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D-330507.13-001-D Response - Horizontal Directional Drill, 2026.04.19
Page 1 of 1 Shop Drawing Submittal Response Date: April 19, 2026 Project Name: Town of Yarmouth – Wastewater Collection & WRRF Phase 1 Contract 5 Submittal: D-330507.13-001-D Horizontal Directional Drill Spec Section No.: 330507.13 Reviewer: K. Pathirage Review Status: ☒ CODE 1: Approved ☐ CODE 2: Approved As Noted ☐ CODE 3: Approved As Noted/Resubmit - Resubmission required ☐ CODE 4: Rejected ☐ CODE 5: Receipt Acknowledged (Not Subject to the Engineer’s Approval) Comments: SHOP DRAWING REVIEW ☒ Approved ☐ Approved As Noted ☐ Approved As Noted/Resubmit ☐ Full ☐ Partial ☐ Rejected ☐ Receipt Acknowledged (Not Subject to the Engineer’s Approval) The Contractor is responsible for the details and dimensions of fabrication and manufacture, the means, methods, techniques, sequences, or procedures of construction, and performing its work in a safe manner. The Contractor is also responsible for confirmation and verification of all field measurements, and coordination with other related shop drawings and Contract requirements. The Engineer’s review of this shop drawing is limited to review for conformance with the Contract Documents and design concept. This review does not relieve the Contractor from errors or omissions in the submittal, or from the Contractor’s responsibility of addressing any deviations from the Contract Documents, or for any other Contract requirement. Note: The review of shop drawings containing design calculations or drawings signed and sealed by a professional engineer (“Contractor Specialty Engineer”) does not constitute a detail check of calculations, nor does it relieve the Contractor’s Specialty Engineer from the responsibility for the design and detailing of the specialty component or system contained in such shop drawings. By: K. Pathirage Date: 4/19/2026 Project: Yarmouth - WW Phase 1 - C5 Rt 28 Yarmouth, Massachusetts Submittal #330507.13-001.D - Horizontal Directional Drill 330507.13 - Horizontal Direction Drilling Revision D Submittal Manager Dereck Pacheco (Dig It Construction LLC) Status Open Date Created Apr 2, 2026 Spec Section 330507.13 - Horizontal Direction Drilling Responsible Contractor Dig It Construction LLC Received From Final Due Date Apr 16, 2026 Lead Time Cost Code Location Type Submittal Package Approvers Amanda Caddell (CDM Smith) Ball in Court Amanda Caddell (CDM Smith) Distribution Amanda Caddell (CDM Smith), Angelina Franklin (Dig It Construction LLC), Jason DelleFemine (Wright and Pierce), Keith Fernandes (Dig It Construction LLC), Lou Ragozzino (Wright and Pierce), Priscilla Bloomfield (CDM Smith), Steve Callahan (CDM Smith) Description Please see attached. Submittal Workflow Name Sent Date Due Date Returned Date Response Attachments General Information Attachments D-3305~1.PDF Amanda Caddell Apr 2, 2026 Apr 16, 2026 Pending Page 1 of 1 Printed On: Apr 6, 2026 10:31 AM EDT LETTER OF TRANSMITTAL DATE: 04/01/2026 TO: CDM Smith ATTENTION: Michael P. Guidice, P.E. Senior Project Manager FROM: Dig-It Construction LLC PROJECT NAME: Yarmouth Phase 1 – Contract #5 -Wastewater Collection System 22 Diamonds Path S.Dennis Ma 02660 Office: 508-432-1635 WE ARE SENDING YOU ☒Submittal ☒Shop Drawings ☐Other Certification Statement: By this submittal, Dig-It Construction LLC hereby represent that we have determined and verified all field measurements, field construction criteria, materials, dimensions, catalog numbers and similar data and we have checked and coordinated each item with other applicable approved shop drawings and all Contract requirements COPIES DATE SPEC Description D-330507.13 001-D Horizontal Directional Drilling THESE ARE TRANSMITTED as checked below ☒For approval ☒As requested ☒Returned for corrections REMARKS: Please see attached resubmittal addressing all previous comments. Please note that the HDD engineer is licensed in the Commonwealth of Massachusetts. The engineer’s professional seal is included within the calculations section of this submittal and is intended to apply to the entirety of the submittal document. Thank you, SIGNED: Dereck Pacheco HORIZONTAL DIRECTIONAL DRILL SUBMITTAL - TABLE OF CONTENTS 1 – Methods, Equipment, and Materials Description Plan 1A – Directional Drilling Means and Methods 1B – Locator – DCI Falcon F5 1C – Vermeer Directional Drill D100 x 120 1D – Ditch Witch Fluid Management System FM5X 1E – Carrier Pipe HDPE PE4710 1F – Drill Fluid and Proposed Additives 1G – Noise Abatement – NOT PROVIDED 2 – Surveying Equipment and Procedures 3 – Protection of Adjacent Structures and Facilities Plan 3A – Monitoring & Protection Plan 4 – Contingency Plan for Remediation of Potential Problems 5 – Disposal of Spoils and Drilling Fluid 6 – Equipment Layout Plan 7 – Inadvertent Return and Surface Spill Contingency Plan 8 – Horizontal Directional Drilling Work Plan 8A – Contingency Plan 9 – Soil Separation Plan 10 – Maximum Allowable Drilling Fluid Pressure Calculations 10A – Horizontal Directional Drill Design 11 – Pipe Filling Methods and Testing 12 – Certified Work Zone TraAic Plan SECTION 1 METHODS, EQUIPMENT, AND MATERIALS DESCRIPTION PLAN SECTION 1A - DIRECTIONAL DRILLING MEANS AND METHODS SECTION 1B - LOCATOR - DCI FALCON F5 SECTION 1C - VERMEER DIRECTIONAL DRILL D100x120 SECTION 1D - DITCH WITCH FLUID MANAGEMENT SYSTEM FM5X Iron Pipe Size (IPS) and Dimension DataDriscoPlex® Pipe for Municipal and Industrial ApplicationsNominal Pipe SizeIPS OD (in)Minimum Wall (in)Average ID (in)Weight (lbs/ft)Minimum Wall (in)Average ID (in)Weight (lbs/ft)Minimum Wall (in)Average ID (in)Weight (lbs/ft)Minimum Wall (in)Average ID (in)Weight (lbs/ft)Nominal Pipe Size1 1/4" 1.660 0.227 1.179 0.45 0.184 1.270 0.37 0.151 1.340 0.31 0.123 1.399 0.26 1 1/4"1 1/2" 1.900 0.260 1.349 0.59 0.211 1.453 0.49 0.173 1.533 0.41 0.141 1.601 0.34 1 1/2"2" 2.375 0.325 1.686 0.92 0.264 1.815 0.77 0.216 1.917 0.64 0.176 2.002 0.53 2"3" 3.500 0.479 2.485 1.99 0.389 2.675 1.66 0.318 2.826 1.39 0.259 2.951 1.16 3"4" 4.500 0.616 3.194 3.29 0.500 3.440 2.75 0.409 3.633 2.31 0.333 3.794 1.92 4"6" 6.625 0.908 4.700 7.12 0.736 5.065 5.96 0.602 5.349 5.00 0.491 5.584 4.15 6"8" 8.625 1.182 6.119 12.07 0.958 6.594 10.11 0.784 6.963 8.47 0.639 7.270 7.04 8"10" 10.750 1.473 7.627 18.75 1.194 8.219 15.70 0.977 8.679 13.16 0.796 9.062 10.93 10"12" 12.750 1.747 9.046 26.38 1.417 9.746 22.08 1.159 10.293 18.51 0.944 10.749 15.38 12"14" 14.000 1.918 9.934 31.81 1.556 10.701 26.63 1.273 11.301 22.32 1.037 11.802 18.54 14"16" 16.000 2.192 11.353 41.55 1.778 12.231 34.78 1.455 12.915 29.15 1.185 13.488 24.22 16"18" 18.000 2.466 12.772 52.58 2.000 13.760 44.02 1.636 14.532 36.89 1.333 15.174 30.65 18"20" 20.000 2.740 14.191 64.91 2.222 15.289 54.34 1.818 16.146 45.54 1.481 16.860 37.84 20"22" 22.000 3.014 15.610 78.55 2.444 16.819 65.75 2.000 17.760 55.10 1.630 18.544 45.79 22"24" 24.000 3.288 17.029 93.48 2.667 18.346 78.25 2.182 19.374 65.58 1.778 20.231 54.49 24"26" 26.0002.889 19.875 91.84 2.364 20.988 76.96 1.926 21.917 63.95 26"28" 28.0003.111 21.405 106.51 2.545 22.605 89.26 2.074 23.603 74.17 28"30" 30.0003.333 22.934 122.27 2.727 24.219 102.47 2.222 25.289 85.14 30"32" 32.0003.556 24.462 139.12 2.909 25.833 116.58 2.370 26.976 96.87 32"34" 34.0003.778 25.991 157.05 3.091 27.447 131.61 2.519 28.660 109.36 34"36" 36.0004.000 27.520 176.07 3.273 29.061 147.55 2.667 30.346 122.60 36"42" 42.0003.818 33.906 200.84 3.111 35.405 166.88 42"48" 48.00048"54" 54.00054"Visit www.performancepipe.com for the most current literature.PE4710 (PE3408)Pressure Ratings are calculated using 0.63 design factor for HDS at 73°F as listed in PPI TR-4 for PE 4710 materials. HDPE can accomodate up to 1.5 times the pipe pressure rating for a recurring surge and up to 2.0 times the pipe pressure rating for an occasional surge. Temperature, Chemical, and Environmental use considerations may require use of additional design factors.160 psiRating DR 9.0 DR 11.0Pressure200 psi317 psi 250 psiThis size and dimension chart is intended for reference purposes. It should not be used in place of the advice from a licensed Professional Engineer. Pipe weights are calculated in accordance with PPI TR-7. Average inside diameter is calculated using IPS OD and Minimum wall plus 6% for use in estimating fluid flows. Actual ID will vary. When designing components to fit the pipe ID, refer to pipe dimension and tolerances in the applicable pipe manufacturing specification. DR 7.3DR 13.5Bulletin: PP 152-4710August 2014 Supersedes all previous publications© 2001-2014 Chevron Phillips Chemical Company LPSECTION 1E - CARRIER PIPE Iron Pipe Size (IPS) and Dimension DataDriscoPlex® Pipe for Municipal and Industrial ApplicationsNominal Pipe SizeIPS OD (in)Minimum Wall (in)Average ID (in)Weight (lbs/ft)Minimum Wall (in)Average ID (in)Weight (lbs/ft)Minimum Wall (in)Average ID (in)Weight (lbs/ft)Minimum Wall (in)Average ID (in)Weight (lbs/ft)Nominal Pipe Size1 1/4" 1.6601 