Cheatham

This is the 25th anniversary issue of SPE Drilling & Completion (SPEDC). So many changes have occurred since SPEDC Volume 1 Number 1 was published in February 1986. Technology that we take for granted today either did not exist then or was just emerging.

Major advances in communication and information technology have played a key role in our industry. Imagine what it was like in 1986 when wells were drilled and completed without the Internet, mobile phones, personal computers, email, search engines, texting, broadband, webinars, and smart phones. True, some of these technologies may be merely nice to have, but others are essential cornerstones of well construction.

Significant improvements have also occurred in drilling and completion technology--such as horizontal wells, 3D/4D seismic, polycrystalline-diamond-compact bits, measuring-while drilling/logging-while drilling, rotary steerable systems, top drives, real-time operations centers, expandable pipe, multilateral wells, intelligent wells, underbalanced drilling, managed-pressure drilling, casing drilling, synthetic-based fluids, hydraulic fracturing, rig mechanization and automation, and many more.

As we mark this anniversary, it seemed appropriate to examine changes in SPEDC over the years. To this end, Chris Carpenter, SPE Managing Editor of Journals, supplied the table of contents for every issue from 1986 to the present. These TOCs are available at http://www.spe.org/go/spedc and provide the basis for the following reflections.

1986—SPE Drilling Engineering Is Born

When it was established in 1986, the journal was called SPE Drilling Engineering. During this inaugural year, 47 papers were published in six bimonthly issues. Domestic subscriptions for SPE members cost USD 17.50. Volume 1 Number 1 contained seven papers on the following topics: reducing cost per foot in drilling deep, hard rock; clear brine drilling fluids; polymer drilling fluids for improved shale stability; cuttings transport experiments in directional wells; air drilling in the Black Warrior Basin to address lost circulation; casing wear; and drilling using foam/mist combination. It surprised me to realize that the topics themselves are still relevant today. Of course, the specific technology discussed today would be quite different. Nevertheless, it is noteworthy that the same general categories of problems still exist 25 years later. In 1986, the first discussion of papers by readers appeared in Volume 1 Number 5; it contained four discussions and one reply by an author.

2010—SPE Drilling & Completion Is 25 Years Old

In 2010, 56 papers were published in four quarterly issues in SPE Drilling & Completion. (The journal format changed to quarterly in 1987, and the journal name changed in March 1993.) Subscriptions for SPE members cost USD 70 for print + online and USD 45 for online only. Unfortunately, there are no discussions of any papers published in 2010. In fact, such discussion is rare in recent years. Why is this? Debate of important and controversial issues in a public forum can accelerate progress. At a minimum, such debates can stimulate interest. Do readers today use other means to discuss papers? Or is everyone simply too busy? A convenient method already exists online at the SPEDC website to submit a discussion for each paper. If readers began submitting online discussions in sufficient quantity, then SPE would look into a type of notification system that would update subscribers on new discussions. Write to let me know your thoughts on discussions of papers.

Some Noteworthy Papers from 1986 to 2004 in My Humble Opinion

From 1986 to 2010, approximately 1,000 papers were published in SPEDC. Starting with the March 2005 issue, all papers are available to subscribers in online archives, so you can access them for free. However, papers published from 1986 to 2004 are available only through OnePetro and are not free. Therefore, to get a sense of when SPEDC first published papers on important technologies, I scanned through the tables of contents from 1986 to 2004 that Chris provided. The following 35 papers seem especially noteworthy in relation to industry firsts:

