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John W. Morrison Wade C. Mann
1995 – 5000 horizontal wells in U.S. ◦ “As much as ten billion barrels” of domestic
incremental recovery predicted 2011 EIA Report ◦ 24 billion barrels of oil and 750 TCF of gas
2012 – ◦ Industry estimates 24 billion barrels will be
recovered from the Bakken alone ◦ Baker Hughes North America Rig Count – July 6,
2012 1077 horizontal out of 1877 total rigs - 57%
Typical JOA ◦ Contract area ◦ Designation of operator ◦ Allocation of expenses and production ◦ Conduct of initial operation and subsequent
operations ◦ Collection of payments due operator ◦ Limitations on abandonment of wells and
conveyances of interests
Alternative to JOA? ◦ Compulsory pooling statutes “opportunity to recover or receive, without unnecessary
expense, his just and equitable share” Participate Surrender working interest for bonus Carried subject to penalty Carried at no penalty – “free ride”
AOGC Form ◦ Typical pooling order options are to participate
subject to administratively prescribed form of operating agreement or be carried subject to 400% penalty Exhibit “B” deemed lease Exhibit “E” gas balancing agreement Exhibit “H” gas marketing agreement
Pooling statutes provide for “payment of the costs of development and operation”
If disputed, agency “shall determine the proper costs”
Regulatory orders are judicial or quasi-judicial ◦ Res judicata – finality attaches ◦ Modification generally requires change of
conditions ◦ Express reservation of continuing jurisdiction to
resolve cost disputes ◦ Implied authority to modify pooling orders to
accommodate subsequent events Benion v. ANR Production Company – Utah, 1991
Agencies are not courts ◦ No jurisdiction to settle private disputes Contract interpretation Title disputes
Resolving disputes over pooling orders can involve private issues ◦ Constantin v. Martin – 10th Circuit, Oklahoma, 1954 Whether ORR is entitled to share of gas in kind ◦ Morgan v. Oklahoma Corporation Commission –
Oklahoma, 2011 No jurisdiction to determined whether surface use was
reasonable
Come Big or Stay Home, LLC v. EOG Resources, Inc. – North Dakota, 2012 ◦ Operator conditioned well information on JOA or
separate non-disclosure agreement ◦ Agency had declined to exercise jurisdiction ◦ Separate action brought in state district court Not an appeal from agency orders
North Dakota Supreme Court affirmed summary judgment ◦ No implied agreement ◦ No joint venture or cotenancy ◦ No “non-contractual” right to receive information
and therefore no conversion Did not expressly address agency’s
jurisdiction
“in the event of any dispute as to the costs of dri l l ing and operating the well , the commission shall determine the proper costs”
K i r k ma n v . Ok l a ho ma Co rp o r a t i o n Commission – Oklahoma, 1983 ◦ Two part analysis Was expenditure required? Was the cost reasonable?
New Dominion LLC v. Mason – Oklahoma, 2009 ◦ Limited to “actual expenditure” of operator ◦ Operator can’t charge fee equal to that charged to
third parties for salt water disposal
AFE issues ◦ AFE’s under JOA are “at best a good faith estimate” Signing AFE commits party to proportionate share of
actual costs M&T Incorporated v. Fuel Resources Development
Company – U.S. District Court, Colorado, 1981 ◦ Cost estimates included in a pooling order are “a
projection of reasonable expenses” and do not constitute a “Commission-fixed limit of liability” Crest Resources & Exploration Corporation v.