1/4"1 1/2" 1.9001 1/2"2" 2.375 0.140 2.078 0.432"3" 3.500 0.206 3.063 0.943"4" 4.500 0.265 3.938 1.55 0.214 4.046 1.274"6" 6.625 0.390 5.798 3.36 0.315 5.957 2.75 0.255 6.084 2.24 0.204 6.193 1.81 6"8" 8.625 0.507 7.550 5.69 0.411 7.754 4.66 0.332 7.921 3.80 0.265 8.063 3.07 8"10" 10.750 0.632 9.410 8.83 0.512 9.665 7.24 0.413 9.874 5.91 0.331 10.048 4.77 10"12" 12.750 0.750 11.160 12.43 0.607 11.463 10.19 0.490 11.711 8.31 0.392 11.919 6.71 12"14" 14.000 0.824 12.253 14.98 0.667 12.586 12.28 0.538 12.859 10.02 0.431 13.086 8.09 14"16" 16.000 0.941 14.005 19.57 0.762 14.385 16.04 0.615 14.696 13.09 0.492 14.957 10.56 16"18" 18.000 1.059 15.755 24.77 0.857 16.183 20.30 0.692 16.533 16.57 0.554 16.826 13.37 18"20" 20.000 1.176 17.507 30.58 0.952 17.982 25.07 0.769 18.370 20.45 0.615 18.696 16.50 20"22" 22.000 1.294 19.257 37.00 1.048 19.778 30.33 0.846 20.206 24.75 0.677 20.565 19.97 22"24" 24.000 1.412 21.007 44.03 1.143 21.577 36.10 0.923 22.043 29.45 0.738 22.435 23.76 24"26" 26.000 1.529 22.759 51.67 1.238 23.375 42.36 1.000 23.880 34.57 0.800 24.304 27.89 26"28" 28.000 1.647 24.508 59.93 1.333 25.174 49.13 1.077 25.717 40.09 0.862 26.173 32.34 28"30" 30.000 1.765 26.258 68.80 1.429 26.971 56.40 1.154 27.554 46.02 0.923 28.043 37.13 30"32" 32.000 1.882 28.010 78.28 1.524 28.769 64.17 1.231 29.390 52.36 0.985 29.912 42.24 32"34" 34.000 2.000 29.760 88.37 1.619 30.568 72.44 1.308 31.227 59.11 1.046 31.782 47.69 34"36" 36.000 2.118 31.510 99.07 1.714 32.366 81.21 1.385 33.064 66.27 1.108 33.651 53.46 36"42" 42.000 2.471 36.761 134.84 2.000 37.760 110.54 1.615 38.576 90.20 1.292 39.261 72.77 42"48" 48.000 2.824 42.013 176.12 2.286 43.154 144.38 1.846 44.086 117.81 1.477 44.869 95.05 48"54" 54.000 3.176 47.266 222.90 2.571 48.549 182.73 2.077 49.597 149.10 1.662 50.477 120.29 54"Visit www.performancepipe.com for the most current literature.PE4710 (PE3408)Pressure Ratings are calculated using 0.63 design factor for HDS at 73°F as listed in PPI TR-4 for PE 4710 materials. HDPE can accomodate up to 1.5 times the pipe pressure rating for a recurring surge and up to 2.0 times the pipe pressure rating for an occasional surge. Temperature, Chemical, and Environmental use considerations may require use of additional design factors.DR 17.0 DR 21.0 DR 26.080 psiRatingThis size and dimension chart is intended for reference purposes. It should not be used in place of the advice from a licensed Professional Engineer. Pipe weights are calculated in accordance with PPI TR-7. Average inside diameter is calculated using IPS OD and Minimum wall plus 6% for use in estimating fluid flows. Actual ID will vary. When designing components to fit the pipe ID, refer to pipe dimension and tolerances in the applicable pipe manufacturing specification. 100 psiDR 32.563 psiPressure 125 psiBulletin: PP 152-4710August 2014 Supersedes all previous publications© 2001-2014 Chevron Phillips Chemical Company LP HALLIBURTON MATERIAL SAFETY DATA SHEET Product Trade Name: BORE-GEL® Revision Date: 25-Feb-201011.CHEMICAL PRODUCT AND COMPANY IDENTIFICATION Product Trade Name: Synonyms: Chemical Family: Application: Manufacturer/Supplier Prepared By BORE-GEL® None Mineral Viscosifier Baroid Fluid Services Product Service Line of Halliburton P.O. Box 1675 Houston, TX 77251 Telephone: (281) 871-4000 Emergency Telephone: (281) 575-5000 Chemical Compliance Telephone: 1-580-251-4335 e-mail: fdunexchem@halliburton.com �-COMPOSITION/INFORMATION ON INGREDIENTS SUBSTANCE CAS Number PERCENT Bentonite 1302-78-9 60 -100% Crystalline silica, cristobalite 14 464-46-1 0-1% Crystalline silica, tridymite 15468-32-3 0-1% Crystalline silica, quartz 14808-60-7 1-5% ACGIH TLV-TWA OSHA PEL-TWA Not annlicable Not annlicable 0.025 mg/m' 1/2 x 10 mgim' %SiO2+2 0.05 mg/m3 1/2 x 10 mg/m' %SiO2+2 0.025 mglm' 10 maim' %SiO2+2 13.HAZARDS IDENTIFICATION Hazard Overview CAUTION! -ACUTE HEAL TH HAZARD May cause eye and respiratory irritation. DANGER! -CHRONIC HEAL TH HAZARD Breathing crystalline silica can cause lung disease, including silicosis and lung cancer. Crystalline silica has also been associated with scleroderma and kidney disease. This product contains quartz, cristobalite, and/or tridymite which may become airborne without a visible cloud. Avoid breathing dust. Avoid creating dusty conditions. Use only with adequate ventilation to keep exposures below recommended exposure limits. Wear a NIOSH certified, European Standard EN 149, or equivalent respirator when using this product. Review the Material Safety Data Sheet (MSDS) for this product, which has been provided to your employer. BORE-GEL® Page 1 of7 SECTION 1F - DRILL FLUID AND PROPOSED ADDITIVES HDD Henniker Directional Drilling, L.L.C. January 16, 2026 Yarmouth, MA Sewer Submittal Noise Abatement Henniker Directional Drilling will not provide noise abatement procedures. Danielle Martin General Manager Henniker Directional Drilling, LLC Henniker Directional Drilling LLC •PO Box 2156 • Henniker, NH 03242 • PH: 603-428-6333 • DanieileM@HDDbore.com• FAX: 603-428-7822 HDDBORE.com SECTION 1G NOISE ABATMENT NOT PROVIDED SECTION 2 SURVEYING EQUIPMENT AND PROCEDURES (REFERENCE "METHODS, EQUIPMENT, AND MATERTIALS DESCRIPTION PLAN" FOR LOCATING EQUIPMENT AND PROCEDURES) SECTION 3 PROTECTION OF ADJACENT STRUCTURES AND FACILITIES PLAN SECTION 3A - MONITORING & PROTECTION PLAN APPENDIX VIII Horizontal Directional Drilling Operations and Monitoring Plan PROJECT OVERVIEW The project involves installing approximately 400 feet each of 10-inch and 6-inch HDPE DR11 PE4710 carrier pipes placed beneath the ENVIRONMENTALLY SENSITIVE AREA using horizontal directional drilling (HDD) methods for construction. The pipe will be terminated with flanges located in new manholes constructed at each end of the pipe, which will in turn be connected to new Ductile Iron Pipe (DIP) as part of the overall project. The portion of the project relevant to the Horizontal Directional Drilling (HDD) Operations and Monitoring Plan involves crossing the ENVIRONMENTALLY SENSITIVE AREA between LOCATION. The discussions in this section pertain only to the ENVIRONMENTALLY SENSITIVE AREA Crossing. A Project Locus is provided on Figure 1 and a plan indicating the project location included as Figure 2 PROJECT AREA GEOLOGY The project site is located within the ENVIRONMENTALLY SENSITIVE AREA. The ENVIRONMENTALLY SENSITIVE AREA valley is characterized by GEOLOGY. SPECIAL DESIGN CONSIDERATIONS Though unlikely, there are environmental concerns with a potential release of drill fluid to the ground or river bottom surface (frac-out) during the HDD process. Special design and construction considerations have been incorporated into the construction documents and this monitoring and operation plan to mitigate the concerns for environmental impacts. For this discussion, hydraulic fracturing is defined where the borehole pressure exceeds the soil stress around the bore hole, resulting in a “tearing” crack developing in the soil as the soil is put into tension. The crack propagates away from the bore in a pattern that is dependent on the ground stress and geology in the immediate vicinity of the borehole. The crack is typically located in the immediate vicinity of the drill bit and occurs with some frequency in the entry and exit portions of a bore in soil because of shallow soil cover. If the crack reaches the ground surface or river bottom, drill fluid is released into the environment, known as a frac-out. The following discussions summarize project design and construction mitigation considerations. Drill Path Design. The proposed drill path is in the river sediments. Subsurface investigations indicated that rock is relatively deep at the west side of the boring and rapidly rises toward the east side. The variability and depth of the bedrock precludes placement of the bore in rock, which would otherwise reduce the risk of hydraulic fracturing. Partial placement in rock increases the risk of a frac-out on land or into the river because of the extended time required to start a reliable hole into the rock. A plan view of the proposed bore path is shown on Figure 2, and a cross section showing the site geology along the borepath is shown on Figure 14. The bottom of the river and the clearance between the proposed bore path and the river bottom are indicated on the cross section, and is up to 25 feet below the existing Federal Channel bottom. Design mitigation for a soil frac-out includes an assessment of soil stress (depth of soil cover and soil properties over the bore path), followed by a bore path that is designed to provide an adequate factor of safety against hydraulic fracturing. The bore path shown on Sheet 14 has OWNER DATE Page 2 been developed as the shallowest depth of the bore for a reasonable factor of safety against hydraulic fracturing and assumes certain controls on the drill fluid density and pressures in the bore. The bore ends are the most vulnerable as the bore path must pass though these shallow zones to the