well is an injector, drilled in 1998, intersecting several oil sands. The well was completed selectively across the sands with permanent packers for zonal isolation. Although several oil sands were intersected during drilling, one was not completed because of its marginal reserves. Because those sands fall above the production packer, a cement-packer job was attempted in 2016 to access the shallow sands while providing an annular barrier. However, after the job, communication was observed between the tubing and the annulus. The communication was attributed to poor cement isolation. Estimation of Channel Size Fluid-flow calculations and a hydraulic simulator were used to estimate the size of channels in the cement. The calculations were based on the real data of treated-water circulation. The circulation was established between the production tubing and the A annulus through holes punched at 2282 to 2284 m. For calculation purposes, the top of cement was assumed to be 1500 m (per the cement-bond log) and the average channel size from a depth of 2282 m to a depth of 1500 m was to be estimated. Also, the actual well directional data were used for the most-accurate hydraulics calculations. After several iterations, the channel size was estimated to be 0.3875 in. in average thickness. Selection Criteria Various techniques were evaluated to remediate the issue of channeling and to restore zonal isolation. Because the scenario was identified as one involving a narrow cement channel to be treated by the pressure-balance method, a proprietary epoxy-resin system was selected as the sealant. The selection was made on the basis of the sealant’s ability to seal the microannuli behind the casing and to restore zonal isolation by shutting off the gas flow, its characteristics in developing high compressive strength, its ability to resist significant strain without failure, and its solids-free formulation.
- Asia > India > Andhra Pradesh > Bay of Bengal (0.55)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.25)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.82)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- Reservoir Description and Dynamics (1.00)
- Well Completion > Well Integrity > Zonal isolation (0.98)
- (2 more...)
Abstract Sustainable well integrity, for the life time of the well and long after abandonment, has always been a target for operators. However, unplanned stresses on the set-cement can cause severe damages to the cement sheath and may ultimately result in its failure. For that reason, a new generation of cementing system with optimized mechanical properties and self-sealing capabilities were designed. The improved elastic constants and tensile strength value of the system make it more resistant to downhole stresses while the self-sealing feature provides an additional layer of assurance for long-term zonal isolation. The cement sheath’s ability to sustain stresses was confirmed using analytical and Finite Element Analysis (FEA) simulators. The mechanical properties and the expansion ratio were tested over several days, and the sealing ability was verified using a novel HPHT multi-function test cell simulating the well’s downhole conditions. The system was successfully deployed in cementing a challenging gas-injector well with a dual hole size in the UAE. Novel fluid displacement software was used to assess effective laminar flow as the industry-recommended turbulent fluid flow was not achievable. The injector well is expected to be under an alternating pressure of 5,500 psi with two sets of perforations set 47 ft. apart. The cement placement operation was carried out successfully and a Cement Bond Log (CBL) run was conducted after 48 hours verifying good zonal isolation over the entire interval. An injectivity test was performed on the two perforated zones. No fluid communication was observed, eliminating the need for any cement remediation. The successful implementation of the fit-for-purpose self-sealing resilient cement system from the slurry design and lab testing through the cement placement is described. Modelling simulation of the stress analysis, ECD and fluid displacement will be also shared. The review of this case history will provide useful lessons learned for successful cementing of critical wells.
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- (5 more...)