This article reports on a laboratory scale investigation of an existing field procedure and its adaptation for sealing of leaky wellbores. It consists of mechanical expansion of metal pipe, which results in an improved metal/cement bond, ultimate sealing of hydraulic pathways and prevention of gas leaks caused by the presence of a microannular channel.
Wellbore cement, a procedural component of wellbore completion operations, primarily provides zonal isolation and mechanical support of the metal pipe (casing), and protects metal components from corrosive fluids. These are essential for uncompromised wellbore integrity. Cements can undergo multiple forms of failure, such as debonding at the cement/rock and cement/metal interfaces, fracturing, and defects within the cement matrix. Failures and defects within the cement will ultimately lead to fluid migration, resulting in inter-zonal fluid migration and premature well abandonment. Currently, there are over 1.8 million operating wells worldwide and over one third of these wells have leak related problems defined as Sustained Casing Pressure (SCP)1.
The focus of this research was to develop an experimental setup at bench-scale to explore the effect of mechanical manipulation of wellbore casing-cement composite samples as a potential technology for the remediation of gas leaks.
The experimental methodology utilized in this study enabled formation of an impermeable seal at the pipe/cement interface in a simulated wellbore system. Successful nitrogen gas flow-through measurements demonstrated that an existing microannulus was sealed at laboratory experimental conditions and fluid flow prevented by mechanical manipulation of the metal/cement composite sample. Furthermore, this methodology can be applied not only for the remediation of leaky wellbores, but also in plugging and abandonment procedures as well as wellbore completions technology, and potentially preventing negative impacts of wellbores on subsurface and surface environments.
The reported experimental procedure has two main components that are critical: composite cylinders that simulate wellbores and the expansion fixture that is used to carry out mechanical manipulation of the cement.
Wellbores are the main gateway for production of subsurface fluids (water, oil, gas, or steam) as well as injection of various fluids. Regardless of its function, the wellbore is required to provide a controlled flow of produced/injected fluids. Wellbore construction has two distinct operations: drilling and completion. Wellbore cement, part of the completions procedure, primarily provides zonal isolation, mechanical support of the metal pipe (casing), and protection of metal components from corrosive fluids. These are essential elements of uncompromised, fully functioning wellbores. The integrity of the wellbore cement sheath is a function of the chemical and physical properties of the hydrated cement, the geometry of the cased well, and the properties of the surrounding formation/formation fluids2,3. Incomplete removal of drilling fluid will result in poor zonal isolation since it prevents formation of strong bonds at interfaces with rock and/or metal. Cement sheaths can be subjected to many types of failure during the life of a well. Pressure and temperature oscillations caused by completion and production operations contribute to the development of fractures within the cement matrix; debonding is caused by pressure and/or temperature changes and cement hydration shrinkage4,5,6. The result is almost always presence of microannular fluid flow, although its occurrence can be detected early or after years of service life.
Heathman and Beck (2006) created a model of cemented casing subjected to over 100 pressure and temperature cyclic loads, which showed visible debonding, initiation of cement cracks which can pose preferential pathways for migrating fluid7. In the field, the expansion and contraction of metal components of a wellbore will not coincide with those of cement and rock, causing interfacial debonding and formation of a microannulus, leading to an increase in permeability of the cement sheath. An additional casing loading can cause the propagation of radial cracks in the cement matrix once the tensile stresses exceed the tensile strength of the material8. All of the aforementioned cement failures can result in micro-channeling, which leads to gas migration, the occurrence of SCP, and long-term environmental risks.
A considerable number of producing and abandoned wells with SCP constitute a potentially new source of continuous natural gas emission9. The analysis conducted by Watson and Bachu (2009) of 315,000 oil, gas, and injection wells in Alberta, Canada also showed that wellbore deviation, well type, abandonment method, and the quality of cement are key factors contributing to potential well leakage in the shallower part of the well10. The existing remedial operations are costly and unsuccessful; the squeeze cementing, one of the most commonly used remedial techniques, has a success rate of just 50%11.