design depth. Overburden casing will be used in this situation as the bore ends will be passing beneath environmentally sensitive areas. At this time, the design indicates placing approximately 85 feet of casing at each end of the bore which should result in a minimum depth of cover over the bore of 20 feet of soil and water. Additionally, a gas transmission pipe river crossing was successfully installed in the soil in the immediate vicinity. The location of this pipe is shown on Sheet 2 and the profile is shown on Sheet 14. Overburden Casing. There is a transition zone between the deep portion of the bore and the exit points at the entry and exit areas on both sides of the river. This transition zone is in an area where relatively low excess annulus pressure in the bore can result in a frac-out. To minimize the risk of a frac-out in this area, the contract documents will require that steel casing be placed to a depth of 20 feet along the bore path, which will result in approximately XXX feet of casing. The steel casing will be driven during the pilot bore process and is an effective method for containing drill fluids in the more shallow entry and exit zones. In-situ Monitoring. The proposed drill path passes under the ENVIRONMENTALLY SENSITIVE AREA, which is a navigable waterway with significant private and commercial traffic. Historical methods for monitoring for potential frac-out in the river include employing a vessel with side scan radar, or other methods such as rhodamine dye tracer. These methods are reactive, however, and only provide indications of a release after a frac-out has occurred. This project instead proposes a pro-active drilling monitoring and operations program utilizing drill fluid properties and pressures to identify and mitigate drill fluid pressure during drilling operations. This method provides early indicators of a potential frac-out before it occurs. Hydraulic fracturing can not occur unless drill fluid pressure exceeds the confining pressure provided by the soil around the bore hole. In most all cases, the highest pressure in the drill fluid is in the immediate proximity of the drill bit. This soil confining pressure at any location can be relatively accurately predicted. Drill fluid applies pressure to the borehole inner wall by a combination of density and depth and dynamic pressure required to move the drill fluid out of the hole. The drill fluid monitoring program involves measuring the drill fluid pressure close to the drill bit and adjusting the drill fluid properties to maintain the pressure below that predicted to cause hydraulic fractruring of the soil In order to implement the Fluid Monitoring Program, a basic fluid composition program that matches the soil conditions is constructed. From a base composition, the critical properties of the fluid are defined along with a range of acceptable property variance to allow for fluctuations. Also defined at this point is the expected Annular Pressure Curves along with its’ acceptable range of variance. As drilling is commenced the next phase of the program is to monitor, in real-time, the changes in fluid composition and the drilling pressures being applied to the annulus of the borehole. OWNER DATE Page 3 The ability of the drilling operation to maintain the expected pressure curve can now be used as a tool to establish drilling efficiency, as well as formation reaction to the drilling process. Fluctuations in annular pressure measurements are used to establish trends. Sharp, spiking pressure conditions or slower more gradual changes can provide indications as to the nature of a developing trend. Fluctuations caused by borehole instability or insufficient hole cleaning will tend to be more dynamic and amplified. Fluctuations as a result of systematic developments (such as changing fluid properties) may be more gradual with less amplitude. Also incorporated into the Fluid Monitoring Program is a rig function monitor and recorder. These systems, called EDR’s (Electronic Drilling Recorders), will allow for several critical measurements involving the drilling rig and fluid circulating system to be continually captured and recorded. Total drilling fluid volumes are monitored by this system including warning alarms if unacceptable fluctuations are encountered. Maximizing the effectiveness of the Fluid Monitoring Program, will be a guideline of established Safe Drilling Practices tailored around the projects specific soil and operating conditions. Quality Assurance. The contractor shall be required to conduct operations in general accordance with “Horizontal Directional Drilling Good Practices Guidelines” published by the HDD Consortium, dated May 2001 and as modified for specific conditions related to this project. [Include this as an Appendix?(I would suggest not including as it is big and is copyrighted)] The contractor shall also be required to have a Drill Fluid Specialist on-site during drilling operations to monitor drill fluid pressure in the borehole in the vicinity of the drill bit, drill fluid properties going down the hole and returning form the hole, and be responsible to adjust the drill fluid properties should pressure measurements indicate that problems may occur during drilling operations. This procedure will be specified in the Contract Bid Documents. Drilling Fluid has many properties designed to successfully advance the boring. For this project, the drill fluid will provide the following functions: Suspend and transport the drill cuttings from the boring then release the cuttings at the mouth of the bore hole or during the drill fluid reprocessing operations. Clean and remove drill cuttings from the drill bit. Cool the tracking electronics in the drill head Provide power to drive the mud motor, if used (we do not anticipate the need for a mud motor on this project) Provide drill fluid jet assist to supplement the soil cutting capability of the drill bit Provide a structural “mud cake” for supporting the bore hole wall Provide a barrier to reduce infiltration of external groundwater into the bore Provide a barrier to keep the drill fluid in the bore hole Provide lubrication for the drilling equipment and product pipe pull OWNER DATE Page 4 Provide a low permeability seal along the bore hole annulus to prevent long-term migration of other fluids along the bore path. Provide a fill for the bore annulus between the soil and the installed product pipe. The Drill Fluid Specialist will develop a drill fluid mix and determine the properties of the mix to maintain optimal functional performance. Drill fluid properties include the density, viscosity, bentonite content, and pH among others. The drill fluid mix and properties and pressure in the bore will be recorded for comparison against engineering predicted maximum pressures that may be tolerated to prevent hydraulic fracturing. MSDS and product data sheets for all materials used in the drill fluid shall be maintained on site and made available to the REGULATORY AGENCY. The drill fluid specialist may need to adjust the mix as conditions warrant to maintain the functional qualities of the drill fluid. Drill fluid design requires an understanding of the drill fluid properties that permit the fluid to do the designed tasks while addressing potential issues associated with hydraulic-fracturing and a resulting frac-out. The drill fluid specialist will be required to know how to design the properties of the fluid for the specific drill system to result in just enough pressure remaining at the drill bit in the bore annulus to move the drill fluid and cuttings up the bore hole without resulting in excess pressure that would fracture the bore hole walls. The drill fluid specialists with the Owners’ project engineer shall determine appropriate bore hole annulus maximum pressures to prevent hydro-fracturing. Similar pro-active drill fluid management programs have been successfully implemented on other environmentally sensitive projects. The intent is to obtain early data that is relevant to hydraulic fracturing and to use the data to timely adjust the drilling method to mitigate potential hydraulic fracturing from occurring. The program shall consist of drill fluid properties monitoring and drill fluid pressure monitoring in the bore annulus in the vicinity of the drill bit. Pressure increases can result from several sources, including: increased drill fluid density resulting from poor drill fluid design or poor cleaning methods; loss of drill fluid suspension properties by drill fluid chemistry changes, resulting in the inability to clean the drill cuttings from the bore; failure to break the thixotropic (solid forming) condition of drill fluid that has stopped moving for a period of time; and/or insufficient pump capacity to maintain sufficient up hole velocity for removing drill cuttings. These parameters and pressures will be monitored and changed to mitigate the potential for hydraulic fracturing during the drilling