1. Flow Line Regulations 18 AAC 75.047
Alaska Department of Environmental Conservation
Spill Prevention and Response Division
Industry Preparedness Program

2. What is a flow line? 18 AAC 75.990(173) "flow line"
(A) means piping and associated fittings, including all valves, elbows, joints, flanges, pumps, and flexible connectors,
(i) containing liquid oil;
(ii) located at a production facility; and
(iii) that is installed or used for the purpose of transporting oil between a well pad or marine structure used for oil production and the interconnection point with a transmission pipeline; and
(B) includes all piping between interconnections, including multi-phase lines and process piping, except
(i) facility oil piping; and
(ii) transmission pipelines;
In plain English, a flow line carries multi-phase (oil/water/gas) to or from a well head manifold or a processing center.

3. Crude Oil Transmission Pipeline Protective coating & CP
What isn’t a flow line?
Crude Oil Transmission Pipeline
Flow Line
Facility Oil Piping
Typical size (diameter)
6 – 48 inches
4 – 30 inches
<8 inches
Pipe Contents
Crude Oil
Multi-phase Oil
Oil
ADEC Regulation
18 AAC
18 AAC
18 AAC
Leak Detection
Yes (1% daily volume) No
Design Standard
Yes ASME B31.4, B31.8
Yes ASME B31.3, B31.4, B31.8
Cathodic Protection Standard
Yes
Yes NACE RP0169, API 570
Corrosion Control Standard
ASMEB31.4, NACE RP0169
Protective coating & CP
Inspection Standard
API 570
Maintenance Standard
ASME B31.4, API 570
These are state regulations, additional federal regulations apply to COTPs

5. How are flow lines regulated?
Design & construction standards
Corrosion monitoring & control
Preventative maintenance
Line markers
Removal from service requirements
Line supports
Compliance documentation & recordkeeping

6. Design & construction standards
ASME B31 series industry standards for design and construction of pipe:
ASME B31.4, Pipeline Transportation Systems for Liquid Hydrocarbons and Other Liquids
ASME B31.8, Gas Transmission and Distribution Piping Systems
Other “equivalent and nationally recognized standard”
Design & construction standards become effective 31 December 2008 (2 year phase-in)
It is assumed that most operators will follow B31.4.
B31.8 is a more stringent standard which may be useful to operators who have plans for conversion to gas production or who want a higher standard.
3rd option is a back door to allow for future changes.

7. Corrosion monitoring & control
Industry standards
ASME B31.4, Chapter VIII
NACE RP for external corrosion control on submerged or buried lines
External corrosion control
Protective coatings on aboveground lines or corrosion-resistant material
Internal corrosion control program
Pigging, inhibitors, biocides, coatings, linings, etc.
Corrosion monitoring & control requirements become effective 31 December 2007 (1 year phase-in)

8. Preventative maintenance
Choice – either:
Use a bundled pipe with an interstitial leak detection system, or
Have a preventative maintenance system in place
Preventative maintenance system
Consistent with ASME or API standards
Effective 31 December 2007 (1 year phase-in)
The first option is for bundled lines, where a comprehensive preventative maintenance system is problematic, but where an effective leak detection system and secondary containment is viable.

9. Preventative maintenance program standards
Submerged lines
ASME B31.4, Chapters VII through IX
Buried lines
ASME B31.4, Chapters VII & VIII
Aboveground lines
API 570 (except Section 8) and
All preventative maintenance programs must have procedures for management of change

10. Line markers, removal from service, and pipe supports
One mile intervals and at each road crossing
Effective 31 December 2007 (1 year phase-in)
Removal from service
Pig, drain, or blow pipe to remove oil
Effective 31 December 2006 (now)
Pipe supports
ASME B31.4, Paragraph 421

11. Documentation / Recordkeeping
Documentation of measures taken to comply with 18 AAC
Corrosion control
Preventative maintenance
Maintain records for minimum of five years
Records must be available to ADEC upon request

12. Other changes to 18 AAC 75, Article 1 that affect North Slope operations
Increased prevention training and documentation requirements
Revised regulations for aboveground oil storage tanks
field-constructed oil storage tanks
shop-fabricated oil storage tanks
Revised regulations for facility piping

13. Prevention training Moved into its own section and expanded
Personnel that inspect, maintain, operate oil storage and transfer equipment must be trained regarding company and state spill prevention measures
Job descriptions and training level needed
Keep training records for 5 years

14. Aboveground storage tanks
Two types defined
Field-constructed storage tank
Constructed to API 650, API 12B, 12C, 12D, 12E, 12F, or 12P
Inspected to API 653 or API 12R1
Shop-fabricated storage tank
Constructed to UL 142 or similar standard
Inspected to API 653 or STI SP001

15. Facility oil piping
New definition: Piping and associated fittings originating from or terminating at a regulated oil storage tank or an exploration or production well
Three classes of facility oil piping, based on installation date:
Before May 14, 1992 – no construction standard applies
May 14, 1992 thru 2008 – protective coating and cathodic protection, all welded
2009 or later – ASME B31.3, B31.4, or B31.8, or equivalent standard; cathodic protection per NACE standard
Inspection consistent with API 570 inspection standard by 2008

16. Effective Dates
Regulations covering design and construction – go into effect in 2009
Regulations covering operations and maintenance – go into effect in 2008
Remaining regulations - December 30, 2006

17. Questions? Craig Wilson Industry Preparedness Program
Spill Prevention and Response Division
Alaska Department of Environmental Conservation