In this paper we report on the evaluation of the Expandable Casing Technology (ECT) as a new remediation technique for leaky wellbores12,13. ECT can be applied in new or existing wells14. The first commercial installation of this technology was performed by Chevron on a well in shallow waters of the Gulf of Mexico in November 1999 15. The current operating envelope for expandable tubulars encapsulates an inclination of 100° from vertical, temperature up to 205 °C, mud weight to 2.37 g/cm3, a depth of 8,763 m, hydrostatic pressure of 160.6 GPa and a tubular length 2,092 m 16. A typical expansion rate for solid expandable tubulars is approximately 2.4 m/min 17.
This study offers a unique approach to the adaptation of ECT technology as a new remediation operation for SCP. The expansion of the steel pipe compresses the cement which would result in closure of the gas flow at the interface and seal the gas leak. It is important to mention that the focus of this study is the sealing of an existing microannular gas flow, therefore we only focused on that as a possible cause of leaky wellbores. In order to test the effectiveness of newly adapted technology for this purpose, we designed a wellbore model with an existing microannular flow. This is obtained by rotating the inner pipe during cement hydration. This is not to simulate any field operations, but simply to fast-forward what would happen after decades of thermal and pressure loading in a wellbore.
1. Composite Sample (Figure 1)
NOTE: Most cement jobs in the Gulf of Mexico (USA) are done using Class H cement18, therefore, the same type of cement was used to perform the lab experiments to simulate field-like conditions, the potential applicability of this technology for SCP remediation in the Gulf of Mexico.
2. Pre-expansion Flow-through Experiments
3. Expansion Setup and Expansion Procedure
4. Post-expansion Multi-rate Flow-through Experiments
5. Calculations of the Effective Permeability of the Microannulus
NOTE: The main purpose of this study was to provide qualitative information regarding existence of gas flow before and after expansion. The experimental design does not possess sophisticated components to be able to measure the width of the channel and flow rate accuracy. During these preliminary experiments sealing of gas flow was the main focus. Therefore, any of permeability calculations shown here are more semi-quantitative and not main goal of the study.
Pre-expansion gas flow-through tests on the composite sample showed pressure recording on the outlet pressure transducer, confirming gas flow through the pre-manufactured microannulus (Figures 7 and 8). Initial conditions were kept the same where initial inlet pressure was 103 kPa and the gas flow rate was kept at 85 ml/min for that period. The time lag in pressure recording between the inlet and outlet pressure transducers was 7.5 seconds, while the highest pressures recorded after increasing the inlet pressure to 172 kPa were 117 kPa (inlet) and 20.7 kPa (outlet). Due to preferential flow of gas through the microannulus, the entire permeability is taken as the effective permeability of the microannulus (Kef). Stabilized pressures used in Kef calculations were Pinlet=12 kPa and Poutlet=0.4 kPa, giving a microannulus effective permeability of Kef=0.66 D. Any residual stress within the cement matrix due to pipe expansion and its effect on permeability is negligible.
The second gas flow-through test was run immediately after imposing an 8% expansion ratio, with a gradual increase in inlet pressure by 172 kPa every five minutes from an initial pressure of 172 kPa to a final pressure of 690 kPa. The test showed no pressure recording on the outlet pressure transducer, as shown in Figure 9.
The same procedure was repeated after 24 hours and then after 60 days. Both tests showed no pressure readings on the outlet pressure transducer, which confirmed that the 8% expansion rate was successful in closing the microannular gas flow in the wellbore model. Four additional samples were expanded with different expansion ratios (2% and 4%) and tested for flow in the same way as the aforementioned sample. The same results were obtained and confirmed the successful sealing of the microannular gas flow (Table 1). It is important to mention that each sample preparation requires labor intensive preparation and time, which is why it cannot be compared with simple studies of cement cores that can be molded effortlessly in large numbers.
Sample | Kef [D] | Expansion ratio [%] | Kef [D] | Kef [D] | Kef [D] |
0 hr | 24 hr | 60 days | |||
1 | 0.14 | 4 | 0 | 0 | 0 |
2 | 0.66 | 8 | 0 | 0 | 0 |
3 | 2.11 | 2 | 0 | 0 | 0 |
4 | 2.31 | 2 | 0 | 0 | 0 |
5 | 7.04 | 8 | 3 x 10-7 | 0 | 0 |
Table 1. List of samples with calculated microannulus effective permeabilities (Kef) and post-expansion results of flow-through tests conducted immediately, 24 hr and 60 days after expansion.