process. An envelope of max and min pressures will be designed for the specific borehole pathway. Construction specifications will state that the contractor stay within this envelope of pressures or pressures modified during the construction by the drill fluid specialist and the bore designer. This ability to monitor and change drilling and drill fluid conditions is proactive, identifying and eliminating the conditions from occurring that could lead to hydraulic fracturing during construction. Monitoring and Operations Plan. Based on the special design considerations described, the following Monitoring and Operations (M&O) plan has been developed specifically for the Thames Basin Regional Water Intertransfer Project to identify parameters that precede a frac- OWNER DATE Page 5 out, design and implement construction procedures to mitigate those parameters; and contain and cleanup a potential release plan. The plan has been divided into five drilling conditions that are described in the following paragraphs. Condition 1 – Normal Drilling Conditions Normal Drilling – no uncontrolled release Entrance/Exit pit drill fluid removal and reconditioning Routine drilling data collection Routine monitoring for bentonite release (hydro-frac) The contractor shall be required to maintain full drill fluid circulation within the bore to the best degree possible to properly perform the drill fluid functions. The following information shall be recorded and made available to the REGULATORY AGENCY and the project engineer on site during the drilling operations. The Driller shall maintain a drilling log with the following minimum recorded information: Monitor and record periodically the approximate drill fluid pump rate and pressure and relative return percentage during drilling of each rod. Start/Stop times and dates for each rod Approximate thrust and rotation hydraulic pressures for the drill rod Approximate location of the drill head Drill string configuration and attached equipment. Equipment breakdowns and time duration of breakdown The Drill Fluid Specialists shall be required to monitor and record the drill fluid properties of both down hole and return fluid such as density and viscosity and possibly chemistry and the pressure of the drill fluid in the bore annulus in the immediate vicinity of the drill bit. These values shall be compared to the design parameters as determined by the drill fluid specialists for compliance with design parameters. The Contractor shall be required to provide a person to monitor ground surface conditions along the bore path on land and on the river bottom where it is visible using a motor boat and sight tube. How practical is this over the entire path of the bore This will work up to about 10 feet of water if there is not turbidity form a storm of boat traffic.? So will there be a motorboat in the river during drillingYes full time access to a boat will be necessary for the contractor thought he boat may only be used intermittently and possibly for ferrying personnel across the river.? If there is a loss of circulation of more than 50% for 30 minutes then proceed to Condition 2. Condition 2 – Loss of Circulation OWNER DATE Page 6 No returns to the entrance/exit pits or less than 50% returns for a period of 30 minutes. Stop drilling and pumping drill fluids Assess monitoring data from Condition 1 for indications of hydro-fracturing. Visually inspect the ground surface or river bottom along the drill path between the drill rig to a distance of 100 feet past the drill head or to a water depth of approximately 10 feet using a sight tube and boat for signs of drill fluid release [how will this be done along the river bottom – is there a team ready to go? SCUBA divers NO ? Boats?]. Implement procedures to restore circulation based on the information available at the time. Restart drilling and attempt to restore drill fluid circulation using the developed procedures. If drill fluid circulation is reestablished and no drill fluid release is visibly detected. Return to Condition 1. If drill fluid loss is determined to be a geological function or the result of a cavity, then assess conditions with the Owner and the REGULATORY AGENCY and determine if drilling can continue. There could be many causes for the loss of drilling fluid including but not limited to: encountering a void such as a pipe, drill fluid density increasing to an extent that it can not be pumped from the hole and has started to hydro-frac the bore hole, or bore hole annulus blockage preventing circulation. Should a loss of circulation occur, the Contractor shall be required to notify the Engineer or designated Owners representative of the situation and review the Condition 1 monitoring data with the Owner’s representative. The Owner shall notify the REGULATORY AGENCY if a frac-out is located. If the cause can not be determined and no frac-out location can be observed then implement drilling steps to restore circulation. These steps may include opening the hole mechanically, removal of drill tools without drill fluid circulation and redrilling with drill fluid circulation, and adjusting the drill fluid properties. The contractor may also elect to pump a hole sealant into the hole to stop a leak from voids or fissures in the ground. If circulation is reestablished then the driller can return to Condition 1. [How long before it goes thixotropic? It will start to gel as soon as it stops moving. The gel strengthens quickly depending on the mix and can several psi strength within a few hours and 5 to 8 psi after a weekend.] Condition 3 – Drill Fluid Pressure and/or Properties Not Within Design Parameters Drill fluid returns but annulus monitoring pressure and/or properties are not within the design parameters for the drill fluid. OWNER DATE Page 7 Assess the deviation history of the drill fluid properties and increase in annulus monitoring pressure. o Situation 1. The drill fluid monitoring demonstrates slow changing to out of design parameter values. Stop drilling, adjust drill fluid to design parameters and continue drilling. o Situation 2. Rapid change in drill fluid parameters or annulus monitoring pressure. Stop drilling immediately. Clean hole and adjust drill fluid parameters until drill fluid fully returns to drill entry/exit pit and drill fluid properties are restored. Once the drill fluid parameters are within design limits and the drill fluids are again returning, return to Condition 1. There are many possible causes of the monitoring data exceeding design limits. The two possible trends are: 1) slow change in parameters and pressure, 2) rapid change in pressure. Slow changes indicate a gradual change in the drill fluid properties or a gradual restriction of the bore annulus. Once the pressure reaches a critical value then the pressurized drill fluid will hydraulically fracture the bore hole. Causes of this type of failure include incorrect drill fluid chemistry for the ground, poor cleaning system performance, insufficient capacity of the drill fluid pumping system, ground/groundwater contamination that changes the drill fluid chemistry, inappropriate drill method. Rapid changes are typically caused by rapid restrictions in the bore annulus such as a collapse or sudden inflow of material when the drill encounters an unstable soil such as sand with an artesian groundwater head or is the mud cake has insufficient strength to maintain a stable bore hole wall. These restrictions build rapidly, sometimes within seconds and if uncorrected will lead to a hydraulic fracturing of the bore hole. The proposed monitoring system and program provides early data and data trends that allow timely modification of drilling methods and drill fluid parameters thus preventing hydraulic fracturing prior to excessive pressures being developed in the bore annulus. Should the monitoring system detect a change in one of the monitoring parameters then the drilling should be stopped and the situation assessed to determine the cause of the change and mitigation applied. Once the mitigation has been completed then drilling can commence under Condition 1 monitoring. Condition 4 – Drilling Fluid Release and Remediation If a drilling fluid release has been detected, and circulation can not be restored or the loss explained and remediated, then the Contractor will implement the following sequence of operations: 1. Shut down the drilling operations, [how long does it take for the drilling fluid to stop flowing?It depends on how long the circulation loss has been. If OWNER DATE Page 8 caught early then a matter of minutes if it has continued and the ground has developed a reservoir, then it may be 10 to 30 minutes depending on stresses in the ground and volume pumped. This is not expected to happen with this program. I expect minutes not hours.] Place containment around the frac-out area [on the river bottom?containment would be straw bales and possibly excavating a hole at the frac-out location to facilitate pumping the fluid out for restoration, on the river bottom, you may want to use a silt curtain in tranquil water orin the water, a metal open top and bottom box that would be dropped over the release area for containing the flocculated drill fluid so it could be removed by pumping into a tank truck for disposal. ] if possible to contain the drill fluid. The contractor, drill fluid specialist, and bore designer shall assess the conditions and develop a procedure for proceeding and remediation. 