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A list and description of some of our products.

A list and description of some of our products.

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  • 1. Professional fluid services, llc PRODUCT LINE TECHNOLOGY QUALITY AND TRUST For Additional Information Please Visit Our Web Site at www.professionalfluid.com ENGINEERED SOLUTIONS FOR: LOSS CIRCULATION MATERIALS CROSS LINK POLYMER TECHNOLOGY CEMENT SPACERS WIRE LINE CEMENT AND RESIN KITS 24 Hour Telephone: RESIN SYSTEMS 888.862.7177 CEMENT ADDITIVES Fax: 337.984.6652 LAB TESTING E-mail: pfsllc@ultrasealinc.com ON SITE CONSULTING
  • 2. Professional Fluid Services, LLC TABLE OF CONTENTS Section 1: Loss Circulation Materials Ultra Seal® XP Page 2, 4 & 6 Ultra Seal® C Page 3, 5 & 6 Ultra Seal® TG Page 7 & 8 Ultra Seal® Plus Page 9 & 10 Pro Seal® Fine Page 11 & 13 Pro Seal® Coarse Page 12 Recommended Treatments Page 14 Particle Size Distribution Ultra Seal® XP and Ultra Seal® TG Page 15 Particle Size Distribution Ultra Seal® C and Ultra Seal® Plus Page 16 Section 2: Cross Link Polymer Technology Poly Plug® Page 17, 18 & 19 Poly Plug® (CLEAR GEL) Page 20 & 21 Ultra Squeeze® Page 22 & 23 Section 3: Cement Spacer Ultra Spacer® Page 24,25 & 26 Ultra Surf® Page 27 Ultra Spacer® Case Histories Page 28-32 Section 4: Wire Line Kits Ultra Bond® Page 33-34 Ultra Set® Page 35-36 Pro Bond™ Page 37 Pro Bond™ SSW Page 38 Ultra Seal® S (SEALANT) Page 39 Liquid Bridge Plug® Page 40 Section 5: Resin Liquid Bridge Plug® Page 41 Section 6: Cement Additives GMA #1 (GAS MIGRATION ADDITIVE) Page 42 ECT® KIT Page 43 Section 7: Customer List References Page 44 Section 8: Services Lab Testing Page 45 On Site Consulting (Cement and Water Shut Off) Page 45 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 3. ULTRA SEAL® Professional Fluid Services, LLC AUGUST 2006 PRODUCT DESCRIPTION PRODUCT DATA SHEETS Unlike most fiber That's one reason why products, Ultra Seal-XP® Ultra Seal® is available is a blend of different ULTRA SEAL-XP® in four different product types of cellulose fiber grades: Ultra Seal® XP groups, filtrate control & Ultra Seal® TG SCM agents and physical ULTRA SEAL-TG® is a fine-grade material lubricants, not just one often used as a primary fiber type. Both preventative; Ultra laboratory testing and ULTRA SEAL-C® Seal® C LCM is a experience on the rigs similar product continues to prove that manufactured in a the unique Ultra Seal® ULTRA SEAL-PLUS® course grade required blend provides consis- for severe or total loss of tently superior returns; Ultra Seal® performance. PRO SEAL® FINE Plus LCM is a Every drilling situation is proprietary blend of different, so there is no fibrous, granular and single answer to loss PRO SEAL® COARSE flake materials designed circulation problems. specifically for massive loss circulation. Special Points of Interest: • Excellent for Controlling Differential Sticking demand more efficient, PRODUCT BENEFITS • Seals Micro-Fractured cost effective operations, the need to Shale minimize lost-time, such • Reduces Torque & Drag as differential sticking tests, Ultra Seal® DFA is Due to the extensive • Solves Loss Circulation and loss circulation, has research required to the most effective and • 90-100% Return Perm become imperative. By develop the Ultra Seal® cost efficient drilling fluid using Ultra Seal® DFA , • 70% Soluble in Bleach DFA product line, the additive of its type on many drilling related quality of raw materials the market today. problems can be selected for the As the oil and gas prevented and manufacturing process industry worldwide controlled. and the conducting of continues to demand numerous quality control PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com Page: 2
  • 4. ULTRA SEAL-XP® SCM(FINE) DESCRIPTION: Ultra Seal® XP is CONCENTRATIONS: a blend of specific micro sized Differential Sticking Prevention: cellulosic fibers combined with a For excessive torque and drag, blend of organic polymers and sweeps of 8-25 lbs/bbl of Ultra lubricity enhancers. Seal® XP is recommended. For APPLICATION: Ultra Seal® XP is extended intervals, Ultra Seal® XP designed to aid in the control of can be added system wide in fluid losses to the well bore, as well concentrations of 4-8 lbs/bbl. as promote the anti friction Seepage Control: characteristics of a drilling fluid. Sweeps of 12-25 lbs/bbl of Ultra Ultra Seal® seals off low pressure Seal® XP combined with up to zones, which in turn reduces rotary 12.5 lbs/bbl Ultra Seal® C is torque and drill string drag that is recommended. present in these differential Packaging: 25 lb sacks, 48 per pressure environments. pallet. Ultra Seal® XP is compatible with both OBM and WBM systems and is coated with a mineral oil. ULTRA SEAL-C® LCM (MEDIUM) “If ULTRA SEAL® C or ULTRA DESCRIPTION: Ultra Seal® C is CONCENTRATIONS: a blend of cellulose vegetable SEAL® Plus is not successful in Partial Losses: fibers and is blended in a medium solving the loss circulation Sweeps/spots of Ultra Seal® C in to coarse grade. The product is problem, consider the use of concentrations of 25 lbs/bbl in coated with a food grade mineral POLY PLUG®. See POLY PLUG® addition to 12.5 lbs/bbl of oil and is compatible with both Ultra Seal® C is recommended WBM and OBM systems. product data sheet for more across the loss zone. information.” APPLICATION: Ultra Seal® C is Total Losses: applied in the form of sweeps or spots within the active drilling fluid. A 50-100 bbl pill of Ultra Seal® C along with 40-60 lbs/bbl Ultra Packaging: 11.36 kg sacks, 42 Seal® Plus should be mixed in the sacks per pallet. slugging tank and spotted across the loss zone. ULTRA SEAL-PLUS® LCM (COARSE) DESCRIPTION: A blend of Ultra CONCENTRATIONS: Seal® XP , Ultra Seal C® and Loss Circulation: additional (larger) sealing agents. A 50-100 bbl pill of 40-60 lbs/bbl The large particle array is Ultra Seal® Plus should be mixed beneficial in establishing a stronger and spotted across the loss zone. initial bridge across the thief zone. By the inclusion of these larger particles, effective control of rigid Packaging: 40 lb sacks, 28 sacks type fractures, vugular or per pallet. unconsolidated formations can be achieved. Ultra Seal® Plus is the LCM portion of POLY PLUG® Page: 3 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 5. PRODUCT DATA SHEET ULTRA SEAL® XP DESCRIPTION: Ultra Seal® XP is a patented blend of specific micro sized cellulose fibers, combined with a blend of organic polymers and lubricity enhancers. Ultra Seal® XP is compatible with both water and oil base mud systems. USES: SEALING MICRO FRACTURED SHALES SEEPAGE CONTROL TORQUE AND DRAG REDUCTION DIFFERENTIAL STICKING PREVENTION FEATURES: Ultra Seal® XP is designed to aid in the control of fluid losses to the well bore, as well as promote the anti-friction characteristics of a drilling fluid. Ultra Seal® XP seals of low pressure zones, which in turn reduces rotary torque and drill string drag that is present in these differential pressure environments. Ultra Seal® XP inhibits seepage loss to the formation, as well as restricting flow into depleted sands. TREATMENT: Ultra Seal® XP is used in concentrations of 4-25 lbs/bbl. PACKAGING: 25 lbs net weight in multi-wall paper bags. ( 48 bags per 44quot;X44quot; pallet) Page: 4 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 6. PRODUCT DATA SHEET ULTRA SEAL® C DESCRIPTION: Ultra Seal® C is a patented four particle blend of specific sized cellulose fibers, compatible with both water and oil base mud systems. USES: LOST CIRCULATION FEATURES: Ultra Seal® C has a broad particle size distribution and is designed to solve partial to total loss circulation. Ultra Seal® C is applied in the forms of sweeps and spots and is mixed with the active mud system. TREATMENT: Ultra Seal® C is used in concentrations of 25-50 lbs/bbl. PACKAGING: 25 lbs net weight in multi-wall paper bags. ( 42 bags per 44quot;X44quot; pallet) Page: 5 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 7. CASE HISTORY LOCATION: ULTRA SEAL-XP and ULTRA SEAL-C® Gulf Coast Page: 6 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 8. PRODUCT DATA SHEET ULTRA SEAL-TG® DESCRIPTION: Ultra Seal-TG® is a specific micro sized cellulose fibers, compatible with both water and oil base mud systems. USES: SEALING MICRO FRACTURED SHALES SEEPAGE CONTROL TORQUE AND DRAG REDUCTION DIFFERENTIAL STICKING PREVENTION