Corporation Commission – Oklahoma, 1980
JOA ◦ Operator has “right … but not the obligation” to
purchase or market non-operators’ oil and gas ◦ Non-operators have the right to take in kind ◦ Gas Balancing Agreement – Exhibit “E” In kind Cash
No JOA ◦ Pooling statutes generally don’t require operator to
market ◦ Notable exceptions Arkansas AOGC –
Gas Balancing Agreement and Gas Marketing Agreement Oklahoma Natural Gas Market Sharing Act
Owners not subject to gas balancing agreement have right to share in sale of production by operator or other owner
McCall v. Chesapeake Energy - Oklahoma, 2007 Not applicable if JOA exists Approved pass through of 3% marketing charge paid to
affiliate
Production imbalances ◦ Hunt Oil Co. v. Batchelor –Louisiana, 1994 Commission order requiring balancing in kind affirmed ◦ Weiser-Brown Oil Co. v. Samson Resources – 8th
Circuit, applying Arkansas law, 1992 No contractual right to in-kind, limited to accounting
as a co-tenant ◦ Beren v. Harper Oil Company - Oklahoma, 1975 Cash balancing approved “under the particular facts of
this case
Production imbalance ◦ Harrell v. Samson Resources – Oklahoma, 1978 Cash balancing ◦ Doheny v. Wexpro – 10th Circuit, Wyoming, 1992 In-kind balancing
JOA ◦ Operator removed “for cause” 1977 and 1982 – “fails or refuses to carry out duties” 1989 – “gross negligence or willful misconduct” and
“material breach or inability to meet … standards … or perform its obligations”
◦ Successor chosen by two or more parties with majority
No JOA ◦ Hold Oil v. Corporation Commission - Oklahoma,
1987 Agency has continuing jurisdiction to remove operator ◦ Crest Resources v. Corporation Commission -
Oklahoma , 1980 Operator can’t delegate status without sanction by
agency ◦ North Dakota regulations Rebuttable presumption that party who, together with
its supporters, owns a majority of interest is entitled to permit and operatorship
JOA – ◦ Parties have obligation to act “in good faith” No independent cause of action
No JOA ◦ Joint venture – Fiduciary duties and joint and several liability
◦ Oklahoma – Hebble v. Shell Western E & P, Inc. - 2010
Operator of a spacing unit or field wide unit has fiduciary duty to other owners
2012 House Bill No. 2654 – “reasonably prudent operator” but no “fiduciary duty,
quasi-fiduciary duty, or other similar special relationship”
Subsurface Trespass and Hydraulic Fracturing Subsurface Trespass and Drilling from Off-
Unit Locations
Coastal Oil & Gas Corp. v. Garza Energy Trust, 268 S.W.2d 1, 6 (Tex. 2008) ◦ No actual injury proven Damages from drainage by hydraulic fracturing are
precluded by the rule of capture.
Majority rationale ◦ Owner claiming drainage from fractures afforded
recourse and had other remedies available ◦ Allowing claim would infringe on Railroad
Commission’s duty of regulating production ◦ Unwise for courts to alter the rule of capture on
which industry and its regulation have relied for decades ◦ Reluctance to regulate by common law a process in
place for over 60 years which neither the Legislature or Commission had seen fit to regulate
Continental Resources, Inc. v. Farrar Oil Company, 559 N.W.2d 841 (N.D.1997) ◦ Addressed rule of capture and the modification of
traditional property law principles by State’s oil and gas conservation act ◦ Property rights not absolute Subject to the police power of the State to impose
restrictions on private rights that are necessary for the general welfare of all
◦ Property law of trespass may be superseded
Egeland v. Continental Resources, Inc., 616 N.W.2d 861 (N.D. 2000) ◦ Court reluctant to insert itself into a regulated area
in a manner that could hinder development ◦ Court explained that penalizing the use of force
pooling “would inhibit use of a statutory procedure designed to implement the strong public policy of fostering the efficient development and use of the state’s oil and gas resources.” ◦ Consistent with analysis in Egeland and Farrar,
North Dakota likely to follow approach of majority in Garza
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Who must grant easement, lease or other right to use? ◦ Surface Owner? ◦ Mineral Estate Owner?
Ownership of mineral estate does not equate with ownership of subsurface stratum ◦ Own the opportunity to recover and produce the oil
and gas ◦ Don’t actually own the land beneath the surface
Pore Space Statutes ◦ Reflect limited nature of mineral estate owner’s
control over subsurface stratum Consider impact use of adjoining surface may
have on ability of mineral owner in tract to develop ◦ Mineral estate dominant ◦ Accommodation doctrine