2. Two drilling procedure alternatives are available: a. Drill past the problem area for some distance without the use of drill fluid then attempt to restore circulation without further frac-out loss. If this alternative (drilling past the problem area) restores circulation and does not result in additional frac-out, then proceed with drilling under Condition 1 - Monitoring. b. Place a commercially available bore hole sealer in the hole in accordance with the manufacturer’s recommendations and reassess drilling procedures. [Where, how, what is it?]. Proceed to Step 3. 3. Shut down drilling operations and place bore sealing materials in accordance with the manufacturer’s recommendations. Pull the drill head away from the bottom of the hole or remove from the hole. Let the bore sit until the bore seal has activated in accordance with the manufacturer’s recommendations. 4. Following the shutdown, turn the rod rotation on without pumping any drill fluid. Rotate the drill rods and move the drill rods up and down the bore to breakdown the drill fluid thixotropic condition. Do this for a minimum of 5 minutes before turning on the drill fluid pump. 5. Turn on the drill fluid pump and set to low pressure and volume while the drill rods are being rotated. If circulation is restored and the frac-out has stopped, then drilling may continue under Condition 1 monitoring. 6. During any shutdown, the driller may rotate the drill to prevent elevated gel strengths from developing in the drill fluid from lack of movement. Drill fluid can only be circulated if the shutdown was for reasons other than drill fluid loss. 7. The contractor may attempt to seal a frac-out up to six times prior to making a decision to continue drilling under approved modified procedures or to reroute the drill. Alternatively, the contractor may grout the bore hole to seal the crack then drill through the grout to continue the bore. 8. If the decision is made to reroute the drill head because an acceptable solution can not be achieved, then the plans and procedures shall be discussed between the Owner, Contractor, Town, REGULATORY AGENCY, and the US COE. OWNER DATE Page 9 Rerouting is defined as complete abandonment of the bore path and relocating the bore path in the problem area. The abandoned borehole will be grouted with cement and bentonite mixture or an approved bentonite based environmental hole seal to seal a potential pathway for the rerouted drill fluid. Approvals for rerouting shall be obtained from both the REGULATORY AGENCY and the US COE. Condition 5 – Drill Fluid release but not drill fluid loss detected. If a drill fluid release has been detected but circulation has been restored or was never lost, then the contractor shall implement the following sequence of operations. 1. If the contractor is able to contain and control the release with the containment and collection system and removal equipment placed into operation at the site subsequent to the release, then drilling may continue with the approval of the REGULATORY AGENCY. However, if at any time, the amount of material being released exceeds the rate of removal being achieved by the containment and collection and removal system, then the drilling operations shall be suspended until the release can be brought under control by the contractor. Fluid Release Action Plan. The contractor shall be required to implement the following action plan in the event that a drilling fluid release is detected. 1. Notify the Owner or the Owner’s authorized representative about the release. The Owner will be responsible for notifying the following: a. REGULATORY AGENCY b. 2. Locate and mark the origin of the release. [How is this done in the river with currents and at depthUse GPS or shore stakes?] 3. Monitor the release area and the remaining drill path and determine the boundaries of the release area. Use divers if necessary. 4. Investigate down-current areas to assess potential impacts. 5. A dive team shall be assigned to the release area to monitor the status and extent of the release. The area will be confined to minimize the area of impact and facilitate the removal of deposited material. The dive team shall take measurements of the horizontal limits and depth of deposition of the drilling fluid. These measurements shall be made at slack tide. The dive team shall be monitoring the release point when bore hole sealing material is pumped into the borehole and during startup periods following shutdown of drilling operations for signs of renewed hydro-frac. 6. The contractor shall maintain on-site, and have ready at all times, at least 200 feet of bentonite containment fencing with straw bail backup and one underwater containment boom such as a trench box. This fencing, straw bails, OWNER DATE Page 10 and box shall be assembled and ready for immediate deployment when a release, failure, or breach is detected. As warranted by site conditions, the fence shall be installed within the first eight hours of a detected release. The determination of deployment will depend upon the location of the release. For example, it may not be practical to install fencing in a tidal mudflat or in the river should a release occur in those locations. It may not be possible to install the box in a shipping lane unless it will not impact traffic. 7. The contractor shall maintain spare pumps and hoses on-site at all times to initiate cleanup and removal of a release as soon as practical, or until additional equipment can be mobilized to the site. Additionally, the contractor shall maintain a 20,000-gallon sedimentation tank on-site, along with a supply of strawbales, sand bags, and 100 feet of silt fencing to facilitate the removal of release material prior to additional equipment arriving on-site. 8. Following detection of a release, the Contractor shall be required to shutdown drilling operations and mobilize the necessary removal equipment to the project site within 24 to 48 hours. [We should mention the names of contractors that could mobilize this type of equipment. We could do research in CT.] This equipment may include vacuum trucks, additional sedimentation tanks, pumps and hosing, barges and boats, and crane or backhoe with a smooth clam-shell or hoe bucket to dredge the river bottom and to remove and dispose of released material as required. However, the removal method and type of equipment to be used will depend on the location of the release within the river. For example, if a release occurs within the tidal mudflats, the contractor should be able to cleanup the release material using a combination of vacuum trucks and sedimentation tanks. Conversely, if a release occurs within the navigable channel, a barge mounted operation may be required to remove the release material. The contractor will have to make this determination in the field based on actual site conditions and in consultation with the Town and the REGULATORY AGENCY. Under no circumstance shall the contractor employ the use of a dredging operation until all other methods of collection and removal have been exhausted with little or no success. Contract Documents will also require the contractor to prepare and submit to the Owner an “Inadvertent Drilling Fluid Return Contingency Plan” prior to the start of drilling operations. This plan shall describe the means and methods the contractor will employ to address inadvertent surface returns in compliance with all local, state, and federal regulations and permits and name the contractor that will be on call to complete such an operation. A copy of this plan will be provided to REGULATORY AGENCY. 9. The contractor shall be required to mobilize additional equipment as needed, or as directed by the owner or REGULATORY AGENCY, to facilitate the cleanup and removal of release material in a timely manner. 