FEATURES: Ultra Seal-TG® is designed to aid in the control of fluid losses to the well bore, as well as promote the anti-friction characteristics of a drilling fluid. Ultra Seal-TG® seals of low pressure zones, which in turn reduces rotary torque and drill string drag that is present in these differential pressure environments. Ultra Seal-TG® inhibits seepage loss to the formation, as well as restricting flow into depleted sands. TREATMENT: Ultra Seal-TG® is used in concentrations of 4-25 lbs/bbl. PACKAGING: 25 lb net weight in multi-wall paper bags. ( 48 bags per 44quot;X44quot; pallet) Page: 7 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 9. CASE HISTORY ULTRA SEAL-TG® LOCATION: EAST CAMERON AREA, GULF OF MEXICO FLUID TYPE: DIESEL OIL BASE, 16.0 LB/GAL An offshore Operator was making an open hole displacement of a water base system with a diesel oil base system when complete loss of returns occurred. Several attempts were made to regain circulation with competitive types of loss circulation materials. None of these attempts were successful. A 100 bbl sweep of Ultra Seal® TG, 25 lb/bbl concentration, was pumped around and full circulation regained. Final displacement was made and drilling resumed. The hole was then swept on a regular basis to control any seepage losses. Prior to logging the well a pill of Ultra Seal® TG was spotted on bottom to aid in control of any differential sand problems. Another pill was left on bottom during subsequent production pipe run. No problems were encountered during these procedures. Page: 8 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 10. PRODUCT DATA SHEET ULTRA SEAL-PLUS® DESCRIPTION: A patented blend of fibrous, granular and flake materials designed specifically for massive loss of circulation. This product was formulated to expand the existing positive qualities of the Ultra Seal® product line. USES: LOSS CIRCULATION FEATURES: Ultra Seal® Plus is a blend of Ultra Seal® XP, Ultra Seal® C and additional larger, sealing agents. This blend expands the superior range of particle sizes that are consistent with the existing product line. By the inclusion of these larger particles, effective control of rigid type fractures, vugular or unconsolidated formations and highly permeable thief zones can be achieved. TREATMENT: Ultra Seal® Plus is used in concentrations of 40-60 lbs/bbl. PACKAGING: 40 lbs net weight in multi-wall paper bags. ( 28 bags per 42quot;X48quot; pallet) Page: 9 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 11. CASE HISTORY ULTRA SEAL-PLUS® LOCATION: VERMILLION BLOCK 45 B-4 FLUID TYPE: Water Base Mud By sweeping the hole with Ultra Seal® Plus, a project TD of (9,654’) was reached without incident of differential sticking or loss circulation. Sands encountered from surface pipe to TD had formation pressures from 6.6 ppg to normal pressure. Ultra Seal® Plus was used in concentrations of 25 ppb and pumped every connection to prevent loss circulation and differential sticking. A 10 ppg mud weight was required at TD. Page: 10 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 12. PRODUCT DATA SHEET PRO SEAL® FINE DESCRIPTION: A water base or oil base compatible LCM product with a combination of vegetable and cellulose fibers. Pro Seal® Fine is coated with a food grade mineral oil to preferentially oil wet the product. USES: SEEPAGE CONTROL LOSS CIRCULATION TORQUE AND DRAG REDUCTION PREVENTION OF DIFFERENTIAL STICKING FEATURES: Pro Seal® Fine is designed to aid in the control of fluid losses to the well bore, as well as promote the anti-friction characteristics of a drilling fluid. Pro Seal® Fine seals of low pressure zones, which in turn reduces rotary torque and drill string drag that is present in these differential pressure environments. Pro Seal® Fine inhibits seepage loss to the formation, as well as restricting flow into depleted sands. TREATMENT: Pro Seal® Fine is used in concentrations of 4-25 lbs/bbl. PACKAGING: 25 & 50 lbs net weight in multi-wall paper bags. ( 40 bags per 42quot;X48quot; pallet) Page: 11 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 13. PRODUCT DATA SHEET PRO SEAL® COARSE DESCRIPTION: A water base or oil base compatible 4 particle size LCM product with a combination of vegetable and cellulose fibers. Pro Seal® Coarse is coated with a food grade mineral oil to preferentially oil wet the product. USES: SEEPAGE CONTROL LOSS CIRCULATION FEATURES: Pro Seal® Coarse has a broad particle size distribution and is designed to solve partial to total loss circulation. Pro Seal® Coarse is applied in the forms of sweeps and spots and is mixed with the active mud system. TREATMENT: Pro Seal® Coarse is used in concentrations of 25-50 lbs/bbl. PACKAGING: 40 lbs net weight in multi-wall paper bags. ( 40 bags per 42quot;X48quot; pallet) Page: 12 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 14. CASE HISTORY PRO SEAL® LOCATION: Buffalo, Texas FLUID TYPE: Water Base Mud The well was experiencing total loss circulation into a depleted sand. Various attempts to solve the losses with conventional LCM had failed. A 60 bbl pill with 10 ppb Pro Seal® Fine and 40 ppb Pro Seal® Coarse was mixed and spotted across the zone. The pill was allowed to soak for several hours before attempting to break circulation. After several hours the well was circulated with full returns. As a preventative measure, Pro Seal® Fine was added system wide at 6 ppb and maintained for the duration of the interval. No further losses were noted. Page: 13 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 15. GENERAL MIXING RECOMMENDATIONS RECOMMENDED TREATMENTS SEEPAGE LOSS (0-10 bbl’s per hour): Mix 12.5 lb/bbl of Ultra Seal® XP into the mud system and sweep the hole. In oil base mud systems Ultra Seal® TG can be substituted. PARTIAL LOSSES (10-20 bbl’s per hour): Mix 12.5 lbs/bbl to 25 lbs/bbl of Ultra Seal® XP and spot across the thief zone. For high permeability formations, add 25 lbs/bbl of Ultra Seal® C to 12.5 lbs/bbl of Ultra Seal XP® and spot across the thief zone. HEAVY LOSSES: Mix 40 lbs/bbl of Ultra Seal® C and 20 lbs/bbl of Ultra Seal® XP in the slug tank. This pill should be spotted above the thief zone and spotted out of the bit at slow pump rate. If the above formulation is not successful, consider 40-60 lbs/bbl of Ultra Seal® Plus. A minimum pill size of 50 barrels should be mixed and pumped. TOTAL LOSSES: Mix 40-60 lbs/bbl of Ultra Seal® Plus with the existing drilling fluid. A minimum of 100 barrels of pill should be pumped and spotted across the loss zone. It is recommended to allow the pill to soak for two hours before attempting to circulate. Should the above methods fail to regain circulation, consider a Poly Plug® pill, see product data sheets for more information. Page: 14 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 16. Particle Size Distribution of Ultra Seal® XP GILSON DRY SIEVE ANALYSIS CHART REFLECTS % DRY PRODUCT RETAINED ON EACH RESPECTIVE SCREEN Micron / Screen Size Wt. (10 gram sample) % (Cumulative) +1905m / 10 mesh 0.0 0% +279m / 50 mesh 0.34 4% +178m / 80 mesh 0.42 8% +140m / 100 mesh 0.46 12% +74m / 200 mesh 3.19 45% 5.32 55% minus 200 mesh -74m / - 200 mesh Totals 9.73 Particle Size Distribution of Ultra Seal® TG GILSON DRY SIEVE ANALYSIS CHART REFLECTS % DRY PRODUCT RETAINED ON EACH RESPECTIVE SCREEN Micron / Screen Size Wt. (10 gram sample) % (Cumulative) +1905m / 10 mesh 0.0 0% +279m / 50 mesh 0.6 6% +178m / 80 mesh 0.17 8% +140m / 100 mesh 0.81 17% +74m / 200 mesh 6.2 80% 1.97 20% minus 200 mesh -74m / - 200 mesh Totals 9.75% Page: 15 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 17. Particle Size Distribution of Ultra Seal® C GILSON DRY SIEVE ANALYSIS CHART REFLECTS % DRY PRODUCT RETAINED ON EACH RESPECTIVE SCREEN Micron / Screen Size Wt. (10 gram sample) % (Cumulative) +1905m / 10 mesh 0.11 1% +279m / 50 mesh 2.87 30% +178m / 80 mesh 0..82 39% +140m / 100 mesh 0.56 45% +74m / 200 mesh 2.55 71% 2.76 29% minus 200 mesh -74m / - 200 mesh Totals 9.67 100% Particle Size Distribution of Ultra Seal® Plus GILSON DRY SIEVE ANALYSIS CHART REFLECTS % DRY PRODUCT RETAINED ON EACH RESPECTIVE SCREEN Micron / Screen Size Wt. (10 gram sample) % (Cumulative) +1905m / 10 mesh 0.54 6% +279m / 50 mesh 3.96 47% +178m / 80 mesh 0.9 56% +140m / 100 mesh 0.25 59% +74m / 200 mesh 1.21 71% 2.75 29% minus 200 mesh -74m / - 200 mesh Totals 9.61% 100% Page: 16 PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com
