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Abstract Increases in water production can significantly reduce well performance and life of a well, and cause decreased oil production. Water influx can occur through several mechanisms and approach from several directions; accurate diagnostic information is important for the design of successful shutoffs and effective results. To mitigate this situation, water management is crucial. One option is to isolate the water producing zone with a rigless water shut-off technique, which is less costly than the use of workover rigs for interventions. This paper presents case histories of five horizontal wells drilled in carbonate formations and producing excess water; three were completed in open hole and two were cased. A multiphase production logging (MPL) tool equipped with five miniaturized spinners for phase velocity measurement and six electrical and six optical probes for holdup data provided important diagnostic data for the decisions on remedial actions. Using the tool data, the operator pinpointed the water entries and performed shutoff operations based on the source of the entries and water flow profiles. Subsequent production test results showed that the water cut was reduced in all the wells. Examples from open and cased hole completions are shown utilizing a number of different shutoff techniques. In addition, oil production was considerably increased in many of the wells. These results demonstrate that accurate diagnostic information and an integrated approach are keys to successful rigless water shutoffs.
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
Abstract Sabiriyah Lower Burgan is a clastic reservoir in North Kuwait on continuous production for the last 45 years. The reservoir, on active water drive, has its inherent problem of rapid increase in water cut, the production performance of wells declining drastically after water cut level of 40%. The well production improvement is continuous effort based on understanding of well fundamentals and actual analysis of well's historical performance. This can be enhanced with Well modeling based on latest field real time parameters to predict well performance and production forecast. The persistent approach to improve well performance was implemented by dividing entire Field into segments based on water encroachment, pressure distribution and fluid properties as each well is located in a segment requiring specific approach and technique's to sustain well production and performance improvement. To implement production sustenance and enhancement plan, huge well surveillance plan was adopted to acquire TDT/PNC, PLT, FBHP and SBHP, PGOR to get latest well and field data to implement following specific actions a) Quick wins: Rig less water shut-off jobs, additional and re-perforations in dry zones to improve well production; b) Rig work overs to cement squeeze the high water cut zones to reduce water cuts and improve well vertical lift performance on natural flow; c) Selective ESP in low pressure and high water cut field segments to sustain the existing production; d) Use of latest ICD design based on PLT results to sustain well production from the existing horizontal wells with less water cut; e) Recompletion of poor performance wells of other zones after critical evaluation. The case history of Production management of this giant reservoir in North Kuwait leading to significant increase in production is a successful journey to be shared with International professional community.
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Conformance improvement (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Well performance, inflow performance (1.00)
- Production and Well Operations > Well Intervention (1.00)
Abstract The excess of water production from oil wells in several areas of Khafji field is a subject of concern for reservoir management. Water shut-off techniques are common practices to reduce water production which is resulted in well productivity improvement. An oil producer well-A, was worked-over on February 22, 2006 to conduct a water shutoff technique on existing perforation intervals utilizing a cement squeeze. Several logs such as RST and Gamma Ray were carried out to identify the fluid movement. Then, the well was produced with an oil rate of 1,200 BOPD and a rapid increase of water cut of 60%. The well was still unstable in terms of rate due to high water cut. The well was considered for rigless work-over to control the water using Mechanical Through Tubing Bridge Plugs (MTTBP) to isolate the lower two perforation sections. After setting the Bridge Plug with 8 ft. of cement above the plug, the well was revived with production stream. During the first 24 hrs of well production, the treatment result was not as expected which resulted in 100% water cut. A discussion was made by reservoir management engineer to continue of production for additional 24 hrs. With time, the well showed a positive result with a reduction in water up to 95%. It is recommended to keep the well to be produced over 21 days with final results showed the well revived with an oil production of 1,500 BOPD with zero water cut. The result showed a successful water shutoff technique and scenario to retrieve the well with 100% water cut produced after treatment. Challenges, intervals selection, design criteria, lessons learned, and results of the water shutoff technique will be discussed in this paper.
- Geology > Mineral (0.47)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.31)
- Asia > Middle East > Saudi Arabia > Saudi Arabia - Kuwait Neutral Zone ("Partitioned Zone") > Arabian Gulf > Arabian Basin > Arabian Gulf Basin > Khafji Field (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Lower Fadhili Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff D Formation (0.99)
- (6 more...)
Summary Several multirate separator tests (MRTs) have been undertaken on wells in the Veslefrikk field that are on commingled production from the Brent Group and Intra Dunlin Sand (IDS). During these tests, produced-water (PW) samples were also collected. Integrated analysis of the results of interpretion of the PW analyses and the MRT results has provided a range of information for each production zone, including the nature and composition of the PW, the seawater fraction of these produced waters, the fraction of total water flow being produced, pressure, productivity index, oil and water rates, and water cut. This information can reduce the need for running production-logging tools (PLTs), allows the scaling potential between the deeper and the shallower zones to be evaluated, aids squeeze-treatment design, is beneficial for predicting formation damage from crossflow, and aids water-shutoff decisions. In an accompanying paper, McCartney et al. (2012) describe how PW analyses from the MRT are interpreted to determine— among other parameters—the amount of water produced from each zone (water allocation) at each of the test rates during an MRT. In this paper, the methods of analyzing these results in combination with separator-test data are described with the aid of a field example to demonstrate how they provide detailed information about the downhole conditions and zone properties of the well. On the basis of the analysis, a set of well interventions was recommended. Following confirmation of the principal MRT results by a PLT, some of the recommended interventions have been performed successfully. Experience from Veslefrikk suggests that MRTs can be considered as a possible replacement for running PLTs or as an additional source of data that can be acquired more frequently.
