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Collaborating Authors
SPE International Petroleum Conference and Exhibition in Mexico
Abstract Everybody believes to drill a well, it is obviously necessary to use Drill Pipe. Pemex Exploration and Production (PEP) has drilled with Tubing more than a 150 gas wells since June 1996. Now PEP went further, cause PEP already drilled with 5 ½" Casing Hydril Series 500 Type 521, the gas well Culebra281 in the area of Burgos Basin in Reynosa, Tamaulipas, Mexico. This Mexican Technique uses the Casing as a Drill Pipe. The 5 ½" HD-521Casing drills the first section with a 12 ¼ in. tricone bit and the second section with 8 ½ in. PDC bit. After the first section is drilled, the 95/8" Casing with guide shoe and float collar is run and it is cemented from the bottom to the surface. The second section is drilled with the same 5 ½"Casing to the programmed depth and finally the same 5 ½" Casing is run withguide shoe and float collar in stands in order to be cemented as anIntermediate Casing. In both sections, the 5 ½" HD-521 Casing is rotated during drilling and it is retrieved to the surface in stands to lay down the drill bit and bottom hole assembly (BHA). The third section and last section is drilled with 2 7/8" HD-533 Tubing,4 ¾ in. PDC bit and 3 ½ in. Mud motor and then it is retrieved to the surfaceto lay down the drill bit and bottom hole assembly (BHA); finally the completion is done with the same 2 7/8" HD-533 Tubing which is run in stands with guide shoe and float collar to be cemented as a Production Casing(Tubingless Technique). The Mexican technique improves the return on investment, due to the fact, No Drill Pipe is required to drill the well and also this technique reduces drilling time and well cost. Introduction In the planning of drilling in development fields, "Re-engineering of Well Design" should be implemented as common practice in all processes established for the drilling of oil and gas wells. This would allow a constant reduction in drilling cost, and would increase the profitability of investment projects infields at intermediate or advanced stages of exploitation by integrating new technology, which permits the company to obtain their objectives. One of the objectives of Pemex Exploration and Production is to apply cutting-edge technology to make the continuous improvement of Well Drilling and Field Development. This is realized through the joint efforts of the Drilling area and the Oil and Gas Design Engineering area. Pemex is also aided by the advice of oil manufacturing and service companies, in the joint study and assessment of projects; this is with the aim of finding the most feasible application, which is also the most profitable for Petróleos Mexicanos. The Burgos Basin Area was chosen because it met all necessary requirements for the safe implementation of this new technology. This is a development field, and is at an advanced stage of exploitation. For this reason, it isnecessary to make innovative use of cutting-edge technology, which makes it possible to optimize the Well Design and minimize the Drilling cost, while maintaining quality in materials and services. Selecting the Casing Connection for Drilling The Wedge Thread Technology has allowed to drill with tubing more than 150 wells in the Burgos Basin, this experience helped to consider as an option to drill with casing, but now the challenge was to use a plain ends pipe and the appropriate flush joint connection to allow to drill with it. The Casing Connection has to have yield torques values close or superior than the equivalent Drill pipe to drill the same sections of the well.