  • 18. POLY PLUG® P r o f e s s i o n a l F l u i d S e r v i c e s, L LC AUGUST 2006 PRODUCT DESCRIPTION Poly Plug® consists of a XLR® is required. in pharmaceutical grade- Case Histories Ultra Seal-XLD® is a cross-linking agent, a silicone based de-foamer blend of high molecular and aids in reducing Deep Water 2 weight polymer and USA viscosity. Other de- Ultra Seal-Plus® , (a foamers should be pilot Sub Salt - 2 broad range of fibers to tested prior to use. Rubble slow seepage of the poly- Poly Plug® was mer into the formation). Tuscaloosa 2 developed for high Trend The cross-linking action is permeable formations. Oklahoma 3 a function of the loss zone targeted. Poly Plug® has a high temperature. For tem- viscosity thus enabling peratures below 100 Tuscaloosa 3 the polymer to stay with Trend degrees F an accelerator, Ultra Seal-XLA® is Tuscaloosa 3 required. For Trend temperatures above 125 degrees F, a delaying Special points of agent, Ultra Seal- interest: • Time Controlled • Robust Gel Chemistry • Density controllable with barite or hema- tite PRODUCT BENEFITS • Insensitive to H2S and CO2 • Temperature stable up to 400º F Poly Plug® effectively seals Poly Plug® can be Poly Plug® is a single sack, • Not intended for use in fractured, vugular, weak, circulated around the BHA pre-blended product and is the reservoir, product flowing and over pressured without the risk of stuck designed for ease of use. should be considered formations. pipe. Simply add one sack of permanent Poly Plug® per 42 gallons Poly Plug® can be pumped Poly Plug® develops of water. through the bit, mud minimal compressive motors and MWD/LWD strength, eliminating the Poly Plug® is compatible Page: 17 tools. risk of side track. with WBM and OBM. P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 19. Deep Water–Casing Shoe Estimated SAVINGS $700,000 After waiting 8 hours, the drill string Drilled out 13 3/8” casing shoe and was TIH and the Poly Plug pill was could not obtain the desired shoe test. tagged at 6,725’. Washing and reaming A 100 bbl 13.3 ppg Poly Plug pill was continued to a depth of 6749’ and the blended. The pill was blended in the drill string was then POOH to the rig slugging tank and took 3 hours and casing shoe. A FIT was performed to 45 minutes to build and weight up. 425 psi-, an EMW of 14.5 ppg. (Note: Only a gun line available for agitation, the Poly Plug was mixed Drilling Operations commenced with- out incident. Money saved on rig time through the rig hopper) when compared to a cement squeeze -The well was drilled to 6,749’ the drill was $700,000. string was POOH to 6,589’. 88 bbls of OPERATOR: EL PASO Poly Plug® was squeezed into the formation. The well was left shut in for LOCATION: EWING BANKS eight hours. DRILLING FLUID: GYP WBM Gulf of Mexico-Sub Salt (Rubble Zone) A 100 bbl pill of Poly Plug® was mixed squeezed into the formation leaving 35 The well was left shut-in and the pill in the slug tank and weighted to 17.0 bbls in the annulus. Shut-in pressure was waited on (8) hours. After (8) ppg. The bit was placed 10’ above the was 300 psi on the casing and 150 psi hours circulation was established and estimated loss zone. The pill was the drill string was staged in the hole. on the drill pipe. pumped to the bit with no returns. The plug was washed through and After 15 bbls of Poly Plug® cleared the drilling commenced without further bit, full returns were observed. losses. OPERATOR: BHP AMERICAS After evacuating the drill string of “Loss Rate was over 100 BPH Poly Plug®, the drill string was POOH DRILLING FLUID: SOBM static and 0ver 200 BPH dynamic” to the casing shoe. The Hydril was closed and 50 bbls of Poly Plug® was South Louisiana-Tuscaloosa Trend (Deep & Hot) All exposed sands were pay zones and loss zone before pressure limitations of the well was loosing 25 BPH. 800 psi on the casing occurred. The OPERATOR: BP Poly Plug pill was held in place for (1) The Poly Plug pill was blended in a 40 DRILLING FLUID: 17.4 lb/gal OBM hour and then a trip was made for a bbl batch blender and took 1.5 hours new bit. Operator was able to wash BHT: 380 DEGREES F to build and weight up to 17.4 ppg. and ream to bottom with no further The pill was pumped down the drill losses and continue to drill without pipe and after clearing the bit by (1) further incident. bbl, the drill string was POOH to 100’ above the casing shoe (+/- 19,000’) and a total of 8 bbls was squeezed into the Page 18 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 20. Grady County, Oklahoma (Oil Sand Creek) Lost complete returns @ 16714’ and mixed & spotted. After 120 bbls into 1000 bbls of OBM was lost while the displacement a trickle of returns attempting to circulate. Mud weight were obtained increasing to 75-80% was cut and LCM pills were spotted in once all the displacement fluid had concentrations of 40-50 ppb. Another been pumped. The drill string was POOH to 15,427’ and shut down. 700 bbls of OBM was lost. After waiting 5 hours POOH to 7951’ The fluid level was checked with wire and break circulation. Full returns were line and was determined to be 800’. A established at 7,951’. The drill string 60 bbl Poly Plug® pill was mixed and was staged into the well bore to the spotted. After 6 hours the annulus was total depth of 16,714’ with full returns. filled with 30 bbls of 11.8 ppg OBM Drilling was completed to the depth of with some seepage noted at 20 BPH. 16962’ with no further losses. The drill string was TIH to 16273’ & OPERATOR: MARATHON attempted to circulate with no returns. A second 60 bbl Poly Plug pill was WELL: MITCHELL 2-34 South Louisiana-Tuscaloosa Trend (Deep & Hot) The objective was to seal off existing the Poly Plug® into the perforations. shut in and the pill was allowed twelve perforations in order to produce a Five bbl’s of Poly Plug was left above hours to develop maximum strength. lower zone (TTPD). The total length of the perforations and the coil tubing was After waiting twelve hours the POOH to 500’ above the estimated top remaining gel was circulated out the the perforated interval was 90’. of the Poly Plug® slurry. The well was well and the perforations tested. Upon A total of 60 bbl’s of Poly Plug® and 5 a positive test the lower zone was bbl’s of Ultra Spacer® was mixed and perforated. The well has been on pumped through 1 1/4” CT to a depth production for over 2 years with a “Successful Shut Off with a of 21,051’. The well was on vacuum 12,600 psi differential across the upper during the displacement and Ultra 12,600 psi Differential Pressure perforations without any cross flow. Spacer® was pumped ahead of the Poly and 380º F” OPERATOR: BP Plug® to prevent over displacement of WELL: PARLANGE #8 South Louisiana-Tuscaloosa Trend (Deep&Hot) The objective was to seal off existing waiting on the pill to develop is currently producing gas from a high perforations in order to produce a maximum strength. After 8 hours the pressure zone below the shut off pill was washed through with 1 1/4” CT lower gas zone. The existing perforations without cross flow. perforations had been producing large and a positive test achieved across the The differential pressure across the amounts of coarse sand and a large perforated interval. A perforating upper (shut off) perforated interval is carvernous zone was suspected behind assembly was picked up and TIH below 9,800 psi. The reservoir temperature the 7-5/8” casing. With the well on the existing perforations to perforate across the upper perforated interval is vacuum, 30 bbls of Poly Plug® was the target zone. 400ºF. pumped to the EOT at 18,045’ and As of April 21, 2005, almost 1.5 years OPERATOR: BP over displaced by 1 bbl. 200 psi over after the Poly Plug® treatment this well initial SIP was held for 8 hours while WELL: DEBATAZ #8 Page 19 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 21. POLY PLUG® (CLEAR GEL) P RO F E S S I O N A L F L U I D S E RV I C E S, L LC AUGUST 2006 Case Histories CHEMICAL 2 LINER PRODUCT DESCRIPTION GRAVEL PACK 2 SHUT-OFF POLY PLUG® (CLEAR GEL) is formulated with high concentrations of low WATER SHUT- 2 molecular weight anionic polymer. When combined with a carboxylate OFF complex cross linking agent, the product produces a rubber like ringing gel structure. POLY PLUG® (CLEAR GEL) is also referred to as MARASEAL-EZSM. MARASEAL-EZSM is exclusively licensed technology from MARATHON PRODUCT BENEFITS Special points