• First paper with deepwater in the title--August 1986.
• First paper on top drives--December 1986.
• "Wellsite Information Transfer Specifications (WITS) for Digital Rig-Site Data"--December 1989.
• "Hydraulic Fracturing Slurry Transport in Horizontal Pipes--September 1990.
• "Bit Whirl--A New Theory of PDC Bit Failure"--December 1990.
• First paper on bottomhole-assembly whirl--also in December 1990.
• "Instrument Performance Models and Their Application to Directional Surveying Operations"--again in December 1990--that was quite an issue!
• First paper on traveling-cylinder method for well-collision avoidance--March 1991.
• First paper on extended-reach drilling--June 1991.
• "Development of Lightweight Steel Drillpipe With a 165-ksi Yield Strength"--September 1991.
• First horizontal well in Gulf of Mexico--June 1992.
• "The Genesis of Torsional Drillstring Vibrations"--September 1992.
• "Dynamic Stability of Drillstrings Under Fluctuating Weight on Bit"--June 1993.
• "The Influence of Chemical Potential on Wellbore Stability"--September 1993.
• "Coiled Tubing Drilling"--also September 1993.
• "Casing Design for Trapped Annular Pressure Buildup"--June 1994.
• "Strategies and Structures for Drilling and Service Contracts in the 1990s"--September 1994.
• "Case Histories and Application of a New Slimhole MWD Multiple-Depth-of-Investigation Resistivity Sensor"--December 1996.
• "Drillstring Component Mass Imbalance: A Major Source of Downhole Vibrations"--also December 1996.
• "Gravel Placement in Horizontal Wells"--June 1997.
• "Downhole Measurements of Synthetic-Based Drilling Fluids in an Offshore Well Quantify Dynamic Pressure and Temperature Distributions"--September 1997.
• "Evaluation and Selection of Drill-In-Fluid Candidates To Minimize Formation Damage"--also September 1997.
• "Field Experience with Multilaterals in the Idd El Shargi North Dome Field, Qatar"--March 1998.
• "Pressure-While-Drilling Data Improve Reservoir Drilling Performance"--also March 1998.
• First rotary-steerable system paper--June 1998.
• First paper on mixed-metal oxide drilling fluids--September 1999.
• First paper on casing drilling--March 2002.
• First paper on dual-gradient drilling--December 2002.
• First intelligent completion in Gulf of Mexico--March 2003.
• "Real-time Specific Energy Monitoring Enhances the Understanding of When to Pull Worn PDC Bits"--also March 2003.
• "Otter: A 21-Kilometer Subsea Tieback with Dual Electric Submersible Pumps"--March 2004.
• "Selective Floatation of Casing from a Floating Vessel"--June 2004.
• "Imaging Unstable Wellbores While Drilling"--December 2004.
• "A Method for Isolating Pressure Depleted Zones with Solid Expandable Tubulars"--also December 2004.
• "Real-time Monitoring and Control of Water Influx to a Horizontal Well Using Advanced Completion Equipped with Permanent Sensors"--again December 2004!

Clearly this highly unscientific selection is biased towards my own experiences and interests. I would be interested in reading your list if you care to share it.

People Make the Difference

The marking of our journals 25th anniversary represents a major achievement. Many people have contributed over the last quarter century, including authors, subscribers, reviewers, and SPE staff.

Currently, SPEDC has over 150 technical editors (TEs) who review papers submitted for peer review. (Since 2009, the SPE peer-review system allows all seven peer-reviewed journals to use each other’s TEs. While this is a good thing, it does make it difficult to obtain a precise count of TEs for SPEDC.) We salute their devotion and service. Each year, associate editors (AEs) select the Outstanding TEs based on quality, timeliness, and number of reviews. Our Outstanding TEs for 2010 are recognized elsewhere in this issue.

In the November 2010 issue of Journal of Petroleum Technology, SPE President Labastie discussed peer review in his article titled "En Route." He noted the significant improvement for all SPE journals in average time to return an initial decision to authors--from 225 days in 2006 to 98 days currently. SPEDC has achieved a similar improvement over this period. Presently, our average time for returning an initial decision to authors is 86 days.

The primary reason for the improved decision time is the hard work and commitment by our reviewers. Special recognition goes to our ten AEs, who are all experts in their field. Each AE is responsible for specific subjects as shown below, with some overlap to accommodate potential conflicts of interest and work load (after all, each one is a volunteer!): Carl Thaemlitz--drilling fluids, completion fluids, and chemistry; Christoph Zerbst--completions planning, design, and installation, sand control, hydraulic fracturing, gravel packing, cuttings re-injection, safety in design and engineering, intelligent completions, and multiphase flow in wells; John Thorogood--directional drilling and surveying, drilling project management, wellbore design/construction, human factors in health, safety, security, environment and social responsibility, deep water, harsh environment, and Arctic operations; Max Medina--hydraulic fracturing, advanced tubing/casing design, completion design and planning, sand control, perforating, thermal completion design, steam-assisted gravity-drainage production and well construction, and intelligent completions; Fionn Iversen--real-time drilling applications, drilling automation, drilling process control and modeling, flow modeling, information systems and data use, measurement and control, well control, and multiphase flow in wells; Kaibin Qiu--wellbore stability, geomechanics, sanding, compaction and subsidence, and pore pressure; Shilin Chen--drill bits, drilling dynamics, downhole tools and equipment, and directional drilling; David Kulakofsky--cement, cementing, and zonal isolation; John Mason--completion equipment, planning, design and installation, perforating, hydraulic fracturing, intelligent completions, and completion and intervention operations; and Deepak Gala--managed-pressure drilling, underbalanced drilling, air drilling, casing and liner drilling, well control, blowout preventers, and blowout control.