- North America > Mexico > Tamaulipas (0.94)
- North America > Mexico > Nuevo León (0.65)
- North America > Mexico > Coahuila (0.65)
- Government > Regional Government > North America Government > Mexico Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > Mexico > Tamaulipas > Burgos Basin (0.99)
- North America > Mexico > Nuevo Leon > Burgos Basin (0.99)
- North America > Mexico > Coahuila > Burgos Basin (0.99)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations > Running and setting casing (1.00)
- Well Drilling > Casing and Cementing > Casing design (1.00)
Abstract The present job is a methodology to systematize the cementing job operation based on drilling information in order to define slurries, preflushes and procedure for planning, execution, controlling and evaluation of cementing job. Difficult geometry, high deviated angle, shallow and deep gas wells, gelled mud and oil based mud are some of the harsh environments where this methodology has been used successfully. Results show excellent zone isolation of Payzone and their impact on drilling. INTRODUCTION Investigators have dedicated their efforts in defining the behaviour of the preflushes and cement slurries in the well. Mathematical models have been developed to simulate ideal conditions of stand off, hole geometry and dynamic erodability. Most of these models are based on experiments carried out under conditions of dynamic filtration and temperature that are not related with what happens truly in the well. These results suggest the use of specialized additives to get properties unpredictables during the cementing operation. A classic example constitutes the additives for gas migration control. These technologies were developed evaluated in totally isolated cells, simulating 100% mud cake remotion, fixed temperature from the bottom until the top and with permeable zone different to the true formations. The present paper shows the methodology to define the parameters of design of cement slurries and preflushes based on operational problems during drilling, well geometry, drilling fluid final properties, type of formation and completion. The results show the success of the methodology and they have allowed the development of an on-line program that works as expert system, able to adapt to the different scenarios of the well. BACKGROUND International approaches. In papers published by several international specialists, approaches have been developed on the design of cement slurries, preflushes selection and displacement mechanisms based on laboratory tests that cannot be reproduced in the field. Some of these techniques or approaches are:Gas Migration Control. Effective Laminar flow. Preflushes displaced in turbulent flow. Low fluid loss. Mud cake erodability. From the theoretical point of view, all these approaches have their validity and application. However, field experience allows us to make some objections to each one of them. Next, a brief discussion of the truthfulness of these technologies based on the observed field results. Gas Migration. The approaches developed for the control of migration of gas are based on setting in right angle, low filtrate (< 80 cc/30 min), high static gel strength development (>500 lb/100 pie). These technologies consider that during the transition of fluid to plastic, the cement loses its capacity to transmit pressure until falling below the pore pressure, allowing the influx of gas for channeling or percolation as show in Fig 1. International approaches. In papers published by several international specialists, approaches have been developed on the design of cement slurries, preflushes selection and displacement mechanisms based on laboratory tests that cannot be reproduced in the field. Some of these techniques or approaches are:Gas Migration Control. Effective Laminar flow. Preflushes displaced in turbulent flow. Low fluid loss. Mud cake erodability. From the theoretical point of view, all these approaches have their validity and application. However, field experience allows us to make some objections to each one of them. Next, a brief discussion of the truthfulness of these technologies based on the observed field results. Gas Migration. The approaches developed for the control of migration of gas are based on setting in right angle, low filtrate (< 80 cc/30 min), high static gel strength development (>500 lb/100 pie). These technologies consider that during the transition of fluid to plastic, the cement loses its capacity to transmit pressure until falling below the pore pressure, allowing the influx of gas for channeling or percolation as show in Fig 1.
- Research Report > New Finding (0.74)
- Research Report > Experimental Study (0.74)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (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)
Abstract (1–4) Environmental constrains on disposals of cutting and drilling fluids have precluded the use of oil base mud (OBM), in addition drilling with OBM can introduce a contaminant into the reservoir. Alternative or synthetic fluids have been developed with many of beneficial properties of inverted emulsion which offer advantages beyond the fact that they are environmentally accepted. In this experimental research emphasis is given to the results of the efficiency of a new water base system, which include the use of a new shale stabilizer additive. Anionic polymers were studied and synthesized of type anionic (ionizable groups with negative charge. It is described the synthesis of homopolymers of acrylic acid (PAA) with differen conditions of synthesis, homopolymers of AA and Dialildimetilammoniumchloride (DADMAC). The characterization phase involves the molecular weights and viscosities determination for homopolymers AA and molecular weights by an alternate method for copolymers of AA-DADMAC, use of I.R. spectroscopy for the structure elucidation. To prove the efficiency of the system were developed CIC test, swelling and dispersion test (by using cores from the Gulf of Mexico basin), rheology HPHT, filtration tests, TSC, lubricity. The results of the describe experiments involved in the hydration of shale. Experimental details and results will be presented. Introduction Unstable formations pose special problems for operators when drilling oil and gas wells. Heaving shale and caving well bores can cause stuck drill pipe, balled-up drill bits, logging failures, and increased drilling time and expense. Water sensitive shale tends to absorb water from the drilling mud. The shale swell and weaknes, causing the well bore to slough or even collapse. Swelling and over pressuring of shales are of major importance in the oil industry, because they may cause extensive damage to drilling operations, oil recovery and exploration (4). Operations through shales are complex, including drilling that may require muds that are not always amiable to the environment. The phenomena are associated with the active clay minerals in the shale and their evolution through compaction, reactions with brines, pore and drilling fluids or among minerals, burial diagenesis, and tectonic or mechanical pressures among others 1. Operators have tried several ways to control unstable shale sections. This research represents an attempt to obtain a synthetic drilling fluid shale stabilizer, which should:To be water soluble To be compatible with the rest of the additives of the water base mud Works efficiently in alkaly media Inhibits the hydration of the shale Have acceptable reology and tixotropy Present low toxicity To carry out with the environmental regulations We have worked with samples of polymer prepared in different ways and these include use of homopolymers of acrylic acid (PAA) and the sodic salt in different concentrations and experimental conditions and the synthesis and purification of AcNa copolymers and dialildimethylammoniumchloride (DADMAC) (5–6).