Figure 1. Wellbore model schematic. Top view shows the cement (red color) between inner and outer pipe. The arrow points the direction of expansion. Bottom view shows the steel plate ring welded to outer pipe and pipe coupling. Inner pipe is screwed into the coupling (the scale is in inches).
Figure 2. Metal components of the bottom part of the wellbore model: a. Steel plate ring (0.63 cm in thickness); b. 6.35 cm OD steel pipe coupling; c. Pipe coupling welded onto steel plate ring; d. Threaded part of the inner pipe being screwed into the pipe coupling; e. Finished assembly. Final part of the wellbore model is the outer pipe which is placed at the end and welded for the steel plate ring on the outer region.
Figure 3. a. Expansion cones with 2%, 4% and 8% expansion ratio; b. Side view of 2% expansion ratio cone. All cones have 14° cone angle and are custom-made from alloy steel which was heat treated to the hardness of 60 RC.
Figure 4. Setup and expansion process (top view): a. the expansion mandrel is retained in order to clear the lower housing for placement of the composite sample; b. the composite sample is placed in the lower housing and the expansion mandrel is fully elongated through the inner pipe; c. the expansion cone is slipped onto the expansion mandrel. Magnified view shows the expansion cone being held in place with the retaining mandrel; d. the expansion mandrel is retained and the expansion cone is pulled through the inner pipe (red arrow shows the direction of expansion).
Figure 5. Back and front view of the sample showing the gas manifold assembly with pipe fittings and nylon tubing. Closer view of inlet and outlet manifolds showing positioning of pressure transducers.
Figure 6. Flow-through experimental setup. The flow meter (FM) controls nitrogen gas flow (red arrows) throughout the experiment. Gas flows and enters the composite sample on the inlet manifold where the inlet pressure transducer (PT-1) records the inlet pressure. Gas flows through the sample’s pre-manufactured microannulus and the pressure recording on the outlet manifold’s pressure transducer (PT-2) provides the information of whether there is a connectivity and microannular gas migration through the composite sample. Pressure transducers are connected to the data acquisition system and pressures are monitored and recorded in real time on the computer and available to view on the screen. Magnified view shows installation of the pipe fittings.
Figure 7. Pre-expansion gas flow-through test data plot showing registered pressures on both the inlet and outlet pressure transducers, confirming the microannular gas flow through the wellbore model. The starting inlet pressure on the gas cylinder was 50 kPa, and it was increased to 172 kPa, which resulted in a spike of both pressures on inlet and outlet ports.
Figure 8. Pre-expansion gas flow-through test data semi-log plot clearly showing a pressure differential (ΔP) between pressures registered on the inlet and outlet pressure transducers. Based on the measured ΔP, calculations of effective permeability of the microannulus resulted in a value of 660 mD.
Figure 9. Multi-rate gas flow-through test data plot recorded immediately after expansion with the 8% expansion ratio cone. After a gradual increase of 172 kPa in inlet pressure on the gas cylinder every five minutes from 172 kPa to 690 kPa, there was no recorded pressure on the outlet pressure transducer, indicating successful remediation of the microannular gas flow.
The reported experimental procedure has two main components that are critical: composite cylinders that simulate wellbores and the expansion fixture that is used to carry out mechanical manipulation of cement. When designing wellbore models (cement/pipe composite cylinders), it is critical to choose adequate cement density, store samples under total humidity conditions (100% RH) and establish pipe-cement debonding before cement slurry completely sets. Failing to achieve this would make the entire gas flow experiment impossible.
Regarding the expansion fixture, only qualified and certified manufacturers capable of providing quality assurance can be used. The high pressures and significant forces can pose a serious safety hazard to the operator if the equipment is not properly designed, manufactured from the adequate materials, assembled, calibrated and tested prior to any data acquisition.