Equally essential to SPEDC is the SPE staff, whose skills and commitment are first class. On behalf of the TEs, AEs, and our readers, we express our heartfelt thanks to each of them. Special thanks go to Stacie Hughes, Mattie Tanner, Glenda Smith, Chris Carpenter, and Victoria Preston.

Next 25 Years and Beyond

Carl Sagan famously said, "We live in a society exquisitely dependent on science and technology, in which hardly anyone knows anything about science and technology." The truth of this statement is worth pondering. How can our society improve our collective ability to understand the ever-changing technology that underpins not only our daily existence but also our industrial progress?

Journals such as ours that use peer review are a key tool in this quest for understanding technology. These journals provide a level of quality control while ensuring that an industry’s technology is written, disseminated, shared, and preserved for future generations. We are grateful to our predecessors for having started SPEDC to publish the best papers on drilling and completing oil and gas wells. We humbly carry on their hard work, noble vision, and dedication to excellence so that future generations will continue to enjoy the same benefits we derived from the first 25 years of SPEDC.

What does the next twenty-five years and beyond hold for SPEDC? Again, we quote President Labastie from his "En Route" article in the November 2010 J. Pet Tech: "In closing, I would say that peer-reviewed journals are one strong element of the distinctive character of SPE. They have done a lot in the past for the prestige of our Society. They will do a lot in the future, as our industry will certainly become more technology intensive and will need more efficient ways to exchange high-quality technical knowledge."

Now to the papers. This issue contains fourteen papers on the following topics: general drilling--six papers, wellbore stability, geomechanics, and drilling fluids--five papers, hydraulic fracturing--one paper, and managed-pressure drilling--two papers.

General Drilling

Automation has had enormous impact on safety, efficiency, and risk reduction in other industries such as aviation. Similar opportunity exists today for drilling automation. Recently both SPE and IADC formed technical sections on drilling automation. How are these two industry committees different in their objectives, goals, and activities? Our first paper answers these questions and more. Drilling Automation: Technologies, Terminology, and Parallels With Other Industries describes concepts for drilling automation that are already in operation or under development. It also proposes a classification scheme for key categories. Automation in the aviation industry is described in relation to drilling automation. Potential pitfalls are discussed that relate to ergonomics, human factors, and avoiding "overautomation" ("Dave? … Just what are you doing, Dave?" from HAL in 2001: A Space Odyssey). The paper concludes that early adoption of standardization is critical for rapid development of drilling automation. This paper comes at a crucial time because such standards are currently under development for terminology, data, and interfaces. The authors invite all interested companies and individuals to join the effort.

Cementing across salt zones was done as early as the late 1940s around salt domes in the Gulf of Mexico. More recently, subsalt reservoirs have been discovered in basins around the world, such as the Gulf of Mexico, the North Sea, West Africa, eastern Canada, and Brazil. Field development in these subsalt reservoirs requires successful cementation of casing strings that contact thousands of feet of salt. Cementing Casing Strings Across Salt Zones: An Overview of Global Best Practices explores the issues and solutions associated with cementing casing strings across extensive salt sections. Key concerns are salt movement (creep and flow), salt dissolution and its impact on cement strength, and determination of safe mud weight when drilling through and immediately below salt. This paper is essential reading for anyone interested in the state of the art on this topic.