of POLY PLUG® (CLEAR GEL) is NEVER a drill-out problem. Simply wash interest: through or dump bail any material left in the casing for easy clean out!!! • Full shut off treat- ments into rock matrix less than 750 milli-darcies POLY PLUG® (CLEAR GEL) is permeability of 5 to 750 md. POLY PLUG® (CLEAR GEL) is • Effective in shutting designed with a low viscos- POLY PLUG® (CLEAR GEL) is a mixed into fresh or salt off water or gas ity prior to cross-linking to solids free fluid which works water at concentrations of • Effective in sealing aid in injectivity. up to 5%. by entering the reservoir casing leak When placed in small and reducing permeability, Each POLY PLUG® (CLEAR • Effective in sealing openings such as pore not by plugging the GEL) treatment is based on gravel pack throats or small channels perforations as in Portland the bottom hole behind casing, the result Cement treatments. temperature, casing size, is total shut-off. POLY linear feet of perforations PLUG® (CLEAR GEL) is and other variables. designed for shut off treatment into matrix Page 20 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 22. Chemical Liner (Depleted Gas Zone) Lake Arthor, Louisiana 120 bbls of Poly Plug® (CLEAR GEL) OBJECTIVE: was squeezed into the depleted Create a chemical liner across a gas reservoir forming a chemical depleted gas reservoir. liner. Target penetration was (14,000 psi Delta “P”) based on 3.0’ radial penetration. The well was drilled to 17,010’ with The liner was run to bottom and an 8-1/2” open hole. Difficulties cemented without incident. Full were encountered running the circulation was observed during the 7-5/8” liner when it became cement displacement with cement hydraulically stuck and could not tops to the required height. The be run to bottom. The portion of differential pressure across the the liner which could not be pulled depleted zone was 14,000 psi. was milled. After milling operations were complete, the hole was reamed from 16,740’-16,950’ and Operator: Noble Energy opened to 9-1/2”. After hole opening operations were complete, Well Name: Laurents #1 Water Shut Off (Gravel Pack) Ewing Banks, Gulf of Mexico estimated to be in the order of sev- well head. OBJECTIVE: eral feet from the perforations. Shut-off gravel pack completion from The well was then put in re- After waiting twenty four hours, the 10,442’-10,466’ and complete / perfo- completion mode and perforated remaining gel was removed via e- rate from 13,886’-13,897’ below the existing perforations. line bailer and the well was tested The well is currently producing over A fifty barrel treatment was bull to 2,500 psi or 1,000 psi over 480 barrels of oil. headed down the tubing and dis- “This was a proven success in gravel placed with sea water. Four bar- Well Specifics: pack shut off where conventional rels of POLY PLUG® CLEAR GEL was 200-1,000 md permeability with cement would have required a side left above the gravel pack screen 31% porosity. track. Furthermore, this application to help prevent over displacement. Gel invasion into the reservoir was proved POLY PLUG® CLEAR GEL could Reservoir Temperature: 205ºF be applied without the expense of a rig or coil tubing.” Water Shut-Off (Gravel Pack) Ewing Banks, Gulf of Mexico accept the gel treatment. As well was pressured up to 1,000 psi OBJECTIVE: expected, the well immediately over well head and the perforation Achieve a complete shut-off went on vacuum. tested. A negative test to 400 psi treatment from channels behind was also applied to verify the shut 4 1/2” casing. The 45 barrel treatment was off. applied to the perforations. A 45 barrel treatment designed for Approximately one barrel of gel per This was a proven success in maximum penetration into matrix linear foot of perforations was formation shut off where pore spaces. Prior to the pumped. The well was left shut in conventional cement would have application, an injection rate was for twelve hours. The remaining required drill out. established with water to determine gel was washed through with via the potential for the interval to Operator: Stone Energy CT and high pressure nozzle. The Well Name: OCS-G 7917 (A-8) Page 21 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 23. ULTRA SQUEEZE® P RO F E S S I O N A L F L U I D S E RV I C E S, L LC AUGUST 2006 PRODUCT DESCRIPTION Ultra Squeeze® Ultra Seal® XLD is a consists of a silicone based de- Case Histories foamer and aids in pharmaceutical grade cross linking reducing viscosity. agent, a blend of low Other defoamers OKLAHOMA 2 molecular weight should be pilot tested polymer and a prior to use. EAST TEXAS 2 filtration agent. XCD polymer is The cross linking required for BC, CANADA 2 action is a function of suspension of the temperature. For filtration agents and temperatures below any weight material. 100 degrees F an Ultra Squeeze® is accelerator, Ultra designed to produce Seal® XLA is both an open hole required. For plug and an inner temperatures above zonal shut off. The 125 degrees F, a product is designed delaying agent, for matrix and Ultra Seal® XLR is Special points of in- fractured formations. required. terest: • Time Controlled • Robust Gel Chemistry • Density controllable with barite or hematite • Insensitive to H2S and CO2 PRODUCT BENEFITS • Temperature stable up to 400º F • Not intended for use in the reservoir, product should be The slurry is pumped to about this product is the The inner zonal plug has considered permanent a vertically defined zone dewatered phase cross sufficient strength to • Provides two plugs in one. and a slight squeeze is links providing an inner prevent fluid intrusion applied. When placed in zonal shutoff. The open into the well bore, even a well bore, the slurry hole plug holds the under high differential dewaters to form an polymer solution in place pressures after drilling open hole plug while it cross links, out the open hole plug. composed of filter aid forming a non flowing Page 22 material. What is unique gel inside the formation. P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 24. Cement City, Oklahoma (Depleted Sand) The second pill was squeezed as WELL HISTORY per the first pill scenario and the Depleted Sandstone at 16,000’. well was left shut in for 6 hours. Well bore loss previous to Ultra Squeeze® was 2,500 bbls of OBM. After tagging the second pill, Three cement plugs were pumped bottoms up was circulated the prior to Ultra Squeeze® and the drilling fluid conditioned. Washing and reaming commenced, and well bore was on vacuum. drilling operations continued for An 80 bbl Ultra Squeeze® pill was another 800’ with no loses and the blended and pumped from the well was T.D. casing shoe at 15,500’. After 8 hours the well was circulated with OPERATOR: CHEVRON full returns. The Ultra Squeeze® LOCATION: OKLAHOMA pill was drilled through and returns DRILLING FLUID: OBM were noted to be approximately 70%. A second pill of 40 bbls was blended. East Texas (Fractured Limestone) pulled above the slurry and the After squeezing a total of 8 bbls, OBJECTIVE Hydril closed. Slight hesitation the well stabilized with 200 psi on Cure loss circulation into the Travis squeezes were applied up to 250 the casing and was left shut in for Peak (Fractured Limestone) and psi. After squeezing 2-3 bbl (6) hours. The plug was washed increase mud weight to safely drill increments, the well was allowed to through and drilling fluid through tectonically stressed shale conditioned. The drill pipe was stabilize. formations. POOH to the casing shoe and a The well was experiencing dynamic “Inner Zonal Shut-Off Provided a FIT performed to 10.9 EMW. The seepage losses of 30 bbls/hour. A well tested. The mud weight was Chemical Liner, Increasing FIT 20 bbl pill of Ultra Squeeze® was increased from 10.1 to 10.7 and Across the Travis Peak Formation mixed and spotted across the drilling commenced without further by 0.7 lb/gal” target formation. The drill pipe was incident. Fort Nelson, B.C., Canada (Fractured Sandstone) Operator was drilling ahead with no With the drill pipe on vacuum, Ultra into the formation at 0.25 BPM. losses when a drill break occurred Squeeze® was pumped into the The well was left shut in for (8) and the bit fell 5’. Total loss of drill pipe. After +/- 140 bbls of hours. The pill was tagged below circulation occurred into a fractured Ultra Squeeze® exited the bit, the casing shoe and washing and sandstone. partial