The reported experimental protocol in terms of major steps is applicable to sample design of different cement densities, however the fixture used in this study would not be able to expand samples with lower water to cement ratios (stronger cement) and would require more powerful hydraulic unit. A more powerful hydraulic unit of 34.5 MPa maximum pressure will be used for future research, which will include experiments on samples cemented with different water to cement ratio slurries and also different types of pipe/cement interface contamination, such as drilling fluid. In addition, the ongoing research is investigating behavior of foamed cements using this procedure. Separate set of experiments will be carried out on samples where temperature cycling will be applied within the inner pipe as a method for interfacial debonding, rather than inner pipe rotation.
In order to be able to directly measure changes within cement during the experiment, various sensors, such as strain gauges and piezoelectric sensors, will be embedded within cement and be connected to a data acquisition portal in the future sample design, which will enable us to gather direct measurements of stresses and potential water buildup in cement during metal expansion. Furthermore, microhardness testing is being incorporated in order to investigate the effect of pipe expansion on mechanical properties of cement. All of this is being investigated in ongoing research and will be reported in future publications.
The main limitation of this procedure is that we used metal to simulate rock wall, which is not ideal and can be approximated only for low permeability rocks such as clay-rich formations, or for simulation of cement sheath between two pipes. The second major improvement we are working on is an alternative design of wellbore model specimens that will be able to withstand higher gas pressures (from current 0.69 MPa to 3.45 MPa or even 6.9 MPa) in order to make this experiment more applicable to the field conditions.
The ongoing research is being carried out on sample design that will allow post-expansion direct coring of cement sheath. These cores will be used to measure permeability of cement using pulse-decay permeameter. This non-invasive technique will allow us to obtain direct measurements of changes in permeability, as the main parameter indicative of an effective zonal isolation and successful hydraulic barrier.
Although we suggest, and are currently working on several improvements of existing setup, this is a unique set up at lab/bench-scale and, to our knowledge, the first of its kind.
The authors have nothing to disclose.
The authors would like to thank the following people and institutions for their help and support: William Portas and James Heathman (Industry Advisors, Shell E&P), Richard Littlefield and Rodney Pennington (Shell Westhollow Technology Center), Daniele di Crescenzo (Shell Research Well Engineer), Bill Carruthers (LaFarge), Tim Quirk (now with Chevron), Gerry Masterman and Wayne Manuel (LSU PERTT Lab), Rick Young (LSU Rock Mechanics Lab), and members of the SEER Lab (Arome Oyibo, Tao Tao, and Iordan Bossev).
ASTM A53 Grade B ERW Schedule 40 Steel pipe – OD=10.16 cm, ID=10.04 cm, L=59.7 cm | Baker Sales | BPE-4.00BB40 | |
ASTM A53 Grade B ERW Schedule 10 Steel pipe – OD=6 cm, ID=5.94 cm, L=61 cm | Service Steel | n/a | |
Expansion Cones – AISI D2 grade alloy steel (60 RC hardness) | Shell | Custom-made | |
Pipe coupling – OD=6.35 cm, ID=6 cm, L=4.4 cm | LSU | Custom-made | |
Steel plate ring – OD=10.16 cm, ID=5.76 cm, thickness=6.35 mm | Louisiana Cutting | Custom-made | |
Class H Cement | LaFarge | 04-16-12 / 14-18 | |
Defoaming agent – D-Air 3000L | Halliburton | n/a | |
Bentonite clay | LSU | n/a | |
Calcium hydroxide | LSU | n/a | |
Expansion Fixture | Shell | Custom-made | |
Pressure transducers | Omega | PX480A-200GV | |
Teflon tubing | Swagelok | PB0754100 | |
Union tee | Swagelok | SS-400-3 | |
Elbow union | Swagelok | SS-400-9 | |
Female elbow | Swagelok | SS-400-8-8 | |
Port connector | Swagelok | SS-401-PC | |
Forged body valve | Swagelok | SS-1RS4 | |
Tube adapter | Swagelok | SS-4-TA-1-2 | |
Pipe lubricant | E.F. Houghoton & Co. | 71323998 | |
Instant Galvanize Zinc Coating | CRC | 78254184128 |