10. In the event that a release occurs on land, the contractor will immediately contain the release with straw bales and silt fencing. The drilling fluid shall be transferred either manually or by pump into a sedimentation tank, flocculated OWNER DATE Page 11 and decanted or otherwise treated for disposal as necessary, and removed from the site. 11. The contractor shall maintain records of the quantity of release material removed from either the river bottom or land surface, transferal of the material to other containment, and daily status of cleanup operations. The contractor shall be responsible for disposing the release material in accordance with all local, state, and federal regulations. Records or manifests of the disposal material shall be furnished to the owner and the REGULATORY AGENCY upon completion of the work. SECTION 4 CONTINGENCY PLAN FOR REMEDIATION OF POTENTIAL PROBLEMS (THIS SECTION PROVIDES A BASIC CONTINGENCY PLAN IF ISSUES ARE ENCOUNTERED DURING DRILLING OPERATIONS. REFERENCE "INADVERTANT RETURN AND SURFACE SPILL CONTINGENCY PLAN" FOR SPECIFIC PROCEDURES PERTAINING TO SECTION 330507.13 - 1.6.C7.) Contingency Plan for Remediation of Potential Problems This contingency plan establishes procedures to be followed if Henniker Directional Drilling (HDD) encounters problems during drilling operations. The intent is to ensure work is stopped promptly, risks are controlled, conditions are assessed, and the Engineer is notified before operations resume. Upon identifying a problem, the Contractor shall: 1. Cease drilling operations immediately. 2. Secure the borehole to prevent further instability or fluid migration. 3. Stabilize the site and implement environmental protection measures as necessary. 4. Shut down equipment safely while maintaining bore integrity, if feasible. 5. Isolate a0ected areas and restrict access if safety is a concern. No drilling advancement or pullback operations shall continue until authorized by the Engineer. After stopping work, the Contractor shall: 1. Document drilling parameters at the time of the event (depth, pressures, torque, fluid volumes, etc.). 2. Inspect equipment and tooling. 3. Verify bore alignment and location. 4. Assess drilling fluid returns and containment. 5. Identify potential impacts to utilities, structures, roadways, or environmentally sensitive areas. 6. Evaluate subsurface conditions relative to geotechnical data Contractor shall provide a written summary of findings to the Engineer and standby for further direction. SECTION 5 DISPOSAL OF SPOILS AND DRILLING FLUIDS PLAN Dig-It Construction LLC 141 Great Western Road S. Dennis, MA 02660 Office: 508-432-1635 March 10, 2025 CDM Smith C/O Michael Guidice – Senior Project Manager RE: Yarmouth Sewer Project – Dig-It Disposal of Potential Spoils & Drilling Fluids Plan To Whom it May Concern, This letter and the accompanying documentation are provided in reference to Section 330507.13, Paragraph 1.6.H. Dig It has confirmed that, in the event of any inadvertent spills or leakage of drilling fluids, a qualified hazardous waste facility is available and willing to accept and properly dispose of such material. Please refer to the attached letter from our approved disposal facility, ReWorld Waste, for additional confirmation. Thank you. Dig It Construction, LLC SECTION 5 - DISPOSAL OF SPOILS AND DRILLING FLUIDS PLAN Page 1 | 1 700 Richmond Street, East Taunton, MA 02718 PH: 508-828-1005 • FX: 508-824-2486 3-09-2026 Dereck Pacheco, Assistant Project Manager DIG-IT Construction RE: Yarmouth Sewer Project Dear Dereck : Reworld in East Taunton, MA is a licensed non-hazardous recycling facility that could potentially accept non hazardous drilling materials as identified in the Safety Data Sheets supplied by Dig-It Construction (attached) All material recycled at Reworld must be non -hazardous and would need to be analyzed prior to acceptance into Reworld. These materials must meet the acceptance criteria listed below: WASTEWATER SPECIFICATIONS INTO REWORLD PARAMETER LIMIT ANALYTICAL METHOD Total Semi-Volatile Organic (“SVOC”) and Volatile Organic Compounds (“VOC”) < 30 mg/l Method 8270 (SVOCs) & Method 8260 (VOCs) Total Nitrogen < 200 mg/l EPA method 300.00 (nitrate & nitrite) & SM4500Org-D (TKN) Total Suspended Solids (TSS) < 1,000 mg/l SM2540D Fecal Coliform < 10,000 colonies/100 ml SM9222D Polychlorinated Biphenyls (PCB) Non-detect (<0.5 ug/l) pH 6.5 to < 12.5 Total Dissolved Solids (TDS) < 1,500 mg/l SM2540C Oil No discernible layer Visual Asbestos <0.1% Pre-filtered at the site, through a 5- micron filter RCRA 8 Metals Non-Haz PFAS CBC MANDATORY TESTING (all other parameters based on generator’s knowledge) TERMS & CONDITIONS • This pricing is strictly based on meeting the specifications as indicated above and characterized as non- RCRA/MA.DEP/TSCA regulated waste. If the analytical indicates that any of the above specifications are exceeded, the pricing will be adjusted accordingly. • Mandatory analytical testing requirements include Total VOC (BY 8260), Total SVOC (BY 8270), TSS, TDS, pH, and any other suspected RCRA or TSCA regulated compounds, total nitrogen and/or fecal coliform, RCRA 8 metals, PFAS…., based on generator’s knowledge, that may be present If you have any questions or if you would like to discuss any other services we can supply, please feel free to contact me at 617-592-6991. Thank you for this opportunity and we look forward to working with you. Sincerely, Heather M. Atwood Heather M. Atwood Senior Account Manager SECTION 6 EQUIPMENT LAYOUT PLAN CONFORMED SETCONFORMED DRAWINGSCONFORMED DRAWINGSHDD WILL BE CONDUCTING OPERATIONS WITHIN THE LIMIT OF WORK AS SHOWN.ROUTE 28 WILL BE CLOSED DURING HDDOPERATIONS FOR ADJACENT SEWER WORKON ROUTE 28. TRAFFIC WILL BE DETOUREDAS SHOWN ON THE TRAFFIC MANAGEMENTPLANS PREVIOUSLY APPROVED BY MA DOT. SECTION 7 INADVERTANT RETURN AND SURFACE SPILL CONTINGENCY PLAN SECTION 8 HORIZONTAL DIRECTIONAL DRILLING WORK PLAN (SEE SECTION 10 FOR DETAILED PROFILE OF THE PROPOSED BORE PATH) EXHIBIT Z HORIZONTAL DIRECTIONAL DRILLING CONTINGENCY PLAN 12/2/2013 Page 1 SECTION 8A - CONTINGENCY PLAN EXHIBIT Z HORIZONTAL DIRECTIONAL DRILLING CONTINGENCY PLAN 1.0 Horizontal Directional Drill Construction Method Horizontal Directional Drilling ("HDD") is a construction method to install pipelines beneath waterbodies, wetlands and features that require special attention to environmental and logistical concerns. In the HDD process, there are three basic steps to install a pipeline crossing: pilot hole, hole opening and pullback. This section will address the HDD process, the different failure modes and the failure criteria for the three steps of HDD. Further, the process Williams Field Services Company, LLC and DMP New York, Inc. (collectively, "Williams") will use to evaluate potential failure of the HDD crossings for the 16-inch New York Mainline Loop Natural Gas Pipeline Project ("Project") and determine when the HDD method will be abandoned. Construction drawings for the two HDD's proposed for the Project are located in Exhibit Z-2. 1.1 Pilot Hole Process The first stage of the HDD process consists of directionally drilling a small-diameter pilot hole along a predetermined path. For these proposed crossings, typical pilot hole diameters will likely range from 9-¼ to 12-¼ inches. During drilling of the pilot hole, directional control is achieved by using a non-rotating drill pipe string with an asymmetrical leading edge. The asymmetry of the leading edge creates a steering bias, which allows the operator to control the direction of the drill bit. The actual path of the pilot hole is evaluated during drilling by a monitoring and control system, which tracks the progress and location of the bottom hole assembly ("BHA"). The horizontal and vertical position of the pilot hole is typically surveyed by two different methods: • downhole survey tools that use an instrument referred to as a probe; and • a secondary, TruTracker, ParaTrack or equivalent survey system that uses a wire installed on the ground surface to create a magnetic field. The most commonly used coil layout is a survey coil grid that is laid on the ground and that is at least as wide as the survey probe is deep. Typically, multiple coils will be installed, with at least one on each side of the feature being crossed. If the ParaTrack survey system is used, it is common for the coil wire to be laid down the centerline with a return wire a minimum of 300 feet left or right of the proposed centerline. The placement of the coils is limited to areas where ground surface conditions and 12/2/2013 Page 2 agreements with landowner’s permit. If ground conditions or landowner agreements do not allow for the installation of a coil wire, a beacon may be used with the ParaTrack system. The beacon does not require a coil wire to be installed but does require repositioning, generally along centerline of the alignment, as the pilot hole progresses. For each survey method, the position of the BHA is located after each segment (joint) of drill pipe has been drilled (approximately 30 feet). A pilot hole surveying technique has been developed that uses an inertial measurement unit to calculate the position of the BHA as the pilot hole is drilled. The azimuth and inclination of the BHA are calculated through the use of fiber-optic gyroscopes rather than the earth's magnetic field. The use of a survey coil grid installed along the alignment is not required with this system. This type of system is relatively new and has seen limited use in the United States. This system could be considered as an alternative to the traditional surveying methods. The pilot hole consists of drilling the initial hole beneath the proposed crossing as per the project plan and profile drawing. Based on the design parameters, the minimum allowable three-joint radius over any consecutive three-joint section is established to reduce the risk of overstressing the product pipe during installation. Under the generally accepted industry standard, the design radius in feet for the entry and exit vertical curves is typically 100 times the product pipe diameter in inches (for example, 16-inch-diameter pipe times 100 = 1,600-foot design radius). The pilot hole is typically drilled using a tri-cone rotary bit connected to either a jetting assembly or a positive displacement mud motor. Drilling fluid is pumped through the drill pipe string to aid the jetting assembly or mud motor in cutting the soil. The drilling fluid also helps lubricate the drill stem, suspend and carry the drilled cuttings to the surface, and form a wall cake to keep the hole open and reduce the potential for infiltration from or drilling fluid loss to the formation. HDD construction is intended to be completed above ground and will not require support of excavation. If necessary, a temporary dewatering plan prepared by GZA was approved for the project and can be found on Procore (Submittal #312319-001 Revision B: Dewatering). 