returns were be observed on reaming commenced. The BHA was placed 5 barrels surface. Five barrels of Ultra A successful FIT was obtained inside the 13 3/8” casing and 180 Squeeze® was left in the drill pipe and drilling commenced without barrels of Ultra Squeeze® was to prevent contamination with OBM further incident. blended and formulated for a static while pulling above the pill. OPEN HOLE SIZE: 12 1/4” BHT of 122 degrees F. The Hydril was closed and 10 bbls of Ultra Squeeze® was squeezed MUD TYPE: 80/20 OWR OBM Page 23 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 25. ULTRA SPACER® P r o f e s s i o n a l F l u i d S e r v i c e s, L LC August 2006 PRODUCT DESCRIPTION FORMATION Because of its fluid loss properties, Ultra DAMAGE & Loss Spacer® aids in CIRCULATION reducing lost circulation Special points of interest: Prevention problems in fragile, ⇒ Reduces potential unconsolidated, and Ultra Spacer® works well damage from filtrate fractured formations. in high permeability invasion from of feet to The polymeric fluid loss formations or in only inches. additive reacts almost formations with low ⇒ Provides excellent immediately upon fracture gradients. compatibility with contact with the Because the seal formed drilling fluids and formation for quick by Ultra Spacer® raises cement. results without filter the formation’s fracture ⇒ Prevents fall back. cake development. pressure, cement can be placed at casing depth ⇒ Improves Cement Bond. For cases in which fluid with higher equivalent loss can be total and ⇒ Density controllable, up circulating densities severe, Ultra Seal® to 19.0 lb/gallon. (ECDs) without Plus should be added to ⇒ Stable to 400º F increasing the risk of the spacer to enhance formation break down. fluid loss prevention. This capability is highly surfactant, Ultra Surf™ Recommended beneficial in wells in is recommended in concentrations are 20 to which a narrow margin concentrations of 0.5 to 40 pounds per barrel. exists between the 2 gallons per barrel of When used in oil base fracture gradient and the water. mud applications, a mud density. PRODUCT BENEFITS “95-100% RETURN PERMEABILITY” Forms a non invasive Improves ECD’s at inches. seal to prevent filtrate casing depth in wells Ultra Spacer’s® low invasion into the where fracture gradients rheology enhances producing formation and mud weights limit removal of gelled drilling (especially important in the density of cement. fluid from the hole for high permeability wells or Reduces potential superior hole cleaning when cementing in damage from filtrate performance. formations with low invasion from feet to only fracture gradients). Page 24 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 26. ULTRA SPACER® What’s good for your well Ultra Spacer® gives you formation’s normal bore is not always good for control over filtrate damage. permeability for optimum an oil bearing formation. Ultra Spacer®, a specially production. Filtrates from the cement formulated cement spacer slurry can seriously damage based on unique invasion a producing formation, prevention technology, forms hindering production and a barrier along the surface of increasing the need for the formation to shut out stimulation. filtrates and preserve the When a cement slurry is placed on top of Filtrate from a cement slurry penetrates Ultra Spacer®, no cement filtrate invasion untreated dry, 20/40-mesh sand in less Ultra Spacer® penetrates untreated nor additional invasion of Ultra Spacer® is than 1 minute.* sand to a depth of 4 inches before observed after 46 minutes.* creating a seal.* Field Results ⇒ Improved zonal isolation & excellent mud displacement are achieved as indicated by bond logs and produced fluids. ⇒ Ultra Spacer® Prevents Fall Back of Cement Tops. ⇒ Provides Increased Well Productivity. Page 25 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 27. CASE HISTORY SOUTH TEXAS - GAS WELL Ultra Spacer® has been used in seven wells in a South Texas formation with exceptional results. The following case history is representative of the results achieved for this operator. Application: An independent operator drilled a directional wildcat well from a small drilling pad surrounded by wetlands. Because drilling from the site was restricted to summer and early fall, no time could be allotted for remediation of cement seals across the producing intervals. The producing interval contained an estimated 25 to 30 sands requiring zonal isolation over a depth of Results: The cementing treatment was successful and excellent 2,000 feet. The operator was bonding and annular seal were achieved throughout the producing concerned about the potential for intervals. Bond logs indicated superior bonding and cement fill, and lost circulation in the wells and did early production from the well exceeded expectations. The operator not want to damage the sands has since drilled three additional wells using Ultra Spacer® in the production cementing treatment. since time was a critical factor in these operations. bonding was established over the entire cemented interval resulting in quot;Good water free completion…It was an important factor in the successful completion of one of the largest discoveries in Southeast Texas in the last 50 years.quot; – Ross Davis, President, Davis Bros. Oil Producers, Inc. CASE HISTORY - OFFSHORE GULF OF MEXICO Ultra Spacer® has been used in allow stable plug placement to pro- two deep, offshore wells to prevent vide long term isolation. Because lost circulation and allow more of damage to the formation sands, efficient clean sweeping of holes. lost circulation was also a problem. Application: An operator with Results: The use of Ultra Spacer® deep, hot wells offshore Gulf of resulted in efficient clean sweeping Mexico was experiencing problems of the hole, reduced lost circulation, achieving efficient hole cleaning to and improved plug results. Page 26 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 28. CASE HISTORY - COAL BED METHANE Ultra Spacer® has been used in over forty wells in the Powder River Basin to eliminate cement fall back and improve production. The following case history is representative of the results achieved in these wells. Application: A major operator was experiencing fall back of cement tops after cementing production strings in coal bed meth- ane (CBM) wells in the Powder River Bain. The wells were shallow (less than 2000 feet) and experienced signifi- cant lost circulation during drilling and cementing operations. Low density drilling fluids and cements did not completely solve the lost circulation problem. Fall back after cementing resulted in incomplete protection of the casing, as well as introduction of cement slurry into the producing formation. Because production in CBM wells is highly dependent on fracture networks in the coal, the loss of cement to the coal formation had a strong potential for inhibiting production. Solution: Ultra Spacer® was used during the cementing of the production casing on five new wells to prevent cement fall back and prevent formation damage to the fracture networks in the coal bed. The operator pumped 10 barrels of Ultra Spacer® ahead of their standard, low density cement. Results: The use of Ultra Spacer® resulted in elimination of cement fall back, produced excellent bond logs, and improved production. CASE HISTORY - COAL BED METHANE An operator (Amvest) in Osage The primary goal of this project County, Oklahoma, has used Ultra was to reduce the lost circulation Spacer® in 31 wells to reduce lost believed to damage the fracture circulation and damage to the network in the coal bed leading to fracture network. reduced productivity and to determine Ultra Spacer’s® affect on cementing, stimulation Application: treatments, and production. Ultra Spacer® was pumped directly ahead of cement or as a Results: This project has just been stabilizing fluid introduced into the completed. Production results are air drilled hole immediately after being analyzed and are not yet significantly lower and initial water drilling. available. However, fracture production rates are higher in wells initiation pressures have been in which Ultra Spacer® was not used. Page 27 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 29. To Order Call: 888-862-7177 RECENT ULTRA SPACER® CASE HISTORIES BASS ENTERPRISES-STATE LEASE, INLAND BARGE Well Location-Well Name: Pointalahache, Louisiana - VUB Morgan City #8 Open Hole Size: 12 1/4” Casing Size: 9 5/8” Mud Weight: 12.4 lb/gal WBM Cement Density: 16.4 lb/gal Ultra Spacer Volume: 55 bbl’s Ultra Spacer Density: 14.0 lb/gal Objective: Solve loss circulation during cement displacement and maximize cement bond. Post well Results: For the first time in this field, full returns were documented for the entire ce- ment displacement. Reference: Pat Blanchard - Drilling Superintendent PH# 504-836-7200 Well Location-Well Name: Pointalahache, Louisiana - VUB Morgan City #8 Open Hole Size: 6 3/4” Liner Size: 5 1/2” Mud Weight: 15.6 lb/gal WBM Cement Density: 16.4 lb/gal Ultra Spacer Volume: 25 bbl’s Ultra Spacer Density: 16.0 lb/gal Objective: Solve loss circulation during cement displacement and maximize cement bond. Post well Results: full returns were documented for the entire cement displacement. Reference: Pat Blanchard - Drilling Superintendent PH# 504-836-7200 Page 28