High-Integrity Wellbore Surveying proposes a new set of minimum requirements for survey validation. It is a product of collaborative work by the SPE Wellbore Positioning Technical Section. The paper documents weaknesses in conventional directional-surveying quality control (QC) procedures. Theoretical considerations, statistical analyses of real survey data, and actual examples of failed surveys that passed conventional QC procedures without detection are presented. The need for survey QC tests that validate survey accuracy claims has been previously described by several authors, but this paper provides the first comprehensive study of the contribution that such tests make to directional-survey reliability. This paper systematically evaluates each of the QC tests and tabulates which error terms are controlled by which tests. The results point out weaknesses in current common practice and demonstrate the significant effort required to achieve appropriate control. This paper also deals with error-model validation. Error models are usually based initially on manufacturing tolerances and estimates of reference tolerances and environmental effects. QC tests derived from models may under- or overestimate actual system performance. As statistically significant quantities of field survey data are accumulated, it is possible to reverse the QC process and test the model's compliance with the data. This practice has also been previously proposed, but it is not commonplace and rarely extended to the global applicability of tool-error models. This paper describes two methods of validating error models using cumulated QC data.

Multiwell thermal interaction will alter the wellbore temperatures as well as formation temperatures in the interwell zones and also farther out from the well template. The change in temperature profile relative to a single well can be significant. Multiwell Thermal Interaction: Predicting Wellbore and Formation Temperatures for Closely Spaced Wells presents a methodology based on standard industry thermal/hydraulic-modeling software and a finite-element model (FEM) in a loosely coupled, iterative analysis that assumes steady-state conditions. A case study for high-pressure/high-temperature offshore field development is presented. The multiwell disturbance on formation and wellbore temperatures affects well design, facilities planning, and operations. Annular pressure buildup, wellhead movement, tubular-stress design, cement-slurry design, subsidence/compaction effects, and facilities health and safety issues can all be affected. If multiwell thermal interaction is not taken into account, then load events, such as annular pressure buildup, wellhead movement, and thermal-induced stresses may be underestimated. In developing this model of multiwell thermal interaction, the objective was to provide a practical, robust method that incorporates standard industry tools and established analytical models. The proposed method can be used to predict both the wellbore temperatures and surrounding formation temperatures.

Managing Drilling Vibrations Through BHA Design Optimization employs a bottomhole assembly (BHA) design evaluation process based on a frequency-domain lateral-dynamic model in both predrill and post-drill hindcast modes. The method conducts a comparative analysis of several specific BHA designs. BHA lateral vibrations are characterized such that alternative BHA configurations may be developed and compared directly with a proposed baseline assembly. In the hindcast mode, the BHA model can be operated at the recorded weight on bit and rotary speed to generate corresponding model results in time or depth, and these values can be compared with the measured performance data. A case study of a BHA with a motor and roller reamer is described, with corresponding field date for four original BHAs and four redesigned assemblies. A second case study shows model and field results for two rotary steerable assemblies. The model employs two vibration modes for each candidate BHA--lateral bending and "twirl," or BHA whirl. In the lateral bending mode, a constant reference side bit force is applied, and the magnitudes of the response are compared along each BHA. In the twirl mode, a reference mass eccentricity is applied. Index values have been developed to summarize dynamic performance to indicate which BHA design is preferred and identify operating sweet spots. The authors have found that the relative performance assessment based on use of this model is a good predictor of field results.

Probabilistic estimation of well duration has been common practice for more than a decade. This paper asserts that it is not possible to use these previous state-of-the-art methods to obtain sufficiently accurate predictions. In Probabilistic Well-Time Estimation Revisited, a database of 118 central North Sea wells was analyzed for nonproductive time (NPT) from the original daily drilling reports. Results showed the data actually underestimated NPT by 19.7% on average. Train wrecks (mechanical NPT more than 2.5 days long) were only 4% by number but represented 50% by duration. It was found that "ordinary" mechanical NPT, train wrecks, waiting on weather in open water, and waiting on weather with riser connected are all statistically distinct, with very different occurrence frequencies and probability distribution functions. Earlier models did not observe this important distinction. The authors claim their analysis technique is accurate and that it may be applied as a template to other areas after proper local calibration. They have published their entire data set and the full technical basis of their method because they believe lack of such information has held back progress in this area by hindering the debate essential to bring the subject to a mature level. Publishing full details of all steps in the analysis makes the paper a little long, but we agree with the authors that it is essential to stimulate debate.