1.2 Hole Opening Process The hole opening process begins after the pilot hole is complete. The pilot hole is enlarged to a diameter that will accommodate the pipeline. There are two types of tools that can enlarge (ream) the pilot hole: • Flycutters, which are used for most soil formations; and • rock hole opening tools, which are used for very dense soil or rock formations. We anticipated that hole openers will be required for enlarging the pilot holes on this 12/2/2013 Page 3 project. The reaming tools are typically attached to the drill pipe string that drilled the pilot hole and are then rotated and pulled back toward the drill rig. As the reaming tool is pulled, a string of drill pipe is added behind the tool to maintain a continuous section of drill pipe in the hole at all times. The diameter of each pass will increase in incremental steps until the desired diameter is reached, typically 12 inches or 1.5 times larger than the diameter of the product pipe. The final hole diameters for these crossings should be a minimum of 24 inches. The HDD contractor may choose to ream away from the drill rig. If so, reamers fitted into the drill pipe string at the rig are rotated and pulled toward the exit point. To accomplish this, a second pulling device (second HDD rig, bulldozer, excavator or some form of pulling unit) is used to pull the reaming tools through the hole toward the exit point while the rig on the entry side applies the rotation to the drill pipe string. The hole opening process in more dense soil or rock formations may require a significant length of time to enlarge the hole to the required diameter. As the length of time to complete this process increases, the probability of failure also increases when differing formations are encountered along the length of the crossing. If loose, unstable, or overburden soil is present, it may be difficult to maintain a fully open hole over an extended length of time for the installation of the product pipe. During the reaming operations, the rate of penetration and drilling fluid flow rates should be evaluated to reduce potential problems with inadequate removal of cuttings, hydraulic fracturing and inadvertent returns. Proper rates of penetration should reduce over cutting of the drilled hole during the reaming operation. Over cutting, especially in soil formations, can lead to the creation of voids that may result in ground settlement. After the reaming passes, the HDD contractor typically completes a swab pass. The swab pass generally consists of a barrel reamer or hole opener being pulled through the hole to: • verify the stability of the hole; • help remove any excess cuttings remaining in the hole; • reinforce the drilling fluid wall cake; • provide fresh drilling fluid immediately prior to pullback; and • help confirm that the hole is in a condition to receive the product pipe. The pullback process typically begins after completing one or more acceptable swab passes. 12/2/2013 Page 4 1.3 Pullback Process The last step to completing a successful installation is the pullback of the prefabricated product pipe into the enlarged hole. The pullback process is the most critical step of the HDD process. A reinforced pullhead is welded to the leading end of the product pipe. A swivel connection is made between the reinforced pullhead and the drill pipe string. Typically, a reamer is placed between the drill pipe string and the swivel to allow additional fluid to be pumped into the hole during pullback. The swivel allows the transfer of the pull load to the product pipe while reducing the transfer of rotation and torsion stresses to the product pipe. Table 5 of the Brierley design calculations indicate a maximum safe pull stress based on a factor of safety of 2.0 is 17,252 pounds. Based on calculations, the anticipated pull force when the pipe is empty 6,280 pounds and for a fully ballasted pipe 9,022 pounds. Anticipated pull forces for both ballasted and unballasted pipe during installation is well within the allowable safe pull force. Thus, the decision to ballast or not ballast the HDPE carrier pipe during the short term pull back installation should remain the decision of the Driller in conformance with the industry practice. Short term is 12 hours starting at the time that the HDPE pipe pull starts. Table 6 of the Brierley design calculations indicate that an air-filled carrier pipe may be subject to unconstrained buckling after short term loading during installation in a drill fluid filled bore hole. Thus, the pipe should be filled with water to stabilize the carrier pipe immediately following the pullback installation. The Drilling contractor may elect to fill the section of the carrier pipe with water during the pullback installation. Do not ballast the carrier pipe in sections above the ground surface. The carrier pipe ballast elevation may be dewatered to the tie in elevation for the duration of the tie in construction, up to 3 weeks. During operational conditions, the pipe should not be dewatered below the tie in elevations for more than short term (12 hour) time intervals and a qualified Professional Engineer should assess the stability of the carrier pipe before any future dewatering operations. During pullback, the pull section is typically supported with a combination of roller stands and/or product pipe handling equipment (cranes, side booms and/or excavators) to direct the product pipe into the hole at the correct angle, to help prevent excessive bending of the product pipe, to reduce tension during pullback and to help protect the product pipe from being damaged. After the product pipe is pulled into place, the installed pipe is hydrostatically tested and pigged, and tie-in welds on each side of the crossing are completed. 12/2/2013 Page 5 2.0 Failure Modes 2.1 Pilot Hole The failure mode that may occur during the pilot hole is the hole collapsing on the drill pipe string. This is typically caused by either not being able to maintain a good bentonite wall cake to keep the hole stable or unfavorable drilling strata that contains non-cohesive alluvial material or cobbles. If the hole collapses on the drill pipe and creates high friction on its surface, the torque required to rotate the drill pipe may increase. The increased friction may either put the drill pipe in a bind in which the drill pipe cannot be moved or if the torque applied to the drill pipe by the drill rig exceeds the strength of the drill pipe, it may cause the drill pipe to either shear or twist into two pieces. The longer the drill length, the more probability there is of this type of failure. 2.2 Hole Opening In soil formations, if the hole-opening passes take a long time, there is one main type of failure. This failure mode consists of the material falling into the hole due to the lack of a good bentonite wall cake and high drilling mud pressures washing out a cavern in the hole. This may make the hole unstable and can keep the drilling mud from returning to the surface. If the drilling mud is no longer able to carry the drilled cuttings out of the hole, there will be an excess of cuttings in the hole. The cuttings may slowly build up in the bottom of the hole, increase the friction on the drill pipe, and start wearing down the drill pipe. Wearing will decrease the wall thickness of the drill pipe and may cause the drill pipe to fail. The increased friction may cause the drill pipe to slow or stop rotation to a point where the drill rig cannot supply enough torque to continue drilling without causing a failure of the drill pipe. The drill pipe may fail by shearing or twisting into two pieces. 