Optimizing HTHP Cementing Operations

Optimizing HTHP Cementing Operations John Shaughnessy; John Shaughnessy BP America Search for other works by this author on: This Site Google Scholar John Helweg John Helweg Schlumberger Dowell Search for other works by this author on: This Site Google Scholar Paper presented at the IADC/SPE Drilling Conference, Dallas, Texas, February 2002. Paper Number: SPE-74483-MS https://doi.org/10.2118/74483-MS Published: February 26 2002 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Shaughnessy, John, and John Helweg. "Optimizing HTHP Cementing Operations." Paper presented at the IADC/SPE Drilling Conference, Dallas, Texas, February 2002. doi: https://doi.org/10.2118/74483-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE/IADC Drilling Conference and Exhibition Search Advanced Search AbstractSuccessful cementing jobs are critical to economically completing HTHP wells. BP and Schlumberger Dowell have consistently been successful cementing wells at total depths between 22,000' and 23,000' and maximum temperatures of 400°F. The proof of successful cement work is demonstrated with record production rates for the state of Louisiana and achieving isolation in sands with over 10,000 psi depletion. The optimization methods and approach will be discussed along with problems experienced and subsequent solutions. Over 15 such wells have been drilled in Louisiana during the last 5 years. This paper will also address the philosophy and procedure of cementing production tieback casing to the surface by reverse circulating.IntroductionThe Tuscaloosa Trend1,2 is a 30 mile wide band of sands running east west just north of Baton Rouge, Louisiana. Some of the most difficult drilling conditions in the Trend are in the Judge Digby Field3. The wells are drilled to a total depth of 23,000', have a bottom hole temperature up to 400° F and maximum bottom hole pressures between 17,000 and 20,000 psi. Figure Numbers 1, 2 and 3 are a wellbore sketch and the temperature and pore pressure plots for a typical field well.In 2000, production from a new well set a Louisiana state production record of 92 MMCFD. The field also has the deepest completion in the state history at 22,200'. The record production rates have contributed to depletion of the volumetric reservoirs located in the upper intervals of the producing Tuscaloosa sands, which has resulted in up to 13,000 psi differential pressure while drilling these depleted sands4.A successful primary cement job is critical to achieving the high production rates and significant depletion. Remedial cementing, required due to poor primary cementing, has been unsuccessful in isolating water sands. The cost of remedial cementing is very high. The difference between an economically successful and a marginal well is the primary cement job. Failure of the primary cement job can result in additional drilling rig time or a rig workover, reduced production rates or increased water production rates and subsequent water disposal costs.Proper placement is critical in HTHP cementing. Many of the wells have very close tolerance between pore and fracture pressure thresholds. To overcome these obstacles, computer aided designs are used extensively. In order to provide the best model, very detailed information needs to be shared between the operator and the cementing service company.On many wells, the drilling assembly and the wellbore is input as the first step. The drill fluid model at heated temperatures is input and the computer model is used to simulate pumping mud at drill rates for the hole section to determine equivalent circulating densities. These numbers are then used as a baseline for designing rates for the cement placement assuming there are no problems with lost circulation while drilling.With the above baseline, all fluid properties at elevated temperatures are input along with any deviation data and centralization. Stand-off calculations are generated from the caliper log and deviation survey. This data is then used to determine needed flow rates for good mud removal based on effective laminar flow in an eccentric annuli5. Keywords: slurry, plug, shaughnessy, liner hanger, packer, drilling fluid management & disposal, cement slurry, production liner, drilling fluids and materials, production rate Subjects: Drilling Fluids and Materials, Casing and Cementing, Drilling fluid management & disposal This content is only available via PDF. 2002. IADC/SPE Drilling Conference You can access this article if you purchase or spend a download.

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