  • 30. To Order Call: 888-862-7177 RECENT ULTRA SPACER CASE HISTORIES BP-OKLAHOMA Well Location/Name: Red Oak, Oklahoma - Harmon McFerran 7-34 Open Hole Size: 8 3/4” Casing Size: 5 1/2” Mud Weight: 10.5 lb/gal OBM Cement Density: 16.4 lb/gal Ultra Spacer Volume: 45 bbl’s Ultra Spacer Density: 8.5 lb/gal Objective: Maximize cement bond, minimize formation damage from the filtrate of the cement slurry. Post Well Results: As indicated by a CBL, good isolation/cement bond resulted across the interval. Reference: Louis Romo - Drilling Engineer Ph# 281-366-4632 Well Location/Name: Red Rock, Oklahoma - Myton #11 Open Hole Size: 12 1/4” Casing Size: 9 5/8” Mud Weight: Air Drilling Cement Density: 16.4 lb/gal Ultra Spacer Volume: 45 bbl’s Ultra Spacer Density: 8.5 lb/gal Objective: Achieve good isolation/cement bond across a shallow fresh water aquifer at +/- 500’ and eliminate a short string of casing which had been required in previous wells to isolate the aquifer. Post Well Results: Great hole cleaning along with good bonding resulted across the entire interval, including across the fresh water aquifer. Substantial savings was realized by eliminating the short string of casing which had been required in previous wells. Reference: Roberto Pena - Drilling Engineer Ph# 281-366-7892 Page 29
  • 31. To Order Call: 888-862-7177 RECENT ULTRA SPACER CASE HISTORIES CIMAREX-MAGNUM HUNTER / GULF OF MEXICO Well Location/Well Name: Main Pass Block 185 - Well #1 Open Hole Size: 9 7/8” Casing Size: 7 5/8” Mud Weight: 15.8 lb/gal Cement Density: 17.0 lb/gal Ultra Spacer Volume: 44 bbl’s Ultra Spacer Density: 16.4 lb/gal Objective: Reduce gas migration and casing pressure issues. Post Well Results: Due to the non invasive seal fluid migration into the formation from the cement slurry was prevented. Gas migration issues were eliminated and zero casing pressure was observed after the cement job which had never occurred in this field. Reference: Clay Clary- Drilling Superintendent Ph# 801-270-3850 Well Location/Well Name: Main Pass Block 185 - Well #1 Open Hole Size: 6 3/4” Liner Size: 5 1/2” Mud Weight: 16.4 lb/gal WBM Cement Density: 17.4 lb/gal Ultra Spacer Volume: 20 bbl’s Ultra Spacer Density: 16.9 lb/gal Objective: Reduce gas migration and loss circulation. Post Well Results: Gas migration was eliminated and full returns were observed during the entire cement displacement. Reference: Clay Clary- Drilling Superintendent Ph# 801-270-3850 Page 30
  • 32. To Order Call: 888-862-7177 RECENT ULTRA SPACER CASE HISTORIES CIMAREX-MAGNUM HUNTER / GULF OF MEXICO Well Location/Well Name: West Cameron Block 295 - Well #3 Open Hole Size: 14 3/4” Casing Size: 13 5/8” Mud Weight: 12.4 lb/gal Cement Density: 16.4 lb/gal Ultra Spacer Volume: 75 bbl’s Ultra Spacer Density: 14.0 lb/gal Objective: Mud/filter cake removal, reduce gas migration and reduce the risk of loss circulation during the cement displacement. Post Well Results: Excellent mud cleaning/filter cake removal as observed at the flow line, the entire interval was cemented without any incidence of loss circulation. Reference: Clay Clary- Drilling Superintendent Ph# 801-270-3850 Well Location/Well Name: West Cameron Block 295 - Well #3 Open Hole Size: 12 1/4” Casing Size: 9 5/8” Mud Weight: 16.8 lb/gal OBM Cement Density: 17.1 lb/gal Ultra Spacer Volume: 56 bbl’s Ultra Spacer Density: 16.9 lb/gal Objective: Mud/filter cake removal, achieve good isolation and reduce the risk of loss circulation during cement displacement. Post Well Results: The interval was cemented without any documented loss of circulation, the casing shoe was tested to 18.4 lb/gal and the production interval is currently being drilled. Reference: Clay Clary- Drilling Superintendent Ph# 801-270-3850 Page 31
  • 33. To Order Call: 888-862-7177 RECENT ULTRA SPACER CASE HISTORIES CIMAREX-MAGNUM HUNTER / GULF OF MEXICO Well Location: West Cameron Block 577 Open Hole Size: 9 7/8” Casing Size: 7 5/8” Mud Weight: 12.8 lb/gal OBM Cement Density: 16.4 lb/gal Ultra Spacer Volume: 30 bbl’s Ultra Spacer Density: 14.0 lb/gal Objective: Prevent micro annular gas migration due to the fluid loss from the cement slurry. Post Well Results: Due to the non invasive seal created across the interval, fluid loss from the cement slurry was re- duced eliminating gas migration/casing pressure issues. The casing shoe was tested and drilling operations commenced. DAVIS PETROLEUM / TEXAS Well Location: Harden County, Texas - Hampton Jenny #1 Open Hole Size: 9 7/8” Casing Size: 7 5/8” Mud Weight: 9.5 lb/gal Cement Density: 16.4 lb/gal Ultra Spacer Volume: 50 bbl’s Ultra Spacer Density: 10.5 lb/gal Objective: Prevent loss circulation and maximize isolation across production sands. Post Well Results: The entire interval was cemented without loss circulation resulting in good isolation across the production sands, as indicated by a CBL. Page 32
  • 34. Ultra Bond® Dump Bailer Cement Kit Professional Fluid Services, LLC is pleased to announce its association with Thru Tubing Systems (TTS) to provide product and service solutions for our wire line cement and resin systems. TTS combines its thru-tubing tools and service experience with Professional Fluid Services, LLC engineered cement and resin product to bring a system solution approach to meeting needs and solving problems with this unique product line. Proven Design Concepts The Ultra Bond® Dump Bailer Kit provides everything you need to produce a cement slurry designed for applications from 100 to 400º F. Designed features include: Shear Bond to Casing - Maximum (Over 3 Times the Competition) Down-Hole Seal to Gas - Excellent Down-Hole Fluid Loss Control – Less Than 50 cc/30 Minutes API at 400º F Down-Hole Strength Stability - Yes Surface Mixability – Excellent Surface Pumpability – Low Rheologies Downhole Slurry Stability – Excellent Thickening Time Control – 4 to 6 Hours at Down-Hole Conditions Cement Density-17.0 lb/gallon Strength Development – 500 PSI in 12 Hours, 2000 PSI in 24 Hours The Ultra Bond® Dump Bailer Kit provides all these features without the problem of designing and testing for each specific application. State of the Art admixture assures performance over a wide range of temperatures and application conditions. The engineered approach that forms the underlying foundation for the product ensures that it will perform predictably under a wide application range. Page 33 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 35. Ultra Bond® Dump Bailer Cement Kit “Continued” Design Shear Bond Values The Ultra Bond® Dump Bailer Kit has a higher Shear Bond Value of any system in the industry. The higher the Shear Bond the higher the anchor strength the cement will produce and better chance to seal and resist a pressure test. The Ultra Bond® Dump Bailer Kit is a combination of several proprietary materials that produce the best shear bonds available. The following table shows several examples of the Ultra Bond® Shear bond compared to two other competitor products: Relative Shear Bond and Anchor Strength 400 Shear Bond 300 200 200 280 100 0 Kit 1 Kit 2 Ultra Bond Products Tested Page 34 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 36. PROFESSIONAL FLUID SERVICES, LLC Ultra Bond Kit vs HIP Kit Prepared For: Donnie Burts Date: 11 August, 2006 Prepared by: Paul Sonnier CSI Technologies makes no representations or warranties, either expressed or implied, and specifically provides the results of this report quot;as is” based upon the provided information.