2.3 Pullback Failure of the pullback process occurs when the pipe becomes lodged in the hole and is unable to be moved in either direction. If the pipeline encounters an obstruction, the pull of the drilling rig may increase to a level causing the drill pipe to fail. This results in the greatest setback, because the only alternative is to abandon the drilled hole and pipeline, relocate the pipeline alignment and start the drilling process from the beginning. If the pipe becomes lodged in the hole, the contractor may utilize specialized equipment on the exit side to assist in trying to move the pipe. 2.4 Mechanical The last type of failure occurs if the contractor has a major mechanical breakdown. If the drill pipe remains idle for an extended duration, there is a possibility the drill pipe may not continue to rotate or move in either direction. Should this occur during the pilot 12/2/2013 Page 6 hole, the contractor will be required to change the alignment of the crossing to miss the abandoned hole and start the drilling process from the beginning. 3.0 HDD Failure Criteria Williams considers the following failure criteria as sufficient reason to abandon the HDD process. 3.1 Pilot Hole The HDD installation method may be considered a failure after several attempts by the HDD contractor at completing the pilot hole are unsuccessful. Williams may determine to consider the pilot hole a failure after two attempts if the actual subsurface materials are determined not to be conducive to the HDD method of installation. If this happens the HDD contractor shall then demobilize their equipment from site after approval from Williams. 3.2 Hole Opening The HDD installation method may be considered a failure after several attempts at opening the hole to the required diameter have failed, as long as the failure does not include losing parts of the hole opening tool downhole; or, loss of entire hole opening tool downhole. Williams may determine to consider the hole-opening process a failure after two attempts if the actual subsurface materials are determined not to be conducive to the HDD method of installation. The HDD contractor will then be allowed 14 working days to attempt retrieving the missing tool or parts from the hole and continue the hole opening process. If failure occurs, the HDD contractor shall then demobilize their equipment from site after approval from Williams. 3.3 Pullback The HDD installation method may be considered a failure after several attempts at completing the pullback unless the pipe can be removed from the hole. Then additional attempts will be made after the hole has been reopened and reconditioned with any necessary hole opening passes as determined jointly by the HDD contractor and Williams. Williams may determine to consider the pullback process a failure after two attempts if the actual subsurface materials are determined not to be conducive to the HDD method of installation. If failure occurs, the HDD contractor shall then demobilize their equipment from site after approval from Williams. 3.4 Mechanical The HDD installation method may be considered a failure if the HDD contractor has a major breakdown and after either repairing or replacing the broken drilling rig or vital piece of ancillary equipment, the drill pipe, hole opening tool or pipeline cannot be rotated or pulled. If failure occurs, the HDD contractor shall then demobilize their 12/2/2013 Page 7 equipment from site after approval from Williams. 3.5 Abandoning the Hole The contractor will grout the top five vertical feet of the hole on both the entry and exit side of the crossing. The grout will be a cement-type grout. The top 12 inches of the hole will be filled with native materials or in accordance with the permit requirements. More extensive grouting may be required to comply with specific permit or other job conditions. 4.0 HDD Geotechnical Bore Tests As part of the design of the proposed pipeline, Williams initiated a geotechnical study of the sub-surface conditions near the proposed HDD crossings. Geotechnical borings (aka core samples) were taken near the proposed pipeline location. From these borings, the recovered soil was sampled to determine the specific physical and engineering properties. The samples were classified using the "Unified Soil Classification System (ASTM D2487) and the results are included as Exhibit Z-1. SECTION 9 SOIL SEPARATION PLAN (HENNIKER DIRECTIONAL DRILL, LLC WILL NOT BE PROVIDING NOISE ABATEMENT PROCEDURES.) SECTION 10 MAXIMUM ALLOWABLE DRILLING FLUID PRESSURE CALCULATIONS +25,=217$/',5(&7,21$/'5,//'(6,*1 352-(&7 &5266,1* ,668( &RQWHQWV 7DEOH '(6,*16800$5<$668037,216&21',7,216 7DEOH '(6,*1'5,//3$7+&$/&8/$7,21 7DEOH (67,0$7('$118/$535(6685(&859( 7DEOH (67,0$7(')250$7,2135(6685(&859( 7DEOH $17,&,3$7('38//,1*)25&(&2167$17)25&( 7DEOH 3,3(675(66 )LJXUH $3&)3&&859(6$1'$6680('*(2/2*,&6(&7,21 3UHSDUHG)RU +HQQLNHU1+ 3UHSDUHG%\ %ULDQ'RUZDUW3( 3URMHFW1R 3ULQW'DWH 5HYLVLRQ ,'%< %&' %&' %&' %HGIRUG1+ 2 +HQQLNHU'LUHFWLRQDO'ULOOLQJ//& :HDUH5RDG %ULHUOH\$VVRFLDWHV 65LYHU5RDG6XLWH 0DU '(6&5,37,21 ,QLWLDO,VVXH 5HYLVHGVXEPLWWDODGGUHVVFRPPHQWV 5HYLVHGWRDGGUHVV(25&RPPHQWV &RQWUDFWRU6XEPLWWDO 3KDVH&RQWUDFW1R 3URMHFW1R&:65) <DUPRXWK0$ 3DUNHUV5LYHU&URVVLQJ+'' '5+'3(3( Brian C Dorwart Digitally signed by Brian C Dorwart Date: 2026.03.29 23:54:52 -04'00' ,WHP &RPPHQW([FHSWLRQ$VVXPSWLRQ $7KLVVXEPLWWDOLVSURYLGHGIRUFDOFXODWLRQVVSHFLILHGLQ6SHFLILFDWLRQ+RUL]RQWDO'LUHFWLRQDO 'ULOOLQJ 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ROUTE 28 WILL BE CLOSED DURING OPERATIONS AND DETOURED AS SHOWN IN THE ATTACHED TRAFFIC MANAGEMENT PLANS APPROVED BY MA DOT.) C:\Users\DereckPacheco\Dig It Construction Dropbox\Active Jobs\Municipal\Yarmouth wastewater C5\Traffic Management Plans\CAD\Xref\PS3 To Winslow Gray Neighborhood Plan.pngTRAFFIC MANAGEMENT PLANN/AN/AN/AKEFDAP11/07/2025N.T.SDIG-ITCONSTRUCTION, LLCPO BOX 268 SOUTH DENNIS, MA 02660 PHONE:508-432-1635 www.digitconstructionllc.comROUTE 28 LANE CLOSUREWINSLOW GRAY RD. TO PUMP STATION 3ISSUED FOR REVIEWP/FP/FP/FP/FHudsonRdAmosRdW in slo w Gra yRdW YarmouthRd SwanPondPlutoLnWi nsl owGr ayRdForestRdLong PondDrBuckIslandRdNa u s e t Rd LakeRdCircuit RdNCircuitRdWLakeRdWMeadowbrookRdFinchLnTaftRdLowerBrook R d CliffordStRoute 28HowesRdNeptuneLn Mattachee Rd WampanoagRdOcean Ave WillowStWi n s l o wGr a y R d Nant uck e t A ve PineGroveRdHolly Ln RunPondRdA spinet Rd DanburyStRout e28Ol dMai nSt WoodRdIceHouseRdRiverStDavisRdLymanLnCarrieLnSouthYarmouthElemSCHJohnSimpkinsSchoolSouthStRiver St WillowStSunsetDr>>>>>> > > >>>>>>> >>>>>>>> > > > > > > > >>>>>>>>>>>>>>>>>>>>>>>>>>>>>> > >>>>> > > > > > > >>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>> > > > > > > >>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>DETOURDETOURDETOURDETOURDETOURNORTHDETOUR28DETOURENDDETOURENDDETOURAHEADNORTHDETOUR28NORTHDETOUR28NORTHDETOUR28NORTHDETOUR28NORTHDETOUR28NORTHDETOUR28NORTHDETOUR28NORTHDETOUR28NORTHDETOUR28NORTHDETOUR28DETOURDETOUR>>>>NORTHDETOUR28DETOURDETOURAHEADNORTHDETOUR28DETOURAHEADDETOURDETOURNORTHDETOUR28NORTHDETOUR28NORTHDETOUR28DETOURAHEADDETOURLEGEND:FIGURE 1 - NEIGHBORHOOD TRAFFIC DETOUR SOUTH OF ROUTE 28(NOT TO SCALE)COURTLAND WAYAPPLEBY ROADHUDSON ROADELTON ROADIROQUOIS ROADSOUTH SEA AVENUE>>>>>>>>>TRAFFIC MANAGEMENT PLAN SSSSSSSXXXXXXXXXXXXXXXXXXXXXXXXSSSN/ASKC-1N/AKEFDAP11/07/2025AS NOTEDDIG-ITCONSTRUCTION, LLCPO BOX 268 SOUTH DENNIS, MA 02660 PHONE:508-432-1635 www.digitconstructionllc.comYARMOUTH SEWERPHASE 1 - CONTRACT 5REV1: PER MA DOT COMMENTS (12-16-2025)SKETCH SHOWING TEMPORARYACCESS ROAD DURING ROUTE 28 CLOSUREW3-3STOPHERE ONREDR10-6LONE LANEROADAHEADW20-4(36" x 36")(36" x 36")(24" x 30")R2-10aWORK ZONESPEEDINGFINESDOUBLED(24" x 18")END ROADWORKDOUBLEFINES ENDR2-10e(24" x 30")STOPHERE ONREDR10-6L(24" x 30")OVERVIEW SIGNAGE PLAN(SCALE: 1" = 200')TEMPORARY ROAD EXHIBIT PLAN(SCALE: 1" = 30')S1-3S1-1S1-2S5-1S5-2SIPHON OUTLETSTRUCTUREFUTURE PUMPSTATION BLDGROUTE 28ROUTE 28W1-6LROUTE 28ROUTE 28S1-4S6-1COURTLAND WAYFLUSHSIDEWALK CLOSEDCROSS HERESIDEWALK CLOSEDCROSS HEREEXHIBIT PLAN SIGNAGE KEY(NO SCALE)EXISTING SIDEWALKEXISTING SIDEWALKEXISTING SIDEWALKPORTABLE CUSTOM MESSAGE BOARDS(NO SCALE)STOPHERE ONREDR10-6L(24" x 30")(24" x 48")W11-2W16-7pRW11-2W16-7pLR9-11aRR9-11aLSIPHON INLETSTRUCTURES8-4S5-3S5-4(BUFFER)W3-3(36" x 36")ONE LANEROADAHEADW20-4(36" x 36")GENERAL CONSTRUCTION NOTES:1)TRAFFIC MANAGEMENT SHOWN HEREIN SHALL BE IN ACCORDANCE WITHMA DOT DETAIL "ALTERNATING ONE-WAY (TEMPORARY SIGNAL)"PROVIDED ON DRAWING 852.4.3.2)EXISTING DOUBLE YELLOW LINES AND WHITE FOG LINES SHALL BEREMOVED BETWEEN TEMPORARY STOP LINES AND THE SECTION OFONE-LANE ROADWAY.3)MAXIMUM SPACING FOR REFLECTORIZED DRUMS SHALL BE EQUAL INFEET TO THE SPEED LIMIT IN MPH (40MPH = 40 FEET MAX SPACING).4)APPROVED DETOUR SHALL BE IN EFFECT DURING DESIGNATED WORKINGHOURS ONLY. ROUTE 28 WILL REMAIN OPEN TO THE PUBLIC ANDEMERGENCY TRAFFIC OUTSIDE OF NORMAL WORK HOURS.REV 12/17/2025R2-10aWORK ZONESPEEDINGFINESDOUBLED(24" x 18")END ROADWORKDOUBLEFINES ENDR2-10e(24" x 30")