Wellbore Stability, Geomechanics, and Drilling Fluids

Wellbore strengthening has been a hot topic in recent years. Case History: Successful Wellbore Strengthening Approach in a Depleted and Highly Unconsolidated Sand in Deepwater Gulf of Mexico discusses drilling through the depleted formations at Total's Matterhorn tension-leg platform in deepwater Gulf of Mexico using a flat-rheology synthetic-based fluid engineered with a high concentration of bridging particles to impart a strengthening effect on the formation. A drill-ahead method of applying the treatment to the formation was used (rather than a pill spotting method) because the risk of fracturing the reservoir existed with the mud weight needed to control the caprock. The paper describes the laboratory approach to fluid design and the operational practices to apply the treatment on location. A post mortem analysis compares formation breakdown pressures taken from fracturing operations to actual wellbore pressures experienced while drilling and cementing to demonstrate that a strengthening effect was realized. The results imply that using such a designer fluid can have a strengthening effect on depleted/unconsolidated formations, in which some operators have had limited success in applying wellbore strengthening techniques.

Significant fluid loss while drilling through fractured formations is a major problem. A common method of dealing with massive losses is to apply lost circulation material (LCM). The authors are convinced that use of LCMs is not the only way of reducing mud losses. In some cases, LCMs may result in permanent damage of productive fractured zones. Field experience shows that type and rheological parameters of the drilling fluid have a strong impact of the rate and volume of losses while drilling through fractured formations. This observation led to the work that is documented in Quantitative Analysis of Mud Losses in Naturally Fractured Reservoirs: The Effect of Rheology, which develops a mathematical model for Herschel-Bulkley (yield-power law) drilling fluid losses in naturally fractured formations. It investigates effects of rheological properties such as yield stress and flow behavior index on mud losses. Results indicate that yield stress can control the ultimate volume of losses while the shear-thinning effect can tremendously affect the rate of losses. Therefore, mud losses in fractures can be minimized by optimizing the rheology of the drilling fluid. The model allows for quantitative analysis of losses that take into account fluid rheology to characterize the fractures. Hydraulic aperture of conductive fractures can be obtained by continuously monitoring mud losses and fitting field records of mud losses to the model. Estimates of fracture width is valuable for designing sealing treatments and other potential cures for lost circulation. The proposed model is useful for drilling and completion design. A practical application of the proposed technique is demonstrated through a field example of mud loss measurements in a fractured well in the Gulf of Mexico. The paper concludes that use of LCM in conjunction with rheology adjustment is recommended as a better way of mitigating fluid losses than the use of LCM alone.

Previously the theory of rock failure based on planes of weakness has been applied primarily for layered rocks. Here it is extended to significantly weaker mudstones showing strength anisotropy. Wellbore-Instability Predictions Within the Cretaceous Mudstones, Clair Field, West of Shetlands describes a study conducted to address problems in earlier high-inclination wells that experienced unstable wellbores in Cretaceous mudstones overlying the Clair oilfield. Results of this study were used to plan an ERD well, which was successfully drilled, cased, and brought on stream using the plane of weakness modeling of wellbore instability. Although the magnitude of the mechanical anisotropy in mildly compacted mudstones is small compared to that in the hard, brittle rocks such as slates and schists for which the weak-plane model was developed, the inherent weakness of these mudstones means that even a small additional weakening can have a critical impact on wellbore stability and drilling success. The characteristic signature of the weak plane failure mode is a pronounced increase in the mud weight required for wellbore stability at medium inclinations and a small additional increase in the mud weight required for stability at high inclinations. Indications of unexpected instability at (say) 20 to 40° should be closely investigated and not dismissed as a consequence of drilling practices. They may be an early indicator of trouble at moderate to high inclinations; conversely, trouble at moderate inclinations need not imply that there is no drilling window at high inclinations. A similar failure mechanism may occur in other parts of the world. Therefore, the method developed here for the Clair field may also be useful elsewhere.