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.54)
Abstract The paper is based on laboratory research and field evaluation data incorporated in a study carried out to select a suitable drill-in fluid for use in naturally fractured HTHP sour gas reservoirs. Laboratory results were verified by monitoring drilling process and initial production of a particular well located at the gas condensate field in SW Pannonian Basin, Croatia. Production zone, naturally microfractured limestone (21% porosity, 2 md matrix permeability) at 2500–2600 m (BHST˜150°C) was left openhole. Reservoir fluid contains 53% CO2 and 800 ppm H2S. Two aspects of a drill-in fluid evaluation were considered: optimal drilling process performance, complicated by harsh reservoir conditions; and minimizing formation damage of plugging susceptible microfracture system. Drilling data, using the selected drill-in fluid, showed a good ROP and borehole stability. Production tests after well completion indicated no damage. Even under extreme down hole conditions, the balance between optimal drilling performance and minimal formation damage could be achieved using described laboratory testing procedure. Introduction The problem of formation damage of naturally fractured reservoirs due to drilling fluid invasion has been reported in petroleum engineering literature only sporadically.1–5 Mechanism of formation permeability reduction in this type of reservoirs 2–7 is in most cases associated with solid particles plugging the fissure-dominated flow paths of hydrocarbons to the wellbore. On the other hand, a drilling practice in such fractured rock systems is faced with many difficulties such as drilling fluid losses, well control uncertainty, cementing job complications etc. In cases where reservoir temperature is considerably high (>150°C) and formation fluid is aggressive (sour gas), a drilling process designed to keep up the optimal drilling performance 8–11 (i.e. high ROP, good borehole stability), as well as minimize formation damage 1–5,9,12,13 of the payzone, could be very hard to establish and maintain. In order to avoid the classical formation damage and drilling practice problems experienced with conventional drilling muds, the drill-in fluids 1,2,8,10,12,13 have recently been designed to drill through the productive zone. Standard procedure consists of drilling with conventional fluids to the top of the payzone 12, and then switching to the cleaner, less damaging drill-in fluid to drill through the hydrocarbon bearing zone. Although drill-in fluids are inherently less damaging than conventional drilling muds, some specific types of permeability reduction can occur in case of naturally fractured reservoirs 2. If a particle-laden fluid is introduced into micro-fracture system under HT conditions, solid particles are captured inside fractures, thus reducing the natural reservoir permeability in near-wellbore zone. A study for selection of the proper drill-in fluid for high-temperature, sour gas, naturally fractured 14 reservoir was performed in order to avoid the payzone damage and maintain the optimal drilling performance. Laboratory results of investigations were verified by monitoring the drilling process and initial production of a particular well located at the gas field in SW Pannonian basin, Croatia. Even under extreme down hole conditions at that well, the balance between optimal drilling performance and minimal formation damage was achieved using the proper laboratory testing procedure. The selected drill-in fluid fulfilled both (often controversial) aspects of drill-in fluid optimization in naturally fractured reservoirs. Reservoir Characteristics Principal reservoir properties of the subject gas field are summarized in Table 1. Reservoir rock is a pure, rather homogeneous limestone with some dolomitic intrusions. This was confirmed by XRD analysis and acid solubility tests. Solubility of rock samples in 15% HCl and in 10% CH3COOH was virtually 100%.
- North America > United States > California > Sacramento Basin > 2 Formation (0.99)
- Europe > Slovakia > Pannonian Basin (0.99)
- Europe > Serbia > Pannonian Basin (0.99)
- (3 more...)