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Oklahoma Corporation Commission Oil & Gas Conservation Division RBDMS Field Inspection Module
Bob G. Griffith Sr. B.S. Information Systems Services Coordinator
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OKLAHOMA
Regulated by Oklahoma Corporation Commission Approximately 500,000 wells drilled More than 25 years ago, the Commission established ability
to request/require reports and records on hydraulic fracturing/chemical treatment on any well
Cross references to rules regarding hydraulic fracturing (2010)
24 hours advance notice of hydraulic fracturing required to the Conservation Division District Office or field inspector (2011) Modified to 48 hours (March 12)
Horizontal wells hydraulically fractured on or after January 1, 2013 and other wells hydraulically fractured on or after January, 2014 required to be filed with FracFocus Registry (2012)
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OKLAHOMA OIL AND GAS INDUSTRY
Active wells (2012): 65,500 Natural gas 117,000 Oil 10,800 Injection/disposal 193,300 Total active wells
~350,000 plugged and abandoned wells ~500,000 wells drilled in Oklahoma history ~3,050 active operators of oil and gas wells
(04/2013) ~41,000 miles of gathering/transmission pipelines ~58 Field Inspectors to cover 76 counties
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Statewide OCC Well Completions All OCC/IHS Wells 01/01/11-05/31/13
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Oklahoma Corporation Commission Horizontal Wells 01/01/10-05/31/13
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All Active Injection Wells Permitted at Greater Than 30,000 Bls/day
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DISPOSAL WELL APPLICATIONS (2012)
Non-Commercial 1015 Applications: 390 Permits or orders issued: 305
Commercial 1015 Applications: 90 Permits or orders issued: 56 Injection Enhanced Recovery 1015 Applications: 312 Permits or orders issued: 228
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10,789 10,371
10,107 9,581
9,155 8,631
8,120 7,600
0
2000
4000
6000
8000
10000
12000
2013 2012 2011 2010 2009 2008 2007 2006
Non-Commercial Disposal Wells
11 OEIAF 06/13/13
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Water Usage in Perspective
* Agricultural Issues & Recommendations, OWRB, June 2011, p. 6 ** www.okc.gov/utilities *** http://www.okgazette.com/oklahoma/article-13296-water-hogs.html
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MARCH 12 RULES (Brief Summary) Chapter 10 – Oil and Gas Conservation Flow back water pits > 50,000 Bbls and new Form 1014F OAC 165:10-7-16 et seq. (Also allows temporary use by
another operator) Disposal wells and Form 1015 OAC 165:10-5-5 Notice Non-commercial – <5,000 Bbls/day to each operator of
producing unit or well within ½ mile radius; >5,000 Bbls 1 mile radius
Commercial – to each operator of a producing unit or well within 1 mile radius and to each surface owner or surface lessee adjacent and contiguous to the site. Additional surety requirements based upon proposed or existing facilities.
Land application (soil farming) OAC 165:10-7-10, et seq. $50,000 surety
13 OEIAF 06/13/13
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14 14
0
10,000,000
20,000,000
30,000,000
40,000,000
50,000,000
60,000,000
70,000,000
D I D II D III
D IV
D I D II D III
D IV
D I D II D III
D IV
D I D II D III
D IV
D I D II D III
D IV
D I D II D III
D IV
D I D II D III
D IV
D I D II D III
D IV
D I D II D III
D IV
D I D II D III
D IV
2nd Quarter 3rd Quarter 4th Quarter 1st Quarter 2nd Quarter 3rd Quarter 4th Quarter 1st Quarter 2nd Quarter 3rd Quarter
FY2011 FY2012 FY2013
Barr
els
Water Volumes Injected in Commercial Disposal Wells
Out of State
In State
Arkansas
Texas
Kansas
Out of State Water 3rd Qtr. FY2013
Arkansas
Texas
Kansas
New Mexico
Colorado
Barrels of Water
Total Volume: 1,133,072 bbls
OEIAF 06/13/13
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OCC OIL AND GAS REGULATION
Prevent waste and safeguard mineral rights Protect the environment Ensure public safety (H2S)
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UIC Disposal Well Inspection
Tracking Out of State Water
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Monthly Injection Volumes
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MIT screen
Thing s that are captured For a MIT.
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H2S Inspection Screen
Add comments here.
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Well Site Inspection
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UIC WELL PLUGGED
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REGULATORY ELEMENTS
Rules Registrations, permits, and
approvals Complaint procedures Inspections and investigations Enforcement
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2005 2006 2007 2008 2009Shale 2,066,935 11,890,546 70,350,638 190,063,391 304,555,882Coal 71,824,429 77,722,800 80,276,359 82,702,855 75,618,991Conventional 1,360,091,094 1,378,001,936 1,365,492,077 1,379,493,804 1,280,318,777
Total 1,433,982,458 1,467,615,282 1,516,119,074 1,652,260,050 1,660,493,650
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FOCUS OF RECENT RULEMAKING
Guide to hydraulic fracturing rules Drilling and completion of horizontal wells Storage and recycling of flow-back water
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GUIDE TO HYDRAULIC FRACTURING RULES
165:10-3-10 (a) Longstanding prohibition on pollution by
fracturing or acidizing operations (b) New rule reference guide on hydraulic fracturing
Used STRONGER guidelines in development of (b)
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CASING AND CEMENTING
Surface casing BTW maps Depth specified on ITD Notice to field inspector Completion report BTW = base of treatable water ITD = intent to drill
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WATER AND WASTE MANAGEMENT
Multi-stage hydraulic fracturing of horizontal wells
Increasing demand on water resources New rules to facilitate recycling of flow-back
water
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PITS FOR STORING FLOW-BACK WATER Pits in Oklahoma fall into three categories with
different permitting procedures: On-site pits (Form 1000) Off-site pits (Form 1014) Commercial pits (Commission order)
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ON-SITE PITS
Reserve pits are authorized on the permit to drill (Form 1000)
Small frac jobs can be handled by designing reserve pits to handle flow-back water
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OFF-SITE PITS
Off-site pits used to store water for hydraulic fracturing are permitted on Form 1014
Pits are typically used for more than one well
Size of pits have grown in recent years to over 100,000 bbl
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NEW RULE (165:10-7-16(F))
Flow-back water pits in excess of 50,000 bbl Rule covers the permitting, construction,
operation, and closure requirements for any pit used for temporary storage of flow-back water that is to be reused for hydraulic fracturing of wells
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CONSTRUCTION REQUIREMENTS
Earthwork compacted to achieve 90% standard proctor density
Slope of berm may not be steeper than 3:1 on the inside and 2.5:1 on the outside
Liner must have minimum thickness of 30 mil UV protection for intended life of pit Maximum fluid level 3 ft below top of berm Width of crown must be minimum of 8 ft
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CONSTRUCTION REQUIREMENTS (CONT.) Additional requirements for Hydrologically
Sensitive Areas (HSA) Minimum 60 mil liner, OR 30 mil liner with a
leachate collection system Monitor wells required
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OPERATION AND MAINTENANCE
Vegetative cover must be established on all areas of earth fill on outside slopes
Pit must be enclosed by a fence Site must be secured by a locked gate
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CLOSURE
Topsoil must be stockpiled for cover Bond or other financial security to cover closure
cost
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Incident Data Entry
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Incident Resides with the Well Record
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OCC RBDMS Data Mining Website
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Operator Well Inventory
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Well Gas Production
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Demo’s of RBDMS Oklahoma upon request