- North America > United States (0.67)
- Europe > Norway > North Sea > Northern North Sea (0.35)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > NOAKA Project > Krafla North Prospect > Etive Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > Block 30/6 > Veslefrikk Field > Statfjord Group Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > Block 30/6 > Veslefrikk Field > Dunlin Group Formation (0.99)
- (14 more...)
Summary Technologies for horizontal-well fracturing in China include multistaged fracturing and hydraulic jetting. As in many other parts of the world, this type of well stimulation employs mechanical zonal isolation or sand and polymer plugs. All of these technologies are used by us in a number of reservoirs, but they depend on the presence of newly targeted and intentionally perforated sections of horizontal wells that are not already perforated. However, because most horizontal wells in the mature Huabei oil field have been producing for a very long time and the perforations are all along the horizontal sections, it is practically impossible to use these technologies. To prevent multiple-fracture initiation in a given section, sealing-ball staged fracturing has been developed and used successfully in horizontal wells of the Huabei field. Three kinds of sealing balls—with densities of <1, 1, and >1 g/cc, respectively—are pumped between stages of fracturing. They can seal perforations 360° around the horizontal-well section. Higher-permeability zones are sealed off preferentially. Because staged fracturing can be carried out effectively without stopping the pumps while running ball sealers downhole, the process can be accomplished in a significantly shorter period of time than other techniques. And, because these sealing balls are made of wax, they can be dissolved and removed later by the oil produced from the formations. In this paper we present field case studies of staged hydraulic fracturing using ball sealers, and we demonstrate the success of this form of zonal isolation in both execution and especially postfracture well performance. We also provide guidelines for the effective length of horizontal-well section in which ball sealers can be used for zonal isolation.
- North America > United States (0.69)
- Asia > China > Hebei Province (0.54)
- Asia > China > Hebei > Bohai Basin > Huabei Field (0.99)
- North America > United States > Louisiana > China Field (0.98)
Corrosion Monitoring, Root Cause Analysis and Selection Criteria for Future Well Completion Design in Deep HPHT Sour Wells
Al-Saeed, Abdulla (Kuwait Oil Company) | Chandra, Ravi (Kuwait Oil Company) | Al-Mai, Noura (Kuwait Oil Company) | Al-Awadi, Mishari (Kuwait Oil Company) | Dashti, Qasem (Kuwait Oil Company)
Abstract In high pressure high temperature (HPHT), deep sour gas condensate and volatile oil fields, in which the wells contains approximately 2 – 8 % H2S and 1 – 2.5% CO2 it is necessary to evaluate the corrosion rates for the downhole completion string. As it is well known that, corrosion leads to several major problems which affect the well integrity and the production sustainability through the production string failures and tubing casing pressure communication. The purpose of this paper is to illustrate an initial monitoring plan to extend the life of a completion string, reduce the number of well interventions and workovers due to corrosion and scale deposition. This systematic approach will improve the future tubing selection criteria and evaluate the need for CRA material also enhancing the downhole inhibition system with reference to KOC safety regulations from operational and economical prospective. The conclusions of the above will be based on data collected from 13 wells to investigate the key factors which accelerate the corrosion occurrence and rate. As such, a detailed analysis was constructed by using the baseline corrosion logs and their outputs such as time lapse, pitting, and fluid properties vs. metallurgy.
- North America > United States (0.29)
- Asia > Middle East > Kuwait (0.16)
- North America > United States > Texas > Anadarko Basin (0.99)
- North America > United States > Oklahoma > Anadarko Basin (0.99)
- North America > United States > Kansas > Anadarko Basin (0.99)
Abstract The wells in the southern area of Saudi Arabia are mostly horizontal wells in highly fractured carbonate reservoirs. Due to high water cut caused by water influxes through the fractures, some of these wells were dead or on intermittent production between 2005 and 2010. To increase oil production, we performed several water shutoff jobs using inflatable packers with mixed results. The water shutoff candidate selection process starts with a reservoir and production data evaluation, followed by a coiled tubing (CT) logging run to identify the water source and adjust the required isolating fluids formulation and volume. Successful execution of the water shutoff treatment requires controlling the placement, inflation, injection, and disconnect of the inflatable packers. Fiber-optic enabled coiled tubing (FOECT) systems, which enable real-time downhole data measurement, can optimize water shutoff treatment design, execution, and evaluation—increasing the success ratio. For the job design, we ran production logging tools on the FOECT string to detect the water source, measure the bottomhole temperature required for the formulation of water shutoff fluids, obtain a gamma ray and/or casing collar locator (CCL) log, and get an X-Y open hole (OH) caliper critical. This helped us determine the best setting depth for the inflatable packer in the openhole section, and confirm the required water shutoff fluids volume. The depth correlation for the packer setting was performed with a fiber-optic bottomhole assembly (BHA) gamma ray conveyed on CT. This enabled us to monitor and adjust the inflation of the packer, and the injection through it, in real time Then, the packer setting and release was confirmed with the world's first application of a fiber-optic, CT-conveyed tension and compression tool. Recent production results showed significantly higher production with no more than 10% water cut. The integrated CT solution proved to be an effective water shutoff technique in these horizontal wells, and has potential to bring many wells around the world back to economic production.
- Asia > Middle East > Saudi Arabia (0.89)
- North America (0.68)