Numerous casing and production-liner deformation/failure problems have been reported in high-porosity chalk formations in both the overburden and the reservoir sections, causing costly operations problems that prevent workovers and recompletions. A Comprehensive Modeling Analysis of Borehole Stability and Production-Liner Deformation for Inclined/Horizontal Wells Completed in a Highly Compacting Chalk Formation presents the results of studies performed to investigate stability of an openhole, cemented liner, and uncemented-liner completions in a highly compacting chalk formation. The effects of critical cavity dimensions caused by various acid stimulation techniques were also investigated. Analytical and numerical models were developed for evaluating cavity-induced axial compression collapse of production liners. Model results indicate that the risk of the cavity-induced axial compression collapse substantially increases for short perforated intervals stimulated with large acid treatments. Increasing the perforation-interval lengths along the entire liner axis results in more uniform acid distribution and will greatly reduced the chance of axial compression collapse caused by localized cavity deformation. Key completion design criteria and stimulation strategies were developed for wells completed in highly compacting chalk reservoirs to reduce risk of casing and liner mechanical problems.
Drilling in depleted and compacted fields can cause costly problems. The Valhall field in the Norwegian sector of the North Sea has experienced significant reservoir compaction in weak chalks, exceeding 10 m in some places. Sixty Days Ahead of Schedule: Reducing Drilling Risk at Valhall Using Computational Geomechanics presents a novel approach for predicting local stress changes in the overburden induced by reservoir compaction and subsidence, whereas previous work has often focused on depletion-induced fracture gradient changes in the reservoir itself. The new technology is based on a history-matched full-field FEM geomechanics model to calculate stresses, strains, and displacements. Results are exported from the FEM to geological modeling software to perform wellbore stability calculations. In this environment, users can incorporate 4D seismic from the permanent life-of-field seismic array at Valhall. By calculating the operational mud weight window over a high-risk interval in the overburden, a good correlation to historical NPT was found. The method is used in detailed well planning where moving the well 50 m in one direction can be the difference between problem-free drilling and huge drilling challenges. The paper presents application of the technology on a new water injector delivered 60 days ahead of schedule with reduced costs of approximately USD 20 million. The application potential for this technology is significant even in reservoirs with less compaction than Valhall, as in high-pressure/high-temperature fields and highly deforming reservoirs.

Hydraulic Fracturing

A Crosslinkable Synthetic-Polymer System for High-Temperature Hydraulic-Fracturing Applications describes a new hydraulic fracturing fluid capable of service temperature up to 232°C. The fluid uses a synthetic polymer that is crosslinkable to metal ions to generate high viscosity. The synthetic polymer fracturing gel overcomes thermal limitations of traditional guar and derivatized guar-based fracturing fluids. Several advancements have been made in the development of this technology to maximize the efficiency of crosslinking and to give an effective breaking profile, resulting in good laboratory gel cleanup in proppant pack. Research efforts have yielded a fracturing fluid with good fluid stability at high temperatures to create better proppant transport and placement. The crosslinking system can be tuned for crosslinking onset as a function of temperature, thereby allowing optimization to specific wellbore conditions. The system has been applied in south Texas at temperatures approaching 232°C.

Managed-Pressure Drilling

Solid case histories are highly useful instruments to transfer knowledge from one area to another. Managed-Pressure Drilling Using a Parasite Aerating String is such a case history that chronicles drilling in Piceance basin in western United States. The basin presents significant challenges for lost circulation and stuck pipe. This paper describes a new technique for this basin that involves acquiring real-time equivalent-circulating-density data and control of annulus mud weight through air injection in a parasite string. The method was successful in achieving the desired major reduction in fluid losses during drilling by controlling equivalent-circulating density.

Pressure maintenance within safe bounds and minimization of influx of fluids from the formation during a kick are basic concerns of well control. Managed-pressure drilling (MPD) offers improved capabilities over conventional well-control methods to address these concerns. Improved Kick Management During MPD by Real-Time Pore-Pressure Estimation asserts that the issue of developing an appropriate process to control flow during MPD operations has not been thoroughly addressed yet. By definition, MPD does not encourage influx into the wellbore. Nevertheless, in some cases an influx will occur. When a kick is taken, obtaining an accurate estimate of the pore pressure at the influx zone as quickly as possible will assist regaining control of the well. The proposed method estimates formation pore pressure automatically on basis of real-time measurements when a gas kick is taken during MPD. It relies on characteristics of the pressure-buildup curve. A North Sea well is used as test case geometry, and an advanced hydraulics model is used in a virtual well in computer simulations for presented results. The method is demonstrated to maintain pressure within desired bounds and reduce formation fluid influx, thereby reducing the risk of hole-stability problems and the cost associated with NPT.

That wraps up this issue. On behalf of your entire Editorial Review Committee, thank you for your continued support of SPE Drilling & Completion.

Curtis Cheatham
cheatham@spemail.org