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3.2.2. Sump Liners Where liners are used in earthen sumps or pits: (a} the liner shall be at least 20 mil (0.508 mm) thick virgin polyvinyl chloride or equivalent; (b) the bottom and the sides of the pit shall be free of objects that could penetrate the liner; (c) ample liner material shall be used to allow for sags and material loading to reduce stress on the liner; (d) the bottom of the lined pit shall be weighted with earthen material or water before anchoring the ends of the liner on the surface or placing drilling mud in the pit; and (e) where liners become torn, punctured or perforated the operator shall repair the liner in accordance with manufacturer's recommended procedures or replace the liner. 3.3. Pit Closure The operator shall close earthen sumps within six months of the TD date of the well and where lined pits are used, within twelve months of the TD date. 3.4. Drilling Program Design The operator shall ensure that the drilling program design: (a) protects the public, worker, environment, and the equipment; (b) permanently isolates and protects all potable water formations from contamination; (c) isolates potential hydrocarbon-bearing formations from contamination caused by the migration of fluids from other permeable formations; (d) prevents the migration of fluids between permeable formations and uncontrolled flow of fluids to surface or subsurface; and (e) prevents shale and unconsolidated material from falling into the open hole during the drilling process. 3.5. Design of Casing Program Casing design, for each stage of drilling operations, shall consider the following: (a) the type of well service (e.g. sour, sweet, corrosive); (b) the intended purpose of the well; (c) the anticipated life span of the well; (d) the location and flow characteristics of potential fresh water zones; (e) the burst and collapse pressures that may be experienced during cementing operations on the casing siring; (f) the potential formation pressures that may be encountered during drilling operations and during subsequent production or injection operations; (g) the tensile loading placed on the casing body and casing joints during running and cementing operations, especially if pipe is to be reciprocated; (h) the pressure exerted on the inside of the casing during pressure integrity tests and formation stimulation operations; (i) the need for corrosion allowance where corrosive formation brines may be produced or may be in contact with the exterior of the casing; (j) the internal drift diameter of the casing relative to the outside diameter of the drill bit to be used in subsequent drilling operations; (k) the reduction in casing joint strength due to bending forces in deviated wells; 9