  • 37. Objective A performance comparison between the High Shear Bond HIP Mix Kit supplied by HPI and the Ultra Bond Kit supplied by M & D Industries was conducted at CSI Technologies. Conclusions Testing data demonstrates that the kits were comparable in most of the categories listed except the Ultra Bond Kit’s shearbond was double the value obtained for the HIP Kit. Test Data HIP Kit: High Shear Bond HIP Mix Kit: P/N 980-201-01 mixed at 16.0 lb/gal with 230°F design. Ultra Bond Kit: Ultra Bond Kit mixed at 17.0 lb/gal with 230°F design. Tests Ultra Bond Kit HIP Kit Measured 17.0 lb/gal 16.0 lb/gal Density Kit yield 5 gallons 4 gallons Temp. Range 100°F – 300°F 175°F – 260°F Testing performed at 230°F Fluid Loss 40 mls 40 mls Free Fluid 0% 0% Rheology 80°F 190°F 80°F 190°F 300 rpm 600+ 600+ 580 490 200 rpm 460 448 426 370 100 rpm 270 266 268 224 60 rpm 178 180 190 168 30 rpm 100 106 116 104 6 rpm 26 30 36 34 3 rpm 14 18 20 20 Shearbond 439 psi 220 psi Stability Stable Stable 50 psi 3:04 hrs:min 3:04 hrs:min 500 psi 4:06 hrs:min 3:56 hrs:min 12 hours 2012 psi 1624 psi 24 hours 2800 psi 2432 psi CSI Technologies makes no representations or warranties, either expressed or implied, and specifically provides the results of this report quot;as is” based upon the provided information.
  • 38. Ultra Set® Activator Solution System: ULTRA SET® is a pre-flush of proprietary chemicals which provide the following benefits: Water Wetting of Casing Adhesive For the Cement Catalyst For the Cement to Set Rapidly Excellent Gas Blocking Properties Slurry Density: 11.4 lb/gal Kit Yield: 4.6 gallons per pail and will treat up to 23 Gallons of Ultra Bond® Mix Requirement: Mix With a High Speed Mixer, Mix For (5) Minutes Job Procedure: 1. Inspect the dump bailer for contamination of cement and or Ultra Set™ Activator. 2. Mix Ultra Set® Activator for (5) minutes prior to loading into the dump bailer. 3. Always use additional sand on top of a vented bridge plug. A minimum recommendation is 2’ of sand. 4. When dumping Ultra Set® Activator or the cement slurry, get as close to the dump depth, +/- 1’ if possible. 5. When dumping Ultra Set® Activator or the cement slurry, allow the product to drain for at least 5 minutes prior to pulling out of the hole. 6. When pulling out of the hole, pull the length of one dump bailer in one minute, then pull as fast as necessary. 7. Close the vent valve on the basket as easily as possible so as to not disturb the cement bond to the casing. Always allow the first dump of cement on top of the activator solution at least three hours 8. before closing the vent valve. This should allow the cement enough time to get initial set and prevent gas migration. NOTE: Typical Job Runs/Dumps Follow: 1. Dump 2’ Sand on Top of TTVBP, POOH with Bailer. 2. Dump 4.5 gallons of Ultra Set® Activator on Sand, POOH with Bailer. 3. Dump up to 23 Gallons of Ultra Bond® cement slurry. As Ultra Bond® Falls Through the Ultra Set® Activator, the Ultra Set® Activator is Displaced up the Hole to Treat Additional Ultra Bond®, up to a Total of 22.5 Gallons of Ultra Bond® Slurry. Page 35 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 39. Ultra Set® Activator Solution ULTRA SET® is a pre-flush of proprietary chemicals which provide the following benefits: Water Wetting of Casing Adhesive For the Cement Catalyst For the Cement to Set Rapidly Excellent Gas Blocking Properties Setting Time/Compressive Strengths Comparisons (Table:1) (See Mix Instruction for Ounces of Retarder Per BHT) Slurry BHT ºF Initial Set (50 PSI) 500 PSI Ultra Bond®+15.3 oz Retarder 300ºF 0 Hours:16 Minutes 3 Hours:23 Minutes 5% Ultra Set® Ultra Bond®+15.3 oz Retarder 300ºF 5 Hours:35 Minutes 7 Hours:30 Minutes Ultra Bond®+1.7 oz Retarder 200ºF 0 Hours:14 Minutes 2 Hours:13 Minutes 5% Ultra Set® Ultra Bond®+1.7 oz Retarder 200ºF 8 Hours:0 Minutes 10 Hours: 0 Minutes Ultra Bond®+6.0 oz Retarder 211ºF 0 Hours:26 Minutes 1 Hours:54 Minutes 5% Ultra Set® Ultra Bond® + 6.0 oz Retarder 211ºF 37 Hours:44 Minutes 41 Hours:8 Minutes Shear Bond Effects Conventional Cement - Class “H” at 500 psi Compressive Strength Will Yield the Following: Perfect Condition/Casing Water Wet - 50 psi Shear Bond Imperfect Condition/Oily Casing - 5 psi Shear Bond Ultra Bond® Cement and Ultra Set® at 500 psi Compressive Strength Will Yield the Following: Perfect Condition/Casing Water Wet - 150 psi Shear Bond Imperfect Condition/Oily Casing - 75 psi Shear Bond Page 36 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 40. PRO BOND™ Dump Bailer Cement Kit Professional Fluid Services, LLC is pleased to announce its association with Thru Tubing Systems (TTS) to provide product and service solutions for our wire line cement and resin systems. TTS combines its thru-tubing tools and service experience with Professional Fluid Services, LLC engineered cement and resin product to bring a system solution approach to meeting needs and solving problems with this unique product line. Proven Design Concepts The Pro Bond™ Dump Bailer Kit provides everything you need to produce a cement slurry designed for applications from 100 to 300º F. Designed features include: Shear Bond to Casing - Good Down-Hole Seal to Gas - Good Down-Hole Fluid Loss Control – Less Than 150 cc/30 Minutes API at 250ºF Down-Hole Strength Stability - Yes Surface Mixability – Good Surface Pumpability – Low Rheologies Downhole Slurry Stability – Good Thickening Time Control – 4 to 6 Hours at Down-Hole Conditions Cement Density-17.0 lb/gallon Strength Development – 500 PSI in 12 Hours, 2000 PSI in 24 Hours The Pro Bond™ Dump Bailer Kit provides all these features without the problem of designing and testing for each specific application. State of the Art admixture assures performance over a wide range of temperatures and application conditions. The engineered approach that forms the underlying foundation for the product ensures that it will perform predictably under a wide application range Page 37 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 41. PRO BOND™ SSW (SATURATED SALT WATER) PRODUCT DESCRIPTION “Standard cement slurries have the potential for a 2/3 reduction in compressive strengths, shear bond and ultimate compressive Pro Bond™ SSW is a new addition to the Pro Bond™ product strengths compared to line of dump bailer cement kits. Pro Bond™ SSW is specifically Pro Bond™ SSW when dumped designed for dump bail placement into saturated NaCl brines. into saturated NaCl brines” The Pro Bond™ SSW dump bailer kit is designed for placement into a well which contains a 10 lb/gal NaCl brine. The kit has been formulated to minimize the effects of delayed development of compressive strength’s by saturated NaCl brines. Twelve hour compressive strengths for Pro Bond™ SSW at 350º F in a 10.0 lb/gal NaCl brine are 1,342 psi. Most cement slurries would still have 0 psi compressive strengths after twelve hours. The strength measurements were verified with a crush test performed on the set UCA plug. Both Pro Bond™ SSW and competitive slurries were tested on a UCA at 14,000 psi and 356ºF. ·Designed for dump bailer application into saturated NaCl brines ·Formulated for bottom hole temperature from 300ºF-400ºF ·Twelve hour compressive strengths of 1,342 psi ·Six Hour thickening time ·Excellent Down Hole Stability Professional Fluid Services, LLC is pleased to announce its association with Thru Tubing Systems (TTS) to provide product and service solutions for our wire line cement and resin systems. TTS combines its thru-tubing tools and service experience with Professional Fluid Services, LLC engineered cement and resin product to bring a system solution approach to meeting needs and solving problems with this unique product line. Page 38 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 42. ULTRA SEAL® S (SEALANT) Professional Fluid Services, LLC and Thru Tubing Systems introduce the following Wire Line kits for ULTRA SEAL® S which are designed for WATER SHUT-OFF via wire line operations. ULTRA SEAL® S is a two part epoxy resin system. The final slurry volume after mixing Part “A” with Part “B” is 5-Gallons. Three individual kits are available as per the various temperature ranges. ULTRA SEAL® S (KIT 1) Designed for BHT’s from 100˚F up to 160˚F ULTRA SEAL® S (KIT 2) Designed for BHT’s from 161˚F up to 200˚F ULTRA SEAL® S (KIT 3) Designed for BHT’s from 201˚F up to 300˚F Special Properties (Patent Pending) Very high compressive Strengths - Over 7,500 psi Ultimate Compressive Strength Ultra-High Shear Bond Strengths - Over 1,650 psi Low Rheologies Excellent Pumpability/Dumpability Excellent Gas Blocking Properties-Impermeable to Gas/Fluids Exo-Thermic Non Shrinking Water Tolerant-Easily Falls Through Sea Water Design Weight 10.0 lb/gallon (Can be weighted up to 18.5 lb/gallon-Upon Request) Fluid Time of 5-7 Hours Drill Out No Problem-Drillable at 12’ Per Hour ULTRA SEAL® S (SEALANT) provides all these features without the problem of designing and testing for each specific application. State of the Art admixtures assure performance over a wide range of temperatures and application conditions. The engineered approach that forms the underlying foundation for the product ensures that it will perform predictably under the wide application range. Professional Fluid Services, LLC is pleased to announce its association with Thru Tubing Systems (TTS) to provide product and service solutions for our wire line cement and resin systems. TTS combines its thru-tubing tools and service experience with Professional Fluid Services, LLC engineered cement and resin product to bring a system solution approach to meeting needs and solving problems with this unique product line. Page 39 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 43. LIQUID BRIDGE PLUG® LIQUID BRIDGE PLUG® (RESIN) is a two part epoxy resin system designed for TTPB applications. The final slurry volume after mixing Part “A” with Part “B” is 5-Gallons. Three individual kits are available as per the various temperature ranges. LIQUID BRIDGE PLUG® (KIT 1) Designed for BHT’s from 100˚F up to 160˚F LIQUID BRIDGE PLUG® (KIT 2) Designed for BHT’s from 161˚F up to 200˚F LIQUID BRIDGE PLUG® (KIT 3) Designed for BHT’s from 201˚F up to 300˚F Special Properties (Patent Pending) Very high compressive Strengths - Over 7,500 psi Ultimate Compressive Strength Ultra-High Shear Bond Strengths - Over 1,650 psi Low Rheologies Excellent Pumpability/Dumpability Excellent Gas Blocking Properties-Impermeable to Gas/Fluids Exo-Thermic Non Shrinking Water Tolerant-Easily Falls Through Sea Water Design Weight 12.0 lb/gallon (Can be weighted up to 18.5 lb/gallon-Upon Request) Fluid Time of 5-7 Hours Drill Out No Problem-Drillable at 12’ Per Hour LIQUID BRIDGE PLUG® (RESIN) provides all these features without the problem of designing and testing for each specific application. State of the Art admixtures assure performance over a wide range of temperatures and application conditions. The engineered approach that forms the underlying foundation for the product ensures that it will perform predictably under the wide application range. Professional Fluid Services, LLC is pleased to announce its association with Thru Tubing Systems (TTS) to provide product and service solutions for our wire line cement and resin systems. TTS combines its thru-tubing tools and service experience with Professional Fluid Services, LLC engineered cement and resin product to bring a system solution approach to meeting needs and solving problems with this unique product line. Page 40 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 44. LIQUID BRIDGE PLUG® (RESIN) Liquid Bridge Plug® (RESIN) is a special epoxy resin tailored for oil well applications. The material’s viscosity has been lowered to provide easy mixing and placement. The lowered viscosity is accomplished without associated volumetric shrinkage usually accompanying thinning of epoxy resin. A range of hardeners and accelerators have been developed to allow set control over a wide application range. INNOVATIVE SOLUTIONS FOR: MICRO ANNULAR GAS MIGRATION GAS SHUT OFF MECHANICAL ISOLATION VALVE PACKER LEAKS CASING LEAKS WELL BORE STABILITY Rheology Measurements at 22°C Rpm Dial Reading 300 252 200 158 100 80 60 48 30 24 Special points of interest: 6 4 • NON-SHRINKING 3 2 • NO PROBLEM DRILLING/MILLING • FUNCTIONS FROM 50º F TO 300º F • OVER 200 TIMES THE TENSIL STRENGTH 72-hr Shear Bond Strength 1,650 psi OF CEMENT • IMPERMEABLE TO GAS PATENT PENDING • EXOTHERMIC • ULTIMATE COMPRESSIVE STRENGTH OF OVER 7,000 PSI Page 41 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 45. Product Bulletin GMA #1: Gas Control Additive Description This Gas Control Additive is in liquid form, and it effectively controls annular gas migration for the temperature range of 80 F to 450 F. It prevents gas buildup on the surface, prevents interzonal communication, and minimizes the need for costly repetitious remedial cementing. Physical Properties Appearance: Brown Liquid Specific Gravity: 1.17 Water Solubility: Water Soluble Chemical Description Polymer blend. Application GMA #1 is a stable liquid polymer complex used to prevent gas or fluid migration from high pressure reservoirs into a cement column. This material also enhances fluid loss control and slurry dispersibility. For gas control, cement slurries containing GMA #1 must meet the following design specifications: Less than 100 ml/30 min. fluid loss Low free water <2% A maximum pumping time equal to the pumping time plus a 30-min. to 1-hour safety factor A fast (right angle) set when tested on a cement consistometer Recommended range 0.1 gal/sk to 0.5 gal/sk Prior to slurry preparation, mixing equipment must be thoroughly clean, and the drilling mud must be conditioned and removed mechanically and chemically (GLO chemical washes and spacers). The volume of GMA # 1 slurry required depends on the fracture gradient, gas pressure, and properties of the gas zone. A slurry volume that provides 300 to 600 ft of annular fill above the gas zone and 150 to 300 ft of annular fill below the gas zone is generally sufficient. Page 42
  • 46. Engineered Coil Tubing Cement Kit (ECT® KIT) Finally… say goodbye to the worry, confusion, calculation, and purchasing efforts of planning for a coiled tubing cement design. Professional Fluid Services, LLC introduces the ECT® cement kit that provides an Engineered design for your Coiled Tubing cementing application. One kit formulates 5 1/2 bbls of a 16.2 lb/gal cement slurry. Simply use the 5 gallon kit of ECT® product along with a 2000 lb bag of class “H” cement and a 700 lb bag of silica flour. Measure out the applicable amount of liquid retarder (ECT® Retarder) depending on temperature application with 118 gallons of water and you are ready to go. Proven Design Concepts The ECT® Kit provides everything you need to produce a cement slurry designed for applications from 100 to 400º F. Designed features include: • Down-Hole Gas Sealing Ability - Excellent • Down-Hole Fluid Loss Control – Less Than 50 cc/30 Minutes API @ 400º F • Down-Hole Strength Stability - Yes • Surface Mixability – Excellent • Surface Pumpability – Low Rheologies • Downhole Slurry Stability – Excellent • Thickening Time Control – 5 to 7 Hours at Down-Hole Conditions • Strength Development – 500 PSI in 12 Hours, 2000 PSI in 24 Hours The ECT® kit provides all these features without the problem of designing and testing for each specific application. State of the Art admixture assures performance over a wide range of temperatures and application conditions. The engineered approach that forms the underlying foundation for the product ensures that it will perform predictably under the wide application range. Page 43 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 47. A FEW OF OUR CUSTOMERS APACHE BASS BP AMERICA CHEVRON CIMAREX DEVON EL PASO EOG ENERGY PARTNERS ERT OGE MARATHON OIL COMPANY STONE ENERGY W&T OFFSHORE Page 44 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 48. Lab Testing and On Site Consulting Please Contact our Office for Pricing and Additional Information!!!! Page 45 P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com
  • 49. P.O. BOX 80293 LAFAYETTE, LA 70598 WWW.PROFESSIONALFLUID.COM 24 Hour Telephone: 888.862.7177 Fax: 337.984.6652 Professional Fluid Services, LLC is proud to be part of the Alliance Partnership with M&D Industries of La, Inc. to better serve